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Home My WebLink About204-196STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UN ORIN L-202 JBR 12/11/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Tested everything with 4" & 4.5" test Joints. N2 backup 20@ 1000 psi Solid test. Test Results TEST DATA Rig Rep:Mike LarsonOperator:Hilcorp North Slope, LLC Operator Rep:Clint Montague Rig Owner/Rig No.:Hilcorp Innovation PTD#:2041960 DATE:10/22/2025 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopJDH251024115435 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 940 Sundry No: 325-640 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8" 5K P #1 Rams 1 2 7/8" x 5 1/2 P #2 Rams 1 Blinds 5K P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5K P HCR Valves 2 3 1/8" 5K P Kill Line Valves 2 3 1/8" 5K P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1600 200 PSI Attained P23 Full Pressure Attained P83 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2400 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P9 #1 Rams P9 #2 Rams P9 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1       Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. T41226PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: 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 L-202 RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-196 50-029-23229-00-00 ADL 0028238 12628 Conductor Surface Intermediate Production Liner 4732 80 3244 7639 5498 6710 20" 10-3/4" 7-5/8" 4-1/2" 4353 30 - 110 29 - 3273 26 - 7665 7127 - 12625 940 30 - 110 29 - 2635 26 - 4589 4504 - 4732 Unknown, 10350 2480 4790 7500 6710 5210 6890 8430 6781 - 12583 4-1/2" 12.6# L80 24 - 67584380 - 4730 Structural 4-1/2" Baker Premier Packer No SSSV Installed 6643, 4325 Date: Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY 10/10/2025 Current Pools: Schrader Bluff Oil Pool, Orion Dev Area Proposed Pools: Schrader Bluff Oil Pool, Orion Dev Area 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 8:54 am, Oct 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.25 18:27:05 - 08'00' Torin Roschinger (4662) 325-640 J.Lau 10/20/25 X TS 10/20/25 10-404 AOGCC witnessed BOP and annular test to 3000 psi. Passing MIT-T and MITIA to 3000 psi before pulling B&R. Preserve wellhead indefinitely for further analysis. Notify AOGCC of any new discoveries pertaining to the parted casing spool Fully cement 7-5/8 x 10-3/4 annulus from casing cut to surface. Send CBL to AOGCC. 10/21/25 RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 Well Name:L-202 Permit to Drill:204-196 Current Status:Not Operable, SI API Number:50-029-23229-00 Estimated Start Date:October 10, 2025 Estimated Duration:14 days Rig:I-Rig Sundry Number: Regulatory Contact:Abbie Barker First Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Second Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M) Program Revision:0 Current Bottom Hole Pressure:1,380 psi @ 4,400 TVDss 6.03 ppge | SBHPS 12/18/2021 Max Anticipated Surface Pressure:940 psi Based on 0.1 psi/ft gas gradient Last SI WHP:300 psi 3/4/2025 Min ID:2.59 @ 6,942 MD 4-1/2 Isolation Sleeve Max Angle:93 deg @ 8,326 MD Brief Well Summary: L-202 was drilled and completed in 2005 as a Schrader Bluff, multi-lateral (OA, OBa, OBb, OBd), gas lifted producer. During a routine hot oil treatment to clear hydrate buildup from the tubing on 3/2/25, the outer annulus casing spool parted from the casing hanger. L-202 was successfully shut-in at the tree later that afternoon and subsequently secured with a tubing tail plug (TTP) on 3/4/25. A passing CMIT-TxIA against the TTP was performed on 3/4/25 to 1,380 psi. Due to the parted casing spool, the OA remained open to atmosphere. The OA was continuously filled with 9.8 ppg brine until a temporary packoff could be manufactured and installed on 3/22/25. The temporary packoff fastens the 10-3/4 casing hanger to the exposed 7-5/8 casing. The 7-5/8 x 10-3/4 annulus has been filled periodically with 9.8 ppg brine to minimize pressure on the temporary packoff. Through detailed investigation it was confirmed that the Gen 5 FMC wellhead installed in 2005 was compromised during manufacturing due to its base flange thickness being milled down. Prior to the wellhead separation event, L-202 was flowing at ~1000 IOR. Hilcorp will pursue a RWO to decomplete the well to remove the defunct wellhead and recomplete the well to install fit for purpose wellhead equipment. Objective: Pull 4-1/2 tubing from well. Cut and pull 7-5/8 production casing. Preserve wellhead for further analysis. Install new wellhead. Run new 7-5/8 production casing with ECP and cementing sleeve. Overshot stub and cement 7- 5/8 x 10-3/4 annulus to surface. Run new 4-1/2 gas lifted completion. Current Status: Not Operable PAL, shut-in 2/21/2025 Test: 1008 IOR, 1221 bopd, 2720 bwpd, 69% WC, 6.5mm Fgas, 1.8mm Lgas, 432 psi WHP, 59 deg F WHT, FOC Recent Integrity: 03/04/25: Load IA Set TTP @ 6710' MIT-T & CMIT-TxIA Passed to 1380 psi 03/02/25: Surface casing / surface casing spool failure, 4' tree growth RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 Pre-RWO Work: Slickline & Fullbore 1. Pull PX plug from X-nipple at 6,710 MD. 2. Perform SBHPS per the following: a. Bleed lubricator prior to opening swab b. Lubricator 10 minutes c. 6,775 MD (4,300 TVDSS) 15 minutes d. 6,543 MD (4,200' TVDSS) 15 minutes e. 6,358 MD (4,100 TVDSS) 15 minutes f. 6,164 MD (4,000' TVDSS) 15 minutes g. Send data to Tyson Shriver (tyson.shriver@hilcorp.com) 3. Set PX plug with fill extension in X-nipple at 6,710 MD. a. Load wellbore with crude as necessary. 4. Set junk basket on top of PX plug. 5. Perform MIT-T and CMIT-TxIA to 2,500 psi. E-Line 1. Perform mechanical cut of 4-1/2 tubing at 6,625 MD. (~2 down on pup joint immediately below gauge mandrel. a. Utilize Tubing Summary dated 7/9/2005 for tie-in. Fullbore 1. Circ out well with 9.8 ppg brine (add Barakleen or equivalent to brine to help clean pipe) and diesel FP. a. 4-1/2 Tubing Volume to TBG Cut = 6,625 x 0.0152 bpf = 100.7 bbls b. 4-1/2 x 7-5/8 Annulus Volume to TBG Cut = 6,625 x 0.0262 = 173.6 bbls c.Total TBG and Annulus Volume = 274.3 bbls Valve Shop 1. Set and test 4 CIW Type H TWC. RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 Proposed RWO Procedure: 1. MIRU Hilcorp Innovation rig. 2. Nipple down tree and tubing head adapter. Inspect landing threads. 3. NU 11 x 13-5/8 adapter, 13-5/8 BOPE with three preventers configured top down: Annular, 2-7/8 x 5- 1/2 VBRs, Blinds, flow cross. 4. Test BOPE to 250 psi low / 3,000 psi high, annular to 250 psi low / 3,000 psi high, (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per Hilcorp Innovation BOP test procedure. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8x 5-1/2 VBRs with 4 and 4-1/2 test joint. e. Test the annular with 4 test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 5. RU and pull TWC. Use lubricator if pressure is expected. 6. RU control line spooler. 7. MU landing joint or spear, BOLDS and pull hanger to the floor. Circulate bottoms up with 9.8 ppg brine. a. Expected PU weight in 9.8 ppg brine = 70k lbs (excluding block weight) 8. Pull existing 4-1/2 tubing from cut. a. Drilling & Completion report indicates 85 cross coupling clamps and 2 SS bands were installed to attach the I-wire. Another 12 Blast Rings and 1 Stop Ring were installed immediately below the tubing hanger. Report clamp count in AWGRS. Note that there are 2 centralizers installed, 1 on each of the pups above and below the CMD sliding sleeve. 9. RU E-Line and run CBL log from top of tubing stub to surface to confirm cut depth of 7-5/8 casing. 10. PU and RIH 4 DP w/ RBP. Set RBP at ~3,500 MD. Test to 1,000 psi. 11. Dump ~50 of sand on top of RBP. 12. MU and RIH with mechanical cutter on 4 DP. Cut 7-5/8 casing at ~3,150 MD. Final cut depth will be determined based on results of CBL. a. Prior to performing the deep 7-5/8 cut, remove temporary packoff that is currently installed between the 10-3/4 hanger neck and 7-5/8 production casing. When cut is made, fluid will U- tube between the 7-5/8 casing and the 7-5/8 x 10-3/4 annulus due to hydrostatic imbalance. Fluid returns from the 7-5/8 x 10-3/4 annulus will be taken to the lined cellar and vacd out. 13. Circulate 7-5/8 x 10-3/4 annulus to 9.8 ppg brine through casing cut. Take returns to lined cellar and vac out. 14. Set back BOPs, ND 11 x 13-5/8 adapter. Cut 7-5/8 casing just below the 10-3/4 landing nipple. a. Preserve wellhead and send it to Well Support shop for further analysis. 15. Install new 11, 5M FMC Gen 5 wellhead. Externally test metal to metal seal connection between the 10- 3/4 mandrel hanger and casing head to 3,500 psi. a. If the connection fails, contingent weld the ID of the casing head to the top of the hanger neck. 16. NU 11 x 13-5/8 adapter and BOPs. Test BOP breaks to 3,000-psi. 17. Swap upper Rams to 7-5/8 fixed and test to 3,000-psi on 7-5/8 test joint. 18. Spear 7-5/8 casing and pull. a. Expected PU weight in 9.8 ppg brine = ~82.1k lbs 19. RIH with cleanout assembly down to top of 7-5/8 cut. 20. PU and run new 7-5/8 29.7# L-80 H563 production casing with sealing overshot, ECP and cementing sleeve. 21. Space-out and set 7-5/8 on emergency slips with ~100 kips tension. 22. Set ECP, function cementing sleeve and fully cement 7-5/8 x 10-3/4 annulus with a 150 bbls (1.2x volume of 7-5/8 x 10-3/4 annulus to casing cut) of 15.3 ppg Class G. Displace with 1% KCl. RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 23. ND BOPs and install 7-5/8 packoff. Test 500 psi low / 3,500 psi high. 24. NU BOPs and test breaks to 3,000 psi. Swap upper Rams from 7-5/8 fixed to 2-7/8 x 5-1/2 VBRs and test with both 4 and 4-1/2 test joints. 25. RIH with drill-out assembly on 4 DP and drill out cementing sleeve. 26. Pressure test 7-5/8 casing to 3,000 psi. 27. PU cleanout BHA w/ RCBJs and RIH to top of sand. Cleanout sand down to top of RBP. 28. MU RBP retrieval tool. Pull RBP and LDDP. 29. Run 4-1/2 12.6# L-80 JFE Bear gas lifted tubing string as detailed on proposed schematic. Confirm final tally with OE prior to running. a. Sliding sleeve will be run for potential future use of alternative artificial lift. b. Baker Lok connections below production packer. Torque turn connections. 30. Space out non-sealing overshot and land hanger. Reverse in corrosion inhibited 1% KCl or seawater. 31. Drop ball and rod and pressure up to set packer. 32. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 33. Shear out valve in the top GLM. FP tubing and IA with diesel to 3,000 MD. 34. Set TWC and ND BOPE. 35. NU tree and tubing head adapter. 36. Test both tree and tubing hanger void to 500 psi low / 5,000 psi high. 37. RDMO Hilcorp Innovation rig. Post RWO Work: Valve Shop 1. Pull TWC. Slickline 1. Pull shear-out valve, run deep GLV design. 2. Pull B&R and RHC profile. Attachments Current Wellbore Schematic Proposed Wellbore Schematic 4-1/2 Tubing Tally 7-5/8 Casing Tally BOP Schematic Sundry Change Form RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 Current Wellbore Schematic: RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 Proposed Wellbore Schematic: RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 4-1/2 Tubing Tally: Cut Joint RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 7-5/8 Casing Tally RWO Well: L-202 PTD: 204-196 API: 50-029-23229-00 Hillcorp Innovation Rig BOP Schematic: Hilcorcp Innovation Rig Choke Manifold: RWOWell: L-202PTD: 204-196API: 50-029-23229-00Sundry Revision Change Form:Changes to Approved Sundry ProcedureDate:Subject:Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNSPreparedBy(Initials)HNSApprovedBy(Initials)AOGCC WrittenApprovalReceived (Personand Date)Approval:Operations Manager DatePrepared:Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: L-202 May Investigation Status Update Date:Monday, June 2, 2025 10:07:44 AM Attachments:L-202 (PTD-204196) Monthly Update 06.01.25 with attachment.pdf From: Torin Roschinger <Torin.Roschinger@hilcorp.com> Sent: Saturday, May 31, 2025 10:40 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: L-202 May Investigation Status Update Good morning Jack, Please see the attached monthly L-202 update per your request. You will note that any new updates have been provided in green font for ease of viewing and quick reference to progress this passed month. I am hopeful that we will be able to provide you with a Final Investigation Report before the end of June, however, I will keep you informed if there are any delays to that timing. Thank you, Torin The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Hilcorp North Slope, LLC Torin Roschinger, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 06/01/2025 Jack Lau, Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Hilcorp North Slope, LLC response to 20 AAC 25.205 (b), report regarding the oil and gas release on Prudhoe Bay Unit L-202 (PTD #2041960) Please see Hilcorp’s response per 20 AAC 25.205 (b) to the L-202 (PTD #2041960) uncontrolled release of oil and gas.Per AOGCC’s request, Hilcorp will submit monthly updates until the investigation is complete. (1) Time of Incident. a. The incident occurred at 10:04am March 02, 2025. (2) The location where the incident took place. a. Inside the Prudhoe Bay Unit L-202 wellhouse. (3) The volumes of oil and gas released and recovered. a. The volume of gas released prior to the well being shut-in at 2:29pm, March 02 is estimated to be 302mscf, as reported in the 5-Day report submitted 03/07/2025. b. The volume of gas released after the well was shut-in, but before the machined clamp installation to contain the exposed outer annulus (per Sundry 325-143) was complete at 3:00pm, March 21 is estimated to be 910scf. c. The final amount of oil recovered is 96 bbl. This includes 35 bbl recovered from the well cellar, and 6 bbl recovered from outside the well cellar, from the initial release; and 55 bbl recovered from the well cellar after the well was shut-in, but before the machined clamp was installed to contain the outer annulus. d. Spill cleanup is complete as of 05/15/25. (4) The cause of the release. a. The investigation is ongoing, but the team’s preliminary assessment of the failure mechanism is as follows: i. The identified failure point is the FMC Gen 5 Slim Hole wellhead connection between the casing spool and the surface casing mandrel hanger. ii. Loads contributing to the failure of this connection likely include: 1. Permafrost subsidence imparting a downward load to the 10-3/4” surface casing, which in turn compressed the 7-5/8” production casing and 4-1/2” production tubing. 2. Further loading of the production casing and tubing due to thermal changes during the hot oil treatment in progress at the time of failure. iii. When the wellhead connection failed, it released the stored energy that had accumulated in the production casing and tubing strings which then lifted the wellhead and Xmas tree approximately 3 feet. This resulted in the pumping check valve manifold that was tied into the tree cap shearing off, and the subsequent loss of primary containment. iv. The bottom of the L-202 casing spool (where the casing spool was connected to the surface casing mandrel hanger with 10 lock screws, before that connection failed) is thinner than expected based on wellhead manufacturer’s drawings of Gen 5 Slim Hole wellheads. This likely reduced the load capacity of the connection. Hilcorp is actively working with the wellhead manufacturer to investigate this anomaly. 05/01/25 update: The FMC Gen 5 casing heads with lock screws installed on West End PBU wells before June 2005, and after December 2005, have a belled design and flush lock screws. Two alternate forgings of Gen 5 casing heads have been identified, with original completion dates between June and December 2005: 1. L-202 (07/11/05) and S-122 (08/22/05): the bottom of the casing head is straight or slightly tapered (not belled), and the lock screws stick out (not flush). The casing head thickness below the lock screws is significantly thinner than the belled design. Both wells are secured, as are 3 similar wells identified at MPU: MPE-31 (06/21/05), MPF-93 (07/21/05), MPF-89 (08/21/05). 2. L-218 (09/08/05), L-215 (09/28/05), L-250 (12/03/05), V-212 (12/16/05): the bottom of the casing head is tapered. The lock screws are flush. The casing head thickness below the lock screws is similar to the belled design. Because of the comparable thickness, these casing heads are not thought to be at risk of an L- 202-type failure. All 3 casing head styles (belled with flush lock screws, straight with lock screws sticking out, tapered with flush lock screws) have the same FMC part number and associated drawing. The casing head thickness is noted on the drawing as “as forged.” There is no minimum casing head thickness specified. Per FMC, there are no currently accessible records for the alternate forgings. FMC states the documentation for the alternate forgings would have been paper copies in 2005, and that API Specification 6A, Wellhead and Tree Equipment, only requires quality records be kept for 10 years. 06/01/25 update: The first “alternate forging” described in the 05/01/25 update (L-202, S- 122, MPE-31, MPF-93, and MPF-89) is similar in appearance, thickness, and outer diameter to an older Gen 5 casing head design, which utilized an acme lock ring retention device instead of lock screws. A well-by-well review of PBU West End wells indicates the following Gen 5 Slim Hole (10- 3/4” surface casing) and Ultra Slim Hole (9-5/8” surface casing) installation history: x 1996 – 2002: original Gen 5 casing head design with acme lock ring. x 2003 – 2004: new Gen 5 casing head design with lock screws. Bottom of casing head is belled, and lock screws are flush with the casing head. x 2005: between June and December 2005, the “alternately forged” casing heads were installed, as well as one original Gen 5 casing head with acme lock ring (S- 111, completed 7/8/2005). The acme lock ring design appeared to have been phased out until installed on S-111. x 2006 – 2014: returned to the same design as 2003 – 2004. See attachment, “PBU West End Gen 5 Slim Hole and Ultra Slim Hole Wellheads.” b. Notable events since the 5-Day report submittal: i. 03/06/25: Functioned the SSV fully closed 4 times with 0 psi on the flowline. Times for closure were 2:34, 2:34, 1:58, and 2:08 (the SSV did not fully close during the event; it’s suspected this was due to the platform clamps around the tree dislodging when the sudden upward movement occurred, leaving the platform’s weight on the outermost part of the SSV barrel and putting the SSV in a bind). ii. 03/07/25 – 03/08/25: loaded outer annulus (OA) full of diesel. Pumped a total of 16 bbl diesel into OA between 16:30 on March 07 and 08:00 on March 08. iii. 03/09/25: Loaded OA with 9.8 ppg brine. Pumped a total of 14.5 bbl of brine into OA. While monitoring, brine and diesel mixture released out of the OA into the wellhouse. Spill Response Team (SRT) notified. iv. 03/10/25: floor grating and wellhouse removed. Gas lift line, s-riser, and Xmas tree removed. Dry hole tree installed. Witnessed by AOGCC Inspector. v. 03/11/25: loaded OA with 56.2 bbl of 9.8 ppg brine and established fluid returns at surface. From this point until the clamp was successfully installed, the OA was monitored continuously and kept full of brine. vi. 03/21/25: machined clamp successfully installed per Sundry 325-143. vii. 03/31/25: OA gas sample is 98% methane, indicating the source of OA gas is hydrates in communication with the open shoe. OA shoe is open to a known hydrate zone within the SV1 formation. viii. 04/07/25: Shop-tested the SSV. AOGCC Inspector notified 24 hours in advance, declined witness. Results are summarized as follows: 1. No downward load applied to the actuator – closed fully three times. 2. Downward load applied to the end of the actuator, similar to how the weight of the scaffolding would have applied force after the event – failed to close 3 times. (5) Responsive actions taken to prevent additional releases. a. As reported in the 5-Day report submitted 03/07/25, L-202 was secured on March 04 at 8:33am with a downhole plug set below the packer and passing mechanical integrity test of both the tubing and production casing confirming both tubing and production casing integrity. b. An investigation into the event and failure mechanism is still ongoing with Hilcorp, the wellhead manufacturer and a structural engineering consultant. Modeling is underway to evaluate: i. The failure mechanism –06/01/25: Hilcorp has finalized the wellhead separation model. This is an FEA model that calculates a range of separation loads at the failure point, based on vendor-provided drawings and as-built well conditions. ii. The following load cases: initial casing installation; normal operating conditions; hot oil treatment (HOT) –06/01/25: WellCat and load modeling is ongoing. Expected to be complete approximately 06/20/25. (6) Plans, actions, equipment, or procedural changes to prevent or minimize the risk of future releases. a. As mentioned in Section 4 above, it is suspected that the anomalously thin FMC Gen 5 Slim Hole casing spool specifically installed on L-202 may have contributed to the failure. Hilcorp is actively working with the wellhead manufacturer and an engineering consultant to further investigate this abnormality. b. A fieldwide survey was conducted across Prudhoe searching for similar Gen 5 FMC wellheads with lock screws sticking out (proud), instead of flush with the casing head. During the survey, one additional wellhead was identified (S-122 PTD# 205081) and has since been shut-in and secured with a downhole plug. 06/01/25 update: Hilcorp submitted a response to OTH 25-017 on 05/02/25. No additional wells were identified with set screws protruding more than 0.25”. c. The investigation, including the modeling referenced in Section 5 above, is ongoing. Hilcorp will update this report as soon as the investigation is complete, and final recommendations are issued. If you have any questions, please call me at 406-570-9630 or Oliver Sternicki at 907-564-4891. Sincerely, Torin Roschinger PBW Operations Manager Attachment: PBU West End Gen 5 Slim Hole and Ultra Slim Hole Wellheads Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.05.31 10:34:03 - 08'00' Torin Roschinger (4662) ÍŜĖĲČώFôÍîώ"ôŜĖČĲ ͑͏͏͏ ͑͏͏͐ ͑͏͏͑ ͑͏͏͒ ͑͏͏͓ ͑͏͏͔ ͑͏͏͕ ͑͏͏͖ ͑͏͏͗ ͑͏͏͘ ͑͏͐͏ÍŘťώbĺϟώ͐͒ϱ͕͑͏ϱ͕͕͘ώϼ͐͒ϱ͔ϯ͗ГϽÍŘťώbĺϟώ͐͒ϱ͒͏͏ϱ͖͑͑ώϼ͐͐ГϽèıôώ[ĺèħώĖĲČťŘÍĖČēťώÍŜĖĲČώFôÍîÍŜĖĲČώFôÍîώēĖèħĲôŜŜϡ͏ϟ͖͔Гώϱώ͏ϟ͓͘ГώϼŜÍıŕīôώĺċώ͔ώſôīīŜϽϱ͐͐͐ώϼ͖ϯ͗ϯ͏͔ϽÍŘťώbĺϟώ͕͓͐͗͐͘ώϼ͐͐ГϽ>īŪŜēώ[ĺèħώèŘôſŜôīīôîώÍŜĖĲČώFôÍîÍŜĖĲČώFôÍîώēĖèħĲôŜŜϡ͐ϟ͓͗Гώϱώ͐ϟ͔͗ГώϼŜÍıŕīôώĺċώ͓ώſôīīŜϽīťôŘĲÍťôώ>ĺŘČĖĲČώϭ͐ÍŘťώbĺϟώ͕͓͐͗͐͘ώϼ͐͐ГϽŘĺŪîώ[ĺèħώèŘôſŜťŘÍĖČēťώÍŜĖĲČώFôÍîÍŜĖĲČώFôÍîώēĖèħĲôŜŜϡ͏ϟ͕͔͑Г[ϱ͑͏͑ώϼ͖ϯ͐͐ϯ͏͔Ͻϱ͐͑͑ώϼ͗ϯ͑͐ϯ͏͔ϽīťôŘĲÍťôώ>ĺŘČĖĲČώϭ͑ÍŘťώbĺϟώ͕͓͐͗͐͘ώϼ͐͐ГϽ>īŪŜēώ[ĺèħώèŘôſŜÍŕôŘôîώÍŜĖĲČώFôÍîÍŜĖĲČώFôÍîώēĖèħĲôŜŜϡ͐ϟ͕͔͑Гώϱώ͐ϟ͖͖͏Г[ϱ͑͐͗ώϼ͘ϯ͗ϯ͏͔Ͻ[ϱ͔͑͐ώϼ͘ϯ͑͗ϯ͏͔Ͻ[ϱ͔͑͏ώϼ͐͑ϯ͒ϯ͏͔Ͻ«ϱ͑͐͑ώϼ͐͑ϯ͕͐ϯ͏͔Ͻώ®ôŜťώ(ĲîώϼϠώ®Ϡώ[Ϡώ«Ϡώ¾ώÍîŜϽώ>aώ@ôĲώ͔ώīĖıώFĺīôώÍĲîώīťŘÍώīĖıώFĺīôώ®ôīīēôÍîŜ͑͏͏͏ώϱώ͑͏͐͏ 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 L-202 Install Clamp Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-196 50-029-23229-00-00 12628 Conductor Surface Intermediate Production Liner 4732 80 3244 7639 5498 12623 20" 10-3/4" 7-5/8" 4-1/2" 4732 30 - 110 29 - 3273 26 - 7665 7127 - 12625 30 - 110 29 - 2635 26 - 4589 4504 - 4732 Unknown, 10350 2480 4790 7500 None 5210 6890 8430 6781 - 12583 4-1/2" 12.6# L80 24 - 6758 4380 - 4730 Structural 4-1/2" Baker Premier Packer 6643 4325 Torin Roschinger Operations Manager Jessica Worthington jessica.worthington@hilcorp.com 907-564-4626 PRUDHOE BAY, Schrader Bluff Oil Pool, Orion Dev Area 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 0028238 24 - 4371 N/A N/A Well Not Online Well Not Online 0 25 0 0 325-143 13b. Pools active after work:Schrader Bluff Oil, Orion Dev Area No SSSV Installed 6643, 4325 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 2:36 pm, Apr 02, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.02 09:39:07 - 08'00' Torin Roschinger (4662) RBDMS JSB 040325 JJL 5/8/25 DSR-4/2/25 ACTIVITY DATE SUMMARY 3/2/2025 Standby for L-202 Secure well 3/2/2025 T/I/O= 787/990/453 (HOT OIL TBG WASH) Pumped 75 bbls of 190* Crude down TBG before tree grew ~3'. Dumped SSV, ESD equipment, make notifications. After the well was secured. Freeze protected FL with 8 bbls of 60/40. Pumped 130 bbls of Crude down TBG to verify well injectivity. FWHP's Vac/874/0 3/3/2025 T/I/O= 1030/2/NA (SECURE WELL) Pumped 170 bbls of 60* Crude down IA to load. Pumped 10 bbls of 60/40 to assist SL with drift. Pumped 245 bbls crude down TBG, ***Job continued to 3-4-25*** 3/3/2025 T/I/O = SSV/830/0. Temp SI. Bleed IAP to 0 psi (OPs). IA FL @ 6479' (sta #1, SO). Bled IAP from 830 psi to 390 psi to production( L-200) in 4 hrs. Continued bleed to BT to 10 psi in 6 hrs. Monitored for 1 hr. IAP & IA FL unchanged. Continue to monitor IAP throughout day. During bleed, noticed flange between MV & SSV started leaking, called Pad Op and SI MV. Well support torqued leaking flange. SL rigged up on well. SL in control of valves 3/3/2025 ***WELL S/I ON ARRIVAL*** RAN 10' X 3.66' DUMMY GUN S/D @ -1.5' SLM (SEVERAL TIGHT SPOTS THROUGH TREE) LRS LOADED IA W/ 170 BBLS CRUDE LRS LOADED TUBING W/ 5 BBLS METHANOL, 20 BBLS HOT CRUDE, WELL CONTROL DRILL NIGHTS (RAGSDALE) RAN 10' X 3.66" DUMMY GUN S/D @ 1.5' SLM (TROUBLE SHOOT TREE OBSTRUCTION) MAN DOWN DRILL NIGHTS (RAGSDALE) RAN 3.80" CENT. DOWN TO 6,780' SLM (NO OBSTRUCTION) RAN 3.80" CENT. 2' X 1-7/8" STEM, 3.80" CENT. TO 6,780' SLM (NO OBSTRUCTION) ***CONTINUE 3/4/25*** 3/4/2025 ***CONTINUE FROM 3/3/25*** SET 4-1/2" PX PLUG BODY @ 6,710' MD (PUMPED 20 BBLS CRUDE W/LRS) SET P-PRONG @ 6,710' MD LRS PERFORMED PASSING MIT-T LRS PERFORMED PASSING CMIT TxIA ***WELL LEFT S/I ON DEPARTURE*** 3/4/2025 T/I/O = SSV/270/0. Temp = SI. WHPs strap OA FL (eval SC leak). OA FL strap >35'. 16% LEL at top of SC, 4% LEL 1' above SC, 0% LEL +1' from WH. SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00 3/4/2025 ***Job continued from 3-2-25*** Pumped 84 bbls crude downTBG to assist SL and to ensure well stays on vac, MIT-T to 1250 max applied 1500, PASSED, Pressured TBG up with 1.5 bbls with 40* crude, TBG lost 96 Psi in 15 min, and Lost 21 Psi in 2nd 15 min for a total loss of 117 psi in 30 min test. CMIT-TxIA to 1250 psi, max applied 1500, PASSED, Pressured TBG/IA up with 1530/1508 bbls with 40* crude, TBG/IA lost 17/44 Psi in 15 min, and Lost 11/15 Psi in 2nd 15 min for a total loss of 28/59 psi in 30 min test. Bled TBG/IA down got back 2 bbls. FWHP's 304/318/0 DSO notified of well status upon LRS departure. Daily Report of Well Operations PBU L-202 Daily Report of Well Operations PBU L-202 3/5/2025 T/I/O = SSV/250/0. Temp = SI. Strap OA FL. ALP = 0 psi. SI @ CV & LV. Run 215' of weighted string down OA, did not find fluid level. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 3/6/2025 LRS Unit 46 (FUNCTION TEST SSV) Cycled SSV total of four times. 1st Cycle- Closed in 2:34 at 4 1/2", 2nd Cycle- Closed in 2:34 at 4/1/2", 3rd cycle- Closed in 1:58 at 4 1/2", and 4th Cycle- Closed in 2:08 at 4 1/2". Piston is 5 1/2" long, each cycle had 4 1/2" of travel. DSO notified of well status upon LRS departure. 3/7/2025 Fill OA with diesel to within 25' - 50' of surface. Pumped 5 bbls diesel initially. Strap didn't find fluid level. Fill OA in 1 bbll increments, strapping open hole in between pumping. Pumped additional 3 bbls, 1 bbl at a time. Fluid level at ~26'. Monitored FL in OA. After ~2 hrs OA FL @ 35'. OA FL @ 45' 2 hrs later. Next strap was inconclusive. Have LRS pump 2 more bbls. OA FL appears to be @ 35'. ***Job Cont to 3/8/25 WSR*** 3/8/2025 ***Job Cont from 03-07-2025 WSR*** Keep OA fluid level near surface (SECURE WELL) OA FL @ 41'. Next OA FL >50', LRS pumped 1 bbl of diesel. OA FL @ 65'. LRS pumped 1 bbl of diesel. OA FL @ 40'. OA FL appears to be @ 100' after ~2 hrs. LRS pump 2 bbls, OA FL @ 50'. OA FL dropped to 75', LRS pumped 2 bbls. OA FL @ 25' (8:00 am). OA FL @ 42' (9:00 am). OA FL @ > 100'. (10:15 am). LRS not pumping anymore diesel. On stand by. Pad Op open SSV to check TP. TP = 155 psi. Monitor for OA gas returns. Pumped a total of 16 bbls diesel. Pause pumping. Monitor OA, small amount of gas venting from OA hole. **Job Cont to 03- 09-205 WSR*** 3/9/2025 ***Job Cont from 03-08-25 WSR*** Monitor OA (SECURE WELL) Monitor OA. Monitored OA for changes in gas or fluid, unchanged, still has signs of vapor coming to surface. LRS begin loading OA w/ brine. LRS pumped 14.5 bbls 9.8# . OA FL @ > 100'. Continue to monitor well for any change in conditions. Fluid to surface when OA burped brine/diesel. Shut down equipment and notified SRT. Move to V-pad and standby for SRT to clean up. ***Job Cont to 3-10-25 WSR*** 3/10/2025 L-202 Job Scope: Secure well Initiate clean up around well area. Contingency Pump (SECURE WELL) SB on edge of pad for clean up. Bleed IAP to 0 psi. T/I/O = SSV/110/0. IA FL @ surface. Bled IAP to BT to 0 psi in <10 min (fluid 0.2) bbl, hold open bleed for 15 min. Monitored for 20 min. IAP increased 1 psi. Final WHPs = SSV/1/0. Well support removing wellhouse, disconnecting FL, gas lift line. Install dryhole tree and setting well up for pump job. Witnessed by AOGCC Rep Adam Earl ***Job Cont to 3-11- 2025 WSR ***Continued on 3/11/2025*** 3/10/2025 T/I/O=SI/0/0. Dry hole tree conversion. Removed 4" CIW upper tree assembly and installed Temp valve #51. Torqued flanges to spec. PT temp valve against MV to 300/5000 psi. Passed. ***Job Complete*** Final WHP's SI/9/0. Daily Report of Well Operations PBU L-202 3/11/2025 L-202 Job Scope: Secure well Spot in LRS pump truck. Pumped 7 bbls 60/40 meth down disconnected FL for FP. Pressured up FL to 500 psi per Pad Op. Load OA with 56.2 bbl of 9.8ppg NaCl and establish fluid returns at surface. Shut down and monitor. Establish loss rate. Standby for fluids to arrive on loc. Wellhead guy requested measurement from center of lockdown screw #3 to divot on casing = 33-1/2". PJSM. LRS run hose to OA and begin pumping 9.8# brine. Monitor LEL's while pumping. LELs = 20 % @ 2' above collar after 20 bbls away. 56.2 total bbls pumped, Fluid to surface. Fluid @ surface active & bubbling. LELs = 4%. Continue to monitor OA FL, FL @ surface began more aggressive bubbling. Stay back and monitor from distance. At diriection of WSL, head to V pad until agressive bubbling subsided. Return to L-202. Strap OA FL @ 8.5'. LELs = 0% @ 1' above collar LRS pumped 1/4 bbls. OA FL @3.5'. Monitor OA FL and LELs every 30 mins. OA FL slowly rising. OA FL @ 1'4", LELs = 10%.. Added 5 gals of brine, OA FL began to foam over and then stop after ~30 min. Settled out at 2.5", 10% LELs. ***Continued on 3/12/2025*** 3/12/2025 *** Continued from 3/11/2025 *** L-202 Job Scope: Secure well OA FL decreasing 3 to 4"/ hr. Filled OA up 30" to 1.5" from top of casing with 5 gals of 9.8 brine. Foamed over for ~15 min. Showed some stability for ~ 1.5 hrs. Then began deceasing at same rate 3" to 4"/ hr . Fall out rate seems to increase the lower the fluid drops. 10:00 am, OA FL drops to 4'. Fill OA void with 5 gallons of 9.8 brine. OA FL @ 9". FL rising to 3", before begining to gradually fall back down. Continue straps every 30 min throughout day. OA FL down to 30". ** Cont WSR on 3/13/25 ** ***Continued on 3/13/25 WSR*** 3/13/2025 ***Job Cont from 3-12-25 WST*** OA Fill (SECURE WELL) Monitored OA fluid level. OA FL @ 30". LELs sporatic 0% to 22%. OA FL @ 32", added 4 gals of 9.8 brine. OA FL @ 10". OA FL dropped 3" in 4 hrs to 13". OA FL decreased to 25" in 17 hrs. ***Job Cont to 3-14-25 WSR*** 3/14/2025 ***Job Cont from 3-13-25 WSR*** OA Fill (SECURE WELL) Monitor OA fluid level fall off. OA FL @ 25". OA FL has fell out 6" in 12 hrs, LELs = 0% 6" above casing. OA FL 36.5" by end of the day. Decreased 11.5" total for the day. ***Job Cont to 3-15-25 WSR*** 3/15/2025 ***Job Cont from 3-14-25 WSR*** OA Fill (SECURE WELL) Monitor OA fluid level. Well support did location prep. LRS added 4 gals of 9.8 brine. OA FL @ 7". OA FL decresed 9" in 22 hrs. ***Job Cont to 3-16-25 WST*** 3/16/2025 ***Job Cont from 3-15-25 WSR*** OA Fill (SECURE WELL) OA FL @ 17". OA FL dereased 9" in 24 hr period. OA FL @ 26" ***Job Cont to 3-17-25 WSR*** 3/17/2025 ***Job Cont from 3-16-25 WSR*** OA Fill (SECURE WELL) OA FL @ 26". OA FL @ 27", LRS added 2 gals of 9.8 brine. OA FL @ 11". OA FL @18", OA FL decrease 8" total for the day.***Job Cont to 3-18-25 WSR*** 3/18/2025 ***Job Cont from 3-17-25 WSR*** OA FIll (SECURE WELL)OA FL @ 19". OA FL decreased 8" for the day to 27". ***Job Cont to 3-19-25 WSR*** 3/19/2025 ** Cont WSR from 3/18/25" ** OA FL @ 27". T-Bird fliuds added 2.5 gals of 9.8 brine. OA FL @ 7". OA FL decreased 6" in 19 hrs. TFS assist ** Cont WSR on 3/20/25 ** 3/20/2025 ** Cont WSR from 3/19/25 ** OA FL @ 14". OA FL dropped 6" in 24 hrs. OA FL @ 20". TFS assist **Cont WSR to 3/21/25** Daily Report of Well Operations PBU L-202 3/21/2025 ** Cont WSR from 3/20/25 **. OA FL @ 20", T-Bird added 2 gal 9.8 brine to OA. OA FL @ 8". OA dropped 3" in 9 hrs. Well head hooched with heaters. WS crew installed patch on casing. ** Cont WSR to 3/22/25 ** 3/22/2025 ** Cont WSR from 3/21/25 ** (SECURE WELL). 0% LELs @ 6" from open 1" port in WH clamp, WH hooched with heaters. OA patch re-torqued as part of patch installation procedure (lower bolt row only at the metal x metal casing seal). Jewelry installed on patch with gauges. Maintain open bleed. T-Bird added 1.75 gal 9.8 brine to OA. Kakivik pulled OA gas sample. Install gas flow meter, gas rate to low to measure. Will seek another low flow gas meter and attempt to measure again. ** Cont WSR to 3/23/25 ** 3/23/2025 LRS 72 Heat UR tank of 290 bbls brine to 52*F by circulatng 120 bbls at 1.8 bpm. Bypass heater and circulate 180 bbls at 3 bpm. 3/23/2025 ** Cont WSR from 3/22/25 ** (SECURE WELL). WH hooched with heaters. Jewelry installed on patch with gauges. Maintain open bleed. 3% LELs ~1' above WH jewelry. T-Bird added 2 gal 9.8 brine to maintain fluid packed OA. Installed low flow rate gas meter (borrowed from Norgasco), monitored 5 hrs ~ 2 SCFH. ** Cont WSR to 3/24/25 ** 3/24/2025 ** Cont WSR from 3/23/25 ** (SECURE WELL). WH hooched with heaters. Maintain open bleed through low rate gas flow meter, continue monitoring gas rate ~2 SCFH. 0% LELs ~1' above WH jewelry. T-Bird added 1 gal 9.8 brine to maintain fluid packed OA. Kakivik acquired OA gas sample. Maintain open bleed, Gas flow meter disconnected. WS removed well houses from L-212 & L-200 for SRT to continue clean up.** Cont WSR to 3/25/25 ** 3/25/2025 ** Cont WSR from 3/24/25 ** (SECURE WELL). WH hooched with heaters. Maintain open bleed. 0% LELs ~1' above WH jewelry. Added ~1 gal 9.8 brine to maintain fluid packed OA. WS removed well houses from L-212 & L-200. SI open bleed on OA, PCC set alarm to 460 psi ** Cont WSR to 3/26/25 ** 3/26/2025 ** Cont WSR from 3/25/25 ** (SECURE WELL). WH hooched with heaters. SI open bleed, PCC set alarm to 460 psi OAP. 0% LELs ~1' above WH jewelry. OAP increased to 23 psi before decreasing to 11 psi (see log for details). Small gas leak found @ 07:00 position on top of clamp using Snoop. Trouble shooting patch. Pad Op notified. Well turned over to OPs. 23:59 3/31/2025 T/I/O = MV/36/27. Temp = SI. Gas sample OA. AL disconected. Dryhole tree instaled, wellhouse, scaffolding removed. Heater, temporary shelter installed. Obtained OA gas sample, 97.6% methane, .05% CO2, .67% N2. IA, OA = OTG. 09:30 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 1 of 25 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/18/2025 P. I. Supervisor FROM: Guy Cook SUBJECT: Casing Head Inspection Petroleum Inspector PBU L-202 Hilcorp North Slope LLC. PTD 2041960 3/17/2025: I was contacted by AOGCC Engineer Jack Lau (lead for the PBU L-202 incident) and asked for a detailed inspection of the surface casing head and factors that may have had a role in the casing head failure. I arrived on site and met with Patrick Beasley, a Hilcorp DHD hand, who was monitoring the well and let him know I was there to inspect at the wellhead. The wellhouse had been removed from the well. I started by measuring the surface casing head set screws that secure the surface casing head to the landing ring. I measured from the outer diameter (OD) of the surface casing head to the end of the set screws to see how far out the set screws were. The measurements for all ten set screws ranged from 11/16” to 15/16” out from the OD of the casing head. See photos 1 through 10. All ten set screws were angled downward in varying degrees suggesting that they had been forced in that direction. The casing head set screw threaded profiles were all deformed as well. The threaded profiles had all been stretched downward suggesting that a force had either pushed the wellhead up or pulled it down or possibly a combination of both. See photos 11 and 12. Viewing the internal diameter (ID) of the surface casing head showed the set screws had all been deformed. They all showed they had been forced upward off the landing ring releasing the wellhead and allowing the intermediate casing and tubing to “grow” approximately 35¼”. See photos 13 and 14. The way the set screws were deformed suggests that all the set screws were angled downward on the OD of the wellhead, and upward on the ID of the wellhead, when the damage to them occurred and when the wellhead released from the landing ring. None of the set screws were sheared when the wellhead came free of the landing ring and there were no indications of the set screws turning during this occurrence and unthreading themselves. See photos 15 through 24. I have included an annotated picture of the PBU L-202 landing ring to show the set screw profile. See photo 25. When I inspected the landing ring, it was obvious that the upper shoulders face of the set screw profile had been redressed using possibly a grinder, emery cloth or similar tool. The set screws had left indentations on the upper profile bevel that gouged into the face of the upper shoulder of the set screw profile, James B. Regg Digitally signed by James B. Regg Date: 2025.03.26 10:21:46 -08'00' 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 2 of 25 indicating that the casing head may not have been set down completely on the landing ring. It also appears that the set screws may not have engaged the set screw profile as deeply as the design intended. See photos 26 – 35. On March 10, 2025, AOGCC Petroleum Inspector Adam Earl sent me a photograph of the landing ring of this well while he was on location. The upper shoulder face of the set screw profile had not been redressed at that time. It is unclear to me why the landing ring was redressed, but it could be that it was done to prep the landing ring for repair to secure the well. This picture showed the indentations from the set screws but also showed additional deformation from the wellhead being forced up or the surface casing being forced down or a combination of both. At the top of the set screw indentations, I found “ridges” of metal on the upper face, of the set screw profile, due to these forces. These “ridges” had been removed when the landing ring was redressed. See photo 36. I also measured the thickness at the bottom of the surface casing head, and found it to be approximately 9/16” from OD to ID. See photo 37. This measurement shows that only four or five of the threads of the set screws could have been engaged in the casing head’s set screw profiles when installed. I should point out that none of the set screws on PBU L-202 have been removed from the surface casing head, so it is impossible to tell if the threads have been damaged in more than one way. My thought on this is questioning whether the set screws have been forced outward causing the difference in the set screw engagement measurements. It is reasonable to assume the threads would have been damaged from the set screw threaded profiles being stretched downward, but impossible to tell if the set screws have been “pushed” outwards when they were forced up and off the landing ring. This can possibly be determined later by removing a set screw. PBU S-122 (PTD 2050810) After I left location, I traveled to PBU S-122 to inspect this wellhead since it allegedly has the same altered surface casing head installed on it. I contacted the pad operator to let him know I would be inspecting the wellhead. I measured the set screws as I did on PBU L-202 from the OD of the surface casing head to the end of the set screw. All the set screws were approximately 7/8” out from the OD of the surface casing head. See photos 38 and 39. That is 3/16” to 7/16” shorter than the measurements of the set screws on PBU L-202, indicating the set screws are more engaged into the landing ring’s set screw profile on this well. I took a measurement of the thickness of the casing head like I did on PBU L-202. This measurement was approximately ¾” which is 3/16” thicker than the surface casing head on PBU L-202. See photo 40. This measurement isn’t exact as I could not get below the surface casing head. The bottom of PBU S-122’s surface casing head is below the grating covering the well cellar preventing me from getting an exact measurement. See photo 41. It is worth noting that the surface casing head on PBU L-202 appears to have been machined on the bottom 4 inches of the casing head OD (photo 12), 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 3 of 25 whereas PBU S-122 does not appear to have been machined on the OD (photo 42). This could account for a 1/16” to 1/8” of the difference in the thickness of the casing heads where the set screws are installed and would suggest that the surface casing head on PBU L-202 would be weaker than the casing head on PBU S-122. The extra thickness on PBU S-122’s casing head would allow for an additional one to two more threads of the set screws to engage than on PBU L-202’s casing head. The threaded set screw profiles on the surface casing head on PBU S-122 shows no signs of being stretched downward as they do on PBU L-202. See photo 43. Conclusion From my inspection, there are several factors that appear to at least have contributed to this failure at PBU L-202: x The thickness of the surface casing head. x The set screws may not have been fully engaged into the landing ring based on measurements taken during this inspection. x Subsidence. x The surface casing head may not have been set down completely. Disclaimer: This opinion is based on limited information available from my inspection. As more information is available from ongoing investigations, other possibilities of why this failure occurred may be identified. Attachments: PBU L-202 Photos (1 through 37) PBU S-122 Photos (38 through 43) 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 4 of 25 Surface Casing Head Inspection – PBU L-202 (PTD 2041960) Photos by AOGCC Inspector G. Cook (except where noted) 3/17/2025 Photos 1 and 2– Set screw; surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 5 of 25 Photos 3 and 4 – Set screw; surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 6 of 25 Photos 5 and 6 – Set screw; surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 7 of 25 Photos 7 and 8 – Set screw; surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 8 of 25 Photos 9 and 10: Set screw; surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 9 of 25 Photos 11 and 12 – set screws angled downward in varying degrees 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 10 of 25 Photo 13 – annotated photo of landing ring 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 11 of 25 Photos 14 and 15 – surface casing head ~35 ¼ inches above landing ring 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 12 of 25 Photos 16 and 17 – set screws from ID of surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 13 of 25 Photos 18 and 19 – set screws from ID of surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 14 of 25 Photos 20 and 21 – set screws from ID of surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 15 of 25 Photos 22 and 23 – set screws from ID of surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 16 of 25 Photos 24 and 25 – set screws from ID of surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 17 of 25 Photos 26 and 27 – set screw indents into the upper bevel of landing ring set screw profile 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 18 of 25 Photos 28 and 29 – set screw indents into the upper bevel of landing ring set screw profile 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 19 of 25 Photos 30 and 31 – set screw indents into the upper bevel of landing ring set screw profile 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 20 of 25 Photos 32 and 33 – set screw indents into the upper bevel of landing ring set screw profile 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 21 of 25 Photos 34 and 35 – set screw indents into the upper bevel of landing ring set screw profile 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 22 of 25 Photo 36: Landing ring; ridges of metal on upper face of set screw profile ring (Photo taken by (AOGCC Inspector A. Earl, 3/10/2025) Photo 37: Thickness measurement at bottom of surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 23 of 25 Surface Casing Head Inspection – PBU S-122 (2050810) Photos by AOGCC Inspector G. Cook 3/17/2025 Photos 38 and 39: Set screws; surface casing head 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 24 of 25 Photo 40: Set screws; surface casing head Photo 41: Surface casing head; set screws 2025-0317_Surface_Casinghead_PBU_L-202_gc Page 25 of 25 Photo 42: Bottom of surface casing head; PBU S-122 Photo 43: PBU S-122 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Torin Roschinger Subject:L-202 (PTD 204-196) Verbal Approval for Surface Casing Patch Installation Date:Saturday, March 15, 2025 11:54:52 AM Good day Torin, Looks like the surface casing patch sundry has not been finalized on our end. This email is a verbal approval to move forward with the patch installation per the sundry application submitted to the AOGCC on 3/13/25. The following are the conditions of approval for this work. Conditions of Approval Pressure test patch in shop to 1000 psi. Continue to keep OA full after patch installation. Monitor location for LEL's to ensure safe working conditions. Let me know if you have issues with the conditions. Jack From: Lau, Jack J (OGC) Sent: Thursday, March 13, 2025 12:02 PM To: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: L-202 Update - 3/13 Thanks for the update Torin. I’ll keep an aye out for the sundry. Jack From: Torin Roschinger <Torin.Roschinger@hilcorp.com> Sent: Thursday, March 13, 2025 11:41 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: L-202 Update - 3/13 Good morning Jack, I’m just getting back in from L-202. The last 24hrs were uneventful with fluid loss rate decreasing from ~1gph to ~.5gph. The well continues to cooperate at this time. The machinists and welders continue to work around the clock on the patch and we are targeting an install this weekend pending flights and weather. Abbie will be sending you a signed sundry for review here shortly. Thank you, Torin The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 this 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 L-202 Install Clamp Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-196 50-029-23229-00-00 ADL 0028238 12628 Conductor Surface Intermediate Production Liner 4732 80 3244 7639 5498 12623 20" 10-3/4" 7-5/8" 4-1/2" 4732 30 - 110 29 - 3273 26 - 7665 7127 - 12625 30 - 110 29 - 2635 26 - 4589 4504 - 4732 Unknown, 10350 2480 4790 7500 None 5210 6890 8430 6781 - 12583 4-1/2" 12.6# L80 24 - 67584380 - 4730 Structural 4-1/2" Baker Premier Packer No SSSV Installed 6643, 4325 Date: Torin Roschinger Operations Manager Jessica Worthington jessica.worthington@hilcorp.com 907.564.4626 PRUDHOE BAY 3/13/2025 Current Pools: Schrader Bluff Oil, Orion Dev Area Proposed Pools: Schrader Bluff Oil, Orion Dev Area 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 2:36 pm, Mar 13, 2025 325-143 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.03.13 11:42:10 - 08'00' Torin Roschinger (4662) Pressure test patch in shop to 1000 psi. Continue to keep OA full after patch installation. Monitor location for LEL's to ensure safe working conditions. 10-404 A.Dewhurst 13MAR25 Jack Lau JJL 3/15/24 3/15/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.17 14:45:48 -08'00' 3/17/25 RBDMS JSB 031825 Surface Casing Clamp Repair Well:L-202 PTD:204-196 Well Name:L-202 API Number:50-029-23229-00 Current Status:SI Producer Rig: Estimated Start Date:March 13, 2024 Estimated Duration:1day Reg.Approval Req’std?Yes Date Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:204-196 First Call Engineer:Jess Worthington 907.602.9715 Current Bottom Hole Pressure: Max. Proposed Surface Pressure: Recent SI Tubing Pressure: Min ID: 1,380 psi @ 4,400’ TVDss 940 psi 25 psi 2.59” Iso Sleeve at 7,627’ (Based on SBHPS on 12/8/21) (Based on .1psi/ft gas gradient) (3/11/2025) Brief Well Summary: L-202 was drilled and completed in 2005 as a Schrader bluff, multi-lateral (OA, OBa, OBb, OBd), gas lifted producer. During a routine hot oil treatment to clear hydrate buildup from the tubing on the 3/2/25, the outer annulus casing spool parted from the casing hanger. L-202 was successfully shut-in at the tree later that afternoon and subsequently secured with a TTP on 3/4/25. A passing CMIT-TxIA against the TTP was performed on 3/4/25 to 1,380 psi. Due to the parted casing spool, the OA remains open to atmosphere. The OA is continuously being filled with 9.8 ppg NaCl. It is suspected that the structural integrity of the Gen 5 FMC wellhead specifically installed on L-202 was compromised during manufacturing due to its base flange thickness being milled down and a possible source for the failure. Hilcorp is actively working with the manufacturer and a structural engineering consultant to further investigate this anomaly. A machined clamp will be installed, fastening the exposed casing hanger to the production casing, to seal the open annulus and allow for controlled pressure monitoring and bleeding. Objective:Install machined clamp fastening to the 10-3/4” casing hanger and sealed to 7-5/8” production casing to cap the exposed OA. Notes On Wellbore Condition: x Tubing and IA loaded with dead crude and pressures bled to 0 psi. x PX plug set in X-nipple at 6,710’ MD. Passing MIT-T and CMIT-TxIA to 1,380 psi on 3/4/25. x OA has open shoe at 3,273’ MD. x OA currently open to atmosphere and continuously being filled with 9.8 ppg NaCl. Loss rate is ~0.8 gph. x Wellhouse has been removed, flowline disconnected and dry hole tree installed. AOGCC witnessed by Adam Earl. Procedure: 1. Pump 9.8 ppg NaCl into OA, keeping hole full. 2. Prep working surface/floor for access around well. 3. Centralize production casing in OA. 4. Install 2-piece clamp and energize packing with bolted connections. 5. Install pressure gauge into NPT fittings. Attachments: x Current Wellbore Schematic x Current Wellhead Picture x Surface Casing Clamp x Sundry Change Form Surface Casing Clamp Repair Well:L-202 PTD:204-196 Current Wellbore Schematic: Surface Casing Clamp Repair Well:L-202 PTD:204-196 Surface Casing Clamp Repair Well:L-202 PTD:204-196 Current Wellhead Picture: 2-piece clamp installed will fasten to the 10-3/4” casing hanger and sealed around 7-5/8” casing10-3/4” Casing Hanger 7-5/8” Production Casing Surface Casing Clamp Repair Well:L-202 PTD:204-196 Surface Casing Clamp: Surface Casing Clamp Repair Well:L-202 PTD:204-196 Surface Casing Clamp Repair Well:L-202 PTD:204-196 Surface Casing Clamp Repair Well:L-202 PTD:204-196 Surface Casing Clamp Repair Well:L-202 PTD:204-196 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: March 13, 2025Subject: Changes to Approved Sundry Procedure for Well L-202Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Friday, March 7, 2025 3:39 PM To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] L-202 (PTD #2041960) Wellhouse Removal and Disconnect From: Torin Roschinger <Torin.Roschinger@hilcorp.com> Sent: Friday, March 7, 2025 3:33 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] L-202 (PTD #2041960) Wellhouse Removal and Disconnect Jack, Understood. I will let the team know that prior to removing the wellhouse and disconnecting the flowline that the AOGCC is present. Thank you, Torin From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, March 7, 2025 3:31 PM To: Torin Roschinger <Torin.Roschinger@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov> Subject: [EXTERNAL] L-202 (PTD #2041960) Wellhouse Removal and Disconnect Good afternoon Torin, Appreciate your time this morning. We do have one request that was briefly discussed. The AOGCC requests notification for witnessing L-202 wellhouse removal and flowline disconnect. Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice (907) 227-2760 Cell CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 2025-0311_Surface_Casinghead_PBU_L-202_ae Page 1 of 7 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/12/2025 P. I. Supervisor FROM: Adam Earl SUBJECT: Well head Failure Petroleum Inspector PBU L-202 Hilcorp North Slope LLC PTD 2041960 3/10/2025: I traveled to PBU L-202 to inspect a well head failure. The casing head had failed and separated approximately 38 inches from the landing ring. This failure took place during pumping operations to thaw hydrates from the well. Hilcorp had several people on location including GC2 Forman George Ivie to the Wells Supervisor, Glenn Brown. Several other well site leaders and Hilcorp North Slope Safety representative John Wagner. I was there to witness removal of the well house and flowlines as well as have a look at the aftermath of the uncontrolled release of wellbore fluids and the condition of the well. I took several pictures that show the descriptions of the well and surrounding area. From a visual inspection it appears to me there were two major factors that caused this to happen – again, this is just my opinion. First and most important was the type of well head installed was a retrofit of two styles that doesn’t appear that it was installed correctly. Allen-type lockdown screws didn’t seem to be set deep enough in the recess of the anchor. I’ve seen several of the allen-type screw and they are always flush or recessed in the spool. This could explain why the screws are bent counterintuitive of the way they should have bent if they were installed correctly. Second was subsidence around the well. I believe that these two factors working together could have caused this failure. Hilcorp will be continuing with their internal investigation. Attachments: Pictures (11) 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.16 15:28:46 -08'00' 2025-0311_Surface_Casinghead_PBU_L-202_ae Page 2 of 7 Surface Casinghead Inspection – PBU L-202 Incident (PTD 2041960) Photos by AOGCC Inspector A. Earl 3/10/2025 2025-0311_Surface_Casinghead_PBU_L-202_ae Page 3 of 7 2025-0311_Surface_Casinghead_PBU_L-202_ae Page 4 of 7 2025-0311_Surface_Casinghead_PBU_L-202_ae Page 5 of 7 2025-0311_Surface_Casinghead_PBU_L-202_ae Page 6 of 7 2025-0311_Surface_Casinghead_PBU_L-202_ae Page 7 of 7 2025-0302_Well_Control_PBU_L-202_ss Page 1 of 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3-3-2025 P. I. Supervisor FROM: Sully Sullivan SUBJECT:Uncontrolled Well Release Petroleum Inspector PBU L-202 Hilcorp North Slope LLC PTD 2041960 3-2-2025: At 1430 hrs I received a call from Inspection Supervisor Jim Regg regarding an unexpected gas release on PBU L-202. I traveled immediately to the location and arrived at 1545 hrs to find the road to PBU L-pad and the Pad itself properly secured by 4 Hilcorp employees in separate vehicles. Before entering the pad, I spoke with Hilcorp Operator Jason Newman who informed me that there was an unexpected release of gas and oil during a hot oil job on well L-202 and that all leaks were stopped. He also stated that they were depressurizing lines at that time and the well still needed to be killed. The incident occurred at or around 1000 hrs and vented gas until 1300 hrs or so. There was a suspected ice plug in the wells tubing, and they were using a hot oil unit to try and free the plug. Mr. Newman stated that the Little Red Services (LRS) hot oil unit pumped 75 bbls at 787 psi down the tubing and heard a loud noise from inside the wellhouse. At that time there was a release of gas and oil from the well head. I was told that LRS had the wing closed and control of the SSV and closed it but that did not stop the release of hydrocarbons. Mr. Newman said the volume of gas released was small, but the well head had shifted about 4 feet upward. Then I was asked to wait at the side of the pad until SRT had finished their work. I drove around the pad staying clear of the well house and took a photo of the surrounding area. I left the scene to attend another job at KRU 2P with plans to return and get photos after the well was killed. 3-3-2025: I returned to the scene on way back to camp @ 0130 hrs. Everyone had gone except one wellhead tech that was keeping an eye on wellhead pressures and taking fluid shots every so often until morning. According to the wellhead tech the well was killed around 1900 hrs and some cleanup of the well house had been done. I took some photos of the well house and well. The well cellar was full of oil and the wellhead was as stated – about 4 feet up out of the conductor. The top of the tree was against the wellhouse ceiling with the flowline in a considerable bind. Wireline is expected to over the well first thing in the morning to start setting plugs. After getting photos and finishing my walk around, I left the area and returned to Deadhorse. Attachments: Photos (6) 2025-0302_Well_Control_PBU_L-202_ss Page 2 of 5 Well Control Incident – PBU L-202 (PTD 1941960) Photos by AOGCC S. Sullivan 3/3/2025 2025-0302_Well_Control_PBU_L-202_ss Page 3 of 5 2025-0302_Well_Control_PBU_L-202_ss Page 4 of 5 2025-0302_Well_Control_PBU_L-202_ss Page 5 of 5 Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221118 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU F-29B 50029216270200 211147 8/20/2022 Halliburton SpinnerPressTemp PBU L-202 50029232290000 204196 10/24/2022 Halliburton PPROF PBU L-222 50029234200000 209119 10/21/2022 Halliburton IPROF PBU M-201 50029237110000 222030 10/17/2022 Halliburton IPROF Please include current contact information if different from above. By Meredith Guhl at 2:37 pm, Nov 18, 2022 T37276 T37277 T37278 T37279 PBU L-202 50029232290000 204196 10/24/2022 Halliburton PPROF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.18 14:44:07 -09'00' L~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 i`1 . ~ ~ a? ~, t} t% J AUgUSt 14, 2009 ' .r~,,+~~ti~u ~:':= ~ ~~~w Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, ~ bp ~~~~~~~~ 0 C T 4i ~ 2009 ~iasVc~ ~il ~ Gas Cons. Commis~ion Anchorage ~p ~~1 q~° Z- " ~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Ezploracion (aaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Conosion inhibitor, Sealant Top-off Report of Sundry Operationa (70-404) o~e L pad 8/13/2009 Well Name PTD # API # IniGal to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibftor Corrosion inhibftod sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 1-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 1-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? MA L-103 2021390 50029231010000 NA 1.6 NA 102 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 1-109 2012010 50029230460Q~0 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6l27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 1-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 5002923043~00 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 1-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.6 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 102 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 07/06/09 ~chrumber~er N0. 5297 z ^~~~" ~laska Data & Consultin Services ~~'~'~~~~~~~ ~~ ~ "~ ` '" ~ `~ ~ 9 Company: State of Alaska ?_525 Gamben Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnk~en taYTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD ~ • ~-06 AYTO-00035 GLSJPRODUCTION PROFILE 05/12/09 1 1 07-336 B4C4-00003 SCMT 05/30/09 1 1 17-14 AVY5-00049 PRODUC ION PRO ILE C/- 05/31/09 1 1 12-01 AYTU-00039 PRODUCTION PROFILE 06/01/09 1 1 04-43 AXWS-00011 IBP/CROSS FLOW CHECK - - ~. 06/0?J09 1 1 D-13A B04C-00059 USIT - 06/03l09 1 1 ~-i1a B2WY-00011 MEM PROD PROFILE '~ - 06/03/09 1 1 06-05 804C-00061 USIT O6/04/09 1 1 _ 12-18 AViH-00014 PRODUCTION PROFILE j~~~_ 06/04/09 1 1 A-35 AY3J-00026 USIT V "' -~" ~(p ~ 06/OM09 1 1 12-22 AXWS-00013 PROD PROF/GLS 06/05/09 1 1 12-16A AXWS-00014 PRODUCTION PROFILE - 06/05/09 1 1 18-298 B04C-00062 PSP XY-CALIPER LOG ~ 06/06/09 1 1 C-12A AXWS-00015 SCMT ~/ 06/06/09 1 1 s-274 AXBD-00028 MEM PROD PROFILE O6l11/09 1 1 L2-13A AWJI-00036 MEM CNL & INJ PROFILE ~ 06/17/09 1 1 L2-i3A AWJI-00036 MEM PROD PROFILE 1 < 06H7/09 1 1 07-21 B14B-00064 LDL O6/20/09 1 1 17-O1A AYQQ-00030 SBHP SURVEY - 06/11/09 1 1 01-25 AP3~-00041 LDL O6/15/09 1 1 L-202 62WY-00010 MEM PROD PROFILE ~- C/ 06/02J09 1 1 IL-903 AXBD-00027 MEM INJ PROFILE O6/04/09 1 1 GNI-03 AWJI-00034 MEM PRESS & TEMP SURVEY ~'~-.- 06/15/09 1 1 G-316 AWJI-00027 MCNL _~~ 04/30/09 1 1 15-29BPB1 o9AKA0t43 OH MWD/LWD EDIT - ~ ~~ 05/11/09 2 1 ' ~-~JG KliRllV tlYLCVVIC nca.c~r ~ o ~.~1~7rvutlV1 NIVIJ 1'fCl U111VIIVla VIVC IiVF'T CN~.-1 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. f Alaska Data & Consulting Services 2525 Gambetl Street, Suite 400 Anchorage, AK 99503-283$ 1~/~ • • ~~~°` MICROFILMED 03101 !2008 D4 NQT PLACE _ ~~~ ~ ~- yP ~ , ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFichelCvrPgs_InsertslAdicrofilm Marker.cioc J1 DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2041960 Well Name/No. PRUDHOE BAY UN ORIN L-202 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23229-00-00 MD 12628 TVD 4732 Completion Date 7!11/2005 Completion Status 1-OIL Current Status 1-OIL UIC N -.~ REQUIRED INFORMATION Mud Log No Samples No Directional Surve es DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR /RES /DEN / NEU / PWD, MWD / GR /RES / (data taken from Logs Portion of Master Well Data Maint Welt Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / type meairrmt rvumoer Name scale Media No Start Stop CH Received Comments E D Asc Directional Survey 0 12628 7/14/2005 pt., Directional Survey 0 12628 7/14!2005 D C Lis 15065 Induction/Resistivity 53 12627 Open 4/30/2007 LIS Veri, ROP, GR, DRHO, NPHI w/Graphics PDS, TXT og 15065 Induction/Resistivity 2 Col 108 12628 Open 4/30/2007 TVD Vision Service, Composite 17-Jun-2005 ~ og 15065 Induction/Resistivity 2 Col 108 12628 Open 4/30/2007 MD Vision Service, Composite 17-Jun-2005 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? Y~'1~'' Analysis `1'TI~~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~/ N Formation Tops N Comments: s -- Compliance Reviewed By: Date: 04/25/07 Sehlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4223 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Color CD L-213 ~ 11649950 MEMORY (PROF 03/17/07 1 W-210 11626075 USIT 03106107 1 S-104 L-216 L-218 10563057 10913045 10913045 INJECTION PROFILE CEMENT/PERF EVALUATION MDT 05103103 09104105 09104105 1 1 1 S-111P81 S-111P82 L-202 40011960 40011960 40012011 OH EDIT MWD/LWD _ OH EDIT MWD/LWD OH EDIT MWD/LWD 05124/05 06/06105 06/17/05 2 2 2 1 1 1 L-202L7 L-202L2 L-202L3 40012011 40012011 40012011 OH EDIT MWDILWD OH EDIT MWDILWD OH EDIT MWDILWD 06/24/05 06129/05 07/05/05 2 2 2 1 1 1 S-122 5-122PB1 5-122P62 40012137 40012137 40012137 OH EDIT MWDILWD OH EDIT MWD/LWD OH EDIT MWDILWD 08/17/05 08109/05 06/14105 2 2 2 1 1 1 5.122P83 40012137 OH EDIT MWDILWD 08115105 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: v ~ ~ BP Exploration (Alaska) Inc. ~~ ~" i~ ~ .zr ~~~3 Schlumberger-DCS Petrotechnical Data Center LR2-1 2525 Gambell St, Suite 400 900 E Benson Blvd. Anchorage, AK 99503-2838 Anchorage AK 99508-4254 y@ (~g'~ `~pyp~ 9'tl I~ ~ ~ &.IIU~ ATTN: Beth Date Delivered: Received by ~ ail his ~~1}~o Gs:~1~99it "~f~;'Y~ ,~'_ ,• STATE OF ALASKA ~ ALASK~L AND GAS CONSERVATION COMNR~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG` - Revised: 09hS/05, Put on+Production 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. WeII Class: ® Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/11/2005 12. Permit to Drill Number 204-196 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/5/2005 13. API Number 50-029-23229-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/17/2005 14. Well Name and Number: PBU L-202 2572 FSL, 3690 FEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 878' FSL. 909' FEL. SEC. 27, T12N, R11 E, UM (OBd) g. KB Elevation (ft): 77.3' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 4770' FSL. 3924' FWL, SEC. 35, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 12628 + 4732 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583224 y- 5978293 Zone- ASP4 10. Total Depth (MD+TVD) 12628 + 4732 Ft 16. Property Designation: ADL 028238 __ TPI: x- 585958 y- 5981911 Zone- ASP4 Total Depth: x- 590809 Y- 5980580 Zone- ASP4 11. Depth where SSSV set (Nipple) 2258' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES /DEN /NEU /PWD, MWD / GR /RES /DEN !NEU /PWD /AIM 22. CASING, LINER AND EMENTING RECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE OP OTTOM TOP OTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 215.5# A53 Surface 109' Surface 109' 48" 260 sx Arctic Set A rox. 10-3/4" 45.5# L-80 29' 3273' 29' 2635' 13-1 /2" 604 sx AS Lite, 489 sx Class 'G' 7-5/8" 29.7# L-80 26' 7665' 26' 4589' 9-7/8" 603 sx Class 'G' 4-1/2" 12.6# L-80 7011' 12625' 4462' 4732' 6-3/4" Uncemented Slotted Liner w/ 23. Perforations open to Produc tion (MD + TV D of Top and ' " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, L-80 6758' 6643' MD TVD MD TVD 7643' - 10999' 4587 - 4686' 11179' - 12583' 4693' - 4730' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Freeze Protect w/ 101 Bbls of Diesel 26. PRODUCTION TEST Date First Production: August 20, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 8/30/2005 Hours Tested $ PRODUCTION FOR TEST PERIOD • OIL-BBL 1,321 GAS-MCF 9,139 WATER-BBL 40 CHOKE SIZE 76 GAS-OIL RATIO 6,917 Flow Tubing Press. 55 Casing Pressure 1,400 CALCULATED 24-HOUR RATE OIL-BBL 3,964 GAS-MCF 27,418 WATER-BBL 119 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 CONTINUED ON REVE~2SE SIDE i...-, r ~ 213. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3650' 2832' None Ugnu MA 6032' 4012' Ugnu MB1 6109' 4051' Ugnu MB2 6236' 4113' Ugnu MC 6400' 4200' Schrader Bluff NA 6460' 4233' Schrader Bluff NB 6506' 4258' Schrader Bluff NC 6579' 4295' Schrader Bluff OA 6783' 4380' Schrader Bluff OBa 6943' 4438' Schrader Bluff OBb 7068' 4483' Schrader Bluff OBc 7231' 4535' Schrader Bluff OBd 7587' 4583' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed T h t D t i l A i t ~ w Titl ~ ~ 5 e an e ec n ca a ss s Terrie Hubble PBU L-202 204-196 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal No. Drilling Engineer: Michael Triolo, 564-5774 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. 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 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COM ~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ia. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ~ , r " ®Development ~(~~`z~il`oratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/11/2005 12. Permit to Drill Number 204-196 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/5/2005 13. API Number 50-029-23229-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/17/2005 14. Well Name and Number: PBU L-202 2572 FSL, 3690 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 878' FSL, 909' FEL, SEC. 27, T12N, Ri 1 E, UM (OBd) g. KB Elevation (ft): 77.3' 15. Field I Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 4770' FSL, 3924' FWL, SEC. 35, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 12628 + 4732 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583224 y- 5978293 Zone- ASP4 10. Total Depth (MD+TVD) 12628 + 4732 Ft 16. Property Designation: ADL 028238 _ _ __ TPI: x- 585958 y-_5981911 Zone-_ ASP4 Total Depth: x- 590809 Y- 5980580 Zone- ASP4 11 • Depth where SSSV set (Nipple) 2258' MD 17. Land Use Permit: ---~~^~~~ ~ ~ --- ~~~~~ ~~~--------- ~ ~ ~ ~-- ~-- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES /DEN /NEU /PWD, MWD / GR /RES /DEN /NEU /PWD /AIM 2. ASING, LINER AND CEMENTING RECORD CASING ETTINO EPTH MD ETTINO EPTH TVD HOLE MOUNT $IZE WT. PER FT. GRADE. OP OTTOM OP TTOM SIZE CEMENTING RECORD PULLED. 20" x 34" 215.5# A53 Surface 109' Surface 109' 48" 260 sx Arctic Set A rox. 10-3/4" 45.5# L-80 29' 3273' 29' 2635' 13-1/2" 604 sx AS•Lite, 489 sx Class 'G' 7-5/8" 29.7# L-80 26' 7665' 26' 4589' 9-7/8" 603 sx Class 'G' 4-1/2" 12.6# L-80 7011' 12625' 4462' 4732' 6-3/4" Uncemented Slotted Liner w/ 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECOtaD- Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, L-80 6758' 6643' MD TVD MD TVD 7643' - 10999' 4587 - 4686' 11179' - 12583' 4693' - 4730' 25. ACID, FRACTURE, CEMENT SQUEF1f ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 101 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS'MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE AIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None CL?~~P~ivl Y ,~ ; ~ ®~a~ ~~~.: ~"~ ~ ~ 7tjt15 SE t _ r ~ i _i IFt~ 9 "a 'a. a, ~ a t 't3 J '~ .,, ~~ ~ 1 s~ ~: i11 p .~ Form 10-407 Revise 2003 CONTINUED ON REVERSE SIDE r 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3650' 2832' None Ugnu MA 6032' 4012' Ugnu MB1 6109' 4051' Ugnu M62 6236' 4113' Ugnu MC 6400' 4200' Schrader Bluff NA 6460' 4233' Schrader Bluff NB 6506' 4258' Schrader Bluff NC 6579' 4295' Schrader Bluff OA 6783' 4380' Schrader Bluff OBa 6943' 4438' Schrader Bluff OBb 7068' 4483' Schrader Bluff OBc 7231' 4535' Schrader Bluff OBd 7587' 4583' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. jj~~ Signed Titl t t D t T h i l A i "~Jl~~ n s an e e ec ca ss a Terrie Hubble PBU L-202 204-196 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Michael Trio/o, 564-5774 INSTRUCTIONS GeNeRaL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. 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). ITEM 20: True vertical thickness. 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: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 7/18/2005 11:22:23 AM BP EXPLORATION Operations Summary Report Page 1 of 21 Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date `From - To Hours Task Code ~ ~ NPT i Phase Description of Operations 6/4/2005 ~ 00:00 - 03:00 ~ 3.00 MOB P ~ ~ PRE Set topdrive in rotary table, disconnect blocks from topdrive, 03:00 -04:30 1.50 MOB P PRE 04:30 - 05:30 1.00 MOB P PRE 05:30 - 07:30 2.00 MOB P PRE 07:30 - 09:30 2.00 BOPSU P PRE 09:30 - 10:30 1.00 MOB P PRE 10:30 - 12:30 2.00 RIGU P PRE 12:30 - 14:00 1.50 RIGU P PRE 14:00 - 16:30 2.50 BOPSU P PRE 16:30 - 18:00 1.50 RIGU P PRE 18:00 - 19:00 1.00 RIGU P PRE 19:00 - 23:00 4.00 RIGU P PRE 23:00 - 00:00 1.00 RIGU P PRE 6/5/2005 00:00 - 01:00 1.00 RIGU P PRE 01:00 - 01:30 0.50 RIGU P PRE 01:30 - 02:00 0.50 BOPSU P PRE 02:00 - 03:00 1.00 RIGU P PRE 03:00 - 03:30 0.50 RIGU P PRE 03:30 - 05:00 1.50 RIGU P PRE 05:00 - 07:00 2.00 DRILL P SURF 07:00 - 07:30 0.50 DRILL P SURF 07:30 - 12:00 4.50 DRILL P SURF 12:00 - 20:30 I 8.501 DRILL I P I I SURF bridle up, prep floor for derrick down move, lay down pipe chute, disconnect power and service lines to pits, move cuttings tank. Pull pits away from sub and position at entrence to pad. Held PJSM, with Toolpusher and rig crew. Un-pin derrick and lay down. Pull sub off L-2141, move sub around pad and position to pull over L-202. move pits around corner. Place well head equipment in cellar, lay mats, spread herculite, hang surface riser in cellar. Spot and level sub on L-202. Nipple up 20" Hydril and 16" diverter line, prior to setting mud pits. Spot and level mud pits, hook up power and service lines to pits. Accept Rig @ 09:00 hrs 6/4/2005 PJSM, inspect and raise derrick. Raise and pin pipe chute. Perform derrick inspection, bridle down, pin blocks to topdrive, take on water in pits. Mix spud mud, load DP and BHA in pipe shed. Nipple up 20" riser and flow line, hookup accumalator lines to Hydril and knife valve. Service topdrive, install bails, adjust kelly hose. Rig up floor. Pick up 102 joints and rack back 34 stands of 5" DP. Cut and slip drilling line. Held Pre-Spud meeting, with Co. Rep, Toolpusher, and all reig personnel. Pickup 14 joints 5" HWDP, jars and stand back. Make up 3, 8" NM drill collars. Function test Diveter valve and 20" Hydril, Jeff Jones with AOGCC waived witness of diverter test. Rack back stand of drill collars. Make up Bit, motor and MW D, tagged ice at 35', lay down stab and MWD. Fill hole, check suface equipment for leaks. Drill ice from 35' to 108', POH rack back 1 stand HWDP. Pickup remaing BHA per directional driller, PJSM, rig up Sperry e-line unit and Gyro tools. Drill 13.5" Surface hole from 108' to 271, 595 gpm, 580 psi, 60 rpm, torque 1.5 to 2k POH, stand back 2 stands 5" HWDP, pickup NM drill collars and jars. Drill 13.5" hole from 271' to 731',10-15k wob, 680 gpm, 1,395 psi, 80 rpm, torque 2.5k, up wt = 86k, do wt = 66k, rt wt = 73k. ART = 3.70 hrs, AST = .18 hrs. Directional drill 13.5" hole from 731' to 1,580' 30-40k wob, 700 gpm, 2,000 psi on bottom, 1,700 psi off bottom, 80 rpm, torque 5k on bottom, 2k off bottom, up wt = 86k, do wt = 84k, rt wt = 85k, ART = 1.38 hrs, AST = 5.83 hrs. Rig down Gyrodata tools and Sperry a-line unit. no gyro's surveys were taken. Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 2 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date f From - To ~ Hours Task ~ Code ~ NPT ~ Phase 6/5/2005 20:30 - 21:30 1.00 DRILL P SURF 21:30 - 00:00 2.50 DRILL P SURF 6/6/2005 100:00 - 01:30 1.501 DRILL P 01:30 - 12:00 I 10.501 DRILL I P 12:00 - 14:00 2.00 DRILL P 14:00 - 15:00 1.00 DRILL P 15:00 - 18:30 I 3.501 DRILL I P 18:30 - 20:00 I 1.501 DRILL I P 20:00 - 20:30 0.50 DRILL P 20:30 - 00:00 3.50 DRILL P 6/7/2005 100:00 - 00:30 0.501 DRILL P 00:30 - 02:00 I 1.501 DRILL I P 02:00 - 04:00 I 2.001 DRILL I P 04:00 - 07:00 I 3.001 DRILL I P 07:00 - 09:00 2.00 CASE P 09:00 - 16:00 7.00 CASE P SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF Description of Operations Circulate hole clean, 710 gpm, 1,700 psi, 80 rpm, torque 3k. Monitor well, POH from 1,580' with no problems, lay down UBHO sub, change out crossover sub and bit. RIH with BHA #2, started taking weight ~ 950' to 1,150' 15 to 20k, stopped and filled pipe, continue to RIH, to 1,489' no further problems. Break circulation, wash last stand to bottom, directional drill 13.5" hole from 1,580' to 2,716', 30-40k wob, 700 gpm, 2150 psi on bottom, 1,860 psi off bottom, 80 rpm, torque 10.5k on bottom, 4.5k off bottom, up wt = 96k, do wt = 84k, rt wt = 92k, Encounterd hyrates ~ 1,850' and 2,050' to 2,520' ART = 1.29 hrs. AST = 5.0 hrs. Directional drill 13.5" hole from 2,716' to 3,283' 30-40k wob, 710 gpm, 2300 psi on bottom, 1,900 psi off bottom, 80 rpm, torque 10k on bottom, 4.5k off bottom, up wt = 95k, do wt = 82k, rt wt = 94k. ART = 2.06 hrs. Circulate 2x bottoms up, 710 gpm, 1,800 psi, 100 rpm, torque 5k. Monitor well, POH from 3,283' encountered tight hole @ 3,045', 2,995' to 2,900', 1,800 to 1,766' 45k excess drag. hole not swabbing. Worked pipe C~ 1,766' several times 50k over pull. Makeup topdrive, backream out slowly from 1,766' to 1,390', 600 gpm,1,325 psi, 80 rpm, torque 5k. no excess drag or torque. Continue POH, from 1,390' to HWDP @640', (pulled good) Monitor well, RIH from 640' to 1,650' set down hard C~ 1,650' attempt to work through, no go, Makeup topdrive and break circulation, wash and ream down with 180 gpm, 40 rpm, set down 50k, torque 4 to 17k,no progress, pulled above tight spot, oriented motor to HS work down with out pump or rotatry, set down hard ~ 1,645' no progress. break circulation began reaming C~ 1,640' with 300 gpm, 80 rpm, taking 10 to 30k wob, torque 10 to 18k reamed down to 1,684', backreamed stand up to 1,588' erratic torque, shut down pumps and worked through tight spot with no problems. Continued to RIH, reamed several spots, 2080' to 2,186', 2,245' to 2,340', RIH dry from 2,340 to 2,800'. RIH from 2,800' stacked out 40k @ 3,110' makeup topdrive and ream from 3,110' to TD C~ 3,283' 300 gpm, 690 psi, 60 rpm, torque 4 to 7k. Circulate 3x bottoms up, 700 gpm, 1,850 psi, 100 rpm, torque 4.5k. Monitor well. POH from 3,283' to 640', tight from 2,050' to 1,890' 10-15k, excess drag, worked back thru tight area, no drag. monitor well at BHA. Stand back HWDP, jars and 7" NM drill collars, lay down BHA, clear floor. PU surface casing hanger and landing joint. Make dummy run to ensure ability to land on hanger -good. Change out bails and RU 350 ton casing handling equipment. PU 10-3/4°, 45.5#, L-80, BTC shoe track and RIH. All connections of the shoe track were Bakerlok'd. Continue to PU Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Start: 6/3/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date ~ From - To ', Hours Task Code NPT '~ Phase __ _ ~ -- 6/7/2005 ~ 09:00 - 16:00 7.00 __ CASE - P -J- -- I SURF 16:00 - 20:00 4.001 CASE I P SURF 20:00 - 00:00 6/8/2005 100:00 - 02:00 02:00 - 07:30 07;30 - 12:00 4.00 CEMT P SURF 2.00 BOPSUF(P SURF 5.501 BOPSUf(P (SURF 4.501 BOPSUFjP (SURF 12:30 - 14:30 2.00 BOPSU~N SFAL SURF 14:30 - 16:00 I 1.501 BOPSUFI P I I SURF Page 3 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Description of Operations surface casing applying Best-o-life 2000 NM and 8,000 ftlbs of torque to 3,273' MD (78 joints), filling pipe every joint with the Franks fillup tool and circulating down intermittently from 2,370' to 2,500' MD. Ran 25 bow spring centralizers - 10' from float shoe, 10' from float collar, remaining around collars of joints #4 to #26. Landed casing and made up the cement head. Break circulation@ 3 bpm, 300 psi and slowly stage the pumps up to 10 bpm, 660 psi, PU - 165K, SO - 122K. Circulate and condition the mud while reciprocating the pipe with 10' of movement. Hold PJSM with Schlumberger and members of the rig team. Line up to Schlumberger and pump 5 bbls of fresh water and pressure test the lines to 4,000 psi. Pump 20 bbls of CW 100 pre-flush C~ 7 bpm, 201 psi. Pump 70 bbls of 10.1 ppg Mudpush II Spacer @ 5 bpm, 123 psi. Shut down and drop bottom plug while getting the 10.7 ppg ArcticSet Lite lead cement up to weight. Kick out the plug (good indication) with 480 bbls of lead cement C~ 8 bpm, 845 psi initial and 916 psi final. Shut down and bring the 15.8 ppg Class G + additives tail slurry up to weight. Pump 102 bbls of tail slurry @ 4 bpm, 275 psi initial and 150 psi final. Shut down and drop the top plug. Kick out the plug (good indication) with 10 bbls of fresh water from Schlumberger. Shut in and turn over to the rig to displace. Displaced the cement with 297 bbls of 9.5 ppg conditioned mud at 10 bpm and caught the falling cement 27 bbls into the displacement. The rate was dropped to 5 bpm with 127 bbls into the displacement when the thick cement interface with red dye came to the surface. Pipe started to take a little weight on the down stroke, so the casing was landed on the hanger at this time. The rate was increased to 10 bpm by 141 bbls into the displacement. Dropped the rate to 5 bpm with 268 bbls into the displacement and then to 3 bpm to bump the plug on calculated strokes and 95% efficiency. Applied 1,500 psi to bump the plug and held for 5 minutes. The floats were then checked and found to be holding. Good lift pressures and full returns were seen throughout the entire cement job. Approximately 170 bbls of lead cement returns were brought to the surface. Cement was in place @ 2330 hours. LD cement head and landing joint. ND diverter. Clear the floor of casing handling equipment. Install Base Flange. Test seals to 1,000 psi -good. MU tubing spool and adapter flange. MU BOPE to tubing spool. RU 5" testing equipment and fill the BOPE with fresh water. Test BOPE and floor safety valves to 250 psi / 3,500 psi. Witness of the BOP test was waived by Jeff Jones of the AOGCC. Test was witnessed by BP Wellsite Leader Tom Anglen and Nabors Rig Supervisor Bill Bixby. Attempt to test the blind shear rams to 250 psi. Test failed. Change out the blind shear rams -found pieces of rubber missing from the seal area. Fill the BOPE with fresh water. Test the blind shear rams and door seals to 250 psi / 3,500 psi. Blow down the choke manifold and surface lines. Pull the test plug and install the Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 4 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To i Phase ~ Description of Operations - Hours Task Code ~ NPT --_JJ~- - -- __ _-_- 6/8/2005 14:30 - 16:00 1.50 BOPSUHP SURF wear ring. 16:00 - 19:00 3.00 DRILL P INT1 PU 60 joints of 5" DP and RIH. Move BHA components which 19:00 - 20:00 1.00 DRILL P 20:00 - 22:30 2.50 DRILL P 22:30 - 23:00 0.50 CASE P 23:00 - 00:00 1.00 CASE P 6/9/2005 ~ 00:00 - 02:00 ~ 2.00 ~ DRILL ~ P 02:00 - 04:00 I 2.001 DRILL 1 P 04:00 - 05:00 ~ 1.00 ~ DRILL ~ P 05:00 - 06:00 1.00 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 09:00 I 2.001 DRILL I P 09:00 - 09:30 0.50 DRILL P 09:30 - 12:30 3.00 DRILL P 12:30 - 16:00 I 3.501 DRILL I P 16:00 - 20:00 I 4.001 DRILL I P 20:00 - 21:30 1.50 DRILL P 21:30 - 00:00 2.50 DRILL P 6/10/2005 100:00 - 12:00 12.00 DRILL P were stood back in the derrick to the drillers side. POH standing back 20 stands of 5" DP. INTi MU BHA#3 - 9-7/8" MXC-1, nb stab, 2 x nm dc's, saver sub, 1 x HWDP, jars, 14 x HWDP. INT1 PU 69 x 5" DP singles and RIH. RIH with 4 stands from the derrick to 3,100'. SURF RU casing testing equipment and circulate the air from the system prior to pressure testing the casing. SURF Hold PJSM with Dowell and the rig team. Line up to Dowell and pressure test lines to 3,800 psi -good. Bleed off pressure. Pressure test the 10-3/4" 45.5# L-80 BTC casing to 3,500 psi - chart and hold for 30 minutes -good test. Bleed off pressure and Rd testing equipment. INTi Drill the shoe track and cement from top of the float collar 3,187' to the top of the float shoe @ 3,271' - 550 gpm, 765 psi, 60 rpm INTi Pump high visc sweep and displace the well over to 8.9 ppg LSND drilling fluid, PU - 112K, SO - 74K, ROT - 90K. Drill out the shoe, 13.5" rat hole and 20' of new formation to 3,303'. Place the bit inside the casing shoe C~3 3,273' INTi PJSM with Schlumberger and rig team. RU Schlumberger and fill lines. Perform LOT to 12.18 ppg EMW using Schlumberger pumping unit and 8.9 ppg drilling fluid - 450 psi surface pressure. Repeat LOT two additional times for Stress Cage Test baseline. INT1 Circulate and spot 34 bbl Stress Cage Test pill #1 at 5 bpm. INTi Line back up to Schlumberger pumping unit and conduct Stress Cage LOT twice. INTi Circulate out pill#1 and clean the mud cleaning equipment. Add spike fluid to the mud system. Spot 30 bbl Stress Cage pill #2. INT1 Perform Stress Cage LOT twice. INTi Circulate out pill #2 and condition the mud system removing the spike fluid - 673 gpm, 1,600 psi. INTi Monitor well -static. LD TIW, head pin and cement line. Pump dry job and POH standing back 5" DP and laying down BHA #3. Clear and clean the floor. INTi Hold PJSM with the rig team. MU BHA#4 - 9-7/8" DS70FNPV, 8.25" 4/5 8.2 stg motor (adjusted to 1.5), xo, nm stab, ARC, MWD, ADN, 2 x nm dc's, saver sub, 1 x HWDP, jars, 14 x HWDP. Shallow test MWD -good. PU remaining BHA#4 - 6 x 5" DP, ghost reamer, 48 x 5" DP, ghost reamer INT1 Cut and slip 39' of drilling line. Inspect inside drum and grease fittings. Lubricate rig and top drive. INTi RIH with BHA#4 on 5" DP to 3,240'. MAD pass from 3,240' to 3,303'. Drill from 3,303' to 3,501', 701 gpm, 1,680 psi, TO on - 6k, PU - 115K, SO - 82K, ROT - 100K, 80 rpm, ART - 0.51. INT1 Drill ahead directionally from 3,501' to 5,574', 700 gpm, 2,190 psi on bottom, 2,020 psi off bottom, TO on - 10k, TO off - 9k, PU - 145k, SO - 94k, ROT - 110k, 80 rpm, Calculated ECD - 10.07 ppg, Actual ECD - 10.4 ppg. AST - 1.8, ART - 4.4 Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To ~ Hours Task ~ Code ~ NPT - _ ~ _ _ - 6/10/2005 ~ 12:00 - 00:00 ~ 12.00 ~ DRILL~P 6/11/2005 100:00 - 06:30 06:30 - 11:00 11:00 - 16:00 16:00 - 18:00 18:00 - 23:00 6.50 DRILL P 4.50 DRILL P 5.00 EVAL P 2.00 DRILL P 5.00 DRILL P 23:00 - 23:30 23:30 - 00:00 6/12/2005 00;00 - 01:30 01:30 - 03:30 03:30 - 08:00 08:00 - 08:30 08:30 - 10:00 10:00 - 13:00 13:00 - 15:30 15:30 - 17:30 17:30 - 22:30 0.501 DRILL I P 0.50 DRILL P 1.50 DRILL P 2.00 DRILL P 4.50 DRILL P 0.50 DRILL P 1.50 DRILL P 3.00 DRILL P 2.50 BOPSU P 2.00 CASE P 5.00 CASE P Page 5 of 21 Spud Date: 6/5/2005 Start: 6/3/2005 End: 7/11 /2005 I Rig Release: 7/11/2005 Rig Number: Phase ~ Description of Operations INTi Drill ahead directionally from 5,574' to 6,895', 700 gpm, 2,250 psi on bottom, 2,130 psi off bottom, TO on - 12k, TO off - 10k, PU - 145k, SO - 94k, ROT - 110k, 80 rpm, Calculated ECD - 9.9 ppg, Actual ECD - 10.26 ppg. AST - 5.06, ART - 1.18 INT1 Drill ahead directionally from 6,895' to 7,675' - 700 gpm, 2,230 psi on bottom, 2,195 psi off bottom, TO on - 10k, TO off - 9k, PU - 155k, SO - 105k, ROT - 125k, 80 rpm. AST - 2.91, ART - 1.76. Calculated ECD - 9.97 ppg. Actual ECD - 10.55 ppg. INTi Circulate and condition the mud to POH and run liner. Mud weight prior to circulation and conditioning - 9.3 ppg. Mud weight after circulation and conditioning - 9.0 ppg. Prior to POH, calculated ECD - 9.85 ppg, Actual ECD - 9.95 ppg. INTi MAD pass from 7,675' to 6,518' - 600 gpm, 1,600 psi, ROT - 128k, 80 rpm, INT1 Monitor well -stable. POH from 6,518' to 3,782'. Encountered 25k max overpull C~ 5,570' and 4,647'. Worked pipe over these intervals and then pulled clean. INTi Hole started to swab at 3,782'. Attempt to pull without pump - unsuccessful RIH with 2 stands of 5" DP from the derrick to 3,971'. Backream out of the hole from 3,971' to 3,273' (previous casing shoe) - 600 gpm, 80 rpm, 875 psi. Hole tried to pack off while backreaming -ECD spikes seen up to 14 ppg EMW and losses were induced. Adjusted flowrate and rpm to 475 gpm and 65 rpm as well as running in the hole -50' each time and were able to regain returns. Saw a considerable amount of sandy returns while backreaming. Lost 122 bbls over this interval. INT1 Stage up the pump rate and circulate bottoms up at the 10-3/4" shoe at 3,273 - 700 gpm, 1,585 psi, 80 rpm. Hole cleaned up well while in casing. Calculated ECD - 9.7 ppg, Actual ECD - 9.9 PPg• INT1 Service the top drive and the crown. INT1 RIH with 5" DP from the derrick from 3,273' to 7,675'. INT1 Circulate and condition drilling. fluid to LDDP and run casing. Calculated ECD - 9.84 ppg, Actual ECD - 10 ppg. INTi Monitor well -stable. POH standing back 5 stands of 5" DP. Monitor well -stable. Pump dry job. LD 5" DP singles and upper ghost reamer to 2,361'. INT1 RIH with 5" DP from the derrick from 2,361' to 3,121'. INT1 LD 5" DP from 3,121' to 855'. INT1 LD BHA#4 from 855'. LD lower ghost reamer, 6 x 5" DP, 14 x HWDP, jars, 1 x HWDP, saver sub, 2 x nm DC's. Hold PJSM for handling nuclear source. LD ADN, MW D, ARC, nm stabilizer, xo, motor and 9-7/8" DS70FNPV -graded 1-2-BT-G-X-I-ER-TD. Clear and clean the floor. INT1 Pull wear ring and flush the BOP stack with fresh water. Install test plug. Change out the top variable rams to 7-5/8" rams. Test the door seals to 3,500 psi -good test. INT1 Make dummy run with 7-5/8" landing joint. RU to run 7-5/8" 29.7# L-80 BTC-M casing. INT1 PJSM with all personnel. PU 7-5/8" shoe track, bakerloc connections and RIH. Fill pipe and check floats -holding. Continue PU 7-5/8" casing to 3,265, filling pipe each joint. Printed: 7!18/2005 11:22:29 AM BP EXPLORATION Page 6 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date , From - To ~~ Hours Task Code ~ NPT 6/12/2005 ~ 17:30 - 22:30 5.00 ~ AC SE P ~~ 22:30 - 23:30 1.00 CASE P INTi 23:30 - 00:00 0.50 CASE P INT1 6/13/2005 00:00 - 08:30 8.50 CASE P INTi 08:30 - 11:30 3.00 CASE P INT1 11:30 - 13:30 2.00 CEMT P INTi 13:30-14:30 ~ 1.OO~WHSURIP ~ ~INT1 14:30 - 15:30 1.00 CASE P INTi 15:30 - 20:00 4.50 BOPSU P INTi 20:00 - 21:30 I 1.501 BOPSUR P I I INT1 21:30 - 22:30 1.00 BOPSUF#N SFAL INTi 22:30 - 23:00 0.50 BOPSU P INTi 23:00 - 00:00 1.00 CASE P INT1 6/14/2005 00:00 - 05:00 5.00 CASE P INT1 05:00 - 07:00 2.00 CASE P INT1 07:00 - 12:00 5.00 DRILL P PROD1 Spud Date: 6/5/2005 Start: 6/3/2005 End: 7/11/2005 Rig Release: 7/11/2005 Rig Number: Phase ' Description of Operations Utilized Best-o-life 2000NM on each connection and torque to teh mark with 9,000 ftlbs. Circulate 1.5 times bottoms up while staging up to 8 bpm, 529 psi, with full returns. PU - 112k, SO - 101 k. Continue to PU 7-5/8" casing and RIH to 3,554'. Continue to PU 7-5/8" 29.7# L-80 BTC-M casing and RIH from 3,554' to 7,665'. Fill pipe every joint. Break circulation every 5 joints, circulate for 15 minutes every 15 joints and circulate bottoms up every 50 joints while keeping the pipe moving. PU landing joint and land hanger with 117K. Ran a total of 184 joints and 71 centralizers with 23 stop rings. LD Franks fillup tool and RU cement head and lines. Break circulation and stage up the pumps to 10 bpm, 698 psi -full returns. Reciprocate pipe while circulating. Hold PJSM with Schlumberger and rig team for the cement job. Batch up the cement. Line up to Schlumberger and pump 5 bbls of fresh water ahead. Shut down and pressure test the lines to 4,000 psi - good. Pump 20 bbls of CW 100 followed by 45 bbls of 10.5 ppg Mudpush II spacer. Drop bottom plug. Chase plug with 130 bbls of 15.8 ppg Gasblok slurry. Shut down and drop the top plug. Kick the plug out with 10 bbls of fresh water. Shut down and pump remainder of displacement with the rig pumps. Pump 338 bbls of additional water to bump the plug on calculated strokes with 3,000 psi -hold for 5 minutes. Bleed off pressure and check floats -holding. Cement in place Ca? 1310 hours. Good lift and full returns seen throughout entire job. RD cement head and LD landing joint. Install pack-off and test to 5,000 psi -good. RD casing handling equipment -elevators and long bails. Flush the stack and install test plug. Change out the 7-5/8" casing rams to 3-1/2" x 6" variables. Change out the blind rams to blind/shear rams. Install secondary annulus valve and change out the quill to 4" HT40. RU to test the door seals, HT40 safety valve, and blind shear rams. Pressure test variable rams, safety valve, and lower well control valve to 250 psi / 3,500 psi. Attempt to test blind/shear rams -failed. RD testing equipment. Open up the doors and inspect the blind/shear rams. Change the blind/shear rams back to blind rams. Test the blind rams to 250 psi / 3,500 psi -good test. RD testing equipment and install wear ring - 9" ID. RU 4" DP handling tools. MU mule shoe and PU 180 joints of 4" HT40 DP. RIH. Simops -clean pits to get ready for MOBM. Simops -inject 125 bbls of 9.1 ppg LSND fluid down the 7-5/8" x 10-3/4" annulus to ensure injectability (cement compressive strength>1,000 psi). Establish injection rate of 3 bpm, 680 psi. POH standing back 4" DP. Bring BHA tools to the rig floor. PU 18 joints of HWDP and stand back in the derrick. MU BHA#5: 6-3/4" Hycalog DS146H+GJNW (6x10's), 4-3/4" Aim 4/5 6stg motor, bypass sub with float, nm stabilizer, nm lead collar, MWD/LWD, INT1 Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Page 7 of 21 Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date 6/14/2005 6/15/2005 From - To 'Hours Task Code ~ NPT '~, Phase 07:00 - 12:00 ~ 5.00 ~ DRILL ~ P 12:00 - 14:00 2.00 DRILL P 14:00 - 14:30 0.50 DRILL P 14:30 - 18:00 3.50 DRILL P 18:00 - 19:30 I 1.501 DRILL I P 19:30 - 20:00 0.50 DRILL P 20:00 - 20:30 0.50 CASE P 20:30 - 22:30 I 2.001 DRILL I P 22:30 - 00:00 1.50 DRILL P 00:00- 01:00 I 1.00 DRILL P 01:00 - 02:00 I 1.001 DRILL I P 02:00 - 02:30 I 0.501 DRILL I P 02:30 - 10:30 I 8.001 DRILL I P 10:30 - 14:00 i 3.501 DRILL I N 14:00 - 00:00 I 10.001 DRILL I P 6/16/2005 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 17:00 ~ 5.00 DRILL 1 P 17:00 - 18:00 1.00 DRILL P 18:00 - 00:00 6.00 DRILL P Description of Operations PROD1 VPWD, ADN, 2 x nm flex collars, circ sub, xo, 1 x 4" DP, jars, 1 x 4" DP. PROD1 RIH with BHA#5 picking up 4" DP from the pipe shed to 1,200' PRODi Shallow test the MWD -good test. PRODi Continue RIH picking up 4" DP from the pipe shed form 1,200' to 6,700'. PROD1 Cut and slip 96' of drilling line. Service the top drive, blocks and the crown. PRODi RIH picking up 4" DP from 6,700' to 7,362'. INTi Pressure test the 7-5/8" 29.7# L-90 BTC-M casing to 3,500 psi. Chart and hold for 30 minutes -good test. PROD1 Tag up on cement ~ 7,456'. Drill cement to the float collar tagged at 7,579'. Drill float collar and cement to 7,661' -above the shoe. PU - 150K, SO - 80K, ROT - 103K, 275 gpm, 1,570 psi, 40 rpm, TO on - 8k. PRODi Circulate bottoms up. Simops: freeze protect the 10-3/4" x 7-5/8" annulus with 100 bbls of dead crude. PROD1 Displace the well over to 9.2 ppg Versapro MOBM - 275 gpm, 2,340 psi, 60 rpm, TO - 5K. PRODi Drill 10' of rat hole and 20' of new formation to 7,695'. Circulate bottoms up. Pull bit inside 7-5/8" casing shoe. PROD1 Perform 10.77 ppg EMW FIT on the 7-5/8" shoe - 375 psi surface pressure, 9.2 ppg fluid and 4,588' TVD. PROD1 Drill 6-3/4" directionally ahead while geo-steering from 7,695' to 8,570' - PU - 138k, SO - 75k, ROT - 101 k, 300 gpm, 2,850 psi on bottom, 2,550 psi off bottom, 60 rpm, TO on - 6k, TO off - 6k, AST - 0.75, ART - 2.59. Calculated ECD - 10.31, Actual ECD - 10.66 PRODi MWD information out of sync. Troubleshoot MWD from surface. Circulate to downlink to tool - no effect. Drilled -30' while trying to troubleshoot the MW D from surface. PRODi Attempt to drill) ahead one more time prior to making a decision to trip out of the hole for MWD -successful. Appears that if we stay below 400'/hr instantaneous, the MW D stays in sync. Drill 6-3/4" directionally ahead while geo-steering from 8,600' to 9,565' - PU - 138k, SO - 76k, ROT - 101 k, 300 gpm, 3,000 psi on bottom, 2,725 psi off bottom, 60 rpm, TO on - 6k, TO off - 6k, AST - 1.03, ART - 2.48. Calculated ECD - 10.6, Actual ECD - 10.91. PROD1 Drill 6-3/4" directionally ahead while geo-steering from 9,565' to 11,028', pumping sweeps as needed - PU - 150k, SO - 60k, ROT - 100k, 294 gpm, 3,050 psi on bottom, 2,860 psi off bottom, 60 rpm, TO on - 7k, TO off - 6k. Calculated ECD - 10.97, Actual ECD - 11.22. AST - 1.8, ART - 3.30 PROD1 Drill 6-3/4" directionally ahead while geo-steering from 11,028' to 11,593', pumping sweeps as needed - PU - 143k, SO - 56k, ROT - 91 k, 299 gpm, 3,400 psi on bottom, 3,000 psi off bottom, 60 rpm, TO on - 7k, TO off - 6k. Calculated ECD - 11.27, Actual ECD - 11.32. PROD1 POH to 11,453' and log down to 11,593'to confirm geology. PROD1 Drill 6-3/4" directionally ahead while geo-steering from 11,593' to 12,061', pumping sweeps as needed - PU - 149k, SO - 56k, ROT - 96k, 299 gpm, 3,450 psi on bottom, 3,150 psi off Printed: 7/ta/2005 11:22:29 AM BP EXPLORATION Page 8 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES ~ i i Date 'From - To Hours ' Task '. Code NPT 6/16/2005 18:00 - 00:00 ~~ 6.00 ~ DRILL I P 6/17/2005 100:00 - 05:00 5.001 DRILL ~ P 05:00 - 06:30 I 1.501 DRILL ~ P 06:30 - 12:30 6.001 DRILL ~ P 12:30 - 13:00 I 0.501 DRILL I P 13:00 - 13:30 0.50 DRILL P 13:30 - 16:30 3.00 DRILL P 16:30 - 18:30 2.00 DRILL P 18:30 - 19:00 0.50 DRILL P 19:00 - 20:30 ~ 1.50 ~ DRILL ~ P 20:30 - 00:00 3.50 DRILL P 6/18/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 03:30 I 3.001 DRILL I P 03:30 - 05:30 I 2.001 DRILL I P 05:30 - 06:00 0.50 DRILL P 06:00 - 06:30 0.50 CASE P 06:30 - 15:00 8.50 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 21:00 5.50 CASE P 21:00 - 22:00 I 1.001 CASE I P Spud Date: 6/5/2005 Start: 6/3/2005 End: 7/11 /2005 I Rig Release: 7/11/2005 Rig Number: i Phase ! Description of Operations PROD1 bottom, 60 rpm, TO on - Sk, TO off - 7k. Calculated ECD - 11.20, Actual ECD - 11.80. For the tour: AST - 1.16, ART - 2.97 PROD1 Drill 6-3/4" directionally ahead while geo-steering from 12,061' to 12,628' (TD), pumping sweeps as needed - PU - 149k, SO - 56k, ROT - 96k, 299 gpm, 3,450 psi on bottom, 3,150 psi off bottom, 60 rpm, TO on - 8k, TO off - 7k. PROD1 Circulate and Condition Hole w/ 9.2 ppg MOBM at 294 gpm / 3,150 psi. Start ECD 11.43 ppg, Final ECD 11.3 ppg. Monitor Well-Static PRODi Backreaming at drilling rate from TD to the 7-5/8" shoe at 7,665'. Start ECD 11.3 ppg. Final ECD 10.84 ppg PROD1 Circulate Bottoms Up at 7,665'. 299 gpm / 2640 psi. 80 rpm. Start ECD 10.78 ppg, Final ECD 10.49 ppg PRODi PJSM-Service Top Drive PROD1 RIH f/ 7,665' - t/ 12,628'. Fill DP C~3 10,623' PRODi Circulate and Condition Hole w/ 9.2 ppg MOBM at 290 gpm / 3300 psi. Start ECD 10.83 ppg. Final ECD 10.83 ppg PROD1 Attempt to Downlink Downhole Toolsw/o Success. As Per MWD Rep. PROD1 Displace Wellbore Fluid w/ Solids Free 9.2 ppg MOBM. Recriprocating and Rotating Drill String While Displacing. 275 gpm / 2755 psi. Dn. Wt. 100K, Up Wt. 110K, 66 rpm l~ 9,000 fUlbs Torque. Start ECD 11.2 ppg, Final ECD 10.69 ppg. Monitor Well-Static PROD1 POH w/ 6-3/4" OBd Lateral BHA t/ 7-5/8" Shoe 7,665'-Recording Up & Down String Weights Every 5 stds. PROD1 Drop 2" Circulating Sub Ball and Pump Down to Seat. Pressure up t/ 2,250 psi and Open Cir. Sub. Pump Dry Job. PROD1 POH w/ 4" DP. Recording Up and Down String Weights Every 10 stds. PROD1 POH w/ 6-3/4" Obd Lateral BHA, Stand Back HWDP, Jars and Flex Collars. L/D MWD tools, Motor & Bit PRODi Clear and Clean Rig Fllor RUNPRD PJSM-R/U 4-1/2" Liner Running Equipment RUNPRD RIH w/ 4-1/2" 12.6# L-80 IBT Slotted/Solid Liner. Utilize BOL2000NM Dope f/ Connections. 3,600 fUlbs Torque on Slotted Liner, 3,800 ft/Ibs Torque on Solid Liner. Run Assorted Jewelry As Per Liner Detail. P/U Seal Bore Extension, Baker "HMC" Liner Hgr./ Baker "HRD" ZXP Liner Top Pkr. and Tie-Back Extension. Up Wt. 85K, Dn. Wt. 70K. Total Liner Length = 5,497.59' RUNPRD R/D 4-1/2" Liner Running Equipment RUNPRD RIH w/ 4-1/2" Liner on 4" DP. Filling Dp Every 10 stds. Tag Bottom at 12,628' RUNPRD M/U Top Drive and Establish Parameters; Up Wt. 175K, Dn. Wt. 70K. Pump Rate at 4 bpm / 700 psi. Drop 1-3/4" Baker Setting Ball and Pump Down at 4 bpm. Set 4-1/2" Liner Shoe at 12,625'. Seat Ball and Pressure Up t/ 2,000 psi to Set Liner Hanger. Slack Down to 50K to Ensure Liner Hgr. Fully Set. Pressure Up t/ 3,500 psi to Release from Hgr. (hold 5 min.). Bleed Pressure to 0 psi. P/U to Free Point, 145K (lost 30K), P/U Additional 8' to Expose Dogs. Rotate Down at 10 rpm Until Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Start: 6/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date ~, From - To Hours ! Task Code ~ NPT Phase - - - _ ~ 21:00 - 22:00 - - -_ 6/18/2005 ~ 1.001 CASE P ~ RUNPRD 22:00 - 00:00 2.00 CASE P RUNPRD 6/19/2005 00:00 - 02:30 2.50 P RUNPRD 02:30 - 03:00 0.50 CASE P RUNPRD 03:00 - 03:30 0.50 CASE P RUNPRD 03:30 - 04:00 0.50 CASE P RUNPRD 04:00 - 05:00 1.00 STWHIP P WEXIT 05:00 - 09:00 4.00 STWHIP P WEXIT 09:00 -14:30 I 5.501 STWHIPI P I I WEXIT 14:30 - 15:30 I 1.001 STWHIPI P I I WEXIT 15:30-16:30 1.00 STWHIP P WEXIT 16:30 - 23:00 6.50 STWHIP P WEXIT 23:00 - 00:00 I 1.001 STWHIPI P I I WEXIT 6/20/2005 ~ 00:00 - 00:30 ~ 0.50 ~ STW HI P A P ~ ~ W EXIT 00:30 - 04:00 I 3.501 STWHIPI P I I WEXIT 04:00 - 04:30 0.50 STWHIP~P WEXIT 04:30 - 05:00 0.50 BOPSU P WEXIT 05:00 - 05:30 I 0.501 BOPSUFI P I I W EXIT 05:30-07:00 1.50 BOPSU~P WEXIT 07:00 - 14:30 7.50 BOPSU P WEXIT 14:30- 15:00 0.50 BOPSU P WEXIT 15:00-17:30 2.50 STWHIP P WEXIT Page 9 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Description of Operations Obsereved Packer Set w/ 50K Dn Wt. Repeat Process to Ensure Pkr. Set. P/U to 145K and Pressure Up Backside U 1,500 psi to Test Pkr. (held 5 min.). P/U 30' to Clear HR Tool. Monitor Well-Static. POH w/ Running Tool on 4" DP POH w/ 4-1/2" Liner Running Tool Clear and Clean Floor Slip and Cut Drilling Line Service Top Drive and Crown P/U 9 - 4-3/4" DC's and Stand Back in Derrick P/U and M/U Whipstock Assy. #1, Seal Assy.-Locator Sub-Unloader Sub-3 1/2" DP Space Out Pup-XO Blank Sub-Btm. Trip Anchor-Shear Disconnect-Unloader Sub-Boot Basket-Bit Sub XO-Ported Sub-7 5/8" Whipstock Slide-Starting Mill-Lower Mill-Flex Jt.-Upper Mill-1 jt. 3-1/2" HWDP-Float Sub-MWDRssy.-Bumper Jar-9 x 4-3/4" DC's-XO-18 x 4" HWDP = 981.42' Total Length. Shallow Test MW D, 254 gpm at 685 psi. RIH w/ Whipstock Assy. #1 on 4" DP.Running Speed of 45 fpm, as per Baker Rep. RIH U 7,043' M/U Top Drive and Establish Parameters; Up Wt. 140K, Dn. Wt. 85K, Pump Rate 275 gpm at 1,925 psi. Orient Whipstock 19 deg. Left and Set Same. Top of Window at 7,072'. Btm. of Window at 7,084'. TVD 4,484' Displace Wellbore w/ 9.1 ppg MOBM at 275 gpm / 1,875 psi. Mill f/ 7,072' - U 7,103', Up Wt. 139K, Dn. Wt. 85K Rt. Wt. 101 K, Pump Rate 298 gpm/ 1,875 psi, 100 rpm Rotary, Torque 5,000 ft /Ibs. Average ROP 3.18 fph. Pumping Hi-Vis Sweep every 2 hrs. Circulate 50 bbl Hi-Vis Sweep Surface to Surface. Working Mills Through Window During Circulation Circulate 50 bbl Hi-Vis Sweep Surface to Surface. Work Mills Through Window While Circulating. Pump Dry Job and Monitor Well. Static. POH w/ 6-3/4" Whipstock Milling BHA on 4" DP. UD BHA Components. All Mills In Gauge Clear and Clean Rig Floor. Remove All Milling Tools from Rig Floor. P/U and M/U BOP Stack Flushing Tool. Circulate at 10 bpm to Remove Excess Metal/Cuttings from Ram Cavities. M/U Floor Valves to Test Jt. Pull Wear Ring and Install Test Plug Remove Standard Blind Rams and Install Blind /Shear Rams Test BOP's, Choke Manifold and Floor Safety Valves. All Tests to 250 psi Low for 5 min. and 3,500 psi High. for 5 min. Test Witnessed by AOGCC Rep. John Crisp and BP Drilling Supervisor Alan Madsen. Blind/ Shear Rams Failed, Replaced w/ Standard Blind Rams and Retested. Remove Test Plug Install Wear Ring PJSM- P/U 6-3/4" Directional OBb Lateral Drilling BHA, Bit-Motor (1.5 deg. bend)-Bypass Sub-Stabilizer- Lead Collar-MWD /LWD-VPWD-ADN-2x Flex Collars-Circulating Sub-XO-1 Jt.4" DP-Jars-2 Jts. 4" DP = 303.48' Total Length. Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 10 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date !From - To l Hours I Task I Code I NPT ~I Phase 6/20/2005 17:30 - 20:00 2.50 STWHIP P 20:00 - 23:00 3.00 STWHIP P 23:00 - 00:00 I 1.001 STWHIPI P 6/21/2005 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 6/22/2005 100:00 - 02:30 02:30 - 03:00 03:00 - 12:00 12:00 - 16:30 16:30 - 17:00 17:00 - 19:00 19:00 - 20:30 20:30 - 00:00 6/23/2005 100:00 - 03:00 03:00 - 06:00 2.50 DRILL P 0.50 DRILL P 9.00 DRILL P 4.50 DRILL P 0.50 DRILL P 2.00 DRILL P 1.50 DRILL P 3.50 DRILL P 3.00 DRILL P 3.00 DRILL P W EXIT W EXIT WEXIT PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Description of Operations RIH w/ 4" DP t/ 6,741' M/U Top Drive and Break Circulation at 270 gpm / 2,100 psi. Log f/ 6,741' - U 6,800'. RA Tag at 6,734.5'. Log f/ 6,930'- t/7,020'. RA Tag at 6,900'. Log Run at 120 fpm. Obtain Drilling Parameters and ECD Baseline Benchmark Readings. Up Wt. 130K, Dn. Wt. 80K, Rt Wt. 100K, Circulating Pressures at 300 gpm. On Btm. 2,600 psi, Off Btm. 2,450 psi. Calc. ECD 10.19 at 270 gpm, Calc. ECD 10.55 at 300 gpm Directional drill 6.75" OBb lateral from 7,103' to 8,045', 5-15k wob, 300 gpm, 2,930 psi on bottom, 2,630 psi off bottom, 60 rpm, torque on bottom 5.1 k, torque off bottom 4.4k, Calculated ECD 10.43, Actual ECD 11.05, AST = 2.23 hrs, ART = 2.04 hrs. Directional drill 6.75" OBb lateral from 8.045" to 9,347', 5-15k wob, 290 gpm, 3,250 psi on bottom, 2,850 psi off bottom, 60 rpm, torque on bottom 8.4k, torque off bottom 5.4k, Pumped sweep ~ 8,692' slight increase in cuttings. Calculated ECD 10.80, Actual ECD 11.23, AST = 2.02 hrs, ART = 3.64 hrs. Directional drill 6.75" OBb lateral from 9,347' to 9,658 5-15k wob, 290 gpm, 3,250 psi on bottom, 2,850 psi off bottom, 60 rpm, torque on bottom 8.4k, torque off bottom 5.4k, Pumped sweep 9,627' no increase in cuttings. Calculated ECD 11.05, Actual ECD 11.78. Circulate to reduce ECD, lower ECD from 11.78 to 11.43, clean hole ECD 11.12. Continue drilling 6.75" OBb lateral from 9,658' to 10,561' 5-10k wob, 290 gpm, 3,210 psi on bottom, 3,050 psi off bottom, 60 rpm, torque on bottom 8.4k, torque off bottom 5.4k, Up wt = 145k, do wt = 60k, rt wt = 97k, calculated ECD 11.11, Actual ECD 11.65, AST = 1.30 hrs, ART = 2.78 hrs Drill 6.75" OBb lateral from 10,561' to 11,401' 5-10k wob, 290 gpm, 3,340 psi on bottom, 3,030 psi off bottom, 60 rpm, torque on bottom 7.4k, torque off bottom 6.8k, up wt = 160k, do wt = 50k, rt wt = 90k, calculated ECD 11.12, Actual ECD 11.84, AST = 1.08 hrs, ART = 1.80 hrs Circulate, reduce ECD from 11.84 to 11.46 Drill from 11,401' to 11,504' ECD increased from 11.46 to 11.80, AST = .17 ART = .10 Circulate to reduce ECD from 11.78 to 11.40 Control drill at 200 fph to maintain an ECD of not more than .60 over clean hole. from 11,504 to 11,775' 2-5k wob, 287 gpm, 3,050 psi on bottom, 2,985 psi off bottom, 65 rpm, torque on bottom 7.4k, torque off bottom 6.8k, up wt = 150k, do wt = 60k, rt wt = 95k, calculated ECD 11.06, Actual ECD 11.46, AST = .22 hrs, ART = 1.16 hrs. Control drill at 200 fph to maintain ECD with set limit of .06 from 11,775' to 12,115' TD early due to low resistivity, 2-5k wob, 290 gpm, 3,150 psi on bottom, 3,010 psi off bottom, 60 rpm, torque on bottom 7.8k, torque off bottom 6.6k, up wt = 143k, do wt = 61 k, rt wt = 95k, calculated ECD 10.98, Actual ECD 11.48, AST = .27 hrs, ART = 1.88 hrs. Circulate bottoms up, 300 gpm, 3180 psi, 80 rpm, torque 7.2k, Pump 20 bbl high vis sweep weighted to 11.5 ppg around C~3 Printed: 7!18/2005 11:22:29 AM BP EXPLORATION Page 11 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code ~ NPT ~ Phase ~ Description of Operations 6/23/2005 03:00 - 06:00 3.00 DRILL P PROD2 300 gpm, 3,180 psi, increase rpm to 120 while pumping sweep, 06:00 - 10:30 10:30 - 11:00 11:00 - 13:30 13:30 - 16:30 16:30 - 19:00 19:00 - 20:30 20:30 - 00:00 6/24/2005 00:00 - 01:00 01:00 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 11:00 11:00 - 11:30 11:30 - 12:00 12:00 - 17:00 17:00 - 18:30 18:30 - 19:00 19:00 - 19:30 19:30 - 00:00 6/25/2005 00:00 - 02:00 torque 7.5k, had a 30% increase in cuttings when sweep came back, with larger (pencil lead) sized cuttings. 4.50 DRILL P PROD2 Monitor well, POH from 12,115' to to 7,000', hole taking proper till, no problem pulling through window, monitor well. 0.50 DRILL P PROD2 Service Topdrive. 2.50 DRILL P PROD2 RIH from 7,000' to 12,115', taking 10 to 15k wieght from 11,050' to 11,850', no other hole problems. 3.00 DRILL P PROD2 Make up topdrive and break circulation, intial rate 300 gpm, 3,565 psi, 80 rpm, torque 8.1 k, ECD 11.98. Reduce circulating rate to 235 gpm, 2,500 psi, 40 rpm for first bottoms up, ECD had dropped to 11.35. Pumped 20 bbl weighted sweep (11.3 ppg) Cam? 300 gpm 3,514 psi, rotating 120 rpm, reduced rpm to 80 when sweep was up inside casing. no noticable increase in cuttings when sweep at surface. 2.50 DRILL N DFAL PROD2 Attempt to down link MW D tools to faster data rate, down link was unsuccessful 1.50 DRILL P PROD2 Displace well to SFMOBM, @ 230 gpm, 2205 psi, 80 rpm, torque 8.5k 3.50 DRILL P PROD2 Monitor well, POH from 12,115' to 7,000', record up and down weights every 5 stands in open hole, no problems pulling through window. 1.00 DRILL P PROD2 Monitor well, drop 2" ball to open circ sub, pump to seat @ 160 gpm 850 psi, sheared at 1,070 psi. Pump dry job, blow down topdrive. 3.00 DRILL P PROD2 POH from 7,000' to BHA, recording up and down weights every 10 stands. monitor well at BHA. 1.50 DRILL P PROD2 PJSM, lay down BHA, remove sources, clear floor of all directional tools. 0.50 FISH P PROD2 Clean floor, P/U Baker fishing tools to rig floor. 2.00 FISH P PROD2 Make up Whipstock retrieval BHA, Retrieval hook, 1 jt 3 1/2' HWDP,float sub, MWD, bumper sub, oil jar, 12 4 3/4" drill collars,XO, 18 jts 4" HWDP and 1 stand 4" DP to 1,011'. 0.50 FISH P PROD2 Shallow test MWD, 230 gpm, 650 psi, ok. 2.50 FISH P PROD2 RIH with whipstock retriving assembly from 1,011' to 7,043', fill DP C~3 4,276' 0.50 FISH P PROD2 Make up topdrive and break circulation, orient retrieving lug C~ 19L, Up wt = 150k, do wt = 85K, slack down to 7,078', Picked up to engage fish, pulled up to 175K, allow jars to bleed open, pulled up to release bottom anchor, released @ 215K, pulled seals from from seal bore extension, 165k, once clear up wt = 150k, monitor well, static: 0.50 FISH P PROD2 Circulate bottoms up ~ 250 gpm, 1,485 psi, no gas at bottoms up, Monitor well, dead. 5.00 FISH P PROD2 POH slowly with whipstock, rack back HWDP and collars. 1.50 FISH P PROD2 Lay down fishing BHA, break and lay down whipstock and related tools. 0.50 FISH P PROD2 Clear floor of Baker fishing tools, Clean floor. 0.50 CASE P RUNPRD Rig up to run 4.5" slotted liner. 4.50 CASE P RUNPRD PJSM, run 4.5" 12.6# L-80 IBT -BTC slotted liner to 1,810', per running detail, dope with BOL 2000, make up torque 2,400 fUlbs. 2.00 CASE P RUNPRD Continue running 4.5" 12.6# L-80 IBT- BTC OBb slotted liner Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Start: 6/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date ~; From - To I Hours I Task I Code ~ NPT -- 6/25/2005 00:00 - 02:00 2.00 CASE P 02:00 - 02:30 0.50 CASE P 02:30 - 04:30 2.00 CASE P 04:30 - 05:00 I 0.501 CASE I P 05:00 - 08:30 I 3.501 CASE I P 08:30 - 09:30 I 1.001 CASE I P 09:30 - 10:00 I 0.501 CASE I P 10:00 - 11:00 1.00 CASE P 11:00 - 14:30 3.501 CASE I P 14:30 - 15:30 1.00 CASE P 15:30 - 16:00 0.50 TIEBAC P 16:00 - 18:30 2.50 TIEBAC P 18:30 - 22:00 3.50 TIEBAC P 22:00 - 23:30 1.50 TIEBAC P Page 12 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Phase C Description of Operations RUNPRD per running detail, record up and down weights every 25 joints. Make up Baker hook hanger assembly. Up wt = 70k, do wt = 59k. Ran a total of 76 joints 4.5" 12.6# L-80 IBT slotted liner, 6 joints 4.5" 12.6# BTC slotted liner, 1 4.5" 12.6# L-80 Slotted crossover joint, 13 joints 4.5" 12.6# L-80 IBT solid liner, 2 swell packers, baker hook hanger and 1 4.5" 12.6# L-80 IBT bent joint with float shoe. Ran a total of 94 5 3/4" straight blade rigid centralizers. RUNPRD Rig down casing tongs, change over to 4" handling equipment. RUNPRD RIH with OBb slotted liner on 4" DP, to 7,043' Recording up & down weights every 1000' in casing. RUNPRD Position bent joint at the top of the window ~ 7,072' Up wt = 111 k do wt = 79k, slack off slowly, saw a 5-5K increase in drag, continued down tagged up on OBd liner top extension @ 7,127' pulled back to 7,040' make up topdrive and establish rotation 2 rpm torque 2.8 to 3k, rotate C~3 2 rpm while slacking off to the middle of the window saw a slight increase in torque 200-300 fUlbs, shut down rotary, continued RIH slowly, bent joint exited window.. RUNPRD Continue RIH with OBb slotted liner, record up & down weights every 500' in open hole. RUNPRD Make up topdrive, slowly slack off to engage hook wall hanger, ran in 10' past bottom of the window, pulled 20' above top of the window. Up wt = 175k, do wt = 70k, rotate string 3/4 turn and work torque down, slack off slowly engaged hook wall hanger,set down 15k, picked up several times to confirm hanger hooked, marked pipe pulled up above window, rotate string 1/2 turn, and worked hanger 10' past bottom of window, pulled back up and oriented pipe to original mark and engaged hook hanger in the same place. RUNPRD Drop 29/32" ball and pump to seat, 2 bpm 500 psi, pressured up to 2,800 psi to release hydraulic setting tool, picked up to confirm released, pressure up to 3,400 psi and sheared ball seat. RUNPRD Circulate bottoms up, 350 gpm, 2200 psi, monitor well, pump dry job. RUNPRD POH with running tool, make service breacks and lay down running tool. clear floor. RUNPRD Cut and slip drilling line, service rig and topdrive. OTHCMP Rig up handling tools to run LEM and hanger assembly. OTHCMP Make up,non locating seal assembly, 2 4.5" 12.6# IBT pup joints, LEM assembly, Baker seal bore extension with swivel, made up 2 7/8" inner siting, ZXP packer assembly and HR running tool. OTHCMP RIH with LEM on 4" Dp to 7,052' OTHCMP Make up topdrive, break circulation, up wt = 140k, do wt = 95k, slack off slowly while seal assembly and inner string pass through hook hanger assembly, wash down slowly ~ 3 bpm, 450 psi as inner string enters seal bore extension, set down 25k when non locating seal assembly entered the seal bore extension, 300 psi increase, Pulled inner string 10' above seal bore extension, rotate string 3/4 turn and worked torque down, washed down slowly, taking 5-10k as seal assembly entered Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 13 of 21 Operations Summary Report Legal Well Name: L -202 Common W ell Name: L -202 Spud Date: 6/5/2005 Event Nam e: DRILL+COMPLE TE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours ~I Task Code ~ NPT ~! Phase ~ Description of Operations 6/25/2005 22:00 - 23:30 1.50 TIEBAC P OTHCMP seal bore, set down 30k with seal assembly 9' into seal bore, worked string back up no overpull, washed back down to calculated latch up depth, set down 50k, pulled up to 150k 10k over to confirm LEM was engaged. Set down 40k drop 1 3/4" ball and pump to seat 160 gpm, 815 psi, pressure up to set ZXP packer, and release from setting tool, indication of packer set C~ 4000 psi continue to pressure up to 4,200 psi. Bled pressure to zero picked up on string to confirm HR tool released, up wt 140k set down 50K. Close annular and test ZXP packer to 1,500 psi for 5 min ok. bled of pressure. 23:30 - 00:00 0.50 TIEBAC P OTHCMP POH with inner string and setting tool to 6,872' 6/26/2005 00:00 - 00:30 0.50 TIEBAC P OTHCMP Monitor well, pump dry job. 00:30 - 04:00 3.50 TIEBAC P OTHCMP POH with running tool and 2 7/8" inner string. 04:00 - 05:30 1.50 TIEBAC P OTHCMP lay down running tool, rig up 2 7/8" handling equipment, lay down 2 7/8" inner string. 05:30 - 06:00 0.50 TIEBAC P OTHCMP Clear and clean floor. 06:00 - 09:30 3.50 STWHIP P WEXIT Pickup whipstock and milling assembly for OBa lateral per ( Baker Rep. Orient MWD RIH with 12 4 3/4" drill collars and 18 ' ' joints 4 HW to 1,084 09:30 - 10:00 0.50 STWHIP P WEXIT Shallow test MWD, 280 gpm, 1050 psi, ok. 10:00 - 13:00 3.00 STWHIP P WEXIT RIH with whipstock and milling assembly on 4' Dp to 6,961' 13:00 - 14:30 1.50 STWHIP P WEXIT Make up topdrive, break circulation, orient whipstock to 14L, up wt = 140k, do wt = 80K, wash down slowly, set down 20k on OBb liner tieback with locater sub, to set bottom trip anchor, Picked up 10k to verify anchor set, set down 40k and shear oft whipstock. Top of whipstock ~ 6,946' Bottom of whipstock C~3 6,958' 14:30 - 15:30 1.00 STWHIP P WEXIT Displace well over to 9.2 ppg MOBM, 295 gpm, 2,070 psi. 15:30 - 19:00 3.50 STWHIP P WEXIT Mill window from 6,946' to 6,958, 305 gpm, 2145 psi, 2-6k wob, 60 - 100 rpm, torque 5-8k 19:00 - 21:00 2.00 STWHIP P WEXIT Mill formation from 6,958' to 6,976', 305 gpm, 2,150 psi, 2-4k wob 115 rpm, torque 5-6k, 21:00 - 22:00 1.00 STWHIP P WEXIT Pump 35 bbl weighted (11.2 ppg) sweep, rotate mills through window several times, worked through with no rotation, clean window, considerable amount of metal back with sweep. 22:00 - 22:30 0.50 STWHIP P WEXIT Monitor well, Pump dry job. 22:30 - 00:00 1.50 STWHIP P WEXIT POH with milling assembly. 6/27/2005 00:00 - 02:00 2.00 STWHIP P WEXIT POH with window milling assembly. Stand back HWDP & 4 3/4" drill collars. Lay down MWD, mills and bumper sub. Upper string mill in gauge 02:00 - 02:30 0.50 DRILL P PROD3 Clear floor of all milling tools and related equipment, clean floor. 02:30 - 03:30 1.00 DRILL P PROD3 Make up ported sub and flush stack, function rams and annular, blow down kill and choke lines. 03:30 -04:00 0.50 DRILL P PROD3 Pick up directional tools to rig floor, service rig, held PJSM. 04:00 - 06:00 2.00 DRILL P PROD3 Make up 6 3/4" OBa drilling assembly, Utilizing RR Hycalog DSX146 form previous lateral, AIM motor, bypass sub, 6 3/4' OD NM stab, NM lead collar,MWD, PWD, ADN, 2 flex drill collars, cir sub, XO, 1 joint 4" DP, jars, 2 jts 4" DP. Shallow test MWD, 242 gpm, 1,100 psi, ok. 06:00 - 09:30 3.50 DRILL P PROD3 RIH with drilling assembly on 4" DP to 6,926' Printed: 7/7 S/2005 11:22:29 AM BP EXPLORATION Page 14 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task 6/27/2005 09:30 11:00 1.50 DRILL Code NPT ~ Phase .Description of Operations P PRODS Make up topdrive, break circulation, circulate bottoms up 271 gpm, 2,165 psi. establish base line ECD, ~ 271 gpm, 60 rpm, calculated ECD 9.96, actual 10.24, C~ 290 gpm, 60 rpm, calculated ECD 9.99, actual 10.33. PRODS Directional drill 6.75" hole from 6,976' to 7,020', 5k wob, 290 gpm, 2,480 psi on bottom, 2,400 psi off bottom, up wi = 115k, do wt = 85k, rt wt = 90k. AST = .26 PRODS Directional drill 6.75" hole from 7,020' to 8,228', 5-10k wob, 290 gpm, 2,680 psi on bottom, 2,550 psi off bottom, 60 rpm torque on bottom 6.2k, torque off bottom 5.6k, up wt = 131 k, do wt = 76k, rt wt = 82k. Caluculated ECD 10.66 Actual 10.88, AST = 3.60 hrs. ART = 1.59 hrs. PRODS Directional drill 6.75" hole from 8,228' to 9,533', 5-10k wob, 290 gpm, 3,000 psi on bottom, 2,820 psi off bottom, 60 rpm torque on bottom 7.6k, torque off bottom 7.3k, up wt = i39k, do wt = 77k, rt wt = 99k. Calculated ECD 10.89 Actual 11.17, AST = 1.55 hrs ART = 2.89 hrs. PRODS Directional drill 6.75" hole from 9,533' to 11,02T, 5-10k wob, 290 gpm, 3,180 psi on bottom, 3,060 psi off bottom, 60 rpm torque on bottom 7.7k, torque off bottom 7.4k, up wt = 145k, do ' wt = 54k, rt wt = 95k. Calculated ECD 10.98 Actual 11.17, AST = 1.88 hrs ART = 3.12 hrs. PRODS Directional drill 6.75" hole from 11,027' to 11,886' 5-10k wob, 290 gpm, 3,270 psi on bottom, 3,150 psi off bottom, 60 rpm torque on bottom 7.Sk, torque off bottom 7.6k, up wt = 146k, do wt = 64k, rt wt = 97k. Calculated ECD 11.04 Actual 11.48, AST = 1.08 hrs ART = 1.69 hrs. PRODS Circulate 2 open hole annular volumes at 289 gpm, 3260 psi, 80 rpm, 7k torque. PRODS Backream out from 11,886' to 6,923', 290 gpm, 2,860 psi, 60 rpm 5-7k torque, C~3 30 to 50 fpm. no hole problems during backreaming. PRODS Service rig. PRODS Cut and slip drilling line. PRODS RIH from 6,923' to 11,775', hole clean, no problems. PRODS Wash last stand to bottom from 11,775' to 11,886', pump 25 bbl weighted sweep (11.2 ppg) at 290 gpm, 3,250 psi, 100 rpm, 8.2k torque, minimal amont of cuttings increase at bottoms up. PRODS Displace well to 9.2 ppg SFMOBM at 290 gpm, 3250 psi, 100 rpm 8k torque, Flnal ECD prior to POH calculated 11.07, actual 11.10. PRODS Monitor well, POH from 11,886' to 11,213' PRODS POH from 11,213' to 6,904', pulled smooth, no problems, hole took proper fill. PRODS Drop 1 3/4" ball to open circ sub, pump to seat C~? 220 gpm 1,440 psi, sheared ~ 1500 psi, pump dry job. PRODS POH from 6,904' to 302' monitor well C~ BHA PRODS PJSM, stand back jars and flex collars, recover sources, lay down MW D, motor and bit. RUNPRD Clear and clean floor, pickup whipstock retriving tools to rig floor. RUNPRD Make up Baker fixed lug retriving tool, 1 jt 3.5" HWDP, float sub, MW D, bumper sub, fishing jar, 12 4 3/4" drill collars, XO, 11:00 - 12:00 1.00 DRILL P 12:00 - 00:00 12.00 DRILL P 6/28/2005 00:00 - 12:00 12.00 DRILL P 12:00 - 00:00 12.00 DRILL P 6/29/2005 00:00 - 07:00 7.00 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 16:30 8.50 DRILL P 16:30 - 17:00 0.50 DRILL P 17:00 - 17:30 0.50 DRILL P 17:30 - 20:00 2.50 DRILL P 20:00 - 21:30 1.50 DRILL P 21:30 - 23:00 I 1.501 DRILL I P 23:00 - 00:00 1.00 DRILL P 6/30/2005 00:00 - 01:30 1.50 DRILL P 01:30 - 02:00 I 0.501 DRILL ( P 02:00 - 04:30 2.50 DRILL P 04:30 - 06:30 2.00 DRILL P 06:30 - 07:00 I 0.501 WHIP I P 07:00 - 09:00 I 2.001 WHIP I P Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary ..Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Start: 6/3/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date From - To __ _ Hours Task i Code ~ __~ NPT Phase 6/30/2005 _ 07:00 - 09:00 2.00 _ WHIP P RUNPRD 09:00 - 09:30 0.50 WHIP P RUNPRD 09:30 - 12:30 3.00 WHIP P RUNPRD 12:30 - 13:00 0.50 WHIP P RUNPRD 13:00 - 14:00 I 1.001 WHIP I P I I RUNPRD 14:00 - 17:00 3.00 WHIP P RUNPRD 17:00 - 20:30 3.50 WHIP P RUNPRD 20:30 - 21:00 0.50 WHIP P RUNPRD 21:00 - 22:00 1.00 CASE P RUNPRD 22:00 - 00:00 I 2.001 CASE I P I (RUNPRD 7/1/2005 (00:00 - 04:00 I 4.001 CASE I P I I RUNPRD 04:00 - 04:30 0.50 CASE P RUNPRD 04:30 - 05:30 1.00 CASE P RUNPRD 05:30 - 06:00 0.50 CASE P RUNPRD 06:00 - 10:00 ~ 4.001 CASE P RUNPRD 10:00 - 10:30 0.501 CASE P RUNPRD 10:30 - 11:00 I 0.501 CASE I P I I RUNPRD Page 15 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Description of Operations 18 joints 4" HWDP to 1,012' Shallow test MW D, 260 gpm, 800 psi, ok. RIH from 1,012' to 6,889', fill pipe ~ 4,000' Make up topdrive and break circulation, orient retrieving lug C~? 14L, (detection problems with MW D) Up wt = 142k, do wt = 86K, work down to 6,953', Picked up to engage fish, pulled up to 178K, allow jars to bleed open, pulled up 235k before bottom trip anchor released, pulled seals from from seal bore extension, 160k up. Once out of tie back extension up wt = 145k, hole took 3 bbls with seals pulled from tie back, monitor well, static. Circulate bottoms up C~ 290 gpm, 1980 psi, no gas at bottoms up. Monitor well, pump dry job and POH with whipstock to 1,012'. Stand back 4" HWDP and 4 stands 4 3/4" drill collars, lay down retriving lug, break and lay down whipstock and related tools. Clear and clean floor. Rig up to run 4.5" slotted OBa liner PJSM with all rig personnel Run 4.5" 12.6# L-80 BTC - tBT slotted liner to 1,006', per running detail, dope with BOL 2000, make up torque 2,400 fUlbs. Continue running 4.5" 12.6# L-80 BTC OBa slotted liner per running detail, make up Baker hook hanger assembly. Up wt = 78k, do wt = 64k. Ran a total of 102 joints 4.5" 12.6# L-80 BTC slotted liner, 1 4.5" 12.6# L-80 Slotted BTC X IBT crossover joint, 6 joints 4.5" 12.6# L-80 IBT solid liner, 2 4.5" 12.6# L-80 BTC X IBT solid crossover joints, 2 4.5" L-80 IBT X BTC soild crossover joints, 2 swell packers, Baker hook hanger, 1 4.5" 12.6# L-80 IBT bent joint with float shoe and 1 4.5" 12.6# L-80 IBT space out pup. Ran a total of 115, 5 3/4" straight blade rigid centralizers. Rig down liner running equipment. RIH with 4.5" slotted liner on 4" DP to 6,891' Make up topdrive, break circulation, 2 bpm ~ 160 psi, up wt = 109k, do wt = 75k, wash down and position bent joint at the middle of the window @ 6,952', rotate string 3/4 turn, run bent joint through window. no excess down drag. Continue RIH with 4.5" Liner on 4" DP to 11,818', recording up and down weights every 500' in open hole. Make up topdrive, slowly slack off to engage hook wall hanger, ran in 10' past bottom of the window, pulled 10' above top of the window. Up wt = 173k, do wt = 83k, rotate string 3/4 turn and work torque down, slack off slowly engaged hook wall hanger on second attempt, set down 15k, picked up several times to confirm hanger hooked, Picked up above window up wt 185k, rotate string 1/2 turn, and worked hanger 10' past bottom of window, pulled back up and oriented pipe, re-engaged hook hanger at the same depth set down 35k. Drop 29/32" ball and pump to seat, 2 bpm 400 psi, pressured up to 2,700 psi to release setting tool, picked up to confirm released, pressure up to 3,200 psi and sheared ball seat. Pulled setting tool from Hook hanger up wt 145k. Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date i From - To 7/1 /2005 7/2/2005 - --T - 11:00 - 12:00 1.00 CASE I P RUNPRD 12:00 - 16:00 4.00 CASE P RUNPRD 16:00 - 17:00 1.00 CASE P RUNPRD 17:00 - 18:00 1.00 CASE P RUNPRD 18:00 - 18:30 0.50 CASE P RUNPRD 18:30 - 20:30 2.00 CASE P RUNPRD 20:30 - 00:00 3.50 CASE P RUNPRD 00:00 - 01:00 1.00 CASE P RUNPRD 01:00 - 01:30 0.50 CASE P RUNPRD 01:30 - 02:00 I 0.501 CASE I P I I RUNPRD 02:00 - 02:30 ~ 0.50 ~ CASE P ~ ~ RUNPRD 02:30 - 06:30 I 4.001 CASE I P I I RUNPRD L-202 L-202 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Hours ~~I Task ~ Code NPT Start: 6/3/2005 Rig Release: 7/11/2005 Rig Number: Phase 06:30 - 07:30 1.00 CASE P RUNPRD 07:30 - 08:30 1.00 CASE P RUNPRD 08:30 - 09:00 0.50 STWHIP P WEXIT 09:00 - 12:30 3.50 STWHIP P WEXIT 12:30 - 13:00 13:00 - 16:30 0.50 STWHIP P 3.50 STWHIP P WEXIT WEXIT 16:30 - 17:00 17:00 - 17:30 17:30 - 18:30 18:30 - 22:30 0.501 STWHIPI P 0.501 STWHIPI P 1.00 STWHIP P 4.00 STWHIP P WEXIT Page 16 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Description of Operations Circulate bottoms up 160 gpm, 610 psi. Monitor well, pump dry job, POH with hook hanger running tool. break and lay down same. Service rig and topdrive, change out topdrive saver sub. Rig up to run OBa LEM and inner string. PJSM with all rig personnel, picking up LEM. Make up, non locating seal assembly, 2 4.5" 12.6# IBT pup joints, LEM assembly, Baker seal bore extension with swivel. Rlg up false rotary table and 2 7/8" handling equipment. Make up 2 7/8" inner stting, ZXP packer assembly and HR running tool, per Baker rep. RIH with OBa LEM and inner string on 4" DP to 3,899' Continue running OBa LEM on 4" DP from 3,899' to 6,960' Make up topdrive and break circulation, 2 bpm, 430 psi. up wt = 147k, do wt = 101 k, wash down slowly from 6,960', saw slight pressure increase (50 psi) as inner string entered seal bore extension, continue washing down slowly, began taking weight 5-10k 4' from latching up, set down 30k, Pulled up to neutral weight 145k, latched up at calculated depth, pulled up to 160K to confirm latch, slack off to neuteral weight 145k. Drop 1 3/4" ball and pump to seat @ 3 bpm 775 psi, pressure up positive indication of packer setting @ 2,500 psi, (gained 15K weight) continue pressuring up to 3,200 psi to release setting tool, held pressure for 3 min, pressrue up to 4000 psi, set down 30k to equalize pressure, bleed pressure to zero, Picked up on string to confirm release, up wt 142k. Close annular and pressure up on annulus to 1,500 psi, good test. POH to 6,860'. Monitor well, pump dry job, POH with 2 7/8" inner string and running tool. Lay down LEM running tool and 2 7/8" inner string Clear floor of all liner running equipment, clean floor. Pickup window mills and whipstock relaeted tools to rig floor. Pickup whipstock and milling assembly for OA lateral per Baker Rep. Orient MWD RIH with 12 4 3/4" drill collars and 18 joints 4' HW to 1,202' Shallow test MWD, 255 gpm, 860 psi, ok. RIH with OA whipstock & milling assembly from 1,202' to 6,741'. Make up topdrive, break circulation, up wt = 145k, do wt = 85k, orient whipstock 16L, wash down to top of OBb liner tie back extension @ 6,885' set down 20k to set bottom trip anchor, picked up to verify anchor set, set down 35k to shear off wipstock. Top of Whipstock ~ 6,781' Bottom of Whipstock @ 6,793' WEXIT Close annular, pressure up on backe side to 1,500 psi to ensure seals properly set in tie back extension, ok. WEXIT Displace well to 9.2 ppg SFMOBM, 300 gpm, 2,130 psi. WEXIT Mill window for OA lateral from 6781' to 6,793', 2-4k wob, 300 gpm, 1950 psi, 75 rpm, torque 7k, good metal returns during milling operation, pumped 25 bbl weighted sweep Printed: 7!18/2005 11:22:29 AM BP EXPLORATION Page 17 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date From - To ~ Hours Task Code ! NPT Phase Description of Operations 7/2/2005 18:30 - 22:30 4.00 STWHIP P WEXIT (super-sweep) C~ 6,793' slight increase of metal cuutings. 22:30 - 00:00 1.50 STWHIP P WEXIT Mill formation from 6,793' to 6,810', 2-7k wob, 300 gpm, 1950 psi, 105 rpm torque 5k. 7/3/2005 00:00 - 01:00 1.00 STWHIP P WEXIT Pump 25 bbl weighted (11.2 ppg) sweep, (Super Sweep)rotate mills through window several times, worked miils through window several times with no rotation, no problem. slight increase in metal cuttings with sweep, Monitor well. 01:00 - 01:30 0.50 STWHIP P WEXIT POH from 6,810' to 6,698' 01:30 - 02:30 1.00 STWHIP P WEXIT Cut and slip drilling line. 02:30 - 03:00 0.50 STWHIP P WEXIT Pump dry job. 03:00 - 06:00 3.00 STWHIP P WEXIT POH with window milling assembly. 06:00 - 06:30 0.50 STWHIP P WEXIT Lay down mills, bumper sub and MWD. Upper string mill in gauge. 06:30 - 07:00 0.50 STWHIP P WEXIT Lay mills and related equipment off floor. Pull wear ring. 07:00 - 07:30 0.50 BOPSU P WEXIT Make up ported sub, flush stack, function rams and annular. 07:30 - 08:30 1.00 BOPSU P WEXIT Drain stack, blow down mud line, choke and kill lines, Install test plug, rig up BOP test equipment. 08:30 - 12:00 3.50 BOPSU P WEXIT Test BOPE to 250 psi low, 3,500 psi high, per testing procedure. Chuck Scheeve with AOGCC waived witness of BOP test. Test was witnessed by WSL BiII Decker, Nabors Toolpusher Bill Bixby. 12:00 - 13:00 1.00 BOPSU P WEXIT Blow down choke, choke line and kill line, pull test plug and install wear ring. 13:00 - 15:00 2.00 DRILL P PROD4 Make up 6 3/4" OA drilling assembly, Utilizing RR Hycalog DSX146 form previous 3 laterals, AIM motor, bypass sub, 6 3/4' OD NM stab, NM lead collar,MWD, PWD, ADN, 2 flex drill collars, cir sub, XO, 1 joint 4" DP, jars, 2 jts 4" DP to 570' Shallow test MWD, 291 gpm, 1,380 psi, ok. 15:00 - 18:00 3.00 DRILL P PROD4 RIH with OA lateral drilling assembly on 4" DP from 570' to 6,750', fill DP @ 3,567' 18:00 - 19:30 1.50 DRILL P PROD4 Circulate bottoms up @ 290 gpm, 2360 psi, obtain ECD bench mark, Calculated ECD 10.32 19:30 - 20:30 1.00 DRILL P PROD4 Orient motor, slide through window with no pump to 6,800' ream from 6,800' to 6,810' with motor. 20:30 - 00:00 3.50 DRILL P PROD4 Directional drill 6 75" hole by sliding from 6,810' to 7,020', 5-10k wob, 290 gpm, 2,400 psi on bottom, 2300 psi off bottom, up wt = 120k do wt = 81 k, Calculated ECD 10.24, Actual 10.12 AST = 1.7 hrs. 7/4/2005 00:00 - 12:00 12.00 DRILL P PROD4 Directional drill 6.75" hole from 7,020' to 8,506' S-10k wob, 290 gpm, 2,750 psi on bottom, 2,600 psi off bottom, 60 rpm torque on bottom 6.7k, torque off bottom 5.3k, up wt = 128k, do wt = 78k, rt wt = 98k. Pumped 15 bbl weighted (11.2) sweep C~ 7,900' no visible increase in cuttings. Calculated ECD 10.29 Actual 10.53, AST = 1.5 hrs ART = 3.28 hrs. 12:00 - 15:30 3.50 DRILL P PROD4 Directional drill 6.75" hole from 8,506' to 8,941' 5-10k wob, 290 gpm, 2,800 psi on bottom, 2,650 psi off bottom, 60 rpm torque on bottom 6.4k, torque off bottom 5.7k, ECD began climbing at 8900' Calculated ECD 10.45, actual 11.17. 15:30 - 17:30 2.00 DRILL P PROD4 Pump 15 bbl high vis sweep around C~3 290 gpm, 2700 psi, 60 rpm, approximately 30% increase in cuttings, ECD dropped to 10.65 17:30 - 00:00 6.50 DRILL P PROD4 Directional drill 6.75" hole from 8,941' to 9,440', Pumped 15 bbl high vis sweeps @ 9,000' & 9,250' no visible increase in Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To Hours Task Code'" NPT _--- 7/4/2005 17:30 - 00:00 ~ 6.50 DRILL P 7/5/2005 100:00 - 06:00 6.00 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 12:30 I 5.501 DRILL I P 12:30 - 13:00 0.50 DRILL P 13:00 - 13:30 0.50 DRILL P 13:30 - 16:00 2.50 DRILL P 16:00 - 16:30 0.50 DRILL P 16:30 - 18:00 1.50 DRILL P 18:00 - 20:00 I 2.001 DRILL I P 20:00 - 22:00 I 2.001 DRILL I P 22:00 - 00:00 2.00 DRILL P /6/2005 00:00 -04:00 4.00 DRILL P 04:00 - 06:00 I 2.001 DRILL I P 06:00 - 07:30 I 1.50 I WHIP I P 07:30 - 09:30 2.00 WHIP P 09:30 - 10:00 0.50 WHIP P 10:00 - 11:00 I 1.001 WHIP I P Start: 6/3/2005 Rig Release: 7/11/2005 Rig Number: Page 18 of 21 Spud Date: 6/5/2005 End: 7/11/2005 Phase Description of Operations PROD4 cuttings, YP increased from 16 to 23 due to sweeps. 5-10k wob, 290 gpm, 2830 psi on bottom, 2,760 psi off bottom, 60 rpm, torque 6.4k on bottom, 5.7k off bottom, up wt = 124k, do wt = 76k, rt wt = 98k, Calculated ECD 10.83, actual 11.12. AST = 1.0 hrs, ART = 2.52 hrs. PROD4 Directional drill 6.75" hole from 9,440', to 10,345', 5-10k wob, 290 gpm, 2,975 psi on bottom, 2,805 psi off bottom, 60 rpm, torque 7.5k on bottom, 6.5k off bottom, up wt = 131 k, do wt = 68k, rt wt = 92k, Calculated ECD 10.98, actual 11.37. AST = 1.13 hrs, ART = 2.37 hrs. PROD4 Circulate 2 x bottoms up, 300 gpm, 3,000 psi, 80 rpm. Calculated ECD - 10.98, Actual ECD - 11.24. PROD4 PU - 145k, SO - 77k without pumps. Monitor well -stable. Backream from 10,345' to 8,930' - TO 6.5k, 300 gpm, 60 rpm. The hole started to pack off at 8,930' while backreaming. Work pipe back down to 8,972'. Shut off the pumps and rotary and pull dry from 8,972' to 8,879' - 15k overpull. RIH to 8,972'. Backkream to 8,879'. Shut off the pumps and rotary and pull dry from 8,879' to 8,785'. RIH to 8,879'. Backream to 8,600' without problem. PROD4 RIH from 8,600' to 8,972' without problems. PROD4 POH from 8,972' to 8,600', PU - 135k, SO - 87k -minimal overpull. PROD4 Backream from 8,600' to 7,113', TO - 6.5k, 300 gpm, 60 rpm. PROD4 Circulate bottoms up - 300 gpm, 2,500 psi, 60 rpm, TO - 4k. PROD4 Pull pipe into the window to 6,740' - no problems. Cut and slip 85' of drilling line. Service the top drive, draw works, crown and blocks. PROD4 RIH from 6,740' to 10,345'. Wash the last stand to bottom. No problems. PROD4 Circulate open hole volume and hi visc/weighted sweep from surface to surface - 300 gpm, 3,100 psi, 80 rpm, TO - 6.3k. Circulate additional bottoms up to ensure hole clean prior to displacement to SFMOBM. PROD4 Displace the 9.2 ppg MOBM to 9.2 ppg SFMOBM - 300 gpm, 3,100 psi, 80 rpm, TO - 6.3k. PROD4 POH from 10,345' to 6,740'. Open up the circ sub and pump a dry job. POH from 6,740' to the top of the BHA at 303'. PROD4 PJSM. LD 6-3/4" OA BHA - 2 jts 4" DP, jars, 1 joint 4" DP, XO, circ sub, 2 flex drill collars, ADN, PWD, MWD, NM lead collar, 6 3/4' OD NM stab, bypass sub, AIM motor, 6-3/4" RR DS146h+gjnw. Bit graded: 0 / 2 / WT / G / X / I / ER / TD. Clear and clean the floor. RUNPRD MU Whipstock #3 Retrieving BHA to 1,012' -fixed lug retrieving tool, 1 x 3.5" HWDP, float sub, MWD, bumper sub, fishing jar, 12 x 4-3/4" drill collars, xo, 18 x 4" HWDP. RUNPRD RIH to 6,750' to retrieve Whipstock #3 RUNPRD PU - 134k, SO - 85k. Orient the retrieving tool to 16 left. Work the lug down the whipstock face. Latch into the retrieval slot. PU to 200k and fire the fishing jars. Pull free with PU - 145k. Lost approximately 3 bbls of fluid when the whipstock released. POH to 6,724'. RUNPRD Circulate bottoms up - 3 bpm, 550 psi. Monitor well -stable. Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary .Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Start: 6/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT . - __ __ - --~ --I. Phase _ - -- - 7/6/2005 11:00 - 14:30 3.50 WHIP P RUNPRD 14:30 - 17:30 3.00 WHIP P RUNPRD 17:30 - 19:00 1.50 CASE P RUNPRD 19:00 - 20:00 1.00 CASE P RUNPRD 20:00 - 00:00 4.00 CASE P RUNPRD 7/7/2005 ~ 00:00 - 02:00 2.00 CASE P ~ 1 RUNPRD 02:00 - 05:00 I 3.001 CASE I P I I RUNPRD 05:00 - 06:00 I 1.001 CASE I P I I RUNPRD 06:00 - 07:00 I 1.001 CASE I P I I RUNPRD 07:00 - 11:00 I 4.001 CASE I P I I RUNPRD 11:00- 13:30 I 2.501 TIEBAC I P I I OTHCMP 13:30 - 18:00 4.50 TIEBAC P OTHCMP 18:00 - 19:30 1.50 TIEBAC P OTHCMP Page 19 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Description of Operations POH from 6,724 to 1,012' Stand back 18 x 4" HWDP and 12 x 4-3/4" drill collars. LD remaining Whipstock #3 Retrieving BHA -fishing jar, bumper sub, MW D, float sub, 1 x 3.5" HWDP, fixed lug retrieving tool, whipstock #3. PU 12 x drill collars and stand back in the derrick. RU to run 4.5" OA liner. PJSM. PU 4.5", 12.6#, L-80, BTC Slotted /IBT-M Solid liner. Utilized Best-o-life 2000 thread lubricant on each connection and torqued to the mark - 3,400 ftlbs BTC, 3,000 ftlbs IBT-M. Continue PU 4.5", 12.6#, L-80, BTC Slotted /IBT-M Solid liner. Utilized Best-o-life 2000 thread lubricant on each connection and torqued to the mark - 3,400 ftlbs BTC, 3,000 ftlbs IBT-M. MU Hookwall Hanger and RIH on 4" DP to the window 6,781'. RIH past the windowand tag up on tieback sleeve #2 at 6,898'. POH and stand back 1 stand. Place the. shoe in the middle of the window and apply 1 wrap to the pipe. Exit the window. Continue RIH with 4.5" liner on 4" DP, HWDP and 4-3/4" collars. PU - 161 k, SO - 90k. RIH 10' past the bottom of the window to 6,803'. PU 12' above the window and apply 1/4 turn to the pipe. Repeat. RIH 10' past the bottom of the window. PU 12' above the window and apply 1/4 turn to the pipe. RIH and land the hookwall hanger on the bottom of the window at 6,793'. PU 12' and apply 1/2 turn. RIH to 10' past the bottom of the window. PU 12' above the window and apply 1/4 turn to the pipe. RIH 10' past the bottom of the window. PU 12' above the window and apply 1/4 turn to the pipe. RIH and re-land the hookwall hanger with 65k. Drop the ball. Pump the ball down on seat. Pressure up to 3,000 psi to release the hanger, PU - 144k, verifying release. Increase pressure to 4,000 psi to blow the ball seat. Monitor the well -stable. Circulate bottoms up at 340 gpm, 2,244 psi. Pump dry job. POH standing back HWDP, dc's and 4" DP. LD hookwall hanger running tool. Clear and clean the floor. Bring LEM #3 tools and materials to the rig floor. MU non-locating seal assy, xo joint, 1 joint 4.5", 12.6#, L-80, IBT-M liner, 2 pups, LEM hanger, pup, casing swivel, xo and zxp packer with 11' tieback with 11' of 2-3/8" inner string. RIH with LEM assy on 4" DP, HWDP and drill collars to 6,888'. PU - 142k, SO - 103k. Screw in with the top drive and wash down into the seal bore extension. Observed intermittent 10k-15k drag. Continue down and engage the LEM. PU 15k to verify engagement. SO 35k and drop ball. Pump the ball on seat and pressure up to 4,000 psi to release the LEM and set the packer - no surface indication of packer set. PU and verify LEM release -released. Bleed off pressure from the drill pipe. Attempt liner top test to 1,500 psi - no go. Bleed pressure off of the back side. Apply 4,500 psi down the drill pipe to set packer. Bleed off pressure. Attempt 1,500 psi liner top test - no go. Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal. Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date ~ From - To ~ Hours I Task ~ Code ~ NPT I 7/7/2005 ~ 19:30 - 21:00 1.50 ~ TIEBAC P 21:00 - 21:30 0.50 TIEBAC P 21:30 - 23:00 1.50 TIEBAC P 23:00 - 00:00 1.00 TIEBAC P 7/8!2005 00:00 - 01:00 1.00 TIEBAC P 01:00 - 08:30 7.50 TIEBAC P 08:30 - 09:30 I 1.001 TIEBAC I N 09:30 - 10:30 ~ 1.00 ~ TIEBAC ~ P 10:30 - 14:30 4.00 TIEBAC N 14:30 - 20:30 6.00 TIEBAC N 20:30 - 22:00 1.50 TIEBAC P 22:00 - 22:30 0.50 TIEBAC P 22:30 - 23:30 1.00 TIEBAC P 23:30 - 00:00 0.50 TIEBAC P 7/9/2005 00:00 -04:30 4.50 TIEBAC P 04:30 - 05:30 1.00 BUNCO 05:30 - 08:00 2.50 BUNCO 08:00 - 18:00 ~ 10.00 18:00 - 20:30 2.50 HMAN HMAN HMAN Page 20 of 21 Spud Date: 6/5/2005 Start: 6/3/2005 End: 7/11/2005 I Rig Release: 7/11/2005 Rig Number: Phase I' Description of Operations OTHCMP PU and expose dogs. Set down 70k to set packer - no surface indication. PU and apply 12 rpm with 50k SO. Repeat. Attempt to test liner top packer by applying 1,500 psi down the backside - no go. Bleed off pressure. Apply 1,500 psi on the drill pipe and lock it in. Apply 1,500 psi down the backside to test the liner top packer -chart and hold for 30 minutes -good test. OTHCMP LD single and stand back 2 stands of 4" DP in the derrick. OTHCMP Pump 30 bbls of LVT, 25 bbls of hi-visc brine, 50 bbls of Safe-O spacers and displace the well over to 9.3 ppg brine. OTHCMP Clean under the shakers and the troughs. OTHCMP Continue to clean under shakers and troughs OTHCMP Pump dry job. LD HWDP, drill collars and 4" DP. LD LEM running tools and inner string. OTHCMP PU 1 stand of 4" DP and MU mule shoe. Pull stripping rubbers. Dropped a 1" thickx 3' long nylon sling down the hole. Did not seethe sling floating in the stack. Pump through {the line -did not find the sling. RIH with one stand of 4" DP. Circulate at 7 bpm, 60 psi and check the possum belly, flow lines, troughs and pill pit -did not find sling. Notify town and call out Slickline for fishing operation OTHCMP Service and lubricate the top drive, draw works, blocks and crown. OTHCMP Clean rig of the MOBM while waiting on Slickline. OTHCMP PJSM. RU Slickline. RIH with 4 prong rope grabber to 6,738'.. POH. Recovered dropped sling. RD slickline. OTHCMP RIH with 4" DP from the derrick to 6,600'. OTHCMP Circulate DP volume to clean out DP prior to laying down. OTHCMP Cut and slip 78' of drilling line. OTHCMP LD 4" DP from 6,600'. OTHCMP Continue to LD 4" DP from 6,600'. RUNCMP Pull wear ring and make dummy run with tubing hanger. RUNCMP RU 4.5" tubing handling tools, tongs, elevators and slips. MU floor safety valve. PU I-wire spool and hang sheave in the derrick. RUNCMP MU 4.5" 12.6# L-80 IBT-M completion and RIH to 6,651'. 4.5" completion includes: WLEG/X asst' (3.813" ID), X asst' (3.813" ID) w/RHC-m profile, 7.625" x 4.5" Baker Premier Packer asst', 4.5" Phoenix Jet Pump gauge asst', 4.5" Baker CMD/Phoenix 7" Discharge Pressure .gauge asst', 3 - 4.5" x 1" KBG-2 GLM's wfDV, 1 - 4.5" x 1" KBG-2 GLM's w/DCK SV, 155 joints of 4.5" 12.6# L-80 IBT-m tubing and X asst' (3.813" ID). Utilized BOL 2000 NM thread lubricant and torqued connections to mark with 3,200 ftlbs average make-up torque. Connections below the packer asst' have been Bakerlok'd. I-wire run from the Phoenix pressure gauge to surface RUNCMP MU 2 additional joints of 4.5" tubing and tag up at 6,759'. LD the 2 additional joints + joint #155 of 4.5" tubing. Add spaceout pups of lengths: 9.81', 9.80', 7.81', 3.81', 2.84' and 1.91'. PU joint #155 and RIH. MU the tubing hanger (1' of blast rings on pup below the hanger held in place with a stop collar). Run I-wire through the hanger and lock in place. Cut I-wire above hanger and secure to landing joint. Land the tubing on the Printed: 7118/2005 tt:22:29AM BP EXPLORAT{ON Operations Summary Report Page 21 of 21 Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING i Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: ~ ~ j I ~~ ~ Date ~ From - To ` Hours I Task Code NPT j Phase ~ Description of Operations 1-- '{^ 7/9/2005 118:00 - 20:30 12.5 BUNCO - - ~ - RUNCMP ~ ~ - - - I~P I I I hanger. Run in the lock down screws, RU circulation lines. WLEG - 6758' X Profile - 6730' X Profile w/RHC-M - 6710' Premier Packer - 6643' Jet pump sensor - 6619' CMD Non-elastomer sliding sleeve - 6595' Discharge pressure gauge - 6585' GLM#1 w/DCK -6479' GLM#2 - 6036' GLM#3 - 5007' GLM#4 - 3024' X Profile - 2258' Ran 85 clamps and 2 SS bands 20:30 - 21:30 1.00 BUNCO RUNCMP Reverse circulate 106 bbls of 9.3 ppg brine, 5 bbls of 9.3 ppg brine w/corrosion inhibitor and 170 bbls of 9.3 ppg brine to spot brine with corrosion inhibitor between the GLM with .the shear valve and the packer. 21:30 - 00:00 2.50 RUNGO RUNCMP Break out the circulation head on the rig floor. Drop the 1-7/8" ball and rod w/rollers and allow to seat in the RHC-m plug at 6710'. Pressure up on the tubing to 4,200 psi to set the packer. Bleed off pressure to 3,500 psi -chart and hold for 30 minutes -good test. Bleed pressure on the tubing down to 2,500 psi. Pressure up on the annulus to 3,500 psi -chart and hold for 30 minutes -good test. Bleed pressure on the annulus to 0 psi and then bleed the pressure to 0 psi on the tubing. Pressure up on the annulus to 3,100 psi and observe the shearing of the DCK in the GLM at 6479'. Ensure circulation down the tubing and up the annulus. 7/10/2005 00:00.- 01:30 1.50 BUNCO RUNCMP Blow down circulation lines. Install TWC and. test from below to 1,000 psi -good test. 01:30 - 03:00 1.50 BUNCO RUNCMP RU super sucker line to the rig floor and remove fluids from under the rotary table, pipe racks and mouse hole plate. 03:00 - 18:00 15.00 BUNCO RUNCMP RU "hotsy" and man rider basket. Scrub derrick and pit complex of MOBM. 18:00 - 20:00 2.00 BOPSU P WHDTRE ND BOPE. 20:00 - 00:00 4.00 WHSUR P WHDTRE NU adapter flange with I-wire penetration. NU 4-118" carbon tree. Test tree to 5,000 psi -good test. Pull TWC with DSM lubricator. RU to reverse circulate. 7/11/2005 00:00 - 00:30 0.50 WHSUR P WHDTRE RU circulation lines. Test to 3,000 psi -good. 00:30 - 01:30 1.00 WHSUR P WHDTRE Reverse circulate 106 bbls of 9.3 ppg brine + corrosion inhibitor. 01:30 - 04:00 2.50 WHSUR P WHDTRE RU LRHOS and reverse circulate 101 bbls of diesel freeze protection fluid. Allow fluids to U-tube. RD LRHOS. 04:00 - 06:30 2.50 WHSUR P WHDTRE Install BPV and test from below to 1,000 psi. Remove annulus working valves from the OA and the IA. Install VR plugs in tubing spool outlets. Release rig to L-03 t~? 0630 hours. Printed: 7/18/2005 11:22:29 AM L'LVL JUf VCY IZ~LJOft Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / L-202 Well: L-202 Borehole: L-202 UWVAPI#: 500292322900 Survey Name I Date: L-202 /June 17, 2005 Tort /AHD / DDI / ERD ratio: 332.279° / 10303.89 ft / 6.981 / 2.177 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70 21 2.394, W 149 19 27.488 Location Gr{d WE YIX: N 5978293.250 ftUS, E 583223.800 ttUS Grid Convergence Angle: +0.63635414° Grid Scale Factor: 0.99990787 Survey / DLS Computation Method: Minimum Curvature / L~ Vertical Section Azimuth: 35.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 77.30 ft relative to MSL Sea Bed 1 Ground Level Elevation: 48.00 ft relative to MSL Magnetic Declination: 24.582° Total Field Strength: 57573.841 nT Magnetic Dip: 80.843° Declination Date: June 13, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> 7rue North: +24.582° • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure oTc ft de de ft ft ft ft ft ft ft de 100 it ftUS kUS v.vv v.vv v.uv -~ i.ov U.uU U.UU U.uU u.vu u.uu u.uu u.UU oartsLaa.[~ D25JLLJ.tSV N /U Z"I Z.Sy4 VV "14y 1y L/.4tit3 First MW D+IFR+MS 300.84 0.34 25.11 223.54 300.84 0.88 0.89 .0.89 0.81 0.38 0.11 5978294.06 583224.17 N 70 21 2.402 W 149 19 27.477 391.65 0.36 9.86 314.35 391.65 1.40 1.44 .1.44 1.33 0.54 0.10 5978294.59 583224.33 N 70 21 2.407 W 149 19 27.472 576.28 0.53 10.49 498.97 576.27 2.71 2.88 2.86 2.74 0.80 0.09 5978296.00 583224.57 N 70 21 2.421 W 149 19 27.464 670.46 0.56 14.93 593.15 670.45 3.53 3.77 3.75 3.62 0.99 0.05 5978296.88 583224.75 N 70 21 2.429 W 149 19 27.459 764.71 2.54 25.42 687.36 764.66 6.03 6.32 6.28 5.95 2.01 2.11 5978299.22 583225.74 N 70 21 2.452 W 149 19 27.429 857.53 4.53 18.44 780.00 657.30 11.57 12.03 11.99 11.28 4.05 2.19 5978304.58 583227.73 N 70 21 2.505 W 149 19 27.369 953.21 6.95 15.51 875.19 952.49 20.65 21.60 21.55 20.45 6.80 2.55 5978313.77 583230.37 N 70 21 2.595 W 149 19 27.289 1047.74 10.47 16.79 968.62 1045.92 34.20 35.91 35.85 34.19 10.81 3.73 5978327.55 583234.23 N 70 21 2.730 W 149 19 27.172 1142.12 13.77 15.29 1060.88 1138.18 52.93 55.73 55.66 53.24 16.25 3.51 5978346.66 583239.45 N 70 21 2.917 W 149 19 27.013 1236.19 16.95 13.24 1151.58 1228.88 76.21 80.64 80.55 77.39 22.34 3.43 5978370.88 583245.28 N 70 21 3.155 W 149 19 2~ 1330.83 19.13 11.06 1241.56 1318.86 103.20 109.94 109.80 106.04 28.48 2.41 5978399.59 583251.10 N 70 21 3.436 W 149 19 2 . 1425.26 20.68 12.40 1330.35 1407.65 132.74 142.09 141.91 137.51 35.03 1.71 5978431.13 583257.29 N 70 21 3.746 W 149 19 26.464 1520.69 23.94 14.64 1418.62 1495.92 166.45 178.31 178.12 172.72 43.54 3.53 5978466.42 583265.42 N 70 21 4.092 W 149 19 26.215 1617.99 23.95 13.68 1507.55 1584.85 203.36 217.80 217.61 211.00 53.20 0.40 5978504.81 583274.65 N 70 21 4.469 W 149 19 25.933 1712.21 28.23 11.54 1592.15 1669.45 241.64 259.22 259.01 251.44 62.19 4.65 5978545.34 583283.18 N 70 21 4.866 W 149 19 25.670 1806.43 30.66 12.06 1674.19 1751.49 264.21 305.53 305.30 296.77 71.67 2.59 5978590.77 583292.16 N 70 21 5.312 W 149 19 25.393 1900.26 33.39 12.61 1753.74 1831.04 330.12 355.28 355.04 345.37 82.30 2.93 5978639.48 583302.25 N 70 21 5.790 W 149 19 25.082 1995.66 38.73 11.57 1830.83 1908.13 381.81 411.42 411.16 400.27 94.03 5.63 5978694.50 583313.37 N 70 21 6.330 W 149 19 24.740 2090.94 43.52 10.77 1902,58 , 1979.88 439.11 474.07 473.78 461.73 106.14 5.06 5978756.09 583324.80 N 70 21 6.935 W 149 19 24.385 2184.89 47.07 11.00 1968.66 2045.96 500.05 540.83 540.50 527.29 118.75 3.78 5978821.78 583336.68 N 70 21 7.579 W 149 19 24.017 2279.02 50.58 11,89 2030.63 2107.93 564.99 611.67 611.33 596.72 132.83 3.80 5978891.35 583349.98 N 70 21 8.262 W 149 19 23.606 2372.26 54.00 12.29 2087.65 2164.95 632.93 685.42 685.08 668.84 148.28 3.68 5978963.63 583364.63 N 70 21 8.971 W 149 19 23.154 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-2021L-202\L-202 Generated 7/5/2005 4:16 PM Page 1 of 7 Comments Measured Inclination Azimuth Sub-Sea ND ~/p Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS LYVV.G:J JV.JY IL.L I G 14 I. I~ LG 10.4y / V4. I0 (VG.VO 2560.42 58.25 12.15 2191.93 2269.23 777.27 841.99 2654.71 2749.60 2843.79 2939.01 3033.56 3128.08 3223.61 3302.79 3332.92 3427.34 3520.48 3614.60 3708.59 3803.17 3897.73 59.04 11 .60 2241.00 2318 .30 851.32 922.51 59.40 11 .73 2289.56 2366 .86 926.18 1004.03 59.44 11 .64 2337.47 2414 .77 1000.65 1085.12 59.34 11 .69 2385.96 2463 .26 1075.90 1167.07 58.86 11 .85 2434.51. 2511 .81 1150.45 1248.20 58.78 11.89 2483.45 59.32 12.07 2532.58 58.27 13.26 2573.60 58.16 12.74 2589.47 57.83 12.68 2639.52 59.11 12.46 2688.22 58.90 12.46 2736.69 58.76 12.33 2785.34 60.00 12.46 2833.51 59.55 12.44 2881.11 3991.42 60.14 12.38 2928.18 4085.47 60 .66 14. 91 2974.64 4180.85 62. 09 18. 79 3020.34 4275.50 62. 77 19. 74 3064.15 4369.33 61 .59 22. 65 3107.95 4463.07 60.92 24.56 4558.50 59.11 25.99 4652.08 58.36 27.82 4745.64 59.00 29.78 4840.53 59.04 32.79 4932.96 58.18 32.71 5029.33 57.47 34.52 5123.41 57.25 34.96 5217.80 58.51 34.97 5312.23 59.95 35.35 5405.78 61.32 35.70 5500.71 60,71 35.59 5596.24 61.46 38.08 5691.12 63.07 42.66 5785.12 63.56 47.61 5879.62 63.10 51.86 5973.89 60.96 55.76 6069.13 60.11 59.75 6163.57 61.29 64.17 2560.75 2609.88 2650.90 2666.77 2716.82 2765.52 2813.99 2862.64 2910.81 2958.41 3005.48 3051.94 3097.64 3141.45 3185.25 l OL.JI l~44.JL 104.07 841.64 821.86 181.40 922.15 900.65 197.97 1003.67 980.49 214.45 1084.76 1059.90 230.88 1166.70 1140.16 247.45 1247.83 1219.59 263.99 1328.70 1298.72 280.63 1410.62 1378.87 297.63 1478.34 1444.94 312.48 1503.95 1469.90 318.24 1584.02 1548.00 335.86 1663.40 1744.08 1824.50 1905.89 1987.60 2068.61 2150.35 2233.80 2317.14 2399.24 2480.08 2561.02 2638.97 2716.37 2794.38 2869.66 2947.31 3022.46 3098.40 3175.59 1625.49 1704.27 1782.81 1862.31 1942.09 2021.21 2100.67 2180.76 2259.96 2337.33 2412.63 2487.38 2558.71 2628.74 2698.25 1224.81 1300.22 1362.86 1386.60 1460.69 1534.07 1608.59 1682.83 1757.97 1833.43 1908.22 1984.37 2063.91 2144.67 2225.24 1329.07 1410.99 1478.72 1504.33 1584.40 1663.78 1744.47 1824.89 1906.28 1987.98 2068.99 2150.76 2234.48 2318.38 2401.36 3153.03 3230.33 2305.80 2483.54 3200.72 3278.02 2387.26 2566.20 3249.29 3326.59 2466.45 2646.18 3297.93 3375.23 2545.90 2726.11 3346.78 3424.08 2627.07 2807.46 3394.93 3472.23 2705.91 2886.36 3446.25 3523.55 2787.45 2967.93 3496.99 3574.29 2866.67 3047.15 3547.17 3624.47 2946.61 3127.09 3595.48 3672.78 3027.75 3208.22 3641.36 3687.36 3733.55 3777.73 3819.96 3862.39 3906.62 3953.46 3999.71 2764.61 2832.54 2897.64 2963.15 3029.48 353.13 370.54 387.80 405.27 422.89 440.30 459.59 483.87 511.55 541.54 574.45 609.73 645,92 684.42 726.66 769.34 814.49 859.64 905.45 952.18 3718. 66 3109.27 3289 .75 3253.19 3095.83 999.55 3764. 66 3192.31 3372 .79 3332.37 3163.31 1047.94 3810. 85 3275.88 3456 .41 3411.76 3230.23 1098.07 3855. 03 3359.45 3540 .37 3489.94 3294.17 1152.46 3897. 26 3442.09 3624 .35 3565.68 3353.38 1211.97 3939. 69 3523.73 3708 .79 3639.13 3407.95 1276.38 3983. 92 3602.53 3792 .04 3709.01 3457.12 1343.54 4030. 78 3678.97 3874 .95 3775.96 3501.35 1413.64 4077. 01 3752.35 3957 .30 3839.40 3540.04 1486.32 L./U oarauJy.ttl DtlJJi5U.1/ N /U Z1 y./"14 VV l4y Iy LZ.6/9 1.82 5979116.99 583396.05 N 70 21 10.476 W 149 19 22.186 0.97 5979195.96 583411.74 N 70 21 11.251 W 149 19 21.701 0.40 5979275.97 583427.33 N 70 21 12.037 W 149 19 21.219 0.09 5979355.55 583442.87 N 70 21 12.818 W 149 19 20.739 0.11 5979435.98 583458.55 N 70 21 13.607 W 149 19 20.255 0.53 5979515.58 583474.21 N 70 21 14.388 W 149 19 19.771 0.09 5979594.89 583489.96 N 70 21 15.166 W 149 19 19.285 0.59 5979675.21 583506.08 N 70 21 15.954 W 149 19 18.788 1.85 5979741.44 583520.18 N 70 21 16.604 W 149 19 18.354 1.51 5979766.45 583525.67 N 70 21 16.850 W 149 19 1 0.35 5979844.74 583542.41 N 70 21 17.618 W 149 19 1 1.39 5979922.41 583558.83 N 70 21 18.380 W 149 19 17.165 0.22 5984001.37 583575.36 N 70 21 19.155 W 149 19 16.656 0.19 5980080.09 583591,74 N702119.927 W 1491916.151 1.32 5980159.77 583608.33 N 70 21 20.709 W 149 19 15.641 0.48 5980239.73 583625.06 N 70 21 21.494 W 149 19 15.126 0.63 5980319.03 583641.58 N 70 21 22.272 W 149 19 14.616 2.40 5980398.69 583659.99 N 70 21 23.053 W 149 19 14.052 3.87 5980479.05 583683.38 N 70 21 23.841 W 149 19 13.342 1.14 5980558.54 583710.18 N 70 21 24.620 W 149 19 12.533 3.02 5980636.23 583739.30 N 70 21 25.381 W 149 19 11.656 1.92 5980711.89 583771.36 N 70 21 26.121 W 149 19 10.694 2.30 5980787.01 583805.81 N 70 21 26.856 W 149 19 9.662 1.85 5980858.73 583841.20 N 70 21 27.558 W 149 19 8.604 1.92 5980929.18 583878.92 N 70 21 28.247 W 149 19 7.478 2.72 5980999.15 583920.38 N 70 21 28.930 W 149 19 6.243 0.93 5981065.97 583962.32 N 70 21 29.583 W 149 19 4 1.75 5981134.39 584006.71 N 70 21 30.251 W 149 19 0.46 5981199.98 584051.13 N 70 21 30.891 W 149 19 2. 1.33 5981265.99 584096.20 N 70 21 31.535 W 149 19 1.015 1.56 5981332.83 584142.18 N 70 21 32.187 W 149 18 59.649 1.50 5981399.70 584188.81 N 70 21 32.840 W 149 18 58.264 0.65 5981467.71 584236.45 N 70 21 33.504 W 14918 56.849 2.41 5981535.17 584285.83 N 70 21 34.162 W 149 18 55.383 4.60 5981599.70 584339.50 N 70 21 34.790 W 149 18 53.792 4.73 5981659.57 584398.34 N 70 21 35.373 W 149 18 52.052 4.05 5981714.84 584462.14 N 70 21 35.909 W 149 18 50.168 4,30 5981764.75 584528.74 N 70 21 36.393 W 149 18 48.205 3.75 5981809.76 584598.34 N 70 21 36.828 W 149 18 46.155 4.27 5981849.24 584670.57 N 70 21 37.208 W 149 18 44.029 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202\L-202 Generated 7/5/2005 4:16 PM Page 2 of 7 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de h ft ft ft ft ft ft de 1100 ft itUS ftUS OLJO.IJ :Jy.l4 OO.JO 4U4O./U 41L4.VU 6350.96 56.53 72.30 4096.13 4173.43 6445.47 57.16 76.61 4147,83 4225.13 6539.08 58.35 80.50 4197.79 4275.09 6633.04 63.82 84.48 4243.22 4320.52 6727.96 67.49 67.23 4282.34 4359.64 6821.91 68.85 90.61 4317.29 4394.59 6915.74 69.25 92.21 4350.84 4428.14 7010.72 68.67 92,35 4384.94 4462.24 7106.19 69.12 93,20 4419.32 4496.62 7201.07 73.97 94.13 4449.34 4526.64 JOLL.40 4UJy.JV JO~~.J4 JUf J.UO ISO 1.41 3886.58 3947.64 4004.99 4060.47 4115.02 4166.36 4214.84 4262.76 4310.25 4357.03 4117.92 4197.03 4276.19 4358.40 4444.86 4532.07 4619.70 4708.34 4797.41 4887.38 3953.62 4004.89 4052.72 4098.84 4144.39 4187.68 4229.26 4271.58 4314.84 4358.74 3599.54 3620.73 3636.41 3647.08 3653.30 3654.93 3652.77 3649.25 3644.93 3639.17 7296.39 78.09 95,21 4472.35 4549.65 4403.72 4979.86 4403.93 3631.64 7391.46 82.36 98.19 4488.49 4565.79 4448.11 5073.53 4448.29 3620.69 7485.28 86.37 100.46 4497.70 4575.00 4488.55 5166.88 4490.27 3605,56 7579.60 85.23 100.61 4504.61 4581.91 4527.50 5260.94 4532.36 3588.36 7602.93 84.97 101.54 4506.60 4583.90 4536.93 5284.19 4542.81 3583.90 7681.09 86.19 101.75 4512.63 4589.93 4567.82 5362.11 4577.83 3568.17 7713.27 86.26 101.83 4514.74 4592.04 4580.48 5394.22 4592.50 3561.61 7744.48 86.09 102.10 4516.83 4594.13 4592.66 5425.36 4606.81 3555.15 7775.02 86.60 102.28 4518.77 4596.07 4604.48 5455.84 4620.87 3548.72 7805.94 $6.02 102.02 4520.76 4598.06 4616.46 5486.70 4635.28 3542.22 7836.79 85,78 102.79 4522.97 4600.27 4628.28 5517.47 4649.69 3535.61 7866.71 85.57 102.05 4525.23 4602.53 4639.74 5547.30 4663.81 3529.20 7896.91 85.37 101.94 4527.61 4604.91 4651.50 5577.41 4678.40 3522.94 7927.46 85.78 103.53 4529.97 4607.27 4663.04 5607.87 4692.97 3516.23 7958.09 86.05 103.03 4532.15 4609.45 4674.35 5638.42 4707.48 3509.21 7989.30 85.64 103.73 4534.41 4611.71 4685.82 5669.55 4722.38 3502.00 8019.76 86.09 105.16 4536.61 4613.91 4696.48 5699.93 4736.57 3494.43 8051.26 86.22 105.71 4538.72 4616.02 4707,01 5731.36 4750.93 3486.06 8080.87 87.08 105.96 4540.45 4617.75 4716.71 5760.92 4764.41 3477.99 8112.54 90.48 107.51 4541.12 4618.42 4726.63 5792.57 4778.56 3468.88 8142.29 91.68 107.64 4540.56 4617.86 4735.54 5822,32 4791.62 3459.90 $173.17 90.58 106.85 4539.95 4617.25 4744.96 5853.19 4805.49 3450.75 8203.75 90.24 107.63 4539.74 4617.04 4754.28 5883.77 4819.38 3441.68 8234.14 89.79 106.24 4539.73 4617.03 4763.71 5914.16 4833.48 3432.83 8265.29 90.51 107.47 4539.65 4616.95 4773.41 5945.31 4848.13 3423.80 8295.51 92.68 105.04 4538.81 4616.11 4783.11 5975.52 4862.76 3415.34 832623 92.81 106.10 4537.33 4614.63 4793.32 6006.20 4878.09 3407.11 8358.69 92.61 106.19 4535.80 4613.10 4803.80 6038.63 4894.17 3398.09 8389.63 92.33 105.62 4534.47 4611.77 4813.91 6069.54 4909.75 3389.62 8420.64 92.06 105.19 4533.28 4610.58 4824.30 6100.52 4925.75 3381.39 1635.37 1711.57 1789.15 1870.64 1956.87 2044.05 2131.65 2220.22 2309.18 2398.97 2491.14 2584.16 2676.27 2768.75 2791.56 2867.88 2899.31 2929.78 2959.57 2989.73 3019.78 3048.92 3078.37 3108.08 3137.81 3168.10 3197.51 3227.81 3256.25 3286.56 3314.92 3344.40 3373.61 3402.68 3432.49 3461.49 3491.05 3522.19 3551.92 3581.79 4.415 Oy0li5r5J.ll Otl4/4D,Lt5 N /UL"I :S/.SJJ VV "14y'It541.tS:S4 4.55 5981910.39 584818.94 N 70 21 37.793 W 149 18 39.671 3.88 5981932.42 584894.89 N 70 21 38.001 W 149 18 37.443 3.74 5981948.97 584972.28 N 70 21 38.155 W 149 18 35.174 6.90 5981960.54 585053.65 N 70 21 38.260 W 149 1 B 32.791 4.68 5981967.71 585139.80 N 70 21 38.321 W 14918 30.270 3.64 5981970.31 585226.94 N 70 21 38.337 W 149 18 27,721 1.65 5981969.13 585314.55 N 70 21 38.315 W 149 18 25.160 0.63 5981966.58 585403.15 N 70 21 38.280 W 149 18 22.570 0.96 5981963.26 585492.15 N 70 21 38.237 W 149 18 19.969 5.20 5981958.50 585581.99 N 70 21 38.181 W 149 18 17 4.46 5981951.98 585674.23 N 70 21 38.106 W 149 18 14.649 5.45 5981942.08 585767,35 N 70 21 37.998 W 149 18 11.929 4.91 5981927.97 585859.61 N 70 21 37,849 W 149 18 9.236 1.22 5981911.80 585952.27 N 70 21 37.680 W 149 18 6.532 4.13 5981907.59 565975.12 N 70 21 37.636 W 149 18 5.865 1.58 5981892.71 586051.61 N 70 21 37.481 W 149 18 3.634 0.33 5981886.50 586083.11 N 70 21 37.416 W 149 18 2.715 1.02 5981880.38 586113.64 N 70 21 37.352 W 149 18 1.824 1.77 5981874.28 586143.50 N 70 21 37.289 W 149 18 0.953 2.05 5981868.12 586173.73 N 70 21 37.225 W 149 18 0.071 2.61 5981861.85 586203.85 N 70 21 37.160 W 14917 59.193 2.56 5981855.76 586233.05 N 70 21 37.097 W 149 17 58.341 0.76 5981849.83 586262.57 N 70 21 37.035 W 149 17 57.480 5.36 5981843.44 586292.34 N 70 21 36.969 W 149 17 56.611 1.85 5981836.76 586322.15 N 70 21 36.900 W 149 17 55.742 2.59 5981829.89 586352.51 N 70 21 36.829 W 149 17 54.857 4.91 5981822.64 586382.01 N 70 21 36.754 W 149 17 5 1.79 5981814.61 586412.39 N 70 21 36.672 W 149 17 5 3.02 5981806.86 586440.92 N 70 21 36.592 W 149 17 52. 11.80 5981798.09 586471.33 N 70 21 36.502 W 149 17 51.393 4.06 5981789.42 586499.78 N 70 21 36.414 W 149 17 50.564 4.39 5981780.60 586529.36 N 70 21 36.324 W 149 17 49.702 2.78 5981771.86 586558.66 N 70 21 36.235 W 149 17 48.848 4.81 5981763.33 586587.83 N 70 21 36.147 W 149 17 47.999 4.58 5981754.63 586617.74 N 70 21 36.058 W 149 17 47.127 10.78 5981746.50 586646.82 N 70 21 35.975 W 149 17 46.279 3.47 5981738.60 586676.47 N 70 21 35.894 W 149 17 45.415 0.68 5981729.93 586707.71 N 70 21 35,805 W 14917 44.505 2.05 5981721.79 586737.52 N 70 21 35.722 W 149 17 43.636 1.64 5981713.89 586767.48 N 70 21 35.641 W 149 17 42.762 SurveyEditor Ver SP 1.0 Bld( docAOx_56) L-2021L-2021E-202\L-202 Generated 7(5!2005 4:16 PM Page 3 of 7 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW pLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de /100 ft ftUS ftUS 8451.13 91.85 105.54 4532.24 4609.54 4834.54 6131.00 4941.64 3373.32 3611.18 1.34 5981706,14 8481.91 91.61 105.27 4531.31 4608.61 4844.86 6161.76 4957.81 3365.14 3640.84 1.17 5981698.30 8512.94 90.93 105.72 4530.62 4607.92 4855.22 6192.79 4974.21 3356.65 3670.73 2.63 5981690.35 8544.63 90.48 106.62 4530.23 4607.53 4865.45 6224.47 4990.78 3348.03 3701.17 3.18 5981681.86 8575.83 90.31 106.18 4530.02 4607.32 4875.40 6255.67 5007.14 3339.22 3731.10 1.51 5981673.39 8606.53 90.62 108.34 4529.77 4607.07 4884.75 6286.37 5022.98 3330.11 3760.41 7.11 5981664.60 8637.61 90.65 109.63 4529.42 4606.72 4893.33 6317.45 5038.35 3320.00 3789.80 4.15 5981654.82 8668.57 90.75 110.05 4529.04 4606.34 4901.42 6348.41 5053.40 3309.50 3818.92 1.39 5981644.64 8699.43 90.45 110.76 4528.72 4606.02 4909.20 6379.26 5068.29 3298.74 3847.84 2.50 5981634.20 8731.09 90.21 110.41 4528.54 4605.84 4917.08 6410.92 5083.62 3287.61 3877.48 1.34 5981623.40 8762.44 90.00 109.84 4528.48 4605.78 4925.13 6442.27 5099.17 3276.82 3906.91 1.94 5981612.95 8793.38 89.73 111.30 4528.55 4605.85 4932.84 6473.21 5114.45 3265.95 3935.88 4.80 5981602.40 8825.04 89.49 110.35 4528.77 4606.07 4940.59 6504.87 5130.11 3254.69 3965.47 3.09 5981591.47 8855.69 89.25 111.91 4529.11 4606.41 4947.94 6535.52 5145.26 3243.65 3994.06 5.15 5981580.75 8886.95 90.69 111.71 4529.12 4606.42 4955.07 6566.78 5160.54 3232.03 4023.08 4.65 5981569.46 8917.62 91.41 110.68 4528.56 4605.86 4962.39 6597.45 5175.95 3220.95 4051.67 4.10 5981558.69 8948.54 91.58 111.02 4527.75 4605.05 4969.94 6628.35 5191.79 3209.94 4080.55 1.23 5981548.01 8978.89 91.85 111.48 4526.85 4604.15 4977.15 6658.69 5207.28 3198.95 4108.83 1.76 5981537.33 9010.67 91.92 110.41 4525.80 4603.10 4984.87 6690.45 5223.78 3187.60 4138.49 3.37 5981526.31 9041.53 91.41 110.81 4524.90 4602.20 4992.53 6721.30 5240.09 3176.74 4167.36 2.10 5981515.77 9072.98 91.30 109.32 4524.16 4601.46 5000.64 6752.74 5257,11 3165.95 4196.90 4.75 5981505.31 9105.23 89.66 108.33 4523.89 4601.19 5009.62 6784.99 5275.28 3155.54 4227.42 5.94 5981495.25 9137.09 88.59 107.92 4524.38 4601.68 5018.87 6816.85 5293.67 3145.64 4257.69 3.60 5981485.68 9167.95 88.59 107.97 4525.14 4602.44 5027,91 6847.70 5311.69 3136.13 4287.04 0.16 5981476.50 9199.05 88.49 108.28 4525.93 4603.23 5036.94 6878.79 5329.89 3126.46 4316.59 1.05 5981467.16 9229.39 88.35 109.85 4526.76 4604.06 5045.26 6909.11 5347.35 3116.55 4345.25 5.19 5981457.57 9259.98 87.98 108.12 4527.74 4605.04 5053.70 6939.69 5365.10 3106.61 4374.16 5.78 5981447.95 9291.86 89.14 108.28 4528.55 4605.85 5062.91 6971.56 5384.08 3096.65 4404.44 3.67 5981438.33 9323.58 90.10 107.10 4528.76 4606.06 5072.35 7003.28 5403.32 3087.01 4434.66 4.80 5981429.03 9355.01 89.83 107.35 4528.78 4606.08 5081.94 7034.71 5422.70 3077.71 4464.68 1.17 5981420.06 9385.23 89.73 106.76 4528.89 4606.19 5091.25 7064.93 5441.50 3068.84 4493.57 1.98 5981411.52 9415.73 89.66 107.21 4529.05 ' 4606.35 5100.69 7095.43 5460.62 3059.93 4522.74 1.49 5981402.93 9447.21 89.21 108.21 4529.36 4606.66 5110.04 7126.90 5480.14 3050.36 4552.72 3.48 5981393.69 9477.82 89.62 108.32 4529.68 4606.98 5118.86 7157.51 5499.00 3040.77 4581.79 1.39 5981384.42 9509.07 89.93 107.60 4529.80 4607.10 5128.01 7188.76 5518.50 3031.13 4611.52 2.51 5981375.12 9540.45 89.69 107.16 4529.90 4607.20 5137.51 7220.14 5538.43 3021.76 4641.46 1.60 5981366.08 9570.74 89.35 106.39 4530.16 4607.46 5146.98 7250.43 5558.01 3013.01 4670.46 2.78 5981357.66 9601.96 88,29 104.96 4530.80 4608.10 5157.31 7281.64 5578.74 3004.58 4700.51 5.70 5981349.56 9633.90 86.61 103.25 4532.22 4609.52 5168.69 7313.55 5600.67 2996.81 4731.46 7.50 5981342.13 9664.80 85.98 102.36 4534.22 4611.52 5180.34 7344.39 5622.46 2989.97 4761.53 3.52 5981335.63 586796.95 N 70 21 35.561 W 149 17 41.903 586826.70 N 70 21 35.481 W 149 17 41.036 586856.68 N 70 21 35.399 W 149 17 40.162 586887.21 N 70 21 35.312 W 149 17 39.273 586917.23 N 70 21 35.225 W 149 17 38.396 586946.64 586976.14 587005.37 587034.41 587064.16 587093.71 587122.80 587152.51 587181.21 587210.36 587239.07 587268.07 587296.46 587326.25 587355.24 587384.88 587415.52 587445.90 587475.35 587505.00 587533.77 587562.78 587593.16 587623.48 587653.60 587682.59 587711.85 587741.94 587771.11 587800.94 587830.98 587860.08 587890.22 587921.24 587951.38 N 70 21 35.135 W 149 17 37.541 N 70 21 35.036 W 149 17 36.682 N 70 21 34.932 W 149 17 35.830 N 70 21 34.$26 W 149 17 34.985 N 70 21 34.717 W 149 1734.118 N 70 21 34.611 W 149 17 3~ N 70 21 34.504 W 149 17 32.411 N 70 21 34.393 W 149 17 31.546 N 70 21 34.284 W 149 17 30.711 N 70 21 34.169 W 149 17 29.862 N 70 21 34.060 W 149 17 29.027 N 70 21 33.952 W 149 17 28.182 N 70 21 33.844 W 149 17 27.356 N 70 21 33.732 W 149 17 26.489 N 70 21 33.625 W 149 17 25,645 N 70 21 33.519 W 149 17 24.781 N 70 21 33.416 W 149 17 23.889 N 70 21 33.319 W 149 17 23.004 N 70 21 33.225 W 149 17 22.146 N 70 21 33.130 W 149 17 21.283 N 70 21 33.032 W 14917 20.445 N 70 21 32.934 W 149 17 19.600 N 70 21 32.836 W 149 17 18 N 70 21 32.741 W 149 17 1 N 70 21 32,649 W 149 17 16. N 70 21 32.562 W 149 17 16.109 N 70 21 32.474 W 149 17 15.256 N 70 21 32.380 W 149 17 14.380 N 70 21 32.285 W 149 17 13.530 N 70 21 32.190 W 149 17 12.661 N 70 21 32.098 W 14917 11.786 N 70 21 32.012 W 149 17 10.938 N 70 21 31.929 W 149 17 10.060 N 70 21 31.852 W 149 17 9.155 N 70 21 31.785 W 149 17 8.276 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202\L-202 Generated 7/5/2005 4:16 PM Page 4 of 7 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Eastfng Latitude Longitude Depth Section Departure ft de de ft ft ft ft 11 ft ft de 1100 tt ftUS ftUS `JO`J0.`J4 i!0./l lUG"13 4OJb.4/ 4b13.// 5l`JG3D /3/bR0 bU44. lU Yy25J.3t5 9727.04 87.02 103.40 4538.45 4615.75 5204.10 7406.48 5666. 82 2976.53 9758.72 87.02 103.41 4540.09 4617.39 5215.74 7438.12 5689. 20 2969.19 9790.00 87.84 104.49 4541.50 4618.80 5226.97 7469.37 5711. 18 2961,66 9821.14 88.18 103.96 4542.58 4619.88 5238.00 7500.49 5733. 05 2954.01 9851.36 87.77 103.91 4543 .64 9883.33 87.84 104.58 4544 .87 9914.52 87.56 105.41 4546 .12 9945,82 87.39 106.20 4547 .50 9976.48 88.18 106.27 4548 .68 10006.82 89.18 105.96 4549 .38 10039.14 88.94 105,73 4549 .91 10070.89 88.70 105.96 4550 .57 10102.00 87.63 105.16 4551 .56 10133.13 87.19 105.58 4552 .97 4620.94 5248.86 7530.69 5754.46 2946.74 4622.17 5260.18 7562.64 5777.08 2938.88 4623.42 5270.84 7593.80 5798.93 2930.81 4624.80 5281.12 7625.07 5820.64 2922.30 4625.98 5290.98 7655.71 5841.82 2913.73 4626.68 4627,21 4627.87 4628.86 4630.27 5300.80 5311.40 5321.81 5332.16 5342.61 10165.11 86.84 105.83 4554.64 4631.94 5353.16 10196.31 85.12 107.00 4556.82 4634.12 5363.08 10227.70 84.68 107.84 4559.61 4636.91 5372.53 10259.08 84.58 106.56 4562.55 4639.85 5382.08 10289.41 84.33 106.41 4565.48 4642.78 5391.66 10320.77 85.43 105.73 4568.28 4645.58 5401.79 10352.09 87.94 107.09 4570.09. 4647.39 5411.76 10382.05 88.18 106.19 4571..11 4648.41 5421.19 10413.61 86.15 106.89 4572.67 4649.97 5431.17 10444.17 84.92 107.56 4575.05 4652.35 5440.47 10474.60 10507.15 10537.66 10568.39 10598.72 10629.64 10660.71 10691.27 10722,93 10754.10 85.16 85.02 85.64 86.54 86.36 85.98 85.64 86,26 87.87 88.11 10785.46 87.77 10816.59 87.46 10847.28 87.22 10877.85 86.91 10909.57 86.71 10941.16 86.40 SurveyEditor Ver SP 1.0 Bid( doc40x_56 ) 107.17 108.56 107.46 106.97 107.30 107.06 105.61 106.07 105.84 104.16 104.35 104.52 103.90 104.29 104.07 105.60 7686.04 7718.35 7750.10 7781.19 7812.29 7844.23 7875.35 7906.61 7937.86 7968.04 7999.28 8030.54 8060.49 8092.01 8122.47 4577.68 4654.98 5449.66 8152.79 4580.46 4657.76 5459.21 8185.22 4582.95 4660.25 5468.10 8215.63 4585.04 4862.34 5477.46 8246.29 4586.92 4664.22 5486.75 8276.56 4588.99 4591.26 4593.41 4595.03 4596.13 4597.26 4598.55 4599.98 4601.54 4603.31 4605.20 5862.91 5885.59 5907.95 5930.05 5952.30 5975.10 5997.13 6018.96 6040.93 6062.51 6085.07 6107.60 6129.16 6151.98 6173.85 6195.64 6218.83 8240.59 6262.90 6285.03 6307.63 6330.71 6353.65 6377.47 6401.35 2905.31 2896.49 2887.82 2879.48 2871.24 2862.59 2853.80 2844.44 2835.20 2826.64 2817.99 2809.16 2800.58 2791.61 2782.59 2773.54 2763.59 2754.19 2745.12 2736.20 2727.08 2718.37 2710.05 2701.36 2693.30 4 / 91.825 4822.15 4852.92 4883.25 4913.42 4942.73 4973.69 5003.79 5033.88 5063.30 5092.44 5123.52 5154.06 5184.02 5214.00 524d.75 5274.60 5304.43 5334.28 5363.22 5393.24 5423.23 5451.92 5482.13 5511.23 5540.16 5571.03 5599.95 5629.23 5658.16 5687.64 5717.37 5746.70 5777.10 5807.18 7.14 5y813L9.38 5.86 5981322.86 0.03 5981315.87 4.33 5981308,68 2.02 5981301.37 1.37 5981294.42 2.11 5981286.90 2.81 5981279.18 2.58 5981270.99 2.59 5981262.76 3.45 5981254.66 1.03 5981246.19 1.05 5981237.86 4.29 5981229.85 1.95 5981221.94 1.34 5981213.64 6.66 5981205.18 3.01 5981196.15 4.07 5981187.25 0.96 5981179.00 4.12 5981170.69 9.11 5981162.20 3.11 5981153.94 6.80 5981145.30 4.58 5981136.61 1.50 5981127.88 4.28 5981118.28 4,13 5981109.20 3.33 5981100.45 1.24 5981091.86 1.45 5981083.07 4.78 5981074.69 2.52 5981066.70 5.14 5981058.34 5.44 59$1050.62 6425.69 2685.58 5837.56 1.24 5981043.24 6449.84 2677.83 5867.68 1.14 5981035.82 6473.78 2670.30 5897.40 2.16 5981028.63 6497.71 2662.87 5927.01 1.63 5981021.52 6522.57 2655.11 5957.72 0.94 5981014.10 6547.16 2647.03 5988.20 4.93 5981006.37 L-2021L-2021L-202\L-202 4666.29 4668.56 4670.71 4672.33 4673.43 4674.56 4675,85 4677,28 4678.84 4680.61 4682.50 5496.19 5506.11 5516.11 5526.43 5537.08 5548.18 5559.11 5569.99 5580.8$ 5592.14 5603.01 8307.41 8338.40 8368.88 8400.50 8431.65 8462.99 8494.09 8524.75 8555.28 8586.95 8618.48 b8/981.8U N /U L1 31./20 W 149 17 7.389 588012.14 N 70 21 31.652 W 149 17 6.504 586042.99 N 70 21 31.580 W 149 17 5.605 588073.40 N 70 21 31.505 W 14917 4.718 588103.64 N 70 21 31.430 W 149 17 3.836 588133.03 588164.08 588194.27 588224.45 588253.95 588283.18 588314.36 588344.99 588375.03 588405.10 588435.94 588465.89 588495.82 588525.76 588554.80 N 70 21 31.358 W 149 17 2.979 N 70 21 31.281 W 149 17 2.074 N 70 21 31.201 W 149 17 1.194 N702131.117 W 149170.315 N 70 21 31.033 W 149 16 59.455 N 70 21 30.950 W 149 16 5 N 70 21 30.863 W 149 16 5, N 70 21 30.777 W 149 16 56.802 N 70 21 30.695 W 149 16 55.926 N 70 21 30.614 W 14916 55.050 N 70 21 30.529 W 149 16 54.151 N 70 21 30.442 W 149 16 53.279 N 70 21 30.350 W 149 16 52.407 N 70 21 30.259 W 149 16 51.534 N 70 21 30.174 W 149 16 50.688 588584.90 N 70 21 30.089 W 14916 49.811 588614.99 N 70 21 30.002 W 149 16 48.934 588643.76 N 70 21 29.917 W 149 16 48.096 588674.08 N 70 21 29.829 W 149 16 47.212 588703.27 N 70 21 29,740 W 149 16 46.362 588732.30 N 70 21 29.651 W 149 16 45.516 588763.27 N 70 21 29.553 W 149 16 44.614 588792.29 N 70 21 29.460 W 149 16 43.769 588821.67 N 70 21 29.371 W 149 16 42 588850.69 N 70 21 29.283 W 149 16 41~ 588880.26 N 70 21 29.193 W 149 16 41.206 588910.09 N 70 21 29.107 W 149 16 40.337 588939.51 N 70 21 29.025 W 149 16 39.479 588970.00 N 70 21 28.939 W 149 16 38.591 589000.17 N 70 21 28.860 W 149 16 37.711 589030.63 N 70 21 26.783 W 149 16 36.824 589060.83 N 70 21 28.707 W 149 16 35.943 589090.63 N 70 21 28.633 W 149 16 35.075 589120.31 N 70 21 28.559 W 149 16 34.209 589151.10 N 70 21 28.483 W 149 16 33.311 589181.67 N 70 21 28.403 W 149 16 32.421 Generated 7/5!2005 4:16 PM Page 5 of 7 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft H ft tt ft ft de 100 it ttUS ftUS warc.oo oo.~c ivo.u~ 4our.n 4064.01 ooiaou oo4a.ni nor i.o[ [nacs.n[ ~ nu125.ZL 1.y4 5at5Uaati.4a btSyLlL/t5 N /U 21 223.322 W 14y 1631.b43 11003.61 86.29 105.43 4609.25 4686.55 5624.05 8680.80 6595.63 2630.62 6048.32 1.33 5980990.63 589241.96 N 70 21 28.241 W 149 16 30.663 11034.52 85.99 105.81 4611.33 4688.63 5634.29 8711.64 6619.58 2622.32 6078.02 1.56 5980982.66 589271.75 N 70 21 28.159 W 149 16 29.795 11066.75 85.95 105.71 4613.60 4690.90 5644.88 8743.79 6644.56 2613.59 6108.96 0.33 5980974.27 589302.78 N 70 21 28.073 W 149 16 28.891 11097.34 87.12 105.92 4615.45 4692.75 5654.91 8774.32 6668.33 2605.27 6138.34 3.89 5980966.28 589332.25 N 70 21 27.991 W 149 16 28.032 11128.32 90.07 104.14 4616.21 4693.51 5665.49 8805.29 6692.75 2597.24 6168.24 11.12 5980958.58 589362.24 N 70 21 27.912 W 149 16 27.158 11159.22 91.34 103.88 4615.83 4693.13 5676.56 8836.19 6717.50 2589.76 fi198.22 4.20 5980951.44 589392.30 N 70 21 27.838 W 149 16 26.282 11190.29 91.27 103.98 4615.12 4692.42 5687.72 8867.25 6742.46 2582.28 6228.37 0.39 5980944.29 589422.52 N 70 21 27.764 W 149 16 25.401 11221.59 91.13 103.51 4614.46 4691.76 5699.07 8898.54 6767.72 2574.84 6258.77 1.57 5980937.20 589453.00 N 70 21 27.691 W 149 16 24.512 11252.80 90.79 103.17 4613.94 4691.24 5710.59 8929.75 6793.08 2567.64 6289.13 1.54 5980930.34 589483.44 N 70 21 27.620 W 149 16 23.625 11283.24 90.45 103.54 4613.61 4690.91 5721.81 8960.19 6817.86 2560.61 6318.75 1.65 5980923.63 589513.12 N 70 21 27.551 W 149 16 2 11314.43 90.21 102.85 4613.43 4690.73 5733.40 8991.37 6843.36 2553.49 6349.11 2.34 5980916.85 589543.56 N 70 21 27.480 W 149 16 2 ~ 11345.47 90.00 102.74 4613.38 4690.68 5745.13 9022.41 6868.90 2546.62 6379.38 0.76 5980910.32 589573.90 N 70 21 27.412 W 149 16 20.987 11377.28 89.93 103.07 4613.39 4690.69 5757.10 9054.23 6895.08 2539.51 6410.39 1.06 5980903.56 589604.99 N 70 21 27.342 W 149 16 20.080 11407.56 89.76 102.98 4613.48 4690.78 5768.43 9084.50 6920.02 2532.69 6439.89 0.64 5980897.06 589634.56 N 70 21 27.275 W 149 1619.218 11439.57 89.52 104.88 4613.68 4690.98 5779.93 9116.51 6946.1A 2524.98 6470.95 5.98 5980889.70 589665.71 N 70 21 27.199 W 149 16 18.310 11469.85 90.24 106.13 4613.74 4691.04 5790.04 9146.79 6970.40 2516.89 6500.13 4.76 5980881.93 589694.97 N 70 21 27.119 W 149 16 17.457 11502.45 89.90 106.41 4613.70 4691.00 5800.51 9179.39 6996.31 2507.76 6531.43 1.35 5980873.15 589726.36 N 70 21 27.029 W 149 16 16.543 11533.16 89.25 106.61 4613.93 4691.23 5810.25 9210.10 7020.69 2499.03 6560.87 2.21 5980864.75 589755.89 N 70 21 26.943 W 149 16 15.682 11563.73 87.91 105.60 4614.69 4691.99 5620.14 9240.66 7045.14 2490.55 6590.23 5.49 5980856.60 589785.34 N 70 21 26.859 W 149 16 14.824 11595.38 88.73 104.84 4615.61 4692.91 5830.85 9272.30 7070.78 2482.25 6620.75 3.53 5980848.64 589815.96 N 70 21 26.777 W 149 16 13.932 11627.37 90.31 105.21 4615.88 4693.18 5841.77 9304.29 7096,.82 2473.96 6651.65 5.07 5980840.69 589846.94 N 70 21 26.695 W 149 16 13.029 11658.01 89.69 105.01 4615.88 4693.18 5852.20 9334.93 7121.79 2465.97 6681.23 2.13 5980833.03 589876.60 N 70 21 26.617 W 149 16 12.164 11688.93 87.29 104.95 4616.70 4694.00 5862.78 9365.83 7147,05 2457.98 6711.09 7.76 5980825.37 589906.54 N 70 21 26.538 W 149 16 11,292 11720.29 86.67 104.23 4618.35 4695.65 5873.70 9397.15 7172.82 2450.09 6741.39 3.03 5980817.82 589936.93 N 70 21 26.460 W 149 16 10.406 11751.78 87.81 104.08 4619.87 4697.17 5884.89 9428.60 7198.88 2442.40 6771.89 3.65 5980810.47 589967,51 N 70 21 26.384 W 149 16 9.514 11782.78 89.62 103.89 4620.56 4697.86 5896.01 9459.59 7224.64 2434.91 6801.96 5.87 5980803.32 589997,66 N 70 21 26.310 W 149 16 8.635 11813.73 89.59 103.75 4620.77 4698.07 5907.19 9490.54 7250.47 2427.52 6832.02 0.46 5980796.26 590027.79 N 70 21 26.237 W 149 16 7.757 11845.23 89.31 104.33 4621.08 4698.38 5918.46 9522.04 7276.72 2419,88 6862.57 2.04 5980788.96 590058.43 N 70 21 26.162 W 149 16 6 11875.93 88.97 103.09 4621.54 4698.84 5929.60 9552.74 7302.45 2412.60 6892.39 4.19 5980782.02 590088.33 N 70 21 26.090 W 149 16 5?~J2 11907.25 88.25 103.09 4622.30 4699.60 5941.28 9584.05 7328.91 2405.51 6922,89 2.30 5980775.26 590118.90 N 70 21 26.020 W 149 16 5.101 11938.52 86.40 103.28 4623.76 4701.06 5952.89 9615.28 7355.32 2398.38 6953.30 5.95 5980768.48 590149.38 N 70 21 25.950 W 149 16 4.212 11968.88 85.92 104.33 4625.79 4703.09 5963.84 9645.57 7380.79 2391.16 6982.72 3.80 5980761.58 590178.88 N 70 21 25.878 W 149 16 3.352 12000,14 86.53 106.40 4627.85 4705.15 5974.32 9676.77 7406.58 2382.89 7012.79 6.89 5980753.65 590209.04 N 70 21 25.797 W 149 16 2.473 12031.08 88.18 107.07 4629.28 4706.58 5964.01 9707.67 7431.76 2373.99 7042.39 5.75 5980745.08 590238.73 N 70 21 25.709 W 149 16 1.608 12063.10 89.18 106.33 4630.01 4707.31 5994.06 9739.68 7457.90 2364.79 7073.05 3.88 5980736.22 590269.49 N 70 21 25.618 W 149 16 0.712 12093.82 89.35 106.13 4630.41 4707.71 6003.95 9770.40 7483.17 2356.21 7102.55 0.85 5980727.97 590299.07 N 70 21 25.533 W 149 15 59.850 12124.32 89,01 106.60 4630.84 4708.14 6013.69 9800.90 7508.26 2347.62 7131.81 1.90 5980719.70 590328.42 N 70 21 25.449 W 149 15 58.995 12155.92 88.66 106.61 4631.49 4708.79 6023.66 9832.49 7534.22 2338.59 7162.08 1.11 5980711.01 590358.80 N 70 21 25.360 W 149 15 58.110 12186.73 88.56 106.99 4632.23 4709.53 6033.28 .9863.29 7559.50 2329.68 7191.57 1.27 5980702.44 590388.38 N 70 21 25.272 W 149 15 57.249 12218.06 88.15 107,19 4633.13 4710.43 6042.91 9894.61 7585.17 2320.48 7221.50 1.46 5980693.57 590418.41 N 70 21 25.181 W 14915 56.374 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202\L-202 Generated 7!512005 4:16 PM Page 6 of 7 i r ~ Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft ft ft ft ft de /100 ft ttUS ttUS l LL4a.l4 i3t5.4~ lU/.i)tl 4034.U4 4/~I1.34 bU~L.37 yyZ0.br5 /b1U.b/ Y39l.ZU (Lbl.1b 12279.57 88.53 106.71 4634.84 4712.14 6061.64 9956.10 7635.56 2302.23 7280.22 12310.73 88.01 106.94 4635.78 4713.08 6071.35 9987.24 7661.29 2293.22 7310.03 12341.75 87.39 107.38 4637.02 4714.32 6080.85 10018.24 7686.83 2284.07 7339.65 12372.73 87.02 107.03 4638.53 4715.83 6090.31 10049.18 7712.36 2274.92 7369.20 12404.87 85.64 106.77 4640.59 4717.89 6100.27 10081.25 7738.95 2265.60 7399.89 12436.03 85.13 107,75 4643.10 4720.40 6109.73 10112.31 7764.63 2256.38 7429.55 12467.63 85.33 108.93 4645.72 4723.02 6118.76 10143.80 7790.37 2246.47 7459.44 12499.52 85.95 108.82 4648.15 4725.45 6127.59 10175.60 7816.24. 2236.19 7489.53 12529.66 87.32 106.27 4649.92 4727.22 6136.62 10205.69 7841.15 2227.12 7518.22 Last MWD+IFR+MS 12573.99 86.84 106.41 4652.18 4729.48 6150.78 10249.96 7878.38 2214.66 7560.70 TD (Projected) 12628.00 86.84 106.41 4655.15 4732.45 6167.97 10303.89 7923.80 2199.43 7612.43 Survey Type: Definitive Survey MWD +IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assu mes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Surface : 2571 FSL 3690 FEL S34 T12N R11E UM BHL : 4766 FSL 1354 FEL S35 T12N R11E UM Northing (Y) [ftUS] Easting (X) {ftUS] 5978293.25 583223.80 5980576.87 590810.62 1.bb 592SUbti4.'j1 59U44k5.15 N !U 1115.Uti9 W 149 15 55.507 2.86 5980675.97 590477.32 N 70 21 25.001 W 149 15 54.658 1.82 5980667.29 590507.23 N 70 21 24.912 W 149 15 53.786 2.45 5980658.47 590536.94 N 70 21 24.822 W 149 15 52.921 1.64 5980649.65 590566.59 N 70 21 24.731 W 149 15 52.057 4.37 5980640.67 590597.38 N 70 21 24.639 W 149 15 51.160 3.54 5980631.79 590627.14 N 70 21 24.548 W 149 15 50.293 3.77 5980622.21 590657.13 N 70 21 24.451 W 149 15 49.420 1.97 5980612.26 590687.33 N 70 21 24.349 W 149 15 48.541 9.59 5980603.51 590716.11 N 70 21 24.260 W 149 15 47.702 1.13 5980591.53 590758.73 N 70 21 24.137 W 149 15 4 0.00 5980576.87 590810.62 ~ N 70 21 23.987 W 149 15 4 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) L-202\L-2021L-202\L-202 Generated 7/5/2005 4:16 PM Page 7 of 7 TREE = FMC: 4-1 /R" 5M WELLHEAD = FMC GEN 5 ACTUATOR = KB. ELEV - 77.30' __ BF. ELEV = 51.08' KOP = 700 Max Angle = 92.7 @ 8295' Datum MD = xxxx' Datum ND = xxxx' SS 20" CONDUCTOR I-'I 114' 10-3/4" CSG. 40#, L-80, ID = 9.95" I-{ 3273' Minimum ID = 3.812" @ 6595' 4-112"CMD Sliding Sleeve 4.5"PHOENIX DSCHRGE PRESS SUB,ID = 3.85" 6585' 4.5" PHNIX MULTFPRESS SENSOR, !D = 3.994" 6619' RA TAG I 6731' 7-5/8" x 5.5" BKR ZXP PACKER, ID = 5.5" 6739' I BKR HUGHES HOOK HGR, ID = 5.64" i-i 6776' RA TAG 6897' 7-5/8" x 5.5" BKR ZXP PACKER, ID = 3.98" 6885' I BKR HUGHES HOOK HGR, ID = 3.98" I-I 6942' IRA TAG I 7021' 7-518" x 5.5" BKR ZXP PACKER, ID = 4.94" 7011' HUGHES HOOK HGR, ID = 3.98" ~ 7067' PERFORATION SUMMARY REF LOG : ANGLE AT TOP PERF: xx @xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD OA 6781' - 10324' O 07/07/05 4-112" SLTD OBa 6946' - 11865' O 06/30!05 4-1/2" SLTD OBb 7072' - 11183' O 06/24/05 4-1/2" SLTD OBd 7665' - 12625' O 06/16/05 I ~ I 1 7 5/8" CSG, 29.7#, L-80, ID = 6.875" 7665' I i 1 1 1 PBTD 12623' L-- ~ S NOTES: 2258' --14-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3024 2000 59 KBG-2 DMY SBK-2 1" 07/09!05 3 5007 2500 57 KBG-2 DMY SBK-2 1" 07/09/05 2 6036 3500 60 KBG-2 DMY SBK-2 1" 07/09/05 1 3459 4234 59 KBG-2 DCK2 BEK 1" 07!09105 _ 6595' 4-1 /2" BKR CMD SLEEV E, ID = 3.812" 6643' 7.625" X 4.5" BKR PRM PKR, ID = 3.875" 6710' 4-1/2" HES X NIP, ID = 3.813" 6731' 4-112" HES X NIP, ID = 3.813" 6758' 4-112" Guide shoe _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 7 518" WINDOW @ 6781'. 6781' -10324' 6-314" OA LATERAL, ID = 3.958" 6913' 4-1/2" Seal Assembly _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ 75/8"WINDOW@6946' 6946' - 11,865' 6-3/4" OBa LATERAL, ID = 3.958" 7040' 4-112" Seal Assembly ._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 7 5/8" WINDOW @ 7072' 7072' -11,183' 6-314" OBb LATERAL, ID = 3.958" 7127' 7.625" X 5.5" BKR ZXP LNR TOP PKR, ID = 4.940" 7166' 4-112" Seal Assembly .7175' S-1/2" X 4-112" XO, ID = 3.96" 7538' I-~ RA TAG 7665' -12,625' 6-3/4" OBd LATERAL, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/11/05 TA/jdf ORIGINAL COMPLETION ORION UNIT WELL: L-202, L-202 L1, L-202 L2, L-202 L3 PERMfTNo: 204196 (197) (198) (199) API No: 50-029-23229-00 (60) (61) (62) SEC 34, T12N, R11 E, 2572' NSL & 3690' WEL BP Exploration (Alaska) L-202 L-202 L1 L-202 L2 L-202 L3 ~' S~ ~` SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... L-202 API number ...............: 50-029-23229-00 Engineer .................. F. MEDINA RIG :...................... Nabors-9ES STATE :.................... Alaska - Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 48.80 ft N/A Top Drive 77.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 35.00 degrees [(c)2005 IDEAL ID9_1C_02] 19-Jun-2005 11:34:52 Page 1 of 9 Spud date ................. 04-June-05 Last survey date.........: 17-Jun-05 Total accepted surveys...: 239 MD of first survey.......: 0.00 ft MD of last survey........: 12628.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............. 04-Jun-2005 Magnetic field strength..: 1152.29 HCNT Magnetic dec (+E/W-).....: 24.44 degrees Magnetic dip .............: 80.81 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 1152.29 HCNT 80.81 degrees (+/-) 2.50 meal (+J-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.44 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.44 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 2 of 9 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course ------- ------- TVD - -------- - -------- Vertical -------- -------- Displ -------- -------- Displ -------- -------- Total ------- ------- At ----- ----- DLS ----- ------ ----- ----- Srvy Tool - # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) ------- (ft) - -------- (ft) -------- (ft) -------- (ft) -------- (deg) ------- 100f) ----- type ----- (deg) ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 ------- 0.00 - -------- 0.00 -------- 0.00 -------- 0.00 -------- 0.00 ------- 0.00 ----- 0.00 ----- TIP ------ None 2 300.84 0.34 25.11 300.84 300.84 0.88 0.81 0.38 0.89 25.11 0.11 MWD IFR MS None 3 391.65 0.36 9.86 90.81 391.65 1.40 1.33 0.54 1.44 22.12 0.10 MWD IFR MS None 4 576.28 0.53 10.49 184.63 576.27 2.71 2.74 0.80 2.86 16.19 0.09 MWD IFR MS None 5 670.46 0.56 14.93 94.18 670.45 3.53 3.62 0.99 3.75 15.37 0.05 MWD IFR MS None 6 764.71 2.54 25.42 94.25 764.66 6.03 5.95 2.01 6.28 18.67 2.11 MWD IFR MS None 7 857.53 4.53 18.44 92.82 857.30 11.57 11.28 4.05 11.99 19.75 2.19 MWD_ IFR_ MS Non 8 953.21 6.95 15.51 95.68 952.49 20.65 20.45 6.80 21.55 18.38 2.55 MWD_ IFR_ MS Non 9 1047.74 10.47 16.79 94.53 1045.92 34.20 34.19 10.81 35.85 17.54 3.73 MWD IFR MS None 10 1142.12 13.77 15.29 94.38 1138.18 52.93 53.24 16.25 55.66 16.97 3.51 MWD IFR MS None 11 1236.19 16.95 13.24 94.07 1228.88 76.21 77.39 22.34 $0.55 16.10 3.43 MWD IFR MS None 12 1330.83 19.13 11.06 94.64 1318.86 103.20 106.04 28.48 109.80 15.03 2.41 MWD IFR MS None 13 1425.26 20.68 12.40 94.43 1407.65 132.74 137.51 35.03 141.91 14.29 1.71 MWD IFR MS None 14 1520.69 23.94 14.64 95.43 1495.92 166.45 172.72 43.54 178.12 14.15 3.53 MWD IFR MS None 15 1617.99 23.95 13.68 97.30 1584.85 203.36 211.00 53.20 217.61 14.15 0.40 MWD IFR MS None 16 1712.21 28.23 11.54 94.22 1669.45 241.64 251.44 62.19 259.01 13.89 4.65 MWD IFR MS None 17 1806.43 30.66 12.06 94.22 1751.49 284.21 296.77 71.67 305.30 13.58 2.59 MWD IFR MS None 18 1900.26 33.39 12.61 93.83 1831.04 330.12 345.37 82.30 355.04 13.40 2.93 MWD IFR MS None 19 1995.66 38.73 11.57 95.40 1908.13 381.81 400.27 94.03 411.16 13.22 5.63 MWD IFR MS None 20 2090.94 43.52 10.77 95.28 1979.88 439.11 461.73 106.14 473.78 12.95 5.06 MWD IFR MS None 21 2184.89 47.07 11.00 93.95 2045.96 500.05 527.29 118.75 540.50 12.69 3.78 MWD IFR MS None 22 2279.02 50.58 11.89 94.13 2107.93 564.99 596.72 132.83 611.33 12.55 3.80 MWD_ IFR_ MS Non 23 2372.26 54.00 12.29 93.24 2164.95 632.93 668.84 148.28 685.08 12.50 3.68 MWD_ IFR_ MS Non 24 2466.25 56.54 12.21 93.99 2218.49 704.16 744.32 164.67 762.31 12.47 2.70 MWD ~ IFR_ MS None 25 2560.42 58.25 12.15 94.17 2269.23 777.27 821.86 181.40 841.64 12.45 1.82 MWD IFR MS None 26 2654.71 59.04 11.60 94.29 2318.30 851.32 900.65 197.97 922.15 12.40 0.97 MWD IFR MS None 27 2749.60 59.40 11.73 94.89 2366.85 926.18 980.49 214.45 1003.67 12.34 0.40 MWD IFR MS None 28 2843.79 59.44 11.64 94.19 2414.77 1000.65 1059.90 230.88 1084.76 12.29 0.09 MWD IFR MS None 29 2939.01 59.34 11.69 95.22 2463.26 1075.90 1140.16 247.45 1166.70 12.24 0.11 MWD IFR MS None 30 3033.56 58.86 11.85 94.55 2511.81 1150.45 1219.59 263.99 1247.83 12.21 0.53 MWD IFR MS None [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 3 of 9 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ------ ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- ift) -------- (deg) ------- 100f) ----- type ----- - (deg) ----- --- 31 -------- 3128.08 ------ 58.78 ------- 11.89 ------ 94.52 -------- 2560.75 -------- 1224.81 -------- 1298.72 -------- 280.63 ------- 1328.70 -------- 12.19 ----- 0.09 ----- - MWD_IFR_ ----- MS None 32 3223.61 59.32 12.07 95.53 2609.88 1300.22 1378.87 297.63 1410.62 12.18 0.59 MWD_IFR_ MS None 33 3302.79 58.27 13.26 79.18 2650.90 1362.86 1444.94 312.48 1478.34 12.20 1.85 MWD_IFR_ MS None 34 3332.92 58.16 12.74 30.13 2666.77 1386.60 1469.90 318.24 1503.95 12.22 1.51 MWD_IFR_ MS None 35 3427.34 57.83 12.68 94.42 2716.82 1460.69 1548.00 335.86 1584.02 12.24 0.35 MWD_IFR_ MS None 36 3520.48 59.11 12.46 93.14 2765.52 37 3614.60 58.90 12.46 94.12 2813.99 38 3708.59 58.76 12.33 93.99 2862.64 39 3803.17 60.00 12.46 94.58 2910.81 40 3897.73 59.55 12.44 94.56 2958.41 41 3991.42 60.14 12.38 93.69 3005.47 42 4085.47 60.66 14.91 94.05 3051.94 43 4180.85 62.09 18.79 95.38 3097.64 44 4275.50 62.77 19.74 94.65 3141.45 45 4369.33 61.59 22.65 93.83 3185.25 46 4463.07 60.92 24.56 93.74 3230.33 47 4558.50 59.11 25.99 95.43 3278.02 48 4652.08 58.36 27.82 93.58 3326.59 49 4745.64 59.00 29.78 93.56 3375.23 50 4840.53 59.04 32.79 94.89 3424.08 51 4932.96 58.18 32.71 92.43 3472.23 52 5029.33 57.47 34.52 96.37 3523.55 53 5123.41 57.25 34.96 94.08 3574.29 54 5217.80 58.51 34.97 94.39 3624.47 55 5312.23 59.95 35.35 94.43 3672.78 1534.07 1625.49 1608.59 1704.27 1682.83 1782.81 1757.97 1862.31 1833.43 1942.09 1908.22 2021.21 1984.37 2100.67 2063.91 2180.76 2144.67 2259.96 2225.24 2337.33 2305.80 2412.63 2387.26 2487.38 2466.45 2558.71 2545.90 2628.74 2627.07 2698.25 2705.91 2764.61 2787.45 2832.54 2866.67 2897.64 2946.b1 2963.15 3027.75 3029.48 353.13 1663.40 370.54 1744.08 387.80 1824.50 405.27 1905.89 422.89 1987.60 440.30 2068.61 459.59 2150.35 483.87 2233.80 511.55 2317.14 541.54 2399.24 574.45 2480.08 609.73 2561.02 b45.92 2638.97 684.42 2716.37 726.66 2794.38 769.34 2869.66 814.49 2947.31 859.64 3022.46 905.45 3098.40 952.18 3175.59 12.26 1.39 MWD _IFR_MS 12.27 0.22 MWD _IFR_MS 12.27 0.19 MWD _IFR_MS 12.28 1.32 MWD _IFR_MS 12.28 0.48 MWD _IFR_MS 12.29 0.63 MWD _IFR_MS 12.34 2.40 MWD _IFR_MS 12.51 3.87 MWD _IFR_MS 12.75 1.14 MWD _IFR_MS 13.04 3.02 MWD_ IFR_MS 13.39 1.92 MWD_ IFR_MS 13.77 2.30 MWD_ IFR_MS 14.17 1.85 MWD _IFR_MS 14.59 1.92 MWD_ IFR_MS 15.07 2.72 MWD _IFR_MS 15.55 0.93 MWD_ IFR_MS 16.04 1.75 MWD_ IFR_MS 16.52 0.46 MWD_ IFR_MS 16.99 1.33 MWD_ IFR_MS 17.45 1.56 MWD_ IFR_MS Non Non None None None None None None None None None None None None None Non Non None None None 56 5405.78 61.32 35.70 93.55 3718.66 3109.27 3095.83 999.55 3253.19 17.89 1.50 MWD_ IFR_ MS None 57 5500.71 60.71 35.59 94.93 3764.66 3192.31 3163.31 1047.94 3332.37 18.33 0.65 MWD IFR MS None 58 5596.24 61.46 38.08 95.53 3810.85 3275.87 3230.23 1098.07 3411.76 18.77 2.41 MWD IFR MS None 59 5691.12 63.07 42.66 94.88 3855.03 3359.45 3294.17 1152.46 3489.94 19.28 4.60 MWD IFR MS None 60 5785.12 63.56 47.61 94.00 3897.26 3442.09 3353.38 1211.97 3565.68 19.87 4.73 MWD IFR MS None [(c}2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 4 of 9 --- --- Seq -------- -------- Measured ------ ------ Tncl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) {ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 61 -------- 5879.62 ------ 63.10 ------- 51.86 ------ 94.50 -------- 3939.69 -------- 3523.73 -------- 3407.95 -------- 1276.38 ------- 3639.13 -------- 20.53 ----- 4.05 -- MWD --- _IFR ------ _MS None 62 5973.89 60.96 55.76 94.27 3983.92 3602.53 3457.12 1343.54 3709.01 21.24 4.30 MWD _IFR _MS None 63 6069.13 60.11 59.75 95.24 4030.78 3678.97 3501.35 1413.64 3775.96 21.99 3.75 MWD _IFR _MS None 64 6163.57 61.29 64.17 94.44 4077.01 3752.35 3540.04 1486.32 3839.40 22.78 4.27 MWD_ IFR _MS None 65 6258.13 59.14 68.38 94.56 4124.00 3822.48 3573.08 1561.41 3899.34 23.60 4.48 MWD_ IFR _MS None 66 6350.96 56.53 72.30 92.83 4173.43 3886.58 3599.54 1635.36 3953.62 24.43 4.55 MWD _IFR _MS Non 67 6445.47 57.16 76.61 94.51 4225.13 3947.64 3620.73 1711.57 4004.89 25.30 3.88 MWD_ IFR _MS Non 68 6539.08 58.35 80.50 93.61 4275.09 4004.99 3636.41 1789.15 4052.72 26.20 3.74 MWD_ IFR _MS None 69 6633.04 63.82 84.48 93.96 4320.52 4060.47 3647.08 1870.64 4098.84 27.15 6.90 MWD_ IFR _MS None 70 6727.96 67.49 87.23 94.92 4359.64 4115.02 3653.30 1956.87 4144.39 28.18 4.68 MWD IFR MS None 71 6821.91 68.85 90.61 93.95 4394.59 4166.36 3654.93 2044.05 4187.68 29.22 3.64 MWD_ IFR _MS None 72 6915.74 69.25 92.21 93.83 4428.14 4214.84 3652.77 2131.65 4229.26 30.27 1.65 MWD_ IFR _MS None 73 7010.72 68.67 92.35 94.98 4462.24 4262.76 3649.25 2220.22 4271.58 31.32 0.63 MWD_ IFR _MS None 74 7106.19 69.12 93.20 95.47 4496.62 4310.25 3644.93 2309.18 4314.84 32.36 0.96 MWD_ IFR _MS None 75 7201.07 73.97 94.13 94.88 4526.64 4357.03 3639.17 2398.97 4358.74 33.39 5.20 MWD_ IFR _MS None 76 7296.39 78.09 95.21 95.32 4549.65 4403.72 3631.64 2491.14 4403.93 34.45 4.46 MWD_ IFR MS None 77 7391.46 82.36 98.19 95.07 4565.79 4448.11 3620.69 2584.16 4448.29 35.52 5.45 MWD_ IFR _MS None 78 7485.28 86.37 100.46 93.82 4575.00 4488.55 3605.56 2676.27 4490.27 36.59 4.91 MWD_ IFR _MS None 79 7579.60 85.23 100.61 94.32 4581.91 4527.50 3588.36. 2768.75 4532.36 37.65 1.22 MWD_ IFR _MS None 80 7602.93 84.97 101.54 23.33 4583.90 4536.93 3583.90 2791.56 4542.81 37.92 4.13 MWD_ IFR _MS None 81 7681.09 86.19 101.75 78.16 4589.93 4567.82 3568.17 2$67.88 4577.83 38.79 1.58 INC_ TREND Non 82 7713.27 86.26 101.83 32.18 4592.04 4580.48 3561.61 2899.31 4592.50 39.15 0.33 MWD_ IFR _MS Non 83 7744.48 86.09 102.10 31.21 4594.13 4592.66 3555.15 2929.78 4606.81 39.49 1.02 MWD_ IFR _MS None 84 7775.02 86.60 102.28 30.54 4596.07 4604.48 3548.72 2959.57 4620.87 39.83 1.77 MWD_ IFR _MS None 85 7805.94 86.02 102.02 30.92 4598.06 4616.46 3542.22 2989.73 4635.28 40.17 2.05 MWD IFR MS None 86 7836.79 85.78 102.79 30.85 4600.27 4628.28 3535.61 3019.78 4649.69 40.50 2.61 MWD_ IFR _MS None 87 7866.71 85.57 102.05 29.92 4602.53 4639.74 3529.20 3048.92 4663.81 40.82 2.56 MWD_ IFR _MS None 88 7896.91 85.37 101.94 30.20 4604.91 4651.50 3522.94 3078.37 4678.40 41.15 0.76 MWD IFR MS None 89 7927.46 85.78 103.53 30.55 4607.27 4663.04 3516.22 3108.08 4692.97 41.47 5.36 MWD IFR MS None 90 7958.09 86.05 103.03 30.63 4609.45 4674.35 3509.21 3137.81 4707.48 41.80 1.85 MWD IFR MS None [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 5 of 9 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 91 -------- 7989.30 ------ 85.64 ------- 103.73 ------ 31.21 -------- 4611.71 -------- 4685.82 ------- 3502.00 --------- 3168.09 ------- 4722.38 -------- 42.13 ----- 2.59 --- MWD_ -- IFR ------ _MS None 92 8019.76 86.09 105.16 30.46 4613.91 4696.48 3494.43 3197.51 4736.57 42.46 4.91 MWD IFR MS None 93 8051.26 86.22 105.71 31.50 4616.02 4707.01 3486.06 3227.81 4750.93 42.80 1.79 MWD IFR MS None 94 8080.87 87.08 105.96 29.61 4617.75 4716.71 3477.99 3256.25 4764.41 43.11 3.02 MWD IFR MS None 95 8112.54 90.48 107.51 31.67 4618.42 4726.63 3468.88 3286.56 4778.56 43.45 11.80 MWD IFR MS None 96 8142.29 91.68 107.64 29.75 4617.86 4735.54 3459.90 3314.92 4791.62 43.77 4.06 MWD_ IFR _MS Non 97 8173.17 90.58 106.85 30.88 4617.26 4744.96 3450.74 3344.40 4805.48 44.10 4.39 MWD_ IFR _MS Non 98 8203.75 90.24 107.63 30.58 4617.04 4754.28 3441.68 3373.61 4819.38 44.43 2.78 MWD_ IFR MS None 99 8234.14 89.79 106.24 30.39 4617.03 4763.71 3432.83 3402.68 4833.48 44.75 4.81 MWD_ IFR _MS None 100 8265.29 90.51 107.47 31.15 4616.95 4773.41 3423.80 3432.49 4848.13 45.07 4.58 MWD_ IFR _MS None 101 8295.51 92.68 105.04 30.22 4616.11 4783.11 3415.34 3461.49 4862.76 45.38 10.78 MWD IFR MS None 102 8326.23 92.81 106.10 30.72 4614.63 4793.32 3407.11 3491.05 4878.09 45.70 3.47 MWD IFR MS None 103 8358.69 92.61 106.19 32.46 4613.10 4803.80 3398.09 3522.19 4894.17 46.03 0.68 MWD IFR MS None 104 8389.63 92.33 105.62 30.94 4611.77 4813.91 3389.62 3551.92 4909.75 46.34 2.05 MWD IFR MS None 105 8420.64 92.06 105.19 31.01 4610.58 4824.30 3381.39 3581.79 4925.75 46.65 1.64 MWD IFR MS None 106 8451.13 91.85 105.54 30.49 4609.54 4834.54 3373.31 3611.18 4941.64 46.95 1.34 MWD_ IFR _MS None 107 8481.91 91.61 105.27 30.78 4608.61 4844.86 3365.14 3640.84 4957.81 47.25 1.17 MWD_ IFR _MS None 108 8512.94 90.93 105.72 31.03 4607.92 4855.22 3356.85 3670.73 4974.21 47.56 2.63 MWD_ IFR _MS None 109 8544.63 90.48 106.62 31.69 4607.53 4865.45 3348.03 3701.17 4990.78 47.87 3.18 MWD_ IFR _MS None 110 8575.83 90.31 106.18 31.20 4607.32 4875.40 3339.22 3731.10 5007.14 48.17 1.51 MV~ID IFR MS None 111 8606.53 90.62 108.34 30.70 4607.07 4884.75 3330.11 3760.41 5022.98 48.47 7.11 MWD_ IFR _MS Non 112 8637.61 90.65 109.63 31.08 4606.72 4893.33 3320.00 3789.80 5038.35 48.78 4.15 MWD_ IFR _MS Non 113 8668.57 90.75 110.05 30.96 4606.34 4901.42 3309.50 3818.92 5053.40 49.09 1.39 MWD_ IFR _MS None 114 8699.43 90.45 110.76 30.86 4606.02 4909.20 3298.74 3847.84 5068.29 49.39 2.50 MWD_ IFR _MS None 115 8731.09 90.21 110.41 31.66 4605.84 4917.08 3287.61 3877.48 5083.62 49.71 1.34 M~n1D_ IFR _MS None 116 8762.44 90.00 109.84 31.35 4605.78 4925.13 3276.82 3906.91 5099.17 50.01 1.94 MWD_ IFR _MS None 117 8793.38 89.73 111.30 30.94 4605.85 4932.84 3265.95 3935.88 5114.45 50.31 4.80 MWD_ IFR _MS None 118 8825.04 89.49 110.35 31.66 4606.07 4940.59 3254.69 3965.47 5130.10 50.62 3.09 MWD_ IFR _MS None 119 8855.69 89.25 111.91 30.65 4606.41 4947.94 3243.65 3994.06 5145.26 50.92 5.15 MWD IFR MS None 120 8886.95 90.69 111.71 31.26 4606.42 4955.07 3232.03 4023.08 5160.54 51.22 4.65 M4~TD IFR MS None [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 6 of 9 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course ------- ------- TVD - -------- - -------- Vertical ------- ------- Displ --------- --------- Displ -------- -------- Total ------- ------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 121 -------- 8917.62 ------ 91.41 ------- 110.68 ------ 30.67 ------- 4605.86 - -------- 4962.39 ------- 3220.95 --------- 4051.67 -------- 5175.95 ------- 51.52 ----- 4.10 -- MWD --- _IFR ------ _MS None 122 8948.54 91.58 111.02 30.92 4605.05 4969.94 3209.94 4080.55 5191.79 51.81 1.23 MWD _IFR _MS None 123 8978.89 91.85 111.48 30.35 4604.15 4977.15 3198.95 4108.83 5207.28 52.10 1.76 MWD IFR MS None 124 9010.67 91.92 110.41 31.78 4603.10 4984.87 3187.59 4138.49 5223.78 52.40 3.37 MWD IFR MS None 125 9041.53 91.41 110.81 30.86 4602.20 4992.53 3176.74 4167.36 5240.09 52.68 2.10 MWD IFR MS None 126 9072.98 91.30 109.32 31.45 4601.46 5000.63 3165.95 4196.90 5257.11 52.97 4.75 MWD_ IFR MS None 127 9105.23 89.66 108.33 32.25 4601.19 5009.62 3155.54 4227.42 5275.27 53.26 5.94 MWD_ IFR _MS Non 128 9137.09 88.59 107.92 31.86 4601.68 5018.86 3145.63 4257.69 5293.67 53.54 3.60 MWD_ IFR _MS None 129 9167.95 88.59 107.97 30.86 4602.44 5027.91 3136.13 4287.04 5311.69 53.81 0.16 MWD_ IFR _MS None 130 9199.05 88.49 108.28 31.10 4603.23 5036.94 3126.46 4316.59 5329.89 54.08 1.05 MWD_ IFR _MS None 131 9229.39 88.35 109.85 30.34 4604.07 5045.26 3116.55 4345.25 5347.35 54.35 5.19 MWD_ IFR _MS None 132 9259.98 87.98 108.12 30.59 4605.04 5053.70 3106.60 4374.16 5365.10 54.62 5.78 MWD_ IFR _MS None 133 9291.86 89.14 108.28 31.88 4605.85 5062.91 3096.65 4404.44 5384.08 54.89 3.67 MWD_ IFR _MS None 134 9323.58 90.10 107.10 31.72 4606.06 5072.35 3087.01 4434.66 5403.32 55.16 4.80 MWD_ IFR _MS None 135 9355.01 89.83 107.35 31.43 4606.08 5081.94 3077.71 4464.68 5422.69 55.42 1.17 MWD_ IFR _MS None 136 9385.23 89.73 106.76 30.22 4606.19 5091.25 3068.84 4493.57 5441.50 55.67 1.98 MWD_ IFR _MS None 137 9415.73 89.66 107,21 30.50 4606.35 5100.69 3059.93 4522.74 5460.62 55.92 1.49 MWD_ IFR MS None 138 9447.21 89.21 108.21 31.48 4606.67 5110.04 3050.36 4552.72 5480.14 56.18 3.48 MWD_ IFR _MS None 139 9477.$2 89.62 108.32 30.61 4606.98 5118.85 3040.76 4581.79 5499.00 56.43 1.39 MWD IFR MS None 140 9509.07 89.93 107.60 31.25 4607.10 5128.01 3031.13 4611.52 5518.50 56.68 2.51 MWD IFR MS None 141 9540.45 89.69 107.16 31.38 4607.20 5137.51 3021.75 4641.46 5538.43 56.93 1.60 MWD_ IFR _MS Non 142 9570.74 89.35 106.39 30.29 4607.46 5146.98 3013.01 4670.46 5558.01 57.17 2.78 MWD_ IFR _MS Non 143 9601.96 88.29 104.96 31.22 4608.10 5157.31 3004.58 4700.52 5578.74 57.41 5.70 MWD_ IFR _MS None 144 9633.90 86.61 103.25 31.94 4609.52 5168.69 2996.80 4731.46 5600.67 57.65 7.50 MWD_ IFR _MS None 145 9664.80 85.98 102.36 30.90 4611.52 5180.34 2989.97 4761.53 5622.46 57.87 3.52 MWD_ IFR _MS None 146 9695.94 85.71 102.13 31.14 4613.77 5192.35 2983.38 4791.88 5644.70 58.09 1.14 MWD_ IFR _MS None 147 9727.04 87.02 103.40 31.10 4615.75 5204.10 2976.53 4822.15 5666.82 58.31 5.86 MWD_ IFR _MS None 148 9758.72 87.02 103.41 31.68 4617.39 5215.74 2969.19 4852.92 5689.20 58.54 0.03 MWD IFR MS None 149 9790.00 87.84 104.49 31.28 4618.80 5226.96 2961.66 4883.25 5711.18 58.76 4.33 MWD IFR MS None 150 9821.14 88.18 103.96 31.14 4619.88 5238.00 2954.01 4913.42 5733.05 58.99 2.02 MWD IFR MS None [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 7 of 9 --- --- Seq -------- -------- Measured ------ ------ Inc1 ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 151 -------- 9851.36 ------ 87.77 ------- 103.91 ------ 30.22 -------- 4620.95 -------- 5248.86 ------- 2946.74 --------- 4942.73 ------- 5754.46 -------- 59.20 ----- 1.37 --- MWD_ -- IFR ------ _MS None 152 9883.33 87.84 104.58 31.97 4622.17 5260.18 2938.88 4973.69 5777.08 59.42 2.11 MWD_ IFR _MS None 153 9914.52 87.56 105.41 31.19 4623.42 5270.84 2930.$1 5003.80 579$.93 59.64 2.81 MWD IFR MS None 154 9945.82 87.39 106.20 31.30 4624.80 5281.12 2922.30 5033.88 5820.64 59.86 2.58 MWD IFR MS None 155 9976.48 88.18 106.27 30.66 4625.99 5290.98 2913.73 5063.30 5841.82 60.08 2.59 MWD IFR MS None 156 10006.82 89.18 105.96 30.34 4626.69 5300.79 2905.31 5092.44 5862.91 60.29 3.45 MWD_ IFR _MS None 157 10039.14 88.94 105.73 32.32 4627.22 5311.40 2896.49 5123.53 5885.59 60.52 1.03 MWD_ IFR _MS Non 158 10070.89 88.70 105.96 31.75 4627.87 5321.81 2887.82 5154.06 5907.95 60.74 1.05 MWD IFR MS None 159 10102.00 87.63 105.16 31.11 4628.87 5332.16 2879.48 5184.02 5930.05 60.95 4.29 MWD IFR MS None 160 10133.13 87.19 105.58 31.13 4630.27 5342.61 2871.24 5214.00 5952.30 61.16 1.95 MWD IFR MS None 161 10165.11 86.84 105.83 31.98 4631.94 5353.16 2862.59 5244.75 5975.10 61.37 1.34 MWD IFR MS None 162 10196.31 85.12 107.00 31.20 4634.12 5363.08 2853.80 5274.60 5997.13 61.58 6.66 MWD IFR MS ^ None 163 10227.70 84.68 107.84 31.39 4636.92 5372.53 2844.44 5304.43 6018.96 61.80 3.01 MWD_ IFR _ MS None 164 10259.08 84.58 106.56 31.38 4639.85 5382.08 2835.20 5334.28 6040.93 62.01 4.07 MWD IFR MS None 165 10289.41 84.33 106.41 30.33 4642.78 5391.66 2826.63 5363.22 6062.51 62.21 0.96 MWD IFR MS None 166 10320.77 85.43 105.73 31.36 4645.58 5401.79 2817.99 5393.24 6085.07 62.41 4.12 MWD_ IFR _MS None 167 10352.09 87.94 107.09 31.32 4647.39 5411.76 2809.16 5423.23 6107.60 62.62 9.11 MWD IFR MS None 168 10382.05 88.18 106.19 29.96 4648.41 5421.19 2800.58 5451.92 6129.16 62.81 3.11 MWD IFR MS None 169 10413.61 86.15 106.89 31.56 4649.97 5431.17 2791.61 5482.13 6151.98 63.01 6.80 MWD IFR MS None 170 10444.17 84.92 107.56 30.56 4652.35 5440.47 2782.59 5511.23 6173.85 63.21 4.58 MWD IFR MS None 171 10474.60 85.16 107.17 30.43 4654.98 5449.66 2773.54 5540.17 6195.64 63.41 1.50 MWD_ IFR _MS Non 172 10507.15 85.02 108.56 32.55 4657.76 5459.21 2763.59 5571.03 6218.83 63.62 4.28 MWD_ IFR _MS Non 173 10537.66 85.64 107.46 30.51 4660.25 5468.10 2754.19 5599.95 6240.59 63.81 4.13 MWD IFR MS None 174 10568.39 86.54 106.97 30.73 4662.34 5477.46 2745.12 5629.23 6262.90 64.00 3.33 MWD IFR MS None 175 10598.72 $6.36 107.30 30.33 4664.22 5486.75 2736.20 5658.16 6285.03 64.19 1.24 MWD IFR MS None 176 10629.64 85.98 107.06 30.92 4666.29 5496.19 2727.08 5687.64 6307.63 64.38 1.45 MWD_ IFR _MS None 177 10660.71 85.64 105.61 31.07 4668.56 5506.11 2718.37 5717.37 6330.71 64.57 4.78 MWD IFR MS None 178 10691.27 86.26 106.07 30.56 4670.71 5516.11 2710.05 5746.70 6353.65 64.75 2.52 MWD_ IFR _MS None 179 10722.93 87.87 105.84 31.66 4672.33 5526.43 2701.36 5777.10 6377.47 64.94 5.14 MWD TFR MS None 180 10754.10 88.11 104.16 31.17 4673.43 5537.08 2693.30 5807.19 6401.35 65.12 5.44 MWD IFR MS None ((c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 8 of 9 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ -------- -------- Total ------- ------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E1W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) -------- ideg) ------- 100f) ----- type ----- (deg) ------ --- 181 -------- 10785.46 ------ 87.77 ------- 104.35 ------ 31.36 -------- 4674.56 -------- 5548.18 -------- 2685.58 -------- 5837.56 -------- 6425.69 ------- 65.30 ----- 1.24 ----- MWD_IFR ------ _MS None 182 10816.59 87.46 104.52 31.13 4675.85 5559.11 2677.83 5867.68 6449.84 65.47 1.14 MWD_IFR _MS None 183, 10847.2$ 87.22 103.90 30.69 4677.28 5569.99 2670.30 5897.40 6473.78 65.64 2.16 MWD_IFR _MS None 184 10877.85 86.91 104.29 30.57 4678.84 5580.88 2662.86 5927.01 6497.71 65.81 1.63 MWD_IFR _MS None 185 10909.57 86.71 104.07 31.72 4680.61 5592.14 2655.11 5957.72 6522.57 65.98 0.94 MWD_IFR _MS None 186 10941.16 187 10972.35 188 11003.61 189 11034.52 190 11066.75 191 11097.34 192 11128.32 193 11159.22 194 11190.29 195 11221.59 196 11252.80 197 11283.24 198 11314.43 199 11345.47 200 11377.28 201 11407.56 202 11439.57 203 11469.85 204 11502.45 205 11533.16 206 11563.73 207 11595.38 208 11627.37 209 11658.01 210 11688.93 86.40 105.60 31.59 4682.50 5603.01 2647.03 5988.20 6547.16 66.15 4.93 MWD_ IFR _MS None 86.22 105.02 31.19 4684.51 5613.50 2638.81 6018.22 6571.32 66.32 1.94 MWD_ IFR _MS Non 86.29 105.43 31.26 4686.55 5624.05 2630.62 6048.32 6595.63 66.49 1.33 MWD_ IFR _MS None 85.99 105.81 30.91 4688.63 5634.29 2622.32 6078.02 6619.58 66.66 1.56 MWD_ IFR _MS None 85.95 105.71 32.23 4690.90 5644.88 2613.59 6108.96 6644.56 66.84 0.33 MWD_ IFR _MS None 87.12 105.92 30.59 4692.75 5654.91 2605.27 6138.34 6668.33 67.00 3.89 MWD_ IFR _MS None 90.07 104.14 30.98 4693.51 5665.49 2597.24 6168.24 6692.75 67.17 11.12 MWD_ IFR _MS None 91.34 103.88 30.90 4693.13 5676.56 2589.76 6198.22 6717.50 67.32 4.20 MWD_ IFR _MS None 91.27 103.98 31.07 4692.42 5687.72 2582.28 622$.37 6742.46 67.48 0.39 MWD_ IFR _MS None 91.13 163.51 31.30 4691.76 5699.07 2574.84 6258.77 6767.72 67.64 1.57 MWD_ IFR _MS None 90.79 103.17 31.21 4691.24 5710.59 2567.64 6289.13 6793.08 67.79 1.54 MWD_ IFR _MS None 90.45 103.54 30.44 4690.91 5721.81 2560.61 6318.75 6817.86 67.94 1.65 MWD_ IFR _MS None 90.21 102.85 31.19 4690.73 5733.40 2553.49 6349.11 6843.36 68.09 2.34 MWD_ IFR _MS None 90.00 102.74 31.04 4690.68 5745.13 2546.62 6379.38 6868.90 68.24 0.76 MWD_ IFR _MS None 89.93 103.07 31.81 4690.70 5757.09 2539.51 6410.39 6895.08 68.39 1.06 MWD_ IFR _MS None 89.76 102.98 30.28 4690.78 5768.42 2532.69 6439.89 6920.02 68.53 0.64 MWD_ IFR _MS Non 89.52 104.88 32.01. 4690.98 5779.93 2524.98 6470.95 6946.14 68.68 5.98 MWD_ IFR _MS Non 90.24 106.13 30.28 4691.04 5790.04 2516.89 6500.13 6970.40 68.83 4.76 MWD_ IFR _MS None 89.90 106.41 32.60 4691.00 5800.51 2507.76 6531.43 6996.31 69.00 1.35 M[nID_ IFR _MS None 89.25 106.61 30.71 4691.23 5810.24 2499.03 6560.87 7020.69 69.15 2.21 MWD_ IFR _MS None 87.91 105.60 30.57 4691.99 5820.14 2490.55 6590.23 7045.14 69.30 5.49 MWD_ IFR _MS None 88.73 104.84 31.65 4692.92 5830.85 2482.25 6620.75 7070.78 69.45 3.53 MWD_ IFR _MS None 90.31 105.21 31.99 4693.18 5841.77 2473.95 6651.65 7096.82 69.60 5.07 MWD_ IFR_ MS None 89.69 105.01 30.64 4693.18 5852.20 2465.97 6681.23 7121.78 69.74 2.13 MWD_ IFR_ MS None 87.29 104.95 30.92 4694.00 5862.78 2457.98 6711.09 7147.05 69.8$ 7.76 MWD_ IFR_ MS None [(0)2005 IDEAL ID9_1C_02] s SCHLUMBERGER Survey Report 19-Jun-2005 11:34:52 Page 9 of 9 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ------ ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- {deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) ------- {deg) -------- 100f) ----- type ----- (deg} ------ --- 211 -------- 11720.29 ------ 86.67 ------- 104.23 ------ 31.36 -------- 4695.65 -------- 5873.70 -------- 2450.09 -------- 6741.39 ------- 7172.82 -------- 70.03 ----- 3.03 ----- MWD_IFR ------ _MS None 212 11751.78 87.81 104.08 31.49 4697.17 5884.89 2442.40 6771.89 7198.88 70.17 3.65 MWD_IFR _MS None 213 11782.78 89.62 103.89 31.00 4697.86 5896.01 2434.91 6801.96 7224.64 70.30 5.87 MWD_IFR _MS None 214 11813.73 89.59 103.75 30.95 4698.08 5907.19 2427.52 6832.02 7250.47 70.44 0.46 MWD_IFR_ MS None 215 11845.23 89.31 104.33 31.50 4698.38 5918.46 2419.$7 6862.57 7276.72 70.58 2.04 MWD_IFR_ MS None 216 11875.93 217 11907.25 218 11938.52 219 11968.88 220 12000.14 221 12031.08 222 12063.10 223 12093.82 224 12124.32 225 12155.92 226 12186.73 227 12218.06 228 12249.14 229 12279.57 230 12310.73 231 12341.75 232 12372.73 233 12404.87 234 12436.03 235 12467.63 236 12499.52 237 12529.66 238 12573.99 239 12628.00 88.97 103.09 30.70 4698.84 5929.60 2412.60 6892.39 7302.45 70.71 4.19 MWD_ IFR_ MS None 88.25 103.09 31.32 4699.60 5941.28 2405.51 6922.89 7328.91 70.84 2.30 MWD_ IFR_ MS Non 86.40 103.28 31.27 4701.06 5952.89 2398.38 6953.30 7355.31 70.97 5.95 MWD_ IFR_ MS None 85.92 104.33 30.36 4703.09 5963.84 2391.16 6982.72 7380.78 71.10 3.80 MWD_ IFR_ MS None 86.53 106.40 31.26 4705.15 5974.32 2382.89 7012.79 7406.58 71.23 6.89 MWD_ IFR_ MS None 88.18 107.07 30.94 4706.58 5984.01 2373.99 7042.39 7431.76 71.37 5.75 MWD_ IFR_ MS None 89.18 106.33 32.02 4707.31 5994.06 2364.79 7073.05 7457.90 71.51 3.88 MWD_ IFR_ MS None 89.35 106.13 30.72 4707.71 6003.94 2356.21 7102.54 7483.17 71.65 0.85 MWD_ IFR_ MS None 89.01 106.60 30.50 4708.15 6013.69 2347.62 7131.81 7508.26 71.78 1.90 MWD_ IFR_ MS None 88.66 106.61 31.60 4708.79 6023.66 2338.59 7162.08 7534.22 71.92 1.11 MWD_ IFR_ MS None 88.56 106.99 30.81 4709.54 6033.28 2329.68 7191.57 7559.50 72.05 1.27 MWD_ IFR_ MS None 88.15 107.19 31.33 4710.43 6042.91 2320.48 7221.50 7585.16 72.19 1.46 MWD_ IFR_ MS None 88.49 107.58 31.08 4711.35 6052.31 2311.20 7251.15 7610.57 72.32 1.66 MWD_ IFR_ MS None 88.53 106.71 30.43 4712.14 6061.64 2302.23 7280.22 7635.56 72.45 2.86 MWD_ IFR_ MS None 88.01 106.94 31.16 4713.08 6071.35 2293.22 7310.03 7661.29 72.58 1.82 MWD_ IFR_ MS None 87.39 107.38 31.02 4714.32 6080.85 2284.07 7339.64 7686.83 72.71 2.45 MWD_ IFR_ MS Non 87.02 107.03 30.98 4715.83 6090.31 2274.92 7369.20 7712.35 72.84 1.64 MWD_ IFR_ MS Non 85.64 106.77 32.14 4717.89 6100.27 2265.60 7399.89 7738.95 72.98 4.37 MWD_ IFR_ MS None 85.13 107.75 31.16 4720.40 6109.73 2256.38 7429.55 7764.63 73.11 3.54 MWD_ IFR_ MS None 85.33 108.93 31.60 4723.03 6118.76 2246.47 7459.44 7790.37 73.24 3.77 MWD_ IFR_ MS None 85.95 108.82 31.89 4725.45 6127.59 2236.19 7489.53 7816.24 73.38 1.97 MWD_ IFR_ MS None 87.32 106.27 30.14 4727.22 6136.62 2227.12 ?518.22 7841.15 73.50 9.59 MWD_ IFR_ MS None 86.84 106.41 44.33 4729.48 6150.78 2214.66 7560.70 7878.38 73.67 1.13 MWD_ IFR_ MS None 86.84 106.41 54.01 4732.46 6167.98 2199.43 7612.43 7923.80 73.88 0.00 Projection to TD [(c)2005 IDEAL ID9_1C_02J • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaskan Inc. L-202 Nabors 9ES Dispatched To: Date Dispatched Dispatched By: Helen Warman (AOGCC- 28-Jun-05 Nlauricio Perdomo Data No Of Prints No of Floppies Surveys 2 1 I Please sign and return to: James H. Johnson Received By: vo.ti BP Exploration (Alaska) Inc. Petrotechnical Data Center(LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:'ohnsojhC~bp.com LWU Log Uehvery V1.1, IU-0Z-U3 r ~ ~~ ~~ ~ 4 ; ~ ~ FRANK H. MURKOWSK/, GOVERNOR ~~ ~ t Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-202 BP Exploration (Alaska) Inc. Permit No: 204-196 Surface Location: 2572' NSL, 3690' WEL, SEC. 34, T12N, R11E, UM Bottomhole Location: 4780' NSL, 3915' EWL, SEC. 35, T12N, R11E, UM Dear Mr, Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). BY ORDER O~ THE COMMISSION DATED this- day of October, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • ~, ~ STATE OF ALASKA ALASKA O~AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~ ~~G~ ICs/z~~~ SAP ~ ~ ~~~~ ~. 1a. Type of work ®Drill ^Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil Itiple done ^ Stratigraphic Test ^ Service ^Development Gas f~~8ne 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU L-202 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12634 TVD 4722 12. Field /Pool(s): Prudhoe Bay Field !Orion 4a. Location of Well (Governmental Section): Surface: 2572' NSL 3690' WEL SEC 34 T12N R11E UM 7. Property Designation: ADL 028238 Schrader Bluff , , , . , , Top of Productive Horizon: 877' NSL, 897' WEL, SEC. 27, T12N, R11E, UM (O Bd) 8. Land Use Permit: 13. Approximate Spud Date: November 8, 2004 Total Depth: 4780' NSL, 3915' EWL, SEC. 35, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 4660' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583224 y- 5978293 Zone-ASP4 10. KB Elevation (Height above GL):Plan 77.3 feet 15. Distance to Nearest Well Within Pool L-118 is approximately 580' away 16. Deviated Wells: Kickoff Depth: 700 feet Maximum Hole Angle: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2035 Surface: 1580 ~ 1 asing rogram: Size Specifications Setting Depth To Bottom uantrty o -ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 48" 20" x 34" 215.5# A53 Weld 80' 29' 29' 109' 109' 260 sx Arctic Set A rox. 13-1/2" 10-3/4" 45.5# L-80 BTC 3171 29' 29' 3200' 2627' 580 sx AS Lite, 442 sx Class 'G' 9-7/8" 7-518" 29.7# L-80 BTC-M 7771' 29' 29' 7800' 4635' 62 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 IBT 4834' 7800' 4635' 12634' 4722' Uncemented Slotted Liner 19. PRESENT W ELL 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): Casing '`length Size Cement Volume MD TVD n tr t it Pr ducti n Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ 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 to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name L ell Crane Title Senior Drilling Engineer Prepared By Name/Number: Si nature `.~ Phone 564-4089 Date f'~ 23 - c Terrie Hubble, 564-4628 Commission flee Only Permit To Drill Number: .. API Number: 50_ d,,,~, '..- ~ 3 2 ~, Permit Approval Date: ~ Gv ~ ` See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ~No Mud Log Required [] Yes f~,No Hydrogen Sulfide Measures ^ Yes ~No Directional Survey Required $(Yes ^ No Other: T~~. CMG ~~ ~ ~''~ ~S~G `~Sfl , j~~ r Z ~. S, D '~ S (~=~ ~ ~ ~ ~ c~ ~ ~ ~~ n.cL ~L ~~~~ ~F S.l~ ~v`~~! t ~.~:i ' ~ S ~~ t ~' t(~ ~ , APPROVED BY A roved B THE COMMISSION Date ~d d fait Form 10-401 Revised Ot~4 ~"~ V ~ ~ ~' ~ ~ ~ ~ ~(ibm~ln Duplicate • • ~ Well Name: ~ L-202, L-202 L1, L-202 L2 & L-202 L3 ~ Drill and Complete Plan Summary Type of Well (producer or injector): Schrader OBd, OBb, OBa, and OA Multilateral Producer Surface Location: 2,572' FSL, 3,690' FEL, Sec. 34, T12N, R11 E -° As Built X = 583,224 Y = 5,978,293 L-202 OBd Target Start: 87T FSL, 89T FEL, Sec. 27, T12N, R11 E X = 585,970 Y = 5,981,910 Z = 4,547' TVDss L-202 OBd Target End: 4,780 FSL, 1,364' FEL, Sec. 35, T12N, R11 E X = 590.800 Y = 5.980.590 Z = 4.645' TVDss L-202 L1 OBb Target Start: 754' FSL, 569' FEL, Sec. 27, T12N, R11 E X = 586,300 Y = 5,981,790 Z = 4,450' TVDss L-202 L1 OBb Target End: 4,864' FSL, 1,663' FEL, Sec. 35, T12N, R11 E X = 590.500 Y = 5.980.670 Z = 4.525' TVDss L-202 L2 OBa Target Start: 815' FSL, 698' FEL, Sec. 27, T12N, R11 E X = 586,170 Y = 5,981,850 Z = 4,415' TVDss L-202 L2 OBa Target End: 4,848' FSL, 1,613' FEL, Sec. 35, T12N, R11 E X = 590,550 Y = 5,980,655 Z = 4,487' TVDss L-202 L3 OA Target Start: 650' FSL, 1 y0' FEL, Sec. 27, T12N, R11 E X = 586,680 Y = 5,981,690 Z = 4,340' TVDss L-202 L3 OA Target End: 12' FSL, 3,208' FEL, Sec. 26, T12N, R11 E X = 588,950 Y = 5,981,080 Z = 4,360' TVDss AFE Number: ORD5M3556 Ri Nabors 9es GL: 48.8' KB: 28.5' KBE: 77.3' Estimated Start Date: November 8, 2004 OBd MD: 12,634' OBb MD: 12,304' OBa MD: 12,349' OA MD 10,674' Current Well Information Distance to Nearest Property: Distance to Nearest Well in Pool: L-202 Original Well API #: L-202 L1 API OBb #: L-202 L2 API OBa #: L-202 L3 API OA #: Well Type: Current Status: Conductor: H2S: BHT: BHP: TVD: 4,722' TVD: 4,602' TVD: 4,564' TVD: 4,437' O eratin da s to com lete: 44.6 Max lnc: 91.5° Max lnc: 91.8° Max lnc: 92.3° Max Inc: 91.0° KOP: 700' KOP: 7,138' KOP: 7,005' KOP: 6,808' 4,660' to PBU Unit Boundary at Top OA 580' to L-118 at Top Nb 50-029-XXXXX-00 50-029-XXXXX-60 50-029-XXXXX-61 50-029-XXXXX-62 Schrader O-sand Quadlateral Producer New well, conductor is set 20" X 34", 215.5 ppf, A53, ERW set at 109' KB 0 ppm from produced fluids (approximated to be around 10 ppm due to contaminated gas lift gas) 84 °F @ 4,400' TVDss (Estimated) 8.6 - 8.7 ppg in Schrader O-Sands ~ Permit to Drill 09/23/04 1 Formation Markers Z-210 P61(Based on Schlumberaer wa03) Formation To s MD TVD TVDss Pore si EMW H drocarbons G 1 337' 337' 260' 120 8.8 No SV6 968' 967' 890' 409 8.8 No Fault #1 1,284' 1,277' 1,200' SV5 1,578' 1,552' 1,475' 679 8.8 No SV4 1,718' 1,677' 1,600' 736 8.8 Poss. Gas Hydrates Base Permafrost 1,805' 1,752' 1,675' 771 8.8 No SV3 2,156' 2,032' 1,955' 899 8.8 Poss. Gas Hydrates SV2 2,400' 2,202' 2,125' 978 8.8 Poss. Gas Hydrates SVi 2,999' 2,527' 2,450' 1,127 8.8 Poss. Gas Hydrates UG4 3,594' 2,822' 2,745' 1,263 8.8 Thin coal UG4A 3,650' 2,850' 2,773' 1,276 8.8 Heavy Oil between 2770' and 2940' ss UG3 4,381' 3,212' 3,135' 1,442 8.8 Thin coals/poss. Heavy oil Fault #2 5,171' 3,597' 3,520' UG1 5,388' 3,702' 3,625' 1,668 8.8 Heavy Oil between 3770' and 3910' ss Schrader Bluff/Ma Sand 5,965' 3,987' 3,910' 1,799 8.8 Heavy Oil between 3910' and 3950' ss Mb1 6,044' 4,027' 3,950' 1,817 8.8 Heavy Oil between 3950' and 4010' ss Mb2 6,164' 4,087' 4,010' 1,807 8.7 Heavy Oil between 4010' and 4095' ss Mc 6,336' 4,172' 4,095' 1,842 8.7 Heavy Oil between 4095' and 4140' ss Na 6,429' 4,217' 4,140' 1,878 8.7 No Nb 6,482' 4,242' 4,165' 1,888 8.7 Yes Nc 6,579' 4,287' 4,210' 1,905 8.7 Yes OA 6,783' 4,377' 4,300' 1,938 8.7 Yes OBa 6,967 4,447 4,370' 1,968 8.7 Yes OBb 7,119' 4,502' 4,425' 1,985 8.6 Yes OBc 7,313' 4,567' 4,490' 2,010 8.6 Yes OBd 7,659' 4,627' 4,550' 2,040 8.6 Yes OBe N/A N/A N/A N/A N/A Not Penetrated Mud Program: 13-1/2" Surface Hole Mud Pro erties: Spud -Freshwater Mud Interval Densi Funnel vis YP PH FL Initial 8.5 - 9.2 250-300 50-70 8.5-9.0 NC-8.0 Base Perm 9 - 9.5 200-250 30-45 8.5-9.0 8.0 Interval TD max 200-250 30-40 8.5-9.0 5.0-7.0 ~~, 9-7/8" Intermediate Hole Mud Pro erties: Freshwater Mud (LSND) Interval Densit YP PV API Filtrate MBT H Chlorides Surface shoe to interval TD 9.0 - 9.3 26-30 12-18 4-6 < 20 9.0-9.5 <600 6-3/4" Production Hole Mud Pro erties: LVT-200 MOBM (Versa-Pro} Interval Densit Stabilit Oil:Water Ratio YP PV API Filtrate MBT All four Laterals 9.0 - 9.2 650-900 80:20 15-19 <20 4-5.5 < 6 Survey and Logginq Program: 13-1/2" Hole Section: Surface Gyro will be needed (run to 1200' MD or as conditions dictate) O en Hole: MWD / GR Cased hole: None 9-7/8" Intermediate Hole: Surveys will need to be IFR + MS corrected real time O en hole: MWD / GR / Res /Den / Neu /PWD All realtime with recorded orosit Cased Hole: None 6-3/4" Produciton Holes: Surve s will need to be IFR + MS corrected real time O en hole: MWD ! GR / Res /Den !Neu /PWD !AIM All realtime with recorded orosit Cased Hole: N/A ~' . (o Permit to Drill 09/23/04 Casina/Tubina Program Hole Size Csg / Tb O.D. Wt/Ft Grade / CorjrS Burst si Collapse si Length Top MD /TVDrkb- Bottom MD /TVDrkb 48" 20" X 34" 215.5# A53 Weld 80' 29'/29' 109'/109' 13-'/z" 10-3/a" 45.5# L-80 BTC 5,210 2,480 3,171' 29'/29' 3,200'/2,627' 9-'/e" 7 5/8" 29.7# L-80 BTC-M 6,890 4,790 7,771' 29'J29' 7,800'!4,635' 6-3/a" OBd 4-~h" slotted 12.6# L-80 IBT N!A N!A 4,834' 7,800'14,635' 12,634'14,722' 6-3/a" OBb 4-~/z"slotted 12.6# L-80 IBT N/A N/A 5,178' 7,126'14,505' 12,304'14,602' 6-3/a" OBa 4-~/2" slotted 12.6# L-80 IBT N/A N/A 5,356' 6,993'/4,456' 12,349'/4,564' 6-3/a" OA 4-~h" slotted 12.6# L-80 IBT N/A N/A 3,878' 6,796'/4,382' 10,674'/4,437' Tubin 4-1/z" 12.6# L-80 IBT-M 8,430 7,500 6,735' 29'/29' 6,764'/4,360' Surface and Anti-Collision Issues Surface Shut-in Wells: L-200 will require surface shut-in and wellhouse removal in order to move over well L-202. No other wells shou{d require wellhouse removal and surface shut-in. Close Approach Shut-in Wells: There are NO wells requiring subsurface isolation for this profile. Close Aauroach Well List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautionar Comment L-200 15.8' 300' 10.7' Use Travelin C tinder G ro L-216 60.3' 249' 56.2' Use Travelin C tinder G ro L-118 61.9' 1,402' 37.5' Use Travelin C tinder G ro L-103 76.7' 499' 68.9' Use Travelin C tinder G ro L-101 95.2' 1,706' 65.3' Use Travelin C tinder G ro Cement Calculations Casing Size: 10-3/a -in 45.5-Ib/ft L-80 BTC surface casing -single stage Basis: Lead: 250% excess o~rer gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 1,000' of open hole with 30% excess, plus 80' shoe track Tail TOC: 2,200' MD 1,000' MD above shoe Total Cement Volume: Spacer 80 bbls of Viscosified cer weighted to 10.60 ppg (Mud P Lead 442 bbls, 2484 cuf sks 10.7 Ib/ al ASL G + adds - cuft/sk Tail 92 bbls, 517 cuft 4 sks 15.8 Ib/ al Class G + adds - cuft/sk Temp BHST ~55° F. B --60° F estimated by Schlumberge _" 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. Open TAM Port Collar and perform second cement job. Casin Size: 7-5/8", 29.7-Ib/ft L-80 BTC-M intermediate casing Basis: Lead: None Lead TOC: N/A Tail: 2,335' open hole with 30% excess, plus 80' shoe track Tail TOC: ,, MD 500' MD above tanned Ma to at 5,965' MD Total Cement Volurr~: Wash 20 bbls CW100 S acer 35 bbls of Viscosifie acer Mud ush II Desi n We' a to 10.3 Tail 120 bbls, 674 cuft, 6 sks 15.8 Ib/ al G + Gasblok -1. cuft/sk Temp BHST -- 90° F fro mo Lop. BHCT 80° F estimate V Schlumberoer l 3 Permit to Drill 09/23/04 ~ . i ~~ Centralizer Recommendations 10-3/a" Casing Centralizer Placement a) Run (25) 9-5/8" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,200' MD (1,000' MD above the shoe). b) This centralizer program is subject to change pending actual hole conditions. 7 5/s" Casing Space Out a) Space 7 5/8" casing out with pups and longlshort joints as required to place the top of a long full joint -- 5-15' above the top of the OBb, OBa and OA sands to allow for the window to be milled just below the top of each sand and in the middle of a full joint of casing. These KOP's may be altered to enhance reservoir contact depending on the angle of intersection of each zone. b) Place 1 RA tag above each window exit. RA tags to be spaced out ~40 - 80' above window depth except on the OBd lateral. It will need to be placed 120' above the casing shoe. c) Emergency 7 5/8" casing slips can be used instead of the 7-5/" mandrel hanger if required for space out. 7 5!e" String Centralizer Placement a) Centralizer size: 7 5/8" X 9-%8" (this is different then the norm of/o" under gauge hole) b) Do not run centralizers on the window joints spaced at the top of each sand. c) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. d) With the exception stated above, alternate 1 rigid straight vane cenralizer floating across a full joint and 2 rigid straight vane centralizers, one floating on the upper half of the joint and one floating on the lower half of the joint separated by a stop collar up to 6,482' MD (Top Nb). Then continue with 1 rigid straight vane centralizer per joint floating to 5,465' MD (500' MD above Ma sand). Zonal isolation with cement is required between the OA and the Nb sands. The centralizer program is subject to change pending modeling and hole conditions. 4 ~/z" Solid Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint, floating between the collars. If any differential sticking is noticed while drilling, it may be necessary to put another centralizer per joint separated by a stop collar. Do not put any centralization on the first two joints above the bent joint. 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 test pressures not exceeding S,000psi it will not be necessary to have two sets of pipe rams installed at all times. G-2oz t~G~ re ular test frequency for , .will e 1 a ~ Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 10-3/4" Casing Test: • Integrity Test - 9-7/8" hole: • Kick Tolerance: 2,035 psi - Schrader OBd (8.6 ppg @ 4,550' TVDss) 1,580 psi -Based on a full column of gas @ 0.10 psi/ft ~ 3,500 psi/250 psi Rams / 2,500 psi/250 psi Annular 3,500 psi OT 20' from -10-3/4"shoe 50abls with an 11.2 ppg EMW LOT 4 Permit to Drill 09!23104 s • Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7-5/8" Casing Test: • Integrity Test - 6-3/4" hole: • Kick Tolerance: • Planned completion fluid: 2,035 psi -Base of Schrader OBd (8.6 ppg C~ 4,550' TVDss) 1,580 psi -Based on a full column of gas C~3 0.10 psi/ft 3,500 psi/250 psi Rams ~ 2,500 psi/250 psi Annular 3,500 psi FIT 20' from 7-5/8" shoe Infinite with an 10.7 ppg EMW FIT Estimated 9.0 ppg Brine 16.8 ppg Diesel 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. Materials Needed Surface Casin - Amount Description - -- 3,200' - 3 ----- -- -- 10- /a", 45.5#, L-80, BTC Casing 1 each 10-3/", BTC Float Shoe and Float Collar 25 each 10-3/a" x 13-~h" Bow Spring Centralizers 1 assembly FMC 11" 5m Gen 5 Wellhead System 1 lot 10-3/a" casing pups 5', 10', 20'. 1 each 10-3/a" TAM Port Collar '`Intermediate Casin Amount Description 7 800' _ _ _ _ _ 7 5/a" 29.7# L-80 BTC-M Casing , 1 each 7-5/8" BTC-M Float Shoe and Float Collar 75 each 7 5/8" x 9-%8" Rigid Straight Blade Centralizers 20 each 7 5/8" Stop Rings 2 lots 7 5/8" casing pups 5', 10', 20' 4 each 7 5/8" RA Tag Prpduction Liner: Amount Descri tion _ _ 4 x Production Liners: 19,300' _________ ___ _____ _ 4 ~/2", 12.6#, L-80, IBT-Mod Slotted Liner 482 each 4'h" x 5 3/a" x 8" Straight Blade Centralizers 4 each 7-5/g" x 4-'/z" Baker ZXP Liner Top Packer 4 each 4-'h" Halliburton Float Shoes 3 assemblies Baker Level 3 Hookwall Han ers with LEM Com ` letion: 'Amount Description 6,800' ___ __ _ _____ 4-~/z", 12.6 Ib/ft, L-80, BTC-M tubing 1 each Baker PRM Production Packer 7 5/" X 4-%2" 1 each 11" X 4-'/z" FMC tubing hanger 1 each 4-'i,s", 5m Cameron Tree 2 each Halliburton X-Nipple (3.813" ID) 1 each 4-'/z" Baker CMD Sliding Sleeve 4 each Camco 4-%z" X 1" KBG-2 Gas Lift Mandrels 2 each Phoenix pressure gauge 6,800' I-wire for the Phoenix gauge 3 each Half-muleshoed joint of 4-'h" IBT-M tubing 1 each 4-'h" WLEG 5 Permit to Drill 09/23104 e • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Schrader in the Polygon 1A fault block is expected to be normal pressured at 8.5-8.6 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are expected at L-pad near the base of the permafrost. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. I11. Lost Circulation/Breathing A. Lost circulation is not expected at the L-Pad fault. In addition the fault wily be crossed at high angle and move away quickly. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 10-3/4" casing will be cemented to surface. B. The 10-3/4" casing test pressure is 3500 psi~.r~` C. The Kick Tolerance for the surface casing 50,,~bbls with 9.0 ppg mud, 11.2 ppg LOT, and an 8.8 ppg pore pressure. :.c:' D. 9-7/8" Openhole Integrity Testing -LOT to a minimum of 11.2 ppg EMW 20' from the shoe. E. The 7-5/8" intermediate casing will be cemented with 15.8 Ib/gal tail cement to 500' MD above the Ma sand @ 5,465' MD. F. The 7-5/8" casing test pressure is 3500 psi. .~--~ G. The Kick Tolerance for the intermediate casing isfinit~~with 9.0 ppg mud, 10.5 ppg FIT, and an 8.8 ppg pore pressure. H. 6-3/4" Openhole Integrity Testing -FIT to a minimum of 10.5 ppg EMW 20' from the shoe. V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at L pad as a result of the use of Ivishak gas lift gas. All L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-02 10 ppm L-101 5 ppm L-116 10 ppm VII. Faults A. Two faults are expected to be crossed at L-202. No losses are expected to be associated with this fault. Details are listed below for reference: Fault Location MD TVD TVDss Throw Direction Uncertainty Fault #1 - SV6 1,285' 1,277' 1,200' 50' to 70' West +/- 150' MD Fault #2 - UG3 5,171' 3,597' 3,520' 40' to 50' South +/- 150' MD CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Permit to Drill 09/23/04 r ~ ~ L-202, L-202 L1, L-202 L2 & L-202 L3 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: i. A 34" x 20" insulated conductor has already been set and surveyed. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Prepare neighboring wells for the rig move and production simops. Drilling Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and riser. Function test diverter. PU 4" DP and stand back in derrick. 2. MU 13-'/z" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,200' MD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand. 3. Run and cement the 10-3/a", 45.5#, L-80 surface casing back to surface. ND drifting spool and riser and NU ~ casing 1 tubing head. NU BOPE and test to 3,500 psi. 4. MU 9-%" directional drilling assembly with MWD/GRfRes/Den/Neu/PWD and a Weatherford Drill-Mill at ±1,000'and 12,000' from the bit. RIH to float collar. Test the 10-3/" casing to 3,500 psi for 30 minutes. 5. Drill out shoe track. Circulate and condition mud. Displace well to new LSND drilling fluid. Drill 20' of new formation below rathole and perform a LOT. Directionally drill ahead to TD (Near top OBd) as per directional ~ profile to 7,800' MD. 6. Make short trip as needed, work tight spots as seen. Circulate and condition mud at TD. Make sure hole is clean prior to POOH. POOH for casing. 7. MU and run 7 5/8" 29.7# L-80 BTC-M long string casing to TD. Cement in one stage to 500' MD above the % Schrader Ma sand. Bump plug with seawater. 8. Clean pits for displacement. Freeze protect 7 g/8" x 10-31a" annulus with dead crude to 2,200' TVD. 9. PU 6-3/" conventional assembly with MWD/GR/Res/Den /NeulPWD/AIM and RIH to the float collar. Test the 7-5/B" casing to 3,500 psi for 30 minutes. 10. Displace well over to new Versapro MOBM. Drill out shoe track, circulate and condition mud. Drift 20' of new for 't~ n below rathole and perform FIT. Directionally drill ahead to TD geosteering through the OBd to TD at ~ ,63 MD. (prognosed). Perform wiper trip, circulate and condition mud. 11. H to near OBb window depth, log into top OBb (RA marker) with GR, log across the OBa and OA windows as well. POOH. 12. MU and run 4-'/2" 12.6# L-80 BTC-M slotted liner with two swell packers, liner hanger and liner top packer to TD. Position liner top packer 100' below the bottom of the OBb window. 13. PU the 7-5/8" whipstock assembly. Set the whipsock on the OBd liner top packer such that the top of the window is near the top of the.OB~sand (planned KOP: 7,113' MD). Orient whipstock to highside. Shear off Whipstock & mill window. POOH. 14. RIH with 6-3Jd' conventional drilling assembly with MWD/GR/Res/Den/Neu/PWD/AIM to whipstock. Directionally drill to the planned TD of 12,304' MD. Circulate and condition mud and perform wiper trip. POOH. 15. Pull whipstock #1. Run and set 4-~/z" slotted liner with two swell packers and hook hanger. POOH and LD liner running string. Run Baker Hook Hanger Lateral Entry Module #1 with ZXP liner top packer, POOH. 16. PU the 7 5/8" whipstock assembly. Set the whipsock on the OBb liner top packer such that the top of the window is near the top of the OBa sand (planned KOP: 6,980' MD). Orient whipstock to highside. Shear off Whipstock & miff window. P~OFi.` 17. RIH with 6-3/a" conventional drilling assembly with MWD/GR/Res/Den/Neu/PWD/AIM to whipstock. Directionally drill to the planned TD of 12,349' MD. Circulate and condition mud and perform wiper trip. POOH. i 8. Pull whipstock #2. Run and set 4-~h" slotted liner with two swell packers and hook hanger, POOH and LD liner running string. Run Baker Hook Hanger Lateral Entry Module #2 with ZXP liner top packer, POOH. 19. PU the 7 5/8" whipstock assembly. Set the whipsock on the OBa liner top packer such that the top of the window is near the top of the OA sand (planned KOP: 6,783' MD). Orient whipstock to highside. Shear off of Whipstock and mill window. POOH. 7 Permit to Drill 09/23104 i ~y 20. RIH with 6-3/4" conventional drilling assembly with MWD/GR/Res/Den/Neu/PWD/AIM to whipstock. Directionally drill to the planned TD of 10,674' MD. Circulate and condition mud and perform wiper trip. POOH. 21. Pull whipstock #3. Run 4-'/2" slotted liner with two swell packers and hook hanger, POOH and LD liner running ~ string. Run Baker Hook Hanger Lateral Entry Module #3 with ZXP liner top packer. Clean pits for displacement. Displace over to 9.0 ppg KCL brine. POOH. 22. MU 4-'/2" 12.6# BTM-M, L-80 completion assembly and RIH. See completion schematic for details. Land tubing hanger and run in lockdown screws. Reverse in brine with Corexit to protect the annulus. / 23. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK-1 valve. 24. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 25. Pull two-way check. Freeze protect the well to 2,200' TVD. Install VR plug in 7 5/8" casing annulus valves. 26. Install BPV. Secure the well and rig down /move off Nabors-9ES. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod /RHC plug. 2. Pull out DCK-1 shear valve, install GLV in all of the other mandrels as per the PE. 8 Permit to Drill 09/23/04 ~ ~ L-202 Detailed Drilling Procedure Job 1: MIRU Critical Issues: - Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. - Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. - L-200 will have to be shut in and require wellhouse removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. - L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at L pad as a result of the use of Ivishak gas lift gas. All L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-02 10 ppm L-101 5 ppm L-116 i 0 ppm Reference SOP: • "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 13-~h" Surface Hole Critical Issues: - Well Design: The Slimhole well design was adopted due to the production GLM 1 downhole pressure gauge requirements. This well design also gives us greater flexibility on junction design and reduces ECD's. - Surface Hole Problems: At L-Pad, no significant surface hole drilling problems have been identified. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In only one case has an obstruction caused the well to be sidetracked. Lost circulation has not been a problem on L-pad. Some minor tight hole has also been encountered below the Permafrost. Hydrates are present at L-pad from the base of the Permafrost all the way through the SV-1 sand and should be treated with conventional practices: pretreating mud, cooling mud, increasing weight, etc. - Close Approach: No wells are required to be shut in. There are several close tolerance wells in the surface interval between 300' - 1,700' MD. Follow the traveling cylinder / no-go plot per established procedures. Magnetic interference is expected to be nonexistent by 1,000' MD. - Directional: Every effort should be made to ensure a `smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Objective is to keep DLS <_1.5° over planned. - Hole Cleaning: Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.5° motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +100- rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. - Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider backreaming across initial tight spots only if washing does not alleviate the problem. 9 Permit to Drill 09!23104 i ~- - Faults: There is one fault that will be crossed in the surface hole section: Fault Location MD TVD TVDss Throw Direction Uncertainty Fault #1 - SV6 1,285' 1,277' 1,200' 50' to 70' West +J- 150' MD - Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the top of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates the upper section of the SVi sands. In order to do this the casing will need to be set --100' TVD below the top of the SV1 sand in the shale. Reference RPs: • "Prudhoe Bay Directional Guidelines" • "Well Control Operations Station Bill" • Follow Schlumberger logging practices and recommendations Job 3: Run 10-3/4" Surface Casina Critical Issues; - Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. - Casing drift: 10-3/a" special drift casing is being used. Ensure that casing equipment is properly drifted to ensure adequate ID for the 9'/a" bit, i.e. float equipment, casing hanger, etc. - Cement to surface: A single-stage job will be done on this well using 250°I° excess in the permafrost and 30% excess below the permafrost. A TAM Port collar will be placed at 1,000-ft MD as a contingency. - Losses during cement job: Lost circulation has been experienced on L-Pad and on offset pads while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is 12.5-Iblgal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs; • "Casing and Liner Running Procedure" • "Surface Casing and Cementing Guidelines" • "Surface Casing Port Collar Procedure" Job 4: Drill 9'/8" Intermediate Hole Critical Issues: - Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. - LOT: Perform a LOT (minimum 11.2 ppg EMW to satisfy kick tolerance). The Kick Tolerance for the surface casing is 50 bbls with 9.0 ppg mud, 11.2 ppg LOT, and an 8.8 ppg pore pressure (most likely 8.6 ppg based on recent MDT's within the block). If the LOT is less then i i .2 ppg EMW, then the kick tolerance will be < 50 bbls. Based upon off-set drilling data on L-Pad, a minimum leak-off of 12.5 ppg is expected at the 10-3/a" shoe. ECD's at the shoe are expected to be in the 10 ppg range while drilling at the shoe and at TD of the well. - Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for ECDs not to exceed 0.6ppg above calculated. If ECDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. ECD should not exceed 11.0 ppg once the M sand has been penetrated. 10 Permit to Drill 09!23/04 • ~ - 7-5/e" casing landing point: The landing point for the 7 5/8" casing will be determined by isopaching down to the top of the OBd sand based on changes in GR/Res curves associated with the tops of the previous OB sands. Top setting the OBd will give us the most possible amount of TVD to work with when landing the 6-3/" horizontal. If tops are coming in 100' or more out from prognosis, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. - Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. - Critical LWD Tools: It is critical to have the GR tool in order to pick the landing point for this hole section. The landing of this well will depend on picking the top of the OBd sand which will be picked by Gamma Ray. If we loose the GR tool, we will need to trip for it. - Faults: There is one fault that will be crossed in this hole section: Fault Location MD TVD TVDss Throw Direction Uncertainty Fault #2 - UG3 5,171' 3,597' 3,520' 40' to 50' South +/- 150' MD - Bowl Protector: With the larger than normal production hole size (9-7/8"), the bowl protector will be very thin. Pull and inspect the bowl protector whenever possible. Replace with any sign of damage. Take caution not to get bowl protector stuck. - Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements and junction requirements. It is critical to design a BHA to minimize inclination and walking tendencies and thus minimize wellbore tortuousity. DLS should be kept <_1 ° over planned. - Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. If a tight spot is encountered, run back in the length of the BHA and circulate for at least 30 minutes at max rotation speed and max flowrate while reciprocating at max allowable speed without exceeding the ECD limit. Reference RPs: • "Standard Operating Procedure for Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" • "ERD Operating Practices" Job 6: Run and Cement 7 5/8" Intermediate Casing Critical Issues: - Cement Job: It is imperative to achieve a good cement job on this well for Nb sand and junction isolation requirements. Good zonal isolation of these sands is imperative to the production success of this well. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job between the sands if any problems are encountered during the cement job. Keep cementing ECD's below 12.5 ppg EMW during the displacement. - Casing Space out: There are 3 important space out zones for this casing run: o There must be a long full joint of casing just starting above the top of the OA and OBa sands so that the multi-lateral junction window can be milled out as close to the top of the respective sands in the top/middle of a full joint of casing. Run full casing joints across the OA and OBa sands. Any casing pup joints required for space out should be placed below the base of the sands. o The shoe must be within 10 feet of the bottom when the casing is cemented in place. o The mandrel hanger must be spaced out correctly at surface if it is to be used. Emergency slips may be used if necessary to achieve proper space out. 11 Permit to Drill 09/23/04 - Freeze Protection: Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7 5/" x 10-3/a" casing outer annulus with dead crude to 2,200'TVD, the hydrostatic pressure will be 7.8 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure adouble-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 100 psi underbalance to the open hole. - Centralization/Differential Sticking: See centralizer strategy above. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. - RA Tags: There will need to be 4 RA tags placed in the 7 5/8' casing for depth control. Placement strategy is ~40 - 80' above each of the windows: Pip #1: OA window, Pip #2: OBa window, Pip #3: OBb window, Pip #4: 120' above the shoe. - Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. - Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7-5/a' casing. - TIW Valve: Ensure that a TIW valve with a cross over to 7 5/" BTC casing is on the rig floor Reference RPs: • "Intermediate Casing and Cementing Guidelines" • "Freeze Protecting an Outer Annulus" • "ERD Operating Practices RP" Job #7 t Job #10 /Job #15 /Job #20: Drill 6-3/a" Laterals (OBd I OBb / OBa / OA Sands) Crifical Issues: - MOBM: The production intervals will be drilled with a 9.2 ppg VersaPro MOBM. This fluid has been utilized before on past wells, however it has inherent HSE issues associated with its handling and thus all safety procedures should be refreshed. Review the BP MOC, the Nabors Hazard Analysis, and the MI drilling fluids program prior to utilizing this fluid. - Faults: There are no planned fault crossings in any of the laterals intervals. - Geosteering: Geosteering in these lateral intervals is expected to be the most challenging aspect of this well. Anadrill AIM will be used and should help mitigate some of this challenge. A 1.5° bent housing motor will be used to help proactively make corrections quicker to avoid unnecessary undulations throughout this interval. There will be a rigsite geologist on location to help with interpretations. o The structure of the horizontal section is expected to be relatively flat for the first 2,000' and then is expected to drop between 1.5 - 2.5° apparent dip depending on how the actual structure tracks the prognosis. o The well L-202 OBd lateral is designed to undulate in 2 1/2 cycles across the 30 foot vertical extent of the OBd net sand/pay section along the length of the L-202 polygon. The undulating well profile will provide low angle offtake points from all sands in the OBd net sand/pay interval and crosscut potential vertical permeability barriers. o The L-202 OBb lateral will target to stay near the center to lower half of the 13-14 foot vertical extent of the OBb net sand/pay section along the length of the L-202 polygon. However, given the thin character of the OBb target interval, it is likely the drillstring will undulate across the entire OBb net sand thickness several times along the length of the drilling polygon. Dip information gained from drilling the underlying OBd lateral leg should help minimize unplanned excursions out of the OBb target interval. 12 Permit to Drill 09/23/04 • • o The L-202 OBa lateral will be targeted to drill the first 1/3 of the total polygon length in the lower sand and second 2/3's of the polygon in the upper sand. By limiting the drilled length in the lower sand to only the upstructure polygon area, it is possible that a lighter updip fraction of the lower OBa oil column may be contacted. Well L-202L2 will then ramp up into the upper OBa sand and finish drilling the lateral in the thicker sand and lighter oil of the upper OBa interval. o The OA lateral is designed to undulate in 1 1/2 cycles across the OA net sand interval along the length of the up-structure L-202 OA polygon. The L-202 OA lateral was shortened relative to the underlying laterals to maintain standoff from wet OA sands in the interval between the L-216 and L- 210PB1 wells. o The directional plans for each lateral should reflect the !earnings derived from the previous laterals but should only be used as a guide and real time adjustments will need to be made to stay within the sands. If for whatever reason we become lost, steer up as hard as possible to determine where within section we are. Once we are able to determine where we are, then we can go back and OH sidetrack. - Surveying: Survey density is critical to achieve vertical positional certainty. It is recommended to survey every 30-45' to ensure accurate vertical positional certainty throughout the horizontal section. This survey density should alleviate the errors associated with vertical section creep. - ECD/Hole Cleaning: Utilize PWD to monitor for good hole cleaning and ECD trends. Cuttings will tend to dune up at the window due to hole geometry. Planned ECD hardline 12.0 ppg EMW. - Target Constraints: The North sidelines of the polygon are defined as hard lines due to standoff to injection. The South sidelines of the polygon are defined as hard lines due to fault proximities. Do not extend beyond the endline points due to potential downdip water. Reference RPs: • "Prudhoe Bay Directional Guidelines" • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "ERD Operating Practices RP" Job 8: Run 4-~/2" Slotted Liner (OBd Sand) Critical Issues: - Liner to bottom: It is imperative that we get this liner to bottom to allow for adequate space-out for subsequent laterals. Liner on bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing all of the reserves possible for this section length. - Centralizer Placement (5-3/a" OD): o See centralizer strategy above Do not run any in the liner lap. - 4-~/z" Rams: Keep VBR's in. Can also utilize annular if necessary. - Have a Baker completion specialists onsite to engineer and supervise this finer job. Reference RPs: • "None Apply' 13 Permit to Drill 09!23!04 Job #9 /Job #14 /Job #19: Mill OBb / OBa / OA Windows Critical Issues: - Equipment Measurements: Verify measurements of all assemblies prior to picking up - Whipstock Orientation !Depth: The whipstock should be oriented to X15° left of high side. This will allow for a better window and allow for easier access into the window with the bent joint on the end of the 4-'h" liner. Exact window depth to be based off of actual logs. Depth control will be very critical on these windows. Space out tubulars below the whipstock may be required to properly position the whipstock at the correct depth while landing out on the ZXP liner top packer used on the previous lateral. A discussion will need to take place to determine the best way to gain accurate depth control for the window setting depth. o Planned OBb window depth is 7,113' MD (4,500' TVD). o Planned OBa window depth is 6,980' MD (4,452' TVD). o Planned OA window depth is 6,783' MD (4,377' TVD}. - Window Milling: It is critical to have a smooth uniform full length window. Extra time spent on the window milling will be well worth it when it comes time to land out the hook hanger. Follow the BOT representative during the milling of the window. - Milling Assembly: In the past debris barrier cups have been sliced in order to allow flow bypass while POOH while retrieving whipstocks. From now on, the assembly will be run without slicing the cups and an unloader sub will be run below the debris barrier to facilitate flow by the swab cups and prevent swabbing. No seals below the whipstock unless fluid losses have been observed. - Whipstock Setting: On past wells, only one shear was observed during the whipstock setting procedure. This introduced some uncertainty as to whether or not the slide was oriented correctly. The most likely explanation for this is that on high angle wells cased hole friction may cause the 15-20K bottom trip and the 35K whipstock shear to occur simultaneously. - Hole Cleaning: Well inclination at the planned kick off points is between 65° - 70°. In addition, the wellbore tangent angle above the KOP's has a 61 ° tangent section prior to building up to 87°. Good window milling and hole cleaning practices will be critical to ensure that metal and formation cuttings are removed from the well. Cuttings will tend to dune up at the window due to hole geometry. - FIT: AN FIT is only required on the first lateral. Therefore the mills will only need to be drilled down far enough to ensure an adequate window and not to ensure 20' of open hole below the bottom of the window. Reference RPs: • "Whipstock Sidetracks" RP Job #11 /Job #16 /Job #21: Retrieve Whipstocks #1, #2, & #3 Critical Issues: - Orientation of Retrieval Hook: When scribing to align the MWD to the hook remember that the orientation of the hook will need to be 180° from the orientation of the whipstock. - Whipstock Retrieval: This whipstock must be retrieved in order to land the hook hanger in the window. Extra time should be taken in order to ensure successful retrieval of the whipstock with the hook due to potential problems associated with the back-up retrieval methods. Reference RPs: • None Apply 14 Permit to Drill 09/23/04 Job #12 /Job #17 /Job #22: Run 4-~/s" Liner w/ Hook Hanger & LEM w/ seals (OBb / OBa / OA1 Critical issues: - Liner to bottom: It is imperative that we get this liner to bottom to allow for proper placement of the Hook Hanger. Liner on bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing all of the reserves possible for this section length. Current modeling for the OBa liner, based on historical data, we should have plenty of SO weight required to land the junctions. Data collected on the OBd liner iob will be utilized to double check the calibration of the model prior to running the OBb liner to confirm additional weight pipe requirements. o If problems are encountered while RIH with the liner call ODE while reciprocating liner and discuss options: • Stop and reposition weight pipe and pick up more if available and try again. • Stop and POOH and make a cleanout run with a hole opener. • Stop and POOH to liner running tool and LD some footage of liner depending on modeling results based on actual drag data. - Liner Swivel: On past wells it was determined that the tension lock liner swivel between the Hook Hanger and the liner was not necessary because the torque needed to orient the Hook with the liner did not present any difficulties landing the junction. The decision has been made to continue with this strategy even on wells with as much as 7,300' of liner (L-201 }. The swivel requires adequate weight in order to lock it out and allow the liner and the hook to rotate together. Without enough weight acting on the swivel, the bent joint on the bottom of the liner will not be able to be manipulated from surface to facilitate access out into the window. - Centralizer Placement (5-3/a" OD): Run one straight blade rigid centralizer per joint, floating between the collars. If any differential sticking is noticed while drilling, it may be necessary to put another centralizer per joint separated by a stop collar. Do not put any centralization on the first two joints above the bent joint. - 4'/z" Rams: Keep VBR's in. Can also utilize annular if necessary. - Have a Baker completion specialist onsite to engineer and supervise this liner job. 4 ~h", 12.6#, L-801ST ID drift Colla se Burst Tensile 100% 3.833 N/A N/A 288,000Ibs 80% N/A N/A 230,4001bs - Connection make-up information: 4-'/2" IBT - makeup to position Reference RPs: • "None Apply" Job #23 : Run 4-~/s" Completion: Critical lssues: - Barriers: o The well will have the OA, OBa, OBb, and OBd production intervals open with an 8.6 ppg EMW formation pressure during completion operations. o Completion will be run with BOPs in place and kill weight fluid for annulus side barriers. Tubing side barriers will be provided via TIW and kill weight fluid. o Once packer is set the annulus above the packer will be tested to 3,500 psi to verify packer/annulus integrity. Kill weight fluid and the tubing hanger provide additional annulus side barriers. At this point the ball and rod with kill weight fluid and a TIW valve comprise the tubing side barriers. o When the DCK valve is sheared a casing annulus valve must be in place along with kill weight fluid to provide sufficient annular barriers. Tubing side barriers are still kill weight fluid on ball and rod and a TIW. 15 Permit to Drill 09/23/04 o A TWC will be installed and tested from above to 1,000 psi for 30 minutes prior to nippling down the BOP's. With the DCK valve sheared the TWC in addition to kill weight fluid provide the tubing side barrier. The annular side is provided by a casing annulus valve and kill weight fluid. With the TWC in place BOPs can be nippled down and the tree nippled up. o With the tree nippled up freeze protecting removes the kill weight fluid as a barrier. We then count on the tree for tubing side barriers, and two casing annulus valves for annulus side protection. o Before rigging down a BPV tested from below to 1,000 psi will be left in the tubing hanger to provide an additional tubing side barrier once the rig is off. Since the DCK valve is still open it will be necessary to leave one casing annulus valve and a VR plug for annular barriers. Make sure that a lubricator is used to install the VR plug white both casing annulus valves are still in place. - Thread Dope: BOL 2000 NM or BOL 2000 is the BP approved thread compound for Carbon API connections. All IBT-M pipe should arrive on location with one of these two thread compounds. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. - Shear Valve: We will run a DCK shear valve in the GLM directly above the production packer to utilize for freeze protecting after the production packer is set. - Phoenix Pressure Gauge: A downhole pressure gauge with control lines will be run on this well. Ensure that a Baker Centrilift hand and a Schlumberger completions hand (Cameo) is on location prior to PU tubing to allow them time to get all of their equipment in order and confirm its working condition. o HSE: Sheaves hung in the derrick and I-wire spools will be utilized during the running of the completion, make sure that this non-routine operation is discussed in length at the PJSM with all relevant personnel prior to PU completion. o Place 1 cannon clamp per joint for the first 10 joints followed by 1 clamp per every 2 joints to surface. o Test the I-wire connection at regular intervals while running in the hole. If the I-wire is damaged in any way contact ODE. - Contact the Field AOGCC Rep with 24 hours of notice to witness the tubing and annulus pressure tests. Reference RPs: • "Completion Design and Running" RP • "Tubing Connections" RP Job #24: ND/NU/Release Rig Critical Issues: - See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. - Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. Reference RPs: • "Freeze Protecting an Inner Annulus" RP 16 Permit to Drill 09/23/04 L-202, L1, L2, & L3 PROPOSED COMPLETION Phoenix Pressure Gauge with control lines to surface ~ 20"X34" 215.5 Ib/ft, A53 ERW Insulated @ 109` \Halliburton X-Nipple (3.813" ID) @ 2200' TVD 4-1/2", 12.6 Ib/ft, L-80, BTC-M Coupling OD: 5.2" Drift/ID : 3.833"/3.958" 10-314", 45.5# L-80 BTC Csg @ 3,200' MD TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head w/ 7" mandrel hanger & packoff 11" x 11", 5M, tbg spoof w/ 11" x 4-1/2" tubing hanger with control line ports 11" X 4-1/16" Adaptor Flange Orig KB elev (N-9ES) = 77.3' 4.5" Baker sliding sleeve with 3.813" ID @ GLM Design: 7-5/8" X 5-1/2" Baker PRM Packer @ #4 - 2500' ND - 4-1/2" X 1" KBG-2 - SV •Halliburton X-Nipples (3.813" ID) #3 - 3500' ND - 4-1/2" X 1"KBG-2 - DV #2 - 4 jts above sliding sleeve - 4-1/2" X 1" KBG-2 - DV . 4.5" WLEG @ 6,764' MD #1 - 2 jts above sliding sleeve - 4-1/2" X 1" KBG-2 - DV Versapro MOBM in each Lateral and in mother bore from tbg tail down. 6-3/4" OA Lateral 6,796'-10,674` ~ RA Tag TBD - - ~ -___. Swell packer placement TBD Junction Specifications: / Junction ID through LEM Module without diverter: 3.68" RA Tag TBD LEM run with internal sealbores to allow the use of isolation sleeve across window. Baker Hughes Hookwall Hanger @ 6,779' MD Window in 7-5/8" casing @ 6,783' - 6,796' MD Well Inclination @ Window = 65° Baker Hughes Hookwall Hanger @ 6,976` MD Window in 7-5/8" casing @ 6,980' - 6,993' MD Well Inclination @ Window = 69° Baker Hughes Hookwall Hanger @ 7,109' MD Window in 7-5/8" casing @ 7,113' - 7,126' MD Well Inclination @ Window = 69° 6-314" OBa Lateral 6,993'-12,349` ~ --=~J-----~--- `t't" Swell packer placement TBD 6-314" OBb Lateral 7,126'-12,304' i =1~~r_ =1~~r_- RA Tag TBD 7-5/8", 29.7#, L-80, BTC-M @ 7800' Casing Drift: 6.75" Casing ID: 6.875" DATE ~ REV. BY ~ COMMENTS I 919/2004 I RBT I Level 3Multi-lateral, 4-1/2" GL Completion I RA Tag TBD Swell packer placement TBD ~~ ~- GP~RatPr1'~i>~6l1[!t~ ~a~ i 6-3/4" OBd Lateral 7 800'- 12 634' API NO: 50-029-xxxxx-00 ORION 50-029-xxxxx-60 WELL: L-202 ML 50-029-xxxxx-61 50-029-: xxxx-62 I PLANT -~15'00'00" GRID t L-PAD ^ e .._,.. _._.. .._._- n~. ._.._.,. ,_. NOTES 1. DATE OF SURVEY: AUGUST 3, 2004. 2. REFERENCE FIELD BOOK: W004-11 PAGES 37-40. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS L-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS L-PAD OPERATOR MONUMENTS. ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. t 34 ~ ~- ~ ~N L-PAD PROJECT ~ T12N AREA T11 N -f- _w { ~ °' ~ 3 2 s 1 ~. , i~ ~ VICINITY MAP N.T.5. LEGEND AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR A °~S~r >r~`4 9 ~- ~ ` ~~ e°o°°°°°°°°°°°oo°°°°°°o°°o°°o°° °°o°°°°°°°°°°°°°°°°°°°°°°°°°°°° ~~, ~° Richard F. Allison ~s °°° 10608 ESSIONP SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 3„ 2004. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA 0 NO WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS POSITION(D.DD BOX ELEV. OFFSETS Y= 5,978,293.25 N= 9999.72 70'21'02.394" 70.3506650' 48 8 2,572' FSL L-202 X= 583,223.80 E= 5,234.92 -149'19'27.488" -149.3243022' ' 3,690' FEL Y= 5,978,297.43 N= 9,999.96 70'21'02.433" 70.3506758' 2,575' FSL L-2121 X= 583,238.45 E= 5,250.15 -149'19'27.058" -149.3241828' 49'3 3,676' FEL r. xO p erL "'~~"'"' pNEIL CIiECKED:ALLISON by O ~ •' DATE. 8/03/04 ~ DRAWING: 112904 WOL 06-00 GPB WOA L-PAD SHEET: ~c~,~ ®14J~~ DO~o JOB N0: AS-BUILT CONDUCTORS ~~~~ uo ~,,,~ ax~ca+s SCALE: 1 OF 1 ,~, , ,w,E µamug, uwvu 1'= 150• WELLS L-202 & L-2121 L-111i ^ ^ N-A (NWE-2) ^ L-113 L-114 ^ ^ L-124 L-SD ^ ^ L-1121 ^ L-02 L-121 ^ ^ L-122 L-110 ^ ^ L-211 i L-SI ^ ^ L-1151 L-116 ^ ^ L-117 L-109 ^ ^ L-118 L-SL ^ L-01 ^ L-200 L-1o7 ^ L-o3 ^ 90D~ L-202 L-212i L-213i ^ L-10Bi^ ~ ^ L-2161 L-105i ^ ~ ^ L-1031 L-106 ^ ^ ^ L-201 L-104 ^ ^ L-1191 S-W ^ ^ L-2101 L-102 ^ 32 ~v 0 ^ L-120 0 by L-202 Expbratlon nbene FINd: Pnxltae Bey unn • wOA ~~., L-PAD,L.202 ~Sibility WaB: Pbn L•202 (N-N) Bonhob: Plan L-202 l1YYYAPM: 50029 Burwy NMne I Dab: L•202 (P4b) / Sepbmber 10, 2004 TortIAND I Od l ERD ratlo: 176.029° / 10278.92 ft / 8.865 / 2,177 Grid Coordinab Eypwn: NAD27 Neeka Stab Planes, Zone 04, US Feet Loeaaon Latllano: N 70.35066486, W 149.32430214 LoeaOon Orld NIE Y!1(: N 5978293.250 ftUS, E 583223.800 ftUS DridCanwrysneaAnpb: +0.63635414° 35.600• v Wrttlad 8sctlon OdYb: N 0.000 R E 0.000 ft TVD Rabn~a DeWm: Rota,y rewe TVD Rahrana t8watlon: 77.30 ft rela8ve to MSL Sa Bad I Ground LavN ENvatlon: 48.80 ft reb8ve b MSL Mq~ DaetnMlon: 74.719° Tool Fold atrNgM: 57592.329 nT tiapnetlc Dlp: 8(1.807° Dadina8on Dab: Ocbber 25, 2004 tilpnMk DadMMlsn tdodN: BfGM 2004 NoM Rahraaa: True NoM • ToW Corr lisp NoM •s Trw Nortlr: +24.719' Loeal CoordNabs Rahrmad To: Web Head Camnsnb ~ bdlnatlon AabaM TVD Sub•SnTW S ~ ~ ~ n NS EW DLE ToolFaoe Bu1ldRab WaftcRab Nartldn9 tFaWrq letltsda LonpRsds acd on Dsp 4r R R R R R R R 00 R 00 R N R RIB RUD Rlt V.W V.W 7Z.A6 U.W -//.JU U.W U.W U.W U.W V.W 1Z..7tiM U.W V.W ~M/tl183d0 ~tSJ7l'3.tlU N /V.3DUtltl4tltl W 748.3L4JUZ74 G1 337.30 0.00 1258 337.30 280.00 0.00 0.00 0.00 0.00 0.00 12.58M 0.00 0.00 5978293.25 583223.80 N 70.35088488 W 149,32430214 KOP Bb 1.5/100 700.00 0.00 12.58 700.00 822.70 0.00 0.00 0.00 0.00 0.00 12.58M 0.00 0.00 5878293.25 583223.80 N 70.35088488 W 149.32430214 Bld 3/100 800.00 1.50 12.58 799.99 722.89 1.21 1.31 1.28 0.29 1.50 12.58M 1.50 0.00 5978294.53 583224.07 N 70.35088837 W 149.32429983 900.00 4.50 12.58 899.84 822.54 8.05 8.54 8.38 1.43 3.00 12,58M 3.00 0.00 5978299.85 583225.15 N 70.35068232 W 149.32429057 SV8 987.78 8.53 12.58 987.30 890.00 12.07 13.08 12.74 2.84 3.00 0.000 3.00 0.00 5978308.02 583226.50 N 70.35089989 W 149.32427905 1000.00 7.50 12.58 999.28 921.98 15.71 16.99 18.59 3.70 3.00 O.OOG 3.00 0.00 5978309.87 583227.32 N 70.35071019 W 149.32427208 1100.00 10.50 12.58 1098.04 1020.74 30.17 32.84 31.85 7.11 3.00 0.000 3.00 0.00 5978325.18 583230.58 N 70.35075189 W 149.32424442 1200.00 13.50 12.58 1195.84 1118.54 49.39 53.42 52.14 11.64 3.00 O.OOG 3.00 0.00 5978345.51 583234.88 N 70.35080732 W 149.32420785 Fault 1 1284.25 18.03 12.58 1277.30 1200.00 89.23 74.89 73.08 18.32 3.00 0.000 3.00 0.00 5978388.51 583239.30 N 70.35088458 W 149.32418988 1300.00 18.50 12.58 1292.42 1215.12 73.31 79.30 77.40 17.28 3.00 O.OOG 3.00 0.00 5978370.63 583240.22 N 70.35087832 W 149.32418188 1400.00 19.50 12.58 1387.52 1310.22 101.87 110.20 107.55 24.01 3.00 O.OOG 3.00 0.00 5978401.05 583246.81 N 70.35095870 W 149.32410723 1500.00 22.50 12.58 1480.87 1403.57 135.00 148,03 142.53 31.82 3.00 O.OOG 3.00 0.00 5976438.11 583254.03 N 70.35105424 W 149.32404385 SVS 1578.00 24.84 1258 1552.30 1475.00 183.95 177.35 173.08 38.84 3.00 0.000 3.00 0.00 5878488.74 583280.51 N 70.35113773 W 149.32398848 1600.00 25.50 12.58 1572.21 1494.91 172.80 188.70 182.22 40.68 3.00 O.OOG 3.00 0.00 5978475.89 583282.45 N 70.35116288 W 149,32397 1700.00 28.50 12.58 1881.30 1584.00 214.56 232.10 228.52 50.57 3.00 0.000 3.00 0.00 5978520.30 583271.84 N 70.35128371 W 149.32389 SV4 1718.25 29.05 1258 1877.30 1800.60 ?22.68 240.88 235.10 5248 3.00 0.000 3.00 0.00 5978528,89 583273.86 N70.35130714 W 149.32387807 1800.00 31.50 12.58 1747.89 1870.59 260.78 282.09 275.31 61.48 3.00 O.OOG 3.00 0.00 5878569.20 583282.19 N 70.35141701 W 149.32380318 Base Penn 1805.17 31.68 12.58 1 752.30 1875.00 283.28 284.80 277.98 82.05 3.00 0.000 3.00 0.00 5978571.85 583282.75 N 70.35142423 W 149.32379839 1900.00 34.50 12.58 1831.75 1754.45 311,12 338.55 328.48 73.33 3,00 O.OOG 3.00 0.00 5978822.48 583293.47 N 70.35158221 W 149.32370685 2000.00 37.50 12.58 1912.84 1835.34 385.45 395.32 385.62 88.13 3.00 0.000 3.00 0.00 5978879.97 583305.83 N 70.35171891 W 149.32380289 2100.00 40.50 12.58 1990.35 1913.05 423.82 458.25 447.24 99.84 3.00 O.OOG 3.00 0.00 5978741.53 583318.88 N 70.35188888 W 149.32349158 SV3 2155.88 4218 1268 203230 1955.00 457.74 495.15 483.25 107.88 3.00 0.000 3.00 0.00 5978777.63 583328.30 N70.35198508 W 149.32342828 2200.00 43.50 12.58 2084.85 1987.35 485.47 525.15 512.53 114.42 3.00 O.000i 3.00 0.00 5978808.98 583332.51 N 70.35208507 W 149.32337322 2300.00 48.50 12.58 2135.38 2058.08 550.83 595.85 581.54 129.82 3.00 O.OOG 3.00 0.00 5978878.14 583347.14 N 70.35225358 W 149.32324816 2400.00 49.50 12.58 2202.26 2124.96 819.52 670.18 854.06 146.01 3.00 O.OOG 3.00 0.00 5978948.83 583382.53 N 70.35245170 W 149.32311870 SV2 2400.08 49.50 12.58 ?202.30 ?125.00 819.58 670.20 854.10 146.02 3.00 0.000 3.00 0.00 5978948.87 583382.54 N 70.35245182 W 149.32311882 2500.00 52.50 12.58 2265.19 2187.89 691.36 747.87 729.90 182.94 3.00 O.OOG 3.00 0.00 5979024.84 583378.61 N 70.35285889 W 149.32297923 Prouosal ~h~umberger WeBI)esfpn Ver 3.1RTSP3.03-HF5.00 Bld( do31rt-548) L-2021PIan L-202 (Nd~l)tPlen L-2021L-202 (P4b) Generated 9/10/200410:33 AM Pape 1 of 3 Coounonts ~ Mdleodon ArMuM THD SuGBw TVD ~lMp~ ein NS EYII W.8 Tool fop 6u0d R+fs W~Oc ~ NaAhhq feoWnO L~tlh~do LonyNi~ R R K h R R R 00 h 1001! 00 h 1818 It08 cwv.w a~.w ~c.ao ww.vo cc4o.vo /oo.~q oco./o ouO.oo 1Wa/ 3.w u.VUV 3.W U.W fit//M1V3.WS .70~73M9.:S6 rv /V.s~Ltl/4D/ W l4m.sLLtlJt3lL 2700.00 58.50 12.56 2378.42 2301.12 843.68 812.62 890.88 198.84 3.00 O.OOG 3.00 0.00 5879188.01 583412.72 N 70.35309815 W 149.32268776 End Bld 2759.40 80.28 12.58 2408,68 2331.38 890.92 983.73 940.58 209.98 3.00 O.OOG 3.00 0.00 5878238.02 563423.30 N 70.35323445 W 148.32259732 SV1 2998.72 80.28 12.58 2527.30 2450.00 1083.08 1171.58 1143.43 255.28 0.00 O.OOG D.00 0.00 5979439.34 583488.32 N 70.35378862 W 149.32222959 10-014" Csp Pt 3200.44 60.28 12.58 2627.30 2550.00 1245.01 1348.77 1314.42 293.43 0.00 O.OOG 0.00 0.00 5979810.72 583502.59 N 70.35425572 W 149.32191981 UG4 3593.80 80.28 1258 2822.30 2745.00 1580.82 1688.39 1847.83 387.87 0.00 O,QOG 0.00 0.00 5979944.91 583573.31 N 70.35516657 W 149.32131512 UG4A 3650.28 80.28 12.58 2850.30 2773.00 1606.17 1737.45 1895.70 378.55 0.00 O.OOG 0.00 0.00 5979992.89 583583.48 N 70.35529738 W 149.32122832 Crv 3/100 4141.79 60.28 12.58 3093.88 3016.66 2000.78 2164.31 2112.31 471.56 0.00 87.846 0.00 0.00 5880410.47 583871,83 N 70.35643547 W 149.32047292 4200.00 80.36 14.59 3122.78 3045.48 2047.86 2214.88 2161.47 483.44 3.00 B8.85G 0.14 3.45 5980458.75 583683.16 N 70.35858976 W 149.32037640 4269.95 60.50 17.00 3157.30 3080.00 2105.31 2275.72 2220.00 500.00 3.00 92.256 0.20 3.44 5980518.46 583699.07 N 70.35872988 W 149.32024190 4300.00 60.47 18.04 3172.11 3094.81 2130.25 2301.87 2244.94 507.87 3.00 91.746 -0.10 3.45 5980543.48 b83708.88 N 70.35879779 W 149.32017798 UG3 4381.48 60.42 20.84 3212.30 3135.00 2198.52 2372.74 2311.78 531.46 3.00 90.366 -0.OS 3.45 5980810.58 583729.50 N 70.35898035 W 149.31998840 4400.00 60.42 21.48 3221.44 3144.14 2214.18 2388.85 2328.79 537.27 3.00 90.046 -0.01 3.45 5980625.64 583735.15 N 70.35702139 W 149.31 4500.00 60.48 24.93 3270.78 3193.48 2299.29 2475.83 2408.72 571.55 3.00 86.346 0.04 3.45 5980705.94 583788.53 N 70.35723974 W 149.31 4800.00 80.80 28.38 3319.99 3242.69 2385.41 2562.88 2484.51 810.59 3.00 86.856 0.13 3.44 5980784.15 583808.71 N 70.35745225 W 149.31934365 4700.00 80.81 31.81 3388.93 3291.63 2472.28 2850.09 2559.95 854.31 3.00 84.976 0.22 3.43 5880860.07 583849.58 N 70.35785834 W 149.31898858 End Crv 4773.75 81.03 34.33 3404.78 3327.48 2536.69 2714.54 2813.96 689.47 3.00 O.OOG 0.30 3.42 5880914.45 583884.14 N 70.35780587 W 149.31870299 Fault 2 5177.27 81.03 34.33 3597.30 3520.00 2884.48 3082.33 2801.18 885.59 0.00 O.OOG 0.00 0.00 5981203.81 584077.01? N 70.358590x7 W 149.31711009 UG1 5388.07 81.03 34.33 3702.30 3825.00 3074.12 325201 3057.82 992,54 0.00 O.OOG 0.00 0.00 5981361.62 584182.23 N70.35901838 W149.31624129 Crv 41100 5550.28 81.03 34.33 3780.85 3703.55 3218.01 3383.91 3175.01 1072.56 0.00 99.286 0.00 0.00 5981479.88 584280.94 N 70.35933850 W 149.31559131 5800.00 60.73 38.58 3805.06 3727.78 3259.48 3437.38 3210.41 1097.76 4.00 98.186 -0.81 4.53 5981515.35 564285.74 N 70.35943519 W 149.31538661 5700.00 80.24 41.14 3854.34 3777.04 3348.25 3524.37 3278.15 1152.33 4.00 95.93E -0.49 4.56 5981583.89 584339.54 N 70.35962023 W 149.31494335 5800.00 59.91 45.74 3904.25 3828.95 3431.95 3811.03 3341.06 1211.89 4.00 93.846 -0.33 4.60 5981847.25 584398.40 N 70.35979207 W 149.31445954 5900.00 59.73 50.38 3954.55 3877.25 3518.12 3697.48 3398.82 1278.15 4.00 91.316 -0.17 4.82 5981705.72 584462.01 N 70.35894985 W 149.31393754 Me 5984.94 59.71 53.37 3987.30 3910.00 3589.78 3753.54 3433,45 1320.28 4.00 89.796 -0.04 4.83 5981740.83 564505.72 N 70.38004442 W 149.31357928 8000.00 59.72 54.99 4004.88 3827.88 3598.38 3783.81 3451.17 1344.80 4.00 88.976 0.04 4.63 5981758.81 584530.07 N 70.38009281 W 149.31337990 MD1 8044.30 59.77 57.04 4027.30 3950.00 3634.09 3822.07 347255 1378.53 4.00 87.946 0.11 4.63 5981780.55 584561.55 N 70.38015121 W 149.31312218 8100.00 59.88 59.82 4055.30 3978.00 3878.30 3870.22 3497.83 1417.51 4.00 86.856 0.19 4.82 5981806.28 584802.24 N 70.38022025 W 149.31278933 M62 8183.82 60.08 82.58 4087.30 4010.00 3727.99 3925.56 3524.57 1485.94 4.00 85.176 0.29 4.81 5981833.55 584650.37 N 70.36028329 W 149.31239592 8200.00 80.19 84.22 4105.27 4027.87 3755.51 3958.84 3538.59 1493.91 4.00 84.356 0.37 4.59 5981847.87 584678.18 N 70.36033155 W 149.31216871 8300.00 80.88 88.79 4154.85 4077.35 3829.83 4043.80 3573.24 1573.65 4.00 82.096 0.47 4.57 5981883.41 584757.52 N 70.38042817 W 149.31152107 Mc 6338.14 80.87 70.43 4172.30 4095.00 3855.59 4075.34 3584.23 1603.21 4.00 81.286 0.58 4.54 5981894.72 584788.95 N 70.38045817 W 149.31128095 6400.00 81.29 73.31 4203.19 4125,88 3900.30 4131.23 3801.82 1858.32 4.00 79.906 0.85 4.51 5981912.70 584838.86 N 70.38050385 W 149.31 Ne 8429.48 81.50 74.83 4217.30 4140.00 3920.42 4157.12 3808.78 1881.19 4.00 79.276 0.72 4.48 5981920.12 584884.85 N 70.36052316 W 149.31084 Nb 8482.22 81.92 76.98 4242.30 4185.00 3955.57 4203.56 3820.15 1726.21 4.00 78.156 0.78 4.45 5981932.01 584909.54 N 70.38055424 W 149.37028185 6500.00 82.08 77.77 4250.85 4173.35 3987.16 4219.25 3823.56 1741.53 4.00 77.786 0.83 4.43 5981935.81 584924.82 N 70.38058380 W 148,31015745 NC 8579.14 62, 78 81.25 4287.30 4210.00 4017.18 4289.40 3836.35 1810.49 4.00 78.176 0.90 4.40 5981949.14 b84993.83 N 70.38059844 W 149.30959731 8600.00 82.96 82,15 4296.81 4219,51 4029.91 4307.96 3639.03 1828.88 4.00 75.786 0.97 4.38 5981952.02 585011.98 N 70.36080575 W 148.30844811 8700.00 84.03 86.47 4341.44 4264.14 4088.22 4397.45 3647.88 1917.89 4.00 73.836 1.05 4.31 5981981.88 585100.88 N 70.36082987 W 149.30872502 OA 6783.30 65.00 90.00 4377.29 4299.99 4133.22 4472.84 3850.19 1993.03 4.00 72.316 1.17 4.24 5981965.00 585175.98 N 70.36083612 W 149.30811470 End Crv 6783.32 85.00 90.00 4377.30 4300.00 4133.23 4472.86 3850.19 1993.05 4.00 O.OOG 1.22 4.20 5981985.00 585176.00 N 70.38083612 W 149.30811453 QA Tpt I Crv 4H00 8783.33 85.00 90.00 4377.30 4300.00 4133.23 4472.88 3850.19 1983.05 0.00 34.596 0.00 0.00 5981985.00 585178.00 N 70.38063812 W 149.30611453 6800.00 85.55 90.42 4384.27 4306.97 4141.87 4487.80 3850.13 2008.20 4.00 34.416 3.30 2.49 5981985.12 585191.15 N 70.38063596 W 148.30799151 EMl Crv 8898.93 88.77 82.77 4421.90 4344.60 4191.02 4577.12 3847.83 2097.47 4.00 O.OOG 3.32 2.42 5981983.81 585280.43 N 70.36082908 W 149.30726848 OBa 8987.08 88.77 92.77 4447.30 4370.OD 4225.89 484249 3644.48 218278 0.00 O.OOG 0.00 0.00 5981961.18 585345.75 N 70.38082040 W 148.30673815 WeOI>asign Ver 3.1RT-SP3.03-HF5.00 Bld( do31rt-546) L-2021PIan L-202 (N-N)~Plan L-202~L-202 (F'4b) Generated 8/10/2004 10:33 AM Pape 2 of 3 l.ommmb I d kidMatlon ArlnnM TVD Sut-Ba TVD V n N8 EYY 1N.8 Tool Fap Bulb Rab Walk RNo NoMkp Fatlnp Lat7Wd~ Lanypudo D 8aUon R R R R R R R 00 R 00 R 00 R fU18 8118 vwanvr vaov.ov oo.r! nc.lr ~~c.w w/o.w 4c3c.ro gooa.3o 3o43.ao 27/.7.07 v.W V.WV V.W V.W Dtlt77SlW./V ~30C.67 N/V.36VC7C6!/ W74lLJVffri37/C OBb KOP 7113.40 68.77 92 77 4500.30 4423.00 4298.65 4778.89 3837.90 2299.00 0.00 O.OOG 0.00 0.00 5981958.11 585482.05 N 70.38080231 W 149.30562959 OBb 7118.92 68.77 9277 4502.30 4425.00 4301.39 4784.04 3637.65 2304.15 0.00 O.OOG 0.00 0.00 5981955.92 585487.19 N 70.38060182 W 149.30558783 Crv 4/100 7179.30 68.77 92.77 4524.17 4446.87 4331.41 4840.32 3634.94 2360.38 0.00 24.396 0.00 0.00 5981953.83 585543.43 N 70.36059416 W 149.30513127 7200.00 89.52 93.13 4531.54 4454.24 4341.68 4859.68 3833.94 2379.88 4.00 24.286 3.84 1.78 5981953.05 585582.75 N 70.36059142 W 149.30497434 7300.00 73.18 94.85 4583.52 4488.22 4390.47 4954.39 3627.34 2474.18 4.00 23.716 3.85 1.72 5981947.50 585657.31 N 70.38057330 W 149.30420885 OBc 7313.25 73.66 95.07 4567.30 4490.00 4398.83 4967.10 3628.24 2486.83 4.00 23.856 3.68 1.68 5981946.54 585869.98 N 70.36057029 W 149.30410408 7400.00 78.84 98.50 4589.38 4512.08 4437.78 5050.97 3817.78 2570.28 4.00 23.286 3.87 1.65 5981939.01 585753.50 N 70.38054710 W 149.30342833 7500.00 80.52 88.10 4808.00 4531.70 4483.33 5149.01 3805.32 2687.52 4.00 22.976 3.86 1.80 5881927.83 585850.87 N 70.38051298 W 149.30263859 7800.00 84.21 99.87 4622.28 4544.98 4528.95 5248.11 3590.01 2785.42 4.00 22.786 3.89 1.57 5981913.41 585948.83 N 70.38047105 W 149.30184148 L-202 OBd Tgt 1 7821.45 85.00 100.00 4824.30 4547.00 4538.03 5289.48 3586.38 2788.48 4.00 56.386 3.89 1.55 5981910.00 585970.00 N 70.38048107 W 149.30187081 OBd 7658.79 85.78 101.28 4827.30 4550.00 4551.38 5308.68 3579.49 2823.04 4.00 58.286 210 3.41 5981903.54 586008.65 N 70.36044228 W 149.30137351 7700.00 88.65 102.68 4830.02 4552.72 4587.48 5347.80 3570.98 2883.27 4.00 58.176 2.11 3.41 5981895.45 588048.97 N 70.36041890 W 149.301 End Crv 7744.88 87.60 104.20 4832.28 4554.98 4563.88 5392.43 3560.59 2908.67 4.00 O.OOG 2.11 3.40 5981885.58 586090.48 N 70.38039052 W 149.30089 7-5/8" Csg Pt 7800.00 87.80 104.20 4834.58 4557.28 4803.49 5447.70 3547.03 2960.25 0.00 O.OOG 0.00 0.00 5981872.80 588144.20 N 70.36035343 W 149.30025923 Crv 81100 8381.98 87.80 104.20 4858.98 4581.68 4809.98 8029.17 3404.40 3523.96 0.00 50.396 0.00 0.00 5981738.25 588709.40 N 70.35998311 W 149.29588142 8400.00 88.29 105.03 4859.83 4582.33 4818.25 8047.17 3399.86 3541.38 8.00 50.386 3.83 4.82 5981731.90 588726.87 N 70.35995087 W 149.28553992 L-202 OBd Tgt 2 8444.75 90.00 107.10 4880.30 4583.00 4830.77 6091.82 3387.47 3584.38 6.00 50.106 3.83 4.82 5981720.00 588770.00 N 70.35991878 W 149.29519075 End Crv 8484.68 91.54 108.94 4859.78 4582.48 4842.43 8131.84 3375.13 3822.34 8.00 O.OOG 3.85 4.80 5981708.08 588808.08 N 70.35988300 W 149.29488251 Crv 8/100 9305.01 91.54 108.94 4837.77 4580.4T 5089.31 8951.88 3108.99 4397.99 0.00 -138.886 0.00 0.00 5981450.59 587588.58 N 70.35915480 W 149.28858418 L-202 OBd Tgt 3 9340.08 90.00 107.50 4837.30 4580.00 5079.44 8988.95 3098.02 4431.29 8.00 -135.41 G 4.38 -4.10 5981440.00 587820.00 N 70.35912479 W 149.28831371 End Crv 9377.79 88.39 105.91 4837.83 4580.53 5081.27 7024.84 3087.19 4467.40 8.00 O.OOG 4.27 4.21 5981429.57 587858.22 N 70.35909513 W 149.28802053 Crv 8/100 10412.82 88.39 105.91 4888.92 4589.82 5429.58 8059.07 2803.59 5482.20 0.00 4.876 0.00 0.00 5981157.07 588854.01 N 70.35831858 W 149.27994308 L-202 O&f Tgt 4 10439.58 90.00 105.78 4887.30 4590.00 5438.39 8085.97 2788.24 5488.11 8.00 -5.986 5.98 -0.49 5981150.00 588880.00 N 70.35829844 W 149.27973288 End Crv 10451.63 80.72 105.70 4887.22 4589.92 5442.37 8098.04 2792.97 5499.72 6.00 O.OOG 5.97 -0.83 5981148.88 588881.65 N 70.35628847 W 148.27983640 Crv8/100 11235.48 90.72 105.70 4857.38 4580.08 5701.38 8881.81 2580.82 8254.24 0.00 -177.256 0.00 0.00 5980943.12 589448.40 N 70.35770829 W 149.27351235 L-202 OBd Tgt 5 11247.48 90.00 105.87 4857.30 4560.00 5705.34 8893.83 2577.57 8285.80 8.00 -177.746 -5.99 -0.29 5980940.00 589480.00 N 70.35788939 W 149.27341845 11300.00 88.85 105.55 4858.74 4581.44 5722.77 8948.32 2583.44 8318.38 8.00 -177.736 -6.00 -0.24 5980928.44 589510.71 N 70.35788088 W 149.27300794 End Crv 11318.18 85.86 105.51 4859.77 4582.47 5728.15 8982.47 2559.12 8331.93 8.00 O.OOG -8.00 -0.24 5980922.29 589528.32 N 70.35784884 W 149.27288159 Crv 8H00 11890.87 85.68 105.51 4701.04 4623.74 5919.38 9535.47 2405.92 8684.07 0.00 -10.066 0.00 0.00 5980775.25 590080.08 N 70.35722899 W 149.28839885 11900.00 88.43 105.41 4701.88 4824.38 5922.47 9544.78 2403.44 6883.04 8.00 -10.076 5.91 -1.05 5880772.87 590089.08 N 70.35722219 W 149.28832804 L-202 OBd Tgt 8 11911.31 87.10 105.29 4702.30 4825.00 5928.27 9558.07 2400.45 8903.93 6.00 -10.046 5.91 -1.05 5980770.00 590100.00 N 70.35721399 W 149.26823780 End Crv 11933.83 88.44 105.05 4703.18 4825.88 5933.93 8578.86 2394.54 6925.74 8.00 O.OOG 5.91 -1.05 5980784.33 590121.87 N 70.35719778 W 149. TD ! 4-112" Lnr Pt 12834.43 88.44 105.05 4722.30 4845.00 8172.82 10278.92 2212.87 7801.98 0.00 O.OOG 0.00 0.00 5980590.00 590800.00 N 70.35689915 W 149.28257 i SuAace : 2571 FSL 3890 FEL S34 T12N R11E UM NoRhina (Yt 5978293.25 tftU81 Easdna OCI B 583223.80 NJ81 OA Tgt : 941 FSL 1890 FEL S27 T1 2N R11E UM 5981965.00 585176.00 L-202 OBd Tgt 1:877 FSL 897 FEL 327 T12N R11E UM 5981910.00 585970.00 L-202 084 Tgt 2 : 878 FSL 100 FEL S27 T12N R11E UM 5981720.00 588770.00 L-202 084 Tgt 3 : 388 FSL 4533 FEL S26 T1 2N R11 E UM 5981440.00 587820.00 L-202 Oed Tg14 : 85 FSL 3477 FEL S28 T12N R11E UM 5981150.00 588880.00 L-202 OBd Tgt 5 : 5148 FSL 2700 FEL S35 T12N R11E UM 5980940.00 589480.00 L-202 OBd Tgt 8 : 4988 FSL 2082 FEL S35 T12N R11E UM 5980770.00 590100.00 TD I BHL : 4780 FSL 1364 FEL S35 T12N R11E UM 5980580.00 590800.00 WeIlDesign Vet 3.1RTSP3.03-HF5.00 Bb( do31rt-546) L-2021PIen L-202 (N-N)1PIan L-2021L-202 (P4b) Generated 9/10/2004 10:33 AM Page 3 of 3 • • by Schlumberger ~` L-202 (P4b) F~ Prudhoe Bay Unit - WOA S'~C11~ L-PAD Mq,lOC Prr1,n°~ SaRO Wa1bn IND]] NMI BOY PYW. LIm W, UB FYI Yl[YYMp° M00M: B(i0M 1001 Ob: 90.90]' OW: Of100-M,1001 W: M0112.9°I NwIM9. 9p]91W.1S 9U9 Cad Gam: ~0.9]0.191U• 9101: 4M TW flM: IbWyT~E4 (]1309100r NBl) Yq Dle: ~b.]tY F9: 6]901.]nT lm: W119101].M9 ErIYp: 691tYJ.909U9 90eM Fri OYOYW)999 Pb[ L101~W01 S1W fMY'. S,pWMar 10.1001 0 800 1600 2400 3200 4000 0 800 1600 0 0 c 2400 u m 0 3200 4000 4800 crv Ene Cn% ae~r c.o 0 800 1600 2400 3200 4000 Vertical Section (ft) Azim = 35°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-W 00 600 400 200 000 (P~l 800 ~-202 P4 Pro S ~ Schlumberger ( ) po a CNard: BP Expkxadon Alaska Fkild: Prudhoe Bay Unit • WOA SWCWnISIot L•PAD/L-202 ~~~~~~f~~ WaS: Plan L-202 (N-N) BonllaN: Plan L•202 UNNAPY: 50029 Survey Name I Data: L•202 (P4b) / Septertdrer 10, 2004 TortlAtR11 Dd 1 ERD ralb: 176.029° / 10278.92 ft / 8.885 / 2.177 Ovkl Coordlnab Syabm: NAD27 Alaska Stns Planes, Zone 04, US Feet t.oatlon LWlarrS: N 70.35068488, W 149.32430214 LocNloa Grid NIE YO(: N 5978293.250 ftUS, E 583223.800 RUS OrldConwryaneaAnylo: +0.63635414° Survey I OL8 Computa8on Yatlrod: Minknum Cun!atwe / Li Vartlal Saetlon A>7mM: 105.000° VarBal Sactlon Odpkc N 0.000 R E 0.000 ft TVD Rehnlra Datum: Rotary Table TVD Rafanneo ENwtlac 77.30 fl reletlve to MSL 8a Bad I Ground LwN Elavafbn: 48.80 ft relative to MSL YagrNlc DaeNnatlorr: 24.719° ToW Fkdd 8trmptlc 57592.329 nT YpnMk Dla 90.807° Dadinatlon Dato: Ocbber 25, 2004 MaprrNk DadlnNbn Yodel: BGGM 2004 North Rahnna: True North Toth fort Yp NaM a Tnra Nortlr: +24.719° Comrlards M kldlnWar ArMwrtlr TVD Seb•&a TVD 8a~ „ N8 EW DLS Taol Faa BuYd Rya WaBt Rab Narlbhp fraatlnS LatllrMa lon8kudo R R R R R R R OD R 00 R 90 R RUS RUS na, wia..+ vc.iv vl.cv +cvl.uv +c lv.w vvl.v+ gcva.~rv JVJV.uV Io IV.9a q.W /o.l/V V.NV 4.4V OY07rHY.74 .704WJ.0J N /V.JOVA}1tl94 W 74M.JrMOr!/.77 8800.00 82.98 82.15 4298.81 4219.51 824.89 4307.98 3839.03 1828.88 4.00 75.786 0.97 4.38 5981952.02 585011.98 N 70.38080575 W 149.30844811 8700.00 84.03 88.47 4341.44 4264.14 808.39 4397.45 3847.88 1917.89 4.00 73.836 1.05 4.31 5981881.86 585100.88 N 70.38082987 W 149.30872502 OA 8783.30 85.00 90.00 4377.29 4299.99 980.38 4472.84 3650.19 1983.03 4.00 72.316 1.17 4.24 5981985.00 585175.98 N 70.38063612 W 149.30811470 End Crv 8783.32 85.00 90.00 4377.30 4300.00 980.40 4472.86 3850.19 1993.05 4.00 O.OOG 1.22 4.20 5981965.00 585178.00 N 70.38083812 W 149.30811453 OA Tgt /Crv 41700 8783.33 85.00 90.00 4377.30 4300.00 980.40 4472.68 3850.19 1993.05 0.00 34.596 0.00 0.00 5981985.00 585176.00 N 70.38083612 W 149.30811453 6800.00 85.55 90.42 4384.27 4308.97 995.04 4487.80 3850.13 2008.20 4.00 34.41 G 3.30 2.49 5981965.12 585191.15 N 70.38063588 W 149.30799151 End Crv 6898.93 88.77 92.77 4421.90 4344.80 1081.92 4577.12 3647.63 2097.47 4.00 O.OOG 3.32 2.42 5981983.61 585280.43 N 70.38082906 W 149.30728848 OBa 8987,06 88.77 9277 4447.30 4370.00 1145.80 4842.49 3644.48 2182.78 0.00 O.OOG 0.00 0.00 5981981.18 585345.75 N70.36082040 W149.30873815 OBa KOP 6980.88 88.77 9277 445230 4375.00 1158.38 4855.35 3843.86 2175.61 0.00 O.OOG 0.00 0.00 5981960.70 585358.81 N 70.38061869 W 148.30683176 O8b KOP 7113.40 88.77 92.77 4500.30 4423.00 1279.11 4778.89 3837.90 2298.00 0.00 O.OOG 0.00 0.00 5981958.11 585482.05 N 70.36080231 W 149.30582959 OBD 7118.92 68.77 92.77 4502.30 4425.00 1284.14 4784.04 3837.65 2304.15 0.00 O.OOG 0.00 0.00 5981955.92 585487.19 N 70.3608018? W 149.30558783 Crv 41100 7179.30 66.77 92.77 4524.17 4448.87 1339.14 4840.32 3634.94 2380.38 0.00 24.396 0.00 0.00 5981853.83 585543.43 N 70.36059416 W 149.3051 7200.00 69.52 93.13 4531.54 4454.24 1358.06 4859.68 3833.94 2379.88 4.00 24.266 3.84 1.78 5981953.05 585582.75 3 N 70.36059142 W 149.3049 7300.00 73.18 94.85 4583.52 4488.22 1451.05 4954.39 3627.34 2474.18 4.00 23.71 G 3.85 1.72 5981947.50 585857.31 N 70.38057330 W 149.3042 OBC 7313.25 73.66 95.07 4567.30 4490.00 1463.58 4967.10 3628.24 2486.83 4.00 23.856 3.68 1.88 5981948.54 585689.98 N 70.36057029 W 149.30410408 7400.00 78.84 98.50 4589.38 4512.08 1548.35 5050.97 3617.78 2570.28 4.00 23.286 3.87 1.85 5981939.01 585753.50 N 70.38054710 W 149.30342833 7500.00 80.52 98.10 4809.00 4531.70 1843.50 5149.01 3805.32 2887.52 4.00 22.976 3.88 1.80 5981927.63 585850.87 N 70.38051298 W 149.30283859 7800.00 84.21 99.87 4822.28 4544.98 1742.03 5248.11 3590.01 2785.42 4.00 22.786 3.88 1.57 5981913.41 585948.93 N 70.36047105 W 149.30184148 L-202 OBd Tgt 1 7821.45 85.00 100.00 4824.30 4547.00 1783.30 5269.48 3588.38 2788.48 4.00 58.366 3.89 1.55 5981910.00 585970.00 N 70.36048107 W 149.30187081 OBd 7858.79 85.78 101.28 4827.30 4550.00 1800.41 5308.88 3579.49 2823.04 4.00 58.286 2.10 3.41 5981903.54 588006.85 N 70.36044226 W 149.30137381 7700.00 88.65 102.88 4830.02 4552.72 1841.47 5347.80 3570.98 2863.27 4.00 58.176 2.11 3.41 5981895.45 588046.97 N 70.38041890 W 149.30104864 End Crv 7744.68 87.80 104.20 4832.28 4554.98 1886.08 5392.43 3580.59 2908.87 4.00 O.OOG 2.11 3.40 5981885.58 588090.48 N 70.36039052 W 149.30089438 7-5/8" Csg Pt 7800.00 87.80 104.20 4834.58 4557.28 1941.34 5447.70 3547.03 2980.25 0.00 O.OOG 0.00 0.00 598187260 586144.20 N 70 38035343 W 149.30025823 Crv 8/100 8381.98 87.80 104.20 4658.98 4581.68 2522.76 8029.17 3404.40 3523.98 0.00 50.396 0.00 0.00 5981738.25 588709.40 N 70.35996311 W 149.29588142 WeBDesign Ver 3.1RTSP3.03-HF5.00 Bld( do31rt-548) L-202~PIen L-202 (N-N)1PIen L-202tL-202 (P4b) Genereted 9/10/200410:41 AM Page 1 of 2 GonanaM~ ~ kwllnatlon Admuth TVD Sub-8a flID n NS teW DLS Tool f~a BuUd Rib Wyk Rib Naikiny 8attlnp I.dIWd~ Laigkud~ R R R R R R R 00 R 00 R 100 R RUS RUS d4W.W tld.28 lU5.U3 4d58.d3 45tlL.33 254U./d dW /.1/ 5388.tld 3541.3tl d.W 5U.3dti 3.tl3 4.d1 58tl7731.8U 5tlt3/ltl.tl7 N 711,35885{N37 W 748.28553892 L-202 OBd Tgt 2 8444.75 90.00 107.10 4660.30 4583.00 2585.50 6091.92 3387.47 3584.38 6.00 50.106 3.83 4.82 5981720.00 586770.00 N 70.35991678 W 149.29519075 End Crv 8484.88 91.54 108.94 4659.78 4582.48 2625.38 8131.84 3375.13 3822.34 6.00 O.OOG 3.85 4.80 5881708.08 586808.09 N 70.35988300 W 149.29488251 Crv 8/100 9305.01 91.54 108.94 4637.77 4580.47 3443.48 6951.88 3108.99 4397.99 0.00 -136.886 0.00 0.00 5981450.59 587588.58 N 70.35915480 W 149.28858418 L-202 OBd Tgt 3 9340.08 90.00 107.50 4837.30 4580.00 3478.47 6988.85 3098.02 4431.29 6.00 -135.416 -4.38 -4.10 5981440.00 587620.00 N 70.35912479 W 149.28831371 End Crv 9377.79 88.39 105.91 4837.83 4560.53 3518.15 7024.64 3087.19 4487.40 8.00 O.OOG x.27 -4.21 5981429.57 587856.22 N 70.35909513 W 149.28802053 Crv 8/100 10412.82 88.38 105.91 4868.92 4589.62 4550.45 8059.07 2803.59 5462.20 0.00 -4.876 0.00 0.00 5981157.07 588654.01 N 70.35831858 W 149.27994308 L-202 OBd Tgt 4 10439.56 90.00 105.78 4887.30 4590.00 4577.39 8085.97 2796.24 5488.11 8.00 5.986 5.98 -0.49 5981150.00 588680.00 N 70.35829844 W 149.27973268 End Crv 10451.63 90.72 105.70 4667.22 4589.92 4589.45 8098.04 2792.97 5499.72 8.00 O.OOG 5.97 -0.63 5981146.86 588691.65 N 70.35828947 W 149.27983840 Crv 6/100 11235.48 90.72 105.70 4657.38 4580.08 5373.18 8881.81 2580.82 8254.24 0.00 -177.256 0.00 0.00 5980843.12 589448.40 N 70.35770829 W 149.27351235 L-202 OBd Tgt 5 11247.48 90.00 105.67 4657.30 4580.00 5385.17 8893.83 2577.57 8285.80 8.00 -177.746 5.99 -0.29 5980940.00 588480.00 N 70.35789939 W 149.27341845 11300.00 88.85 105.55 4858.74 4581.44 5437.87 8948.32 2583.44 8318.36 8.00 -177.736 -6.00 -0.24 5980928.44 589510.71 N 70.35788068 W 149.27 7 End Crv 11318.18 85.88 105.51 4859.77 4582.47 5453.82 8982.47 2559.12 8331.93 8.00 O.OOG 6.00 -0.24 5980922.29 589526.32 N 70.35764884 W 149.2 Crv 61100 11890.87 85.88 105.51 4701.04 4823.74 8028.80 9535.47 2405.92 6884.07 0.00 -10.086 0.00 0.00 5980775.25 591X180.08 N 70.35722899 W 149.28839885 11800.00 88.43 105.41 4701.68 4824.38 8038.11 9544.78 2403.44 8893.04 8.00 -10.076 5.91 -1.05 5980772.87 590089.08 N 70.35722219 W 149.28832804 L-202 OBd Tgt 6 11911.31 87.10 105.29 4702.30 4825.00 6047.40 9558.07 2400.45 8903.93 8.00 -10.046 5.91 -1.05 5980770.00 590100.00 N 70.35721399 W 149.28823780 End Crv 11933.93 88.44 105.05 4703.18 4825.88 6070.00 9578.88 2394.54 8925.74 8.00 0.000 5.91 -1.0.5 5980784.33 590121.87 N 70.35719778 W 148.28808056 TD / 4-1/2" Lnr Pt 12634.43 88.44 105.05 4722.30 4645.00 6770.24 10278.92 2212.67 7801.96 0.00 O.OOG 0.00 0.00 5980590.00 590800.00 N 70.35689915 W 149.28257074 Surtace : 2571 FSL 3690 FEL S34 T12N R11 E UM Nortnina m 5978293.25 fitUSt Fasnno DD N 583223.80 tus1 OA Tgt : 941 FSL 1890 FEL S27 T12N R71E UM 5981965.00 585178.00 L-202 O8d Tgt 1:877 FSL 897 FEL S27 T12N R11E UM 5981910.00 585970.00 L-202 OBd Tgt 2 : 878 FSL 100 FEL S27 T12N R11E UM 5981720.00 588770.00 L-202 OBd Tgt 3 : 388 FSL 4533 FEL S2B T12N R11E UM 5981440.00 587820.00 L-202 OBd Tgt 4 : 85 FSL 3477 FEL S26 T12N R11E UM 5981150.00 588880.00 L-202 OBd Tgt 5 : 5146 FSL 2700 FEL S35 T12N R11 E UM 5980940.00 589480,00 L-202 OBd Tgt 6 : 4988 FSL 2062 FEL S35 T12N R11E UM 5980770.00 590100.00 TD / BHL : 4780 FSL 1364 FEL S35 T12N R11E UM 5980590.00 590800.00 • We1lDesign Ver 3.1RTSP3.03-HF5.00 Bld( do31rt546) L-2021PIan L-202 (N-N)~Plan L-2021L-202 (P4b) Generated 8/10/200410:41 AM Page 2 of 2 by Schlumberger "~" L-202 (P4b) Fes' Prudhoe Bay Unit - WOA ~"~"~ L-PAD Mgn.tleF~w. 8uNSlautlm w~oz, Fl..n eYYPo...m,. a, VB F..t LB.nBn.-. 1emr: eaclLlz°a dF: °B.sm• or: woenza,zaa l.L nwzlzaw ~TBZW36MJ8 arose-: w.wB3s~1v aw: L.zm rvoHa: rmrrrwfn.w°.ew.un) Mq Ow: /H.T19• FB: 67bi1A nT lm: W11B 1B 17ABB Ea°I° 6872?O.IOIMIB 84Y FF1 O.BBBWiB01 Pon: L301 (PVE) BM'Dy: B~prnhr10, 1°01 c i 4200 4800 1800 2400 3000 3600 4200 4800 5400 6000 6600 1800 2400 3000 3600 4200 4800 5400 6000 6600 Vertical Secxion (ft) Azim = 105°, Scale = 1(in):600(ft) Origin = 0 WS, 0 E/-W 4200 4800 b~~ Schlumberger ~" L-202 (P4b) `E`° Prudhoe Bay Unit - WOA '"""°'t"~ L-PAD r.-~nrn s,n.o. ~owm wwn •w am ar... zw a. w rr uro.runu Mosr e°°w zaa °p eoeor °.r: ogre-xa. zoa tx rro x+xaw ren+c snunn~us wiec-..: w.ex3s/~/• eee yam rv°wr: rrr w.r ~n~o a r-. rest /wu ~~. •z/nr Fs: naez~nr L.Ow W1/D 183).Me E/rV~ !~]l0IIU9 4oYfrl °.eeuumeee Plrt l.~M~t >bW°W Byrne. i°, 100/ 0 1000 2000 3000 4000 5000 6000 7000 4000 4000 ~ 3000 n n Z +K c 2000 t m v v v 1000 0 0 1000 2000 3000 4000 5000 6000 7000 «< W Scale = 1(in):1000(it) E »> 3000 2000 1000 0 •i Plan L-202 (N-N)/Plan L-202 •i • o ~\ 00 ~~ o ~_ a O, ,-La o0 00 ~° 0 6 Do ~ 00 ~O O 00 spop ~ °~o ..?ppp 2ppp mil/ /ppO ~O X00 O ~~ O OD Plen L-202 Schlumberger Anticollision Report Company: BP Amoco Dah: l1I1QJ2004 Time: tt)55:21 Page: 1 Fiehi: Prudhoe Bay Reference Site: PB L Pad Ce-srdi~ateiNE) Reteroaoe: WeN: Ply L-202 (TI-N)~ True North Reference Wen: Plan L-202 (N-N) Vertical (TVD) Refere~oe: L-202 Plan N-P!'773 Reference Werth: Plan L-202 Db: Syhase NO GLOBAL SCAN: Using user defined sekclioa & scan criteria Reference: Principal Plan 8 PLANNED PROGRAM Interpolation Method : MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 12834.43 ft Scan Method: Trav Cylinder North Maaimnm Radios:10000.00 ft Error Serface: Ellipse + Casing Survey Program for Definitive WeBpath Date: 8/12/2004 Validated: NO Version: 1 Planned From To Survey Taokode Tool Name ft ft 28.50 1400.00 Planned: Plan #4 V1 MWD MWD -Standard 28.50 12634.43 Planned: Plan #4 V1 MWD+IFR+MS MWD + iFR + MuKi Station Casing Points MD TVD Diameter Hak Sine Name ft ft in in 3200.44 2627.30 10.750 13.500 103/4" 7800.00 4634.58 7.625 9.875 75/8" 12634.43. 4722.30 4.500 6.750 4 1/2" Summary ~- O[fset Wellptth ~ Refre Ofi3et CtrCtr No-Go Allowable site Wen Wef~sth MD ft MD ft Diataace ft Area ft DeviaBoa ft Wsraisg ~% PB L Pad L-01 L-01 V14 350.59 350.00 181.50 5.59 175.91 Pass: Major Risk PB L Pad L-01 L-01L1 V2 Plan: Plan # 350.59 350.00 181.50 5.70 175.80 Pass: Major Risk PB L Pad L-02 L-02 V1 792.94 800.00 168.68 12.15 156.53 Pass: Major Risk PB L Pad L-02 L-02PB1 V21 792.94 800.00 168.68 12.26 156.42 Pass: Major Risk PB L Pad L-02 Plan L-02A V2 Plan: PI 798.61 800.00 168.75 12.34 156.42 Pass: Major Risk PB L Pad L-101 L-101 V4 1705.90 1750.00 95.21 29.94 65.27 Pass: Major Risk PB L Pad L-102 L-102 V2 248.30 250.00 234.57 3.95 230.62 Pass: Major Risk PB L Pad L-102 L-102PB1 V10 248.30 250.00 234.57 4.05 230.53 Pass: Major Risk PB L Pad L-102 L-102PB2 V2 248.30 250.00 234.57 4.05 230.53 Pass: Major Risk PB L Pad L-103 L-103 V23 498.89 500.00 76.68 7.75 68.93 Pass: Major Risk PB L Pad L-104 L-104 V7 398.19 400.00 214.99 6.40 208.59 Pass: Major Risk PB L Pad L-105 L-105 V4 498.47 500.00 198.98 8.68 190.29 Pass: Major Risk PB L Pad L-106 L-106 V14 1082.05 1100.00 155.30 17.54 137.76 Pass: Major Risk PB L Pad L-107 L-107 V14 299.91 300.00 180.72 6.29 174.43 Pass: Major Risk PB L Pad L-108 L-108 V18 842.71 850.00 162.64 14.23 148.41 Pass: Major Risk PB L Pad L-109 L-109 V12 350.89 350.00 198.80 7.01 191.78 Pass: Major Risk PB L Pad L-110 L-110 V11 300.19 300.00 222.88 5.34 217.54 Pass: Major Risk PB L Pad L-111 L-111 V24 251.09 250.00 296.96 4.38 292.58 Pass: Major Risk PB L Pad L-112 L-112 V8 345.24 350.00 192.06 7.04 185.02 Pass: Major Risk PB L Ped L-114 L-114 V15 839.45 850.00 266.42 12.83 253.60 Pass: Major Risk PB L Pad L-114 Plan L-114A V1 Plan: P 839.45 850.00 266.42 12.87 253.55 Pass: Major Risk PB L Pad L-115 L-115 V7 798.21 800.00 109.83 12.70 97.13 Pass: Major Risk PB L Pad L-116 L-116 V10 977.84 1000.00 188.52 15.22 173.30 Pass: Major Risk PB L Pad L-117 L-117 V11 897.09 900.00 103.23 13.98 89.25 Pass: Major Risk PB L Pad L-118 L-118 V9 1402.33 1400.00 61.86 24.33 37.53 Pass: Major Risk PB L Pad L-119 L-119 V9 498.37 500.00 123.24 8.08 115.16 Pass: Major Risk PB L Pad L-120 L-120 V8 298.18 300.00 152.28 4.99 147.29 Pass: Major Risk PB L Pad L-121 L-121 V14 200.89 200.00 242.11 3.59 238.52 Pass: Major Risk PB L Pad L-121 L-121A V7 200.89 200.00 242.11 3.59 238.52 Pass: Major Risk PB L Pad L-122 L-122 V5 350.30 350.00 145.74 5.60 140.14 Pass: Major Risk PB L Pad L-200 L-200 V7 299.65 300.00 15.80 5.14 10.67 Pass: Major Risk PB L Pad L-200 L-200L1 V3 299.65 300.00 15.80 5.14 10.67 Pass: Major Risk PB L Pad L-200 L-200L2 V6 299.65 300.00 15.80 5.14 10.67 Pass: Major Risk PB L Pad L-201 L-201 V6 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-201 L-201 L1 V9 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-201 L-201L1PB1 V10 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-201 L-201L2 V5 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-201 L-201 L3 V2 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-201 L-201L3PB1 V6 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-201 L-201 P81 V12 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-201 L-201 P62 V3 298.58 300.00 105.41 5.00 100.41 Pass: Major Risk PB L Pad L-210 L-210 V6 247.99 250.00 135.38 4.10 131.26 Pass: Major Risk .... i • Schlumberger Anticollision Report Compaey: BP Amooo Die: 9V10V2004 1'~ e: 10:55'i:21 Page: 2 Field: Pnidhce Bay Reference Site: PB L Pad Ce~aa be(NE) Rate reace: WeN: Plan t-202 (N-N), True North Reference Well: Plan L-202 (N-N) Vertlesl (TVD) Reference: L-202 Plan N-N 77.3 Reference Welipatk: Plan L-202. Db: Sybase Summary < a~ we8pat6 - Retarence o~ Ch~Ctr Ne-Go sin wen w i~ Mn ink Wren Devlntion w.r.i~ ft ft ft ft ft PB L Pad L-210 L-210P81 V8 12445.75 9600.00 33.39 15.04 18.35 Pass: Minor 1/50 PB L Pad L-211 L-211 V6 700.13 700.00 119.26 11.59 107.67 Pass: Major Risk PB L Pad L-211 L-211 PB1 V6 700.13 700.00 119.26 11.59 107.67 Pass: Major Risk PB L Pad L-216 L-216 V6 248.90 250.00 60.27 4.26 56.02 Pass: Major Risk PB L Pad NWE7-01 L-100 V2 250.29 250.00 344.72 4.27 340.45 Pass: Major Risk PB L Pad NWE1-01 NWE7-01 V5 250.29 250.00 344.72 4.27 340.45 Pass: Major Risk PB L Pad Plan L-03 (S-W) Plan L-03 V3 Plan: Pla 891.68 900.00 202.01 14.30 187.71 Pis: Major Wsk PB L Pad Plan L-113 (N-B) Plan L-113 V5 Plan: PI 404.69 400.00 220.97 8.72 212.25 Pass: Major Risk PB L Pad Plan L-123 (S-U) Plan L-123 V2 Plan: PI 1266.06 1300.00 172.41 23.32 149.10 Pass: Major Risk PB L Pad Plan L-124 (N-C) Plan L-124 VS Plan: PI 454.65 450.00 205.80 7.95 197.86 Pass: Major Risk PB L Pad Plan L-124 (N-C) Plan L-124PB1 V2 Plan: 454.65 450.00 205.80 7.84 197.97 Pass: Major Risk PB L Pad Plan L-203 (N-Q) Plan L-203 V4 Pian: PI 548.80 550.00 45.47 10.07 35.40 Pass: Major Risk PB L Pad Plan L-212 (NA) Plan L-212 V4 Plan: PI 449.45 450.00 16.45 7.77 8.68 Pass: Major Risk PB L Pad Plan L-212 (N-0) Plan L-212PB1 V4 Plan: 449.45 450.00 16.45 7.77 8.68 Pass: Major Risk PB L Pad Plan L-213 (S-B) Plan L-213 VO 29.30 28.50 185.13 NO Offset Stations 200 100 L00 _...200 Field: Prudhoe Bay Site: PB L Pad Well: Plan L-202 (N-N) Wellpath: Plan L-202 PIan111aiY-~H4QWai L-117 (L L-2 L-~la7Qla L-122 (L-12 L-118 (L-11 Pleo L-I13 (N-B) (Plan L- L-I12 Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre to Centre Separation [IOOft/in] :03 (N-Q) (Plan L-203) ,zlo(L-zlopBl) 120 (L-120) b4$'B2) 3) Plan®afid-H992(bNFHl6Na81Q~21 n TERRIE L RUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 "Mastercard Check" ANCHORAGE, AIC gg519-6612 PAY TO THE ORDER OF ~~~~ wauonal Bank Alaska ~ ~'"°" Anchorarge, AK 99501 MEMO_h ~~,, ~:1 2 5 200060:g914~~~6227~~~L556~~• 01t,8 89-6!1252 148 ,~7 DATE .~C. RS r- r L' • • TRAANSMITAL LETTER CHECK LLST CIRCLE APPROPRIATE LETTER/PARAGRAP'HS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME p/~ ~ ~- ~- Development Exploration Service Stratigraphic CHECK WI3AT ADD-ONS "CLUE"~ APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well Permit No, ~ API No. (lf API number Production, should continue to be reported as last two . (2) digits a function ~of the original API number. staled are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (P~ records, data and logs acquired for the pilot bole must be clearly differentiated ~in both name (name on permit plus P>I) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject •to fuU EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ exception. (Company Namel assumes ibe liability of any protest to the spacing _exception that may occur. DRY DITCI-l ~ AD dry ditch sample sets submitted to the SAMPLE Commission must be in no greater ~1ban 30' sample intervals from below ibe permafrost . or from where samples are first caught and ]0' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool Well Name: PRUDHOE BAY UN GRIN L-202 Program DEV Well bore seg ^ PTD#:2041960 Company BP EXPLORATION (ALASKA) INC Initial ClassRype DEV 11-0IL GeoArea Unit OnlOff Shore ~ Annular Disposal ^ Administration 1 Permit_feeattached____-______________________________ ______ -Yes__ ____________________ -- - - 2 Lease number apprgpriale_____ _________________________ ______ Yes._ _-_--._---__--_-__,- ----------------------------------------------------- 3 Uniquewell_nameandnumbe[_____________________________ _________Yes__ ____-____-__-__- --------------------------------------------------------- 4 Well locatedin.a-defined_pool____________________________ _________Yes-_ ____-.---.-_--_--_-.- - - - -- 5 Well located p[operdistance_fromdrillingunit_boundary_______________ _________Yes._ -.-........-..-..-..__.________-________.._---_--__-___ 6 Well located proper distance-f[om other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ CO 505, RULE 3 SET SPACING FOR THE Orion_Pool-at 10 ac. _ _ _ _ _ _ _ _ _ _ _ _ - . _ _ - - - - - - _ - _ _ _ _ _ _ 7 Sufficient acreageayai!_ablein_drilfingunit_______________________ __---_-Yes-- ___-_---_---_- - - - - -- -- 8 If_deviated,is_wellboreplat_included__________________________ _________Yes-- __--__--__--__-_- 9 Operator only affected party - - - - - - - - - -Yes - - - - - - - - - - - - - - - ------------- 10 Ops[atorhasappropriate.bondinforce- ---------------------- --- -----Yes-- --- -- -- -------- ------- ------- -- --~-------------- --------------- 11 Permit_canbeissuedwithoutconservationorder___________________ __-__-__Yes-- __--__--__--__-_____-_--_______-------------- -- - Appr Date 12 Pe[mit_can be issued without administrative_approval - _ _ _ _ - _ _ - _ - _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - - _ - _ _ - _ - _ _ _ _ - _ -------------------------------------------------- RPC 101512004 13 Can permit be approved before 15-day wait Yes 14 Well located within arQa and strata authorized by Injection Order # (put1O# in_comments)_(Far_ NA_ - _ - - . _ _ - - _ _ - - _ _ _ _ - - - - - - - _ - - _ - - - _ - _ 15 All wells within114.mileateaof[eyiewidentified(Forservicewellonly)______ _________ NA___ ____-___-__-----_------_---_---_---_--_ ---------------------------------- 16 Pre-produced injector; duration of pre-p[oduetion less than 3 months(For_service well only) . _ NA_ _ - - -- - - 17 ACMP_Finding of Consistency-has been issued_forthis project_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ ------------------------------------------------------------------------- Engineering 18 Conductarstring_provided-______________________________ _________ Yes__ ____20"x34"_@1Q9'.______--__--__----,_--___ -------------------------------- 19 Surface casingprotects aII kn9wn U$DWs - - - - - -Yes - - - - - - - - - - 20 CMT_voladequate,tocircul_ate_onconductor&surf_csg_______ _-___-_-. Yes-_ _-_--Adepgateexcess-------------------------------------------------- 21 CMT_vol_ adequate_t4 tie-in long string tosurf csy - - - -- - - -- - - - - - - No- - _ _ _ _ _ - 22 CMT_will coyer all know_n_productive horizgns- _ _ - _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _N_o_ _ _ _ _ _ Slotted, _ _ _ _ _ _ - - -- -- - - 23 Casing designs adequate for C,T,B&_permafrost----------------- -- Yes-- --------- ----------------------------- ---------------------- 24 Adequatetankage_orre_seryepit____________________________ _________Yes__ __.._Nabors_9ES,_._,___ - - - -- - - 25 Ifa_re-drill,has_a_10-403 for abandonment been approved------------- --------- NA_-_ -__--Newwell:-__-_--__._ --------------------------------------------------- 26 Ad@quatewellbore separationproposed --------- - ----------- -- Yes-- ------ ---------- ------------- ----------- ----- --------------- -------------- 27 If diverter required, does it meet regulations_ _ . .. . . ....... . . . . . . . . . . . Yes _ _ , - . - - - - - -- -- -- Appr Date 28 Drillingfluid-program schematic_&equiplistadequate________________ _________Yes__ _____MaxMW9,6ppg_--__-__--__--__---______--__________-_---__-_--_- WGA 10!5!2004 29 BOPES, do they meet regulation - - _ - . - _ _ _ _ - _ _ Yes - - - - . - - -- -- 30 BOPE_press rating appropriate; test to_(put prig in cgmments)- - - - - - - - - - - - - _ _ _ Yes . _ _ . _ Test to 3500 psi. -MSP 1580 psi.- - _ _ - - _ _ _ _ _ _ - _ _ - , _ , - _ - _ _ _ - _ _ , - - - - _ - ----------- 31 Choke_manifoldcomplies.wlAPtRP-53(M_ay84)________---------- ---------Yes-- __-__-------__-__--_,--_--__-__------------- 32 Work will occur without operation shutdown______________________ _________Yes-- __--__--__--__-____- - - - - -- 33 Is presence_ of H2S gas probable - - - - - N0- - NQt an H2S pad. - - - - - - - - - 34 Mechanical-condition of wells within AOR verified (Forservice well onlya - _ _ - _ NA_ , - ------------------------------------------------------------------------- Geology 35 Permitsan be issued wlo hydrogen_sulfidemeaaures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ , _ _ - - - - - 36 Data-presented 4n potentialove-rpressurezones__________-_ __--_-_--NA--- __,-__________________________ Appr Date 37 Seismicanalysisofshallowgas_zones-_______________________ _________ NA___ -- - -- - - ________ _ _ RPC 1015120D4 38 Seabed condition survey,(if off-shore) - - _ _ - - _ - _ __ - _- - - --- 39 ,Contact namelphone for weekly progress_reports [exploratory only! _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - _ _ - . - _ - - - - _ . _ Geologic Engineering Public Commissioner: Date: Commissioner: Date C ~oner Date ~ls ~~ •