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Home My WebLink About204-054Nolan 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: 4/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250402 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 3/20/2025 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 3/16/2025 YELLOWJACKET PLUG BRU 212-26 50283201820000 220058 3/21/2025 AK E-LINE Perf BRU 212-26 50283201820000 220058 3/15/2025 AK E-LINE Perf CLU 7 50133205310000 203191 1/22/2025 YELLOWJACKET PLUG IRU 11-06 50283201300000 208184 3/20/2025 AK E-LINE Perf KALOTSA 10 50133207320000 224147 3/1/2025 YELLOWJACKET GPT-PLUG-PERF KBU 22-06Y 50133206500000 215044 1/25/2025 YELLOWJACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP MPE-20A 50029225610100 204054 3/13/2025 READ CaliperSurvey MPI 1-39A 50029218270100 206187 3/4/2025 YELLOWJACKET PERF MPU C-01 50029206630000 181143 1/30/2025 YELLOWJACKET PERF MPU K-17 50029226470000 196028 2/7/2025 AK E-LINE Caliper MPU S-53 50029238110000 224159 3/7/2025 YELLOWJACKET SCBL MRU A-15RD2 50733201050200 202019 3/10/2025 AK E-LINE TubingCut PBU 18-27E 50029223210500 212131 3/15/2025 YELLOWJACKET RCT PBU B-30A 50029215420100 201105 3/7/2025 READ CaliperSurvey PBU S-10A 50029207650100 191123 11/18/2024 YELLOWJACKET CBL-TEMP PBU W-220A 50029234320100 224161 2/22/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40256 T40256 T40257 T40257 T40258 T40259 T40260 T40261 T40262 T40263 T40264 T40265 T40266 T40267 T40268 T40269 T40270 T40271 T40272 MPE-20A 50029225610100 204054 3/13/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.02 12:55:27 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Todd Sidoti Cc:Taylor Wellman Subject:20250313 1542 APPROVAL Shallower Packer Set: MPE-20 (PTD 204-054) Casing Leak Within Schrader Pool Date:Thursday, March 13, 2025 3:42:58 PM Attachments:image001.png Todd, Hilcorp is approved to set packer @ ~4780’ MD. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Taylor Wellman From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Thursday, March 13, 2025 11:53 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: MPE-20 (PTD 204-054) Casing Leak Within Schrader Pool Hi Mel, ASR is currently performing a workover on MPE-20 converting it from ESP to jet pump. We got the ESP completion out of the hole and went in to perform a casing test to 3600 psi. While performing this test we discovered an isolated casing leak between 4830-4870’. We would like to perform a caliper log to confirm that the production casing is in still in good condition and then move our packer set depth up to 4780’. The original packer set depth was 5000’. The top of the Schrader Pool is at 4275’ MD (4184 TVDSS). The top of the Schrader (in reference to the NA sand) is at 4296’ MD (4204’ TVDSS). Please let me know if you would like any additional information. Thanks, Todd Todd Sidoti | Operations Engineer | Hilcorp Alaska | 907-632-4113 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 thesender'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. 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: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Jet Pump 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,878'N/A Casing Collapse Conductor N/A Surface 1,130psi Production 4,790psi OA Liner N/A NB Liner N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT E-20A 4,415' 9,878' 4,415' 1,360 N/A MILNE POINT / SCHRADER BLUFF OIL Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2/25/2025 Swell Packer & ZXP Liner Top Packer and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 & ADL0047437 204-054 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22561-01-00 Hilcorp Alaska LLC C.O. 477.005 Length Size Proposed Pools: 112' 112' 6.5# / L-80 / EUE 8rd TVD Burst 5,190' N/A MD N/A N/A 3,730psi 6,890psi 2,434' 4,414' 4,415' 2,457' 5,989' 112' 20" 13-3/8" 7-5/8" 2,457' 4-1/2"4,424' 5,989' 9,877' See Schematic 5,785' See Schematic 2-7/8" 4,251'4-1/2" & 4" 5,299(MD)/ 4,289(TVD) & 5,464(MD)/ 4,330(TVD) and N/A Taylor Wellman twellman@hilcorp.com 907-777-8449 11,048' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-077 By Gavin Gluyas at 12:32 pm, Feb 13, 2025 Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2025.02.13 11:17:24 - 09'00' Scott Pessetto (9864) SFD 2/17/2025 DSR-2/18/25 1,360 * BOPE test to 2500 psi. * Requires passing 7-5/8" casing test to 3600 psi. * Approved for reverse or forward circulating jet pump with passing MIT-IC to 3600 psi. * SSV closure on power fluid side will initial closure within 2 minutes on SSV on production side and visa versa. * Compliance to CO 808 required. MGR28FEB25 10-404 *&: 3/3/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.03 08:47:16 -09'00' RBDMS JSB 030425 RWO Convert to JP Well: MPU E-20A Date: 02/11/2025 Well Name:MPU E-20A API Number:50-029-22561-01-00 Current Status:ESP producer Rig:ASR 1 Estimated Start Date:02/26/2025 Estimated Duration:7 days Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:204-054 First Call Engineer:Taylor Wellman 907-947-9533 Second Call Engineer:Todd Sidoti 907-632-4113 Current Bottom Hole Pressure:1,213 psi @ 4,154’ TVD Live DH Gauge on 2/6/25 Max. Proposed Surface Pressure:1,360 psi @ 4,154’ TVD Gas Column Gradient (0.1 psi/ft) | 6.3ppg Min ID:2.250” @ 4,944’ XN Nipple Brief Well Summary and Objective MPU E-20A was sidetracked in 2004 to have a Schrader OA and NB lateral. Both laterals have slotted liner. The well has had ESP’s installed in 2004, 2015, 2016, and 2022. The 2016 ESP install added a section of screens below the ESP which helped to stem soilds production. The decline in the run life of the well (12yrs, 1yr, 6 yrs, 2yrs) is highly attributed to corrosion of the tubing. The introduction of the polymer flood in 2019 also is helping to reduce the solids production from the well. Notes on Well Condition x 7-5/8” casing tested to 2,240 psi @ 5,273’ MD on 09/16/2015 (9yrs 7mo – Casing Test Required) x SSV Pilot Settings: o Power fluid SSV high pressure trip will not exceed 3550 psi. o Power fluid SSV high pressure trip will be set to 50% of header pressure Pre-Rig Procedure (Non-Sundried steps) Slickline & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. MIRU SL. 3. Pull DPSOV from upper station and dummy off same. 4. Pull dummy from lower station. 5. RDMO SL. 6. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 7. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 8. RD Little Red Services and reverse out skid. 9. Set CTS BPV. ND Tree. NU BOPE. 10. NU BOPE house. Spot mud boat. Procedure (Sundried steps) RWO 11. MIRU ASR and ancillary equipment. 12. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to setting CTS. 13. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams and annular on 2-7/8” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. RWO Convert to JP Well: MPU E-20A Date: 02/11/2025 14. Pull CTS plug. Bleed any pressure off casing to the returns tank. Pull CTS, lubricate if pressure expected. Kill well with produced water as needed. 15. MU landing joint or spear and BOLDS. 16. POOH with 2-7/8” tubing. a. PU weight was 42k, SO was 28K from the 2022 RWO with ASR. 17. Rig up ESP spooler. 18. POOH and lay down the 2-7/8’’ ESP completion. a. Wash and toss all tubing joints. b. Keep gas lift mandrels and nipple for inspection and possible re-use. c. Make sure to account for all clamps below: i. 87 Canon Clamps ii. 9 Protectorlizers iii. 1 Splice Clamp d. ESP Shroud is across the seals to the motor centralizer. Shroud is 57.5’ long. e. ESP has an additional 3 joints of screens hanging from below the shroud. 19. Contingency (dependent upon condition of tbg & ESP): PU 7-5/8” casing scraper w/ old rock bit to scrape casing down to 5,200’ MD. Reciprocate around 5,000’ MD. 20. MU 7-5/8” test packer and TIH. Set test packer at ±5,000’ MD / 4,135’ TVD and test casing to 3,600psi for 30 min (charted). 21. PU new 4-1/2’’ Jet Pump Completion and RIH. Nom. Size ~Length Item Lb/ft Material 4.5 1’WLEG Pup Joint at ±5,110’ MD 12.6 L-80 4.5 Joints Joints 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 XN Nip with RHC profile at ±5,060 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 7” X 4-1/2” Packer Set 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 40’ Joint 4-1/2 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 BHPG 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 Sliding Sleeve 12.6 L-80 4.5 10'Pup Joint 12.6 L-80 4.5 Joints 12.6 L-80 4.5 Space out PUPS 12.6 L-80 4.5 1 Joint 12.6 L-80 4.5 PUP 12.6 L-80 4.5 Tubing Hanger 12.6 L-80 22. Space out and land the hanger. a. Note PU and SO weights on tally. 23. RILDS and lay down landing joint. 24. Circulate and spot a 100 bbl pill of corrosion inhibited water to setting packer. RWO Convert to JP Well: MPU E-20A Date: 02/11/2025 25. Drop ball and rod and complete loading tubing with FP and hydraulically set the packer as per Vendor setting procedure. 26. Bleed off the tubing to 1000psi. Perform MIT-IA to 3,600 psi for 30 minutes charted. 27. Set CTS. 28. RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU 4-1/16” tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. Pull CTS. 5. MIRU SL. 6. RIH and pull ball & rod and RHC plug. 7. Open SS and install JP. 8. RD crane. Move 500 bbl returns tank and rig mats to next well location. 9. Turn well over to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By: TDF 5/25/2022 SCHEMATIC Milne Point Unit Well: MPU E-20A Last Completed: 5/16/2022 PTD: 204-054 149jts -4” Excluder Screened Liner & Blanks 5,320’ to 11,006’ 89jts -4-1/2” Slotted Liner 6,149’ to 9,833’ 72’ Rat Hole 1’ Rat Hole TD =9,878’(MD) / TD =4,415’(TVD) 20” 13-3/8” Window 2,457’ to 2,481’ Orig KB-31.25 7-5/8” 9 & 10 3 7 8 11 12 14 15 16 13-3/8” 1 2 17 1819 20 MIN ID @ 4,956’ ID= 2.250” No-go “NB” Lateral 5& 6 4 “OA” Lateral Cap String 13 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / N/A 19.124 Surface 112' N/A 13-3/8” Surface 54.5 / K-55 / Btrc. 12.615 Surface 2,457’ 0.155 7-5/8" Intermediate 29.7 / L-80 / IBT-M 6.875 Surface 5,989’ 0.0459 LINER DETAIL 4” NB Liner 9.5 / L-80 / IBT 3.548 5,263’ 11,048’ N/A 4-1/2” OA Liner 12.6 / L-80 / IBT 3.958 5,453’ 9,877’ N/A TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 5,190’ 0.00579 3/8” Cap String Stainless Steel N/A Surface 5,190’ N/A JEWELRY DETAIL No Depth Item 1 154’ Sta #2: GLM 2-7/8” x 1” – Orifice Installed 2 4,795’ Sta #1: GLM 2-7/8” x 1” – w/ Dummy installed 3 4,944’ HES 2.313 XN Nipple – ID= 2.250” No-go 4 4,965’ Discharge Head: BTN, 400 x 2-7/8” 416/ 420SS 5 4,966’ Pump #2: 400, SF1750, 100S 6 4,983’ Pump #1: 400, SF1750, 100S 7 5,001’ Gas Separator: 400 Series 8 5,005’ Intake (5.5” Shroud at top of Intake): 400X 9 5,006’ Upper Seal: 400, BPBSL, UT, INC, SB, HD (In 5.5” Shroud) 10 5,014’ Lower Seal: 400, BPBSL, INC, SB, HD(In 5.5” Shroud) 11 5,022’ Motor: 456 Series, 150Hp/ 2460V/ 43A, 10RTR (In 5.5” Shroud) 12 5,040’ Gauge & Centralizer - Bottom @ 5,062’ (In 5.5” Shroud) 13 5,065’ 4.5” Weatherford 100u Screen (3 Joints): Bottom @ 5,189’ 14 5,189’ Bullnose Hyd 625 Box – Bottom @ 5,190’ 15 5,269’ Hook Wall Hanger Above 7-5/8” Window 16 5,292’ Hook Wall Hanger Outside 7-5/8” Window 17 5,299’ Easy Well Solutions Swell Packer 18 5,453’ Baker Tie-back Sleeve 19 5,464’ Baker ZXP Liner Top Packer 20 5,470’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arctic set in 24” Hole 13-3/8" 784 sx PF ’L’, 371 sx Class “G”, Top Job 54sx PF ‘L’ in 16” Hole 7-5/8” 520 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 900’ MD Hole Angle Passes 50 Deg. @ 4,100’ Max Angle in Tubing = 68 Deg. Angle @ lower GLM= 68 Deg. TREE / WELLHEAD Tree 2-9/16” 5M CIW Wellhead FMC 11”x 2-7/8” Tubing Hanger, 2-7/8” EUE 8rd T&B 2.5” CIW- Type H BPV Profile GENERAL WELL INFO API: 50-029-22561-01-00 Sidetrack Prep by Nabors 4ES – 3/29/2004 Sidetrack and ESP Completion by Doyon 14 – 5/10/2004 ESP Changeout by Doyon 14 – 12/1/2016 ESP Changeout by ASR – 5/16/2022 NB LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 5,247’ to 5,286’(MD)/ 4,275’ to 4,286’(TVD) Well Angle @ window = 74 Deg. NOTE: 7-5/8” Casing Landed on Emergency Slips w/ 175k Down _____________________________________________________________________________________ Revised By: TDF 2/13/2025 PROPOSED Milne Point Unit Well: MPU E-20A Last Completed: 5/16/2022 PTD: 204-054 149jts -4” Excluder Screened Liner & Blanks 5,320’ to 11,006’ 89jts -4-1/2” Slotted Liner 6,149’ to 9,833’ 72’ Rat Hole 1’ Rat Hole TD = 9,878’(MD) / TD =4,415’(TVD) 20” 13-3/8” Window 2,457’ to 2,481’ Orig KB-31.25 7-5/8” 4 3 6 7 13-3/8” 1 2 8 910 11 MIN ID @ ±5,060’ ID= 3.7250” No-go “NB” Lateral 5 “OA” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / N/A 19.124 Surface 112' N/A 13-3/8” Surface 54.5 / K-55 / Btrc. 12.615 Surface 2,457’ 0.155 7-5/8" Intermediate 29.7 / L-80 / IBT-M 6.875 Surface 5,989’ 0.0459 LINER DETAIL 4” NB Liner 9.5 / L-80 / IBT 3.548 5,263’ 11,048’ N/A 4-1/2” OA Liner 12.6 / L-80 / IBT 3.958 5,453’ 9,877’ N/A TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP-BTC 2.441 Surface ±4,900’ 0.0152 4-1/2” Tubing 12.6 / L-80 / 13Cr80 JFE Bear 2.441 ±4,900’ ±5,110’ 0.0152 JEWELRY DETAIL No Depth Item 1 ±4,900’ Sliding Sleeve 2 ±4,950’ Baker Bottom Hole Pressure Gauge 3 ±5,000’ 4-1/2”x7-5/8” Permanent Packer 4 ±5,060’ HES 3.813 XN Nipple – ID= 3.725” No-go 5 ±5,110’ WLEG 6 5,269’ Hook Wall Hanger Above 7-5/8” Window 7 5,292’ Hook Wall Hanger Outside 7-5/8” Window 8 5,299’ Easy Well Solutions Swell Packer 9 5,453’ Baker Tie-back Sleeve 10 5,464’ Baker ZXP Liner Top Packer 11 5,470’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arctic set in 24” Hole 13-3/8" 784 sx PF ’L’, 371 sx Class “G”, Top Job 54sx PF ‘L’ in 16” Hole 7-5/8” 520 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 900’ MD Hole Angle Passes 50 Deg. @ 4,100’ Max Angle in Tubing = 68 Deg. Angle @ lower GLM= 68 Deg. TREE / WELLHEAD Tree 2-9/16” 5M CIW Wellhead FMC 11”x 2-7/8” Tubing Hanger, 2-7/8” EUE 8rd T&B 2.5” CIW- Type H BPV Profile GENERAL WELL INFO API: 50-029-22561-01-00 Sidetrack Prep by Nabors 4ES – 3/29/2004 Sidetrack and ESP Completion by Doyon 14 – 5/10/2004 ESP Changeout by Doyon 14 – 12/1/2016 ESP Changeout by ASR – 5/16/2022 NB LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 5,247’ to 5,286’(MD)/ 4,275’ to 4,286’(TVD) Well Angle @ window = 74 Deg. NOTE: 7-5/8” Casing Landed on Emergency Slips w/ 175k Down Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head 5HJJ-DPHV%2*& )URP5HJJ-DPHV%2*& 6HQW7KXUVGD\0D\30 7R$ODVND16$65:HOO6LWH0DQDJHUV &F%URRNV3KRHEH/2*& 6XEMHFW5((%23(WHVW ZĞǀŝƐĞĚŽƵƌĐŽƉǇĂƐĨŽůůŽǁƐ͗ ͲtĞůůĐŚĂŶŐĞĚƚŽDWhͲϮϬ ͲWdĐŚĂŶŐĞĚƚŽϮϬϰϬϱϰϬ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂǇ͕DĂǇϭϱ͕ϮϬϮϮϵ͗ϬϱWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗ͲϰϬKWƚĞƐƚ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 5/14/22 Rig Rep.: Rig Phone: 685-1266 Operator: Op. Phone:685-1266 Rep.: E-Mail Well Name: PTD #2040540 Sundry #322-004 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/2500 Valves:250/3000 MASP:1034 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16"P Inside Reel valves 0NA HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1925 P Quantity Test Result 200 psi Attained (sec)16 P No. Valves 16 P Full Pressure Attained (sec)54 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4x2325 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 05/12/22 06:01 HRS Waived By Test Start Date/Time:5/13/2022 21:00 HRS (date) (time)Witness Test Finish Date/Time:5/14/2022 03:00 HRS BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Hilcorp Annular closure time = 27 sec. Colt Pace, J. Haberthur Hilcorp Alaska M. Strom / L. Moore MPU E-20A Test Pressure (psi): skaNS-ASR-Well Site Managers@hilcorp.c Form 10-424 (Revised 02/2022) 2022-0514_BOP_Hilcorp_ASR1_MPU_E-20A 9 9 9 9999 9 9 9 - 5HJJ 9 9 7HVWFKDUWDQGVHTXHQFHDWWDFKHGMEU Annular closure time = 27 sec. 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%23(WHVWWRSVL$QQXODUWRSVL 0*5-$1'65 ; dts 1/12/2022 JLC 1/12/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.13 09:54:01 -09'00' RBDMS HEW 1/14/2022 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗DWhͲϮϬ ĂƚĞ͗ϭͬϳͬϮϬϮϮ tĞůůEĂŵĞ͗DWhͲϮϬW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϱϲϭͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/KŝůtĞůů΀^W΁ WĂĚ͗ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶƵĂƌǇϮϭ͕ϮϬϮϮ ZŝŐ͗^Zηϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϰͲϬϱϰ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗dĞĚ<ƌĂŵĞƌ ;ϵϬϳͿϳϳϳͲϴϯϮϬ;KͿ ;ϵϴϱͿϴϲϳͲϬϲϲϱ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ƌŝĂŶ'ůĂƐŚĞĞŶ ;ϵϬϳͿϱϲϰͲϱϮϳϳ;KͿ ;ϵϬϳͿϱϰϱͲϭϭϰϰ;DͿ &EƵŵďĞƌ͗ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϭ͕ϰϱϱƉƐŝΛϰ͕ϮϬϮ͛ds ;^,WŵĞĂƐƵƌĞĚϭͲϱͲϮϬϮϮ&ͬ^W'ĂƵŐĞͿ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗ϭ͕ϰϱϱƉƐŝΛϰ͕ϮϬϮ͛ds ;EŽŶĞǁƉĞƌĨƐďĞŝŶŐĂĚĚĞĚͬDtсϲ͘ϲϲƉƉŐͿͿ DĂǆ͘WƌĞĚŝĐƚĞĚ^ƵƌĨWƌĞƐƐƵƌĞ͗ϭ͕ϬϯϰƉƐŝ ;hƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐĂƐŐƌĂĚŝĞŶƚͿ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ DWhͲϮϬ^WǁĂƐƌĞƉůĂĐĞĚŝŶĞĐĞŵďĞƌŽĨϮϬϭϲ͘dŚĞhŶŝƚǁĂƐŝŶƐƚĂůůĞĚǁŝƚŚĂƐŚƌŽƵĚĂŶĚƐĐƌĞĞŶƐ ŽŶƚŚĞďŽƚƚŽŵďĞĐĂƵƐĞƚŚĞǁĞůůƉƌŽĚƵĐĞĚƐŽůŝĚƐ͘dŚĞƵŶŝƚƌĂŶǁĞůůƵŶƚŝůKĐƚŽďĞƌϮϬϮϭǁŚĞŶƚŚĞǁĞůůŚĂĚƚƌŽƵďůĞ ƐƵƌĨĂĐŝŶŐĨůƵŝĚ͘ 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ƌĂŵͬǀĂůǀĞĂŶĚƚĞƐƚĨŽƌϱͲŵŝŶͿ͘ZĞĐŽƌĚĂĐĐƵŵƵůĂƚŽƌƉƌĞͲĐŚĂƌŐĞƉƌĞƐƐƵƌĞƐĂŶĚĐŚĂƌƚƚĞƐƚƐ͘ Ă͘ EŽƚŝĨǇK'ϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Đ͘ dĞƐƚsZƌĂŵƐŽŶϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ͘ EŽƚĞ͗,ĂǀĞĂƐĞƚŽĨϮͲϳͬϴ͟ƐŽůŝĚďŽĚǇƌĂŵƐŽŶůŽĐĂƚŝŽŶĂƐĂďĂĐŬƵƉŝŶĐĂƐĞǀĂƌŝĂďůĞƐŚĂǀĞĂ ƉƌŽďůĞŵƐĞĂůŝŶŐŽŶƚŚĞƚƵďŝŶŐ͘ 7UHH7+$ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗DWhͲϮϬ ĂƚĞ͗ϭͬϳͬϮϬϮϮ Ě͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ ϳ͘ŽŶƚŝŶŐĞŶĐǇ͗;/ĨƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǁŽŶ͛ƚƉƌĞƐƐƵƌĞƚĞƐƚĚƵĞƚŽĞŝƚŚĞƌĂƉĞŶĞƚƌĂƚŽƌůĞĂŬŽƌƚŚĞWs ƉƌŽĨŝůĞŝƐĞƌŽĚĞĚĂŶĚͬŽƌĐŽƌƌŽĚĞĚĂŶĚWsĐĂŶŶŽƚďĞƐĞƚǁŝƚŚƚƌĞĞŽŶ͘Ϳ Ă͘ EŽƚŝĨǇƚŚĞ,ŝůĐŽƌƉKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ;,ŝůĐŽƌƉͿ͕Dƌ͘DĞůZŝǆƐĞ;K'ͿĂŶĚDƌ͘:ŝŵZĞŐŐ ;K'ͿǀŝĂĞŵĂŝůĞǆƉůĂŝŶŝŶŐƚŚĞǁĞůůŚĞĂĚƐŝƚƵĂƚŝŽŶƉƌŝŽƌƚŽƉĞƌĨŽƌŵŝŶŐƚŚĞƌŽůůŝŶŐƚĞƐƚ͘ K'ŵĂǇĞůĞĐƚƚŽƐĞŶĚĂŶŝŶƐƉĞĐƚŽƌƚŽǁŝƚŶĞƐƐƚĞƐƚ͘ ď͘ tŝƚŚƐƚĂĐŬŽƵƚŽĨƚŚĞƚĞƐƚƉĂƚŚ͕ƚĞƐƚĐŚŽŬĞŵĂŶŝĨŽůĚƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ Đ͘ ŽŶĚƵĐƚĂƌŽůůŝŶŐƚĞƐƚ͗dĞƐƚƚŚĞƌĂŵƐĂŶĚĂŶŶƵůĂƌǁŝƚŚƚŚĞƉƵŵƉĐŽŶƚŝŶƵŝŶŐƚŽƉƵŵƉ͕;ŵŽŶŝƚŽƌ ƚŚĞƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚĨŽƌůĞĂŬƐƚŽĞŶƐƵƌĞƚŚĂƚƚŚĞĨůƵŝĚŝƐŐŽŝŶŐĚŽǁŶͲŚŽůĞĂŶĚŶŽƚůĞĂŬŝŶŐ ĂŶǇǁŚĞƌĞĂƚƐƵƌĨĂĐĞ͘Ϳ Ě͘ ,ŽůĚĂĐŽŶƐƚĂŶƚƉƌĞƐƐƵƌĞŽŶƚŚĞĞƋƵŝƉŵĞŶƚĂŶĚŵŽŶŝƚŽƌƚŚĞĨůƵŝĚͬƉƵŵƉƌĂƚĞŝŶƚŽƚŚĞ ǁĞůů͘ZĞĐŽƌĚƚŚĞƉƵŵƉŝŶŐƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞ͘ Ğ͘ KŶĐĞƚŚĞKWƌĂŵĂŶĚĂŶŶƵůĂƌƚĞƐƚƐĂƌĞĐŽŵƉůĞƚĞĚ͕ƚĞƐƚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚĞƐǇƐƚĞŵĨŽůůŽǁŝŶŐ ƚŚĞŶŽƌŵĂůƚĞƐƚƉƌŽĐĞĚƵƌĞ;ĨůŽŽƌǀĂůǀĞƐ͕ŐĂƐĚĞƚĞĐƚŝŽŶ͕ĞƚĐ͘Ϳ Ĩ͘ ZĞĐŽƌĚĂŶĚƌĞƉŽƌƚƚŚŝƐƚĞƐƚǁŝƚŚŶŽƚĞƐŝŶƚŚĞƌĞŵĂƌŬƐĐŽůƵŵŶƚŚĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌͬWs ƉƌŽĨŝůĞͬƉĞŶĞƚƌĂƚŽƌǁŽƵůĚŶ͛ƚŚŽůĚƉƌĞƐƐƵƌĞĂŶĚƌŽůůŝŶŐƚĞƐƚǁĂƐƉĞƌĨŽƌŵĞĚŽŶKWƋƵŝƉŵĞŶƚ ĂŶĚůŝƐƚŝƚĞŵƐ͕ƉƌĞƐƐƵƌĞƐĂŶĚƌĂƚĞƐ͘ ϴ͘ ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨĐĂƐŝŶŐƚŽϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬ͘WƵůůdt͘ŝƌĐƵůĂƚĞǁĞůůǁͬϴ͘ϱƉƉŐ<t&ŝĨ ŶĞĞĚĞĚ͘ ϵ͘ DhϮͲϳͬϴ͟ůĂŶĚŝŶŐũŽŝŶƚĂŶĚK>^͘ ϭϬ͘ WƵůůŽǀĞƌƐƚƌŝŶŐǁĞŝŐŚƚŽŶƚƵďŝŶŐŚĂŶŐĞƌƚŽĐŽŶĨŝƌŵĨƌĞĞ͘>ƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ŽŶƚŝŶŐĞŶĐǇ͗;/ĨĂƌŽůůŝŶŐƚĞƐƚǁĂƐĐŽŶĚƵĐƚĞĚ͘Ϳ ŝ͘ DhŶĞǁŚĂŶŐĞƌŽƌƚĞƐƚƉůƵŐƚŽƚŚĞĐŽŵƉůĞƚŝŽŶƚƵďŝŶŐ͘ZĞͲůĂŶĚŚĂŶŐĞƌ;ŽƌƚĞƐƚƉůƵŐͿŝŶ ƚƵďŝŶŐŚĞĂĚ͘dĞƐƚKWƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ͘ ϭϭ͘ Zh^ƉŽŽůĞƌƐĂŶĚƐƚĂŐĞ^WŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚ͘ ϭϮ͘ WKK,ǁŝƚŚϮͲϳͬϴ͟^WĐŽŵƉůĞƚŝŽŶůĂǇŝŶŐĚŽǁŶƚƵďŝŶŐ͘ Ă͘ EŽƚĞ͗^ĞŶĚƚƵďŝŶŐŝŶĨŽƌŝŶƐƉĞĐƚŝŽŶ͘ ď͘ EŽƚĞ͗ϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬWŝƉĞďŽĚǇĂŶĚũŽŝŶƚƐƚƌĞŶŐƚŚŝƐϭϰϱ͕ϬϬϬη͘WhtŽŶůĂƐƚŝŶƐƚĂůůǁĂƐ ϴϬ͕ϬϬϬη͘ Đ͘ 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Đ͘ EŽƚĞĨŝŶĂůWh;WŝĐŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ ϭϳ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ͘Z/>^͘>ĂǇĚŽǁŶůĂŶĚŝŶŐͲũŽŝŶƚ͘ ϭϴ͘ ^ĞƚWůƵŐ;dtͿ͘dĞƐƚƚƵďŝŶŐŚĂŶŐĞƌƚŽϮϱϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝ,ŝŐŚ͘ ϭϵ͘ EKW͕EhǁĞůůŚĞĂĚĂŶĚƚĞƐƚƐĂŵĞƚŽϱ͕ϬϬϬƉƐŝ͘ ϮϬ͘ ZDKƌŝŐ͘dƵƌŶǁĞůůŽǀĞƌƚŽWƌŽĚƵĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ ϰ͘ ^W^ŚƌŽƵĚǁŝƚŚ^ĐƌĞĞŶƐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗E>tϭϮͲϮϲͲϮϭ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWhͲϮϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭͬϮϬϭϲ Wd͗ϮϬϰͲϬϱϰ ϭϰϵũƚƐͲϰ͟ǆĐůƵĚĞƌ^ĐƌĞĞŶĞĚ>ŝŶĞƌΘůĂŶŬƐ ϱ͕ϯϮϬ͛ƚŽϭϭ͕ϬϬϲ͛ ϴϵũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϲ͕ϭϰϵ͛ƚŽϵ͕ϴϯϯ͛ ϳϮ͛ZĂƚ,ŽůĞ ϭ͛ZĂƚ,ŽůĞ dс ϵ͕ϴϳϴ͛;DͿͬdсϰ͕ϰϭϱ͛;dsͿ ϮϬ´ ´ :LQGRZ ¶WR¶ KƌŝŐ<Ͳϯϭ͘Ϯϱ ϳͲϱͬϴ͟ ϭϯͲϯͬϴ͟ WĂƚĐŚƐĞƚϮ͕ϵϮϴ͛ ƚŽ Ϯ͕ϵϳϲ͛DϭϭͲϯͲϮϭ WĂƚĐŚƐƚƵŶŐŝŶĂŶĚƐĞƚ Ϯ͕ϴϵϬ͛ƚŽϮ͕ϵϮϴ͛D ϭϮͲϮϲͲϮϭ D/E/Λ ϰ͕ϵϱϲ͛ /сϮ͘ϮϱϬ͟EŽͲŐŽ ³1%´/DWHUDO ³2$´/DWHUDO ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϰͬ,ͲϰϬͬEͬ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϭϮΖ Eͬ ϭϯͲϯͬϴ͟ ^ƵƌĨĂĐĞ ϱϰ͘ϱͬ<ͲϱϱͬƚƌĐ͘ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ Ϯ͕ϰϱϳ͛ Ϭ͘ϭϱϱ ϳͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϵ͘ϳͬ>ͲϴϬͬ/dͲD 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^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϰͬ,ͲϰϬͬEͬ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϭϮΖ Eͬ ϭϯͲϯͬϴ͟ ^ƵƌĨĂĐĞ ϱϰ͘ϱͬ<ͲϱϱͬƚƌĐ͘ ϭϮ͘ϲϭϱ ^ƵƌĨĂĐĞ Ϯ͕ϰϱϳ͛ Ϭ͘ϭϱϱ ϳͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϵ͘ϳͬ>ͲϴϬͬ/dͲD ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϱ͕ϵϴϵ͛ Ϭ͘Ϭϰϱϵ >/EZd/> ϰ͟ E>ŝŶĞƌ ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϱϰϴ ϱ͕Ϯϲϯ͛ ϭϭ͕Ϭϰϴ͛ Eͬ ϰͲϭͬϮ͟ K>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϱ͕ϰϱϯ͛ ϵ͕ϴϳϳ͛ Eͬ dh/E'd/> ϮͲϳͬϴ͟ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ цϱ͕ϮϬϮ͛ Ϭ͘ϬϬϱϳϵ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ цϱ͕ϮϬϮ͛ Eͬ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϲϵ͛ ^ƚĂηϮ͗'>DϮͲϳͬϴ͟ǆϭ͟ Ϯ цϰ͕ϴϭϳ͛ ^ƚĂηϭ͗'>DϮͲϳͬϴ͟ǆϭ͟ ϯ цϰ͕ϵϱϲ͛ ,^Ϯ͘ϯϭϯyEEŝƉƉůĞʹ/сϮ͘ϮϱϬ͟EŽͲŐŽ ϰ цϰ͕ϵϲϳ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϱ цϰ͕ϵϳϮ͛ WƵŵƉ͗ ϲ цϱ͕ϬϬϳ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϳ цϱ͕ϬϬϵ͛ ^ŚƌŽƵĚ,ĂŶŐĞƌ͗ ϴ цϱ͕ϬϬϵ͛ dĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶ͗ ϵ цϱ͕ϬϮϳ͛ DŽƚŽƌ͗ ϭϬ цϱ͕Ϭϰϴ͛ ĞŶƚƌĂůŝǌĞƌͲŽƚƚŽŵΛϱ͕ϬϱϬ͛ ϭϭ цϱ͕Ϭϱϵ͛ ϰ͟ĂŬĞƌtŝƌĞtƌĂƉƉĞĚ^ĐƌĞĞŶ;ϯ:ŽŝŶƚƐͿ͗ŽƚƚŽŵΛцϱ͕ϮϬϮ͛ ϭϮ ϱ͕Ϯϲϵ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌďŽǀĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϯ ϱ͕ϮϵϮ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌKƵƚƐŝĚĞϳͲϱͬϴ͟tŝŶĚŽǁ ϭϰ ϱ͕Ϯϵϵ͛ ĂƐǇtĞůů^ŽůƵƚŝŽŶƐ^ǁĞůůWĂĐŬĞƌ ϭϱ ϱ͕ϰϱϯ͛ ĂŬĞƌdŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϲ ϱ͕ϰϲϰ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϱ͕ϰϳϬ͛ 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20211227 1149 APPROVAL TO SET MODIFIED PATCH MPU E-20 PTD204-054 Date:Monday, December 27, 2021 11:41:21 AM Attachments:image001.png image002.png From: Rixse, Melvin G (OGC) Sent: Monday, December 27, 2021 11:40 AM To: 'Brian Glasheen' <Brian.Glasheen@hilcorp.com>; Ted Kramer <tkramer@hilcorp.com> Cc: David Haakinson <dhaakinson@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; William Kruskie <wkruskie@hilcorp.com> Subject: RE: E-20 PTD-2040540 Brian, Hilcorp is approved to bring MPU E-20 (PTD204-054) on line. Hilcorp is not required to submit a 10-403, but will be required to submit a 10-404 for setting the modified patch. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Ted Kramer, David Haakinson, Tom Fouts, William Kruskie From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Monday, December 27, 2021 11:20 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Ted Kramer <tkramer@hilcorp.com> Cc: David Haakinson <dhaakinson@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; William Kruskie <wkruskie@hilcorp.com> Subject: E-20 PTD-2040540 Mel, Ted is out sick and talked with you about this well already. But we want to double check to make sure we are all aligned and can bring the well online. Over the holidays we did some troubleshooting on E-20 after we reviewed the ESP data and wells tests. After a few diagnostics we found the temporary patch needed to be modified. We pulled the old patch out and adjusted the depth/length and pressure tested for a pass. We plan to submit another 404 but do not plan to submit a 403 prior to bringing the well online. Do you agree with our interpretation of the matrix below? Thanks 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch Install Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,878 feet N/A feet true vertical 4,415 feet N/A feet Effective Depth measured 9,878 feet 5,299 & 5,464 feet true vertical 4,415 feet 4,289 & 4,330 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 5,202' 4,261' Swell Packer Packers and SSSV (type, measured and true vertical depth)ZXP Liner Top Packe N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A N/A 3,730psi 6,890psi N/A N/A Burst N/A Collapse N/A 1,130psi 4,790psi 2,434' 4,414' 4,415' 4,251' 9,877' 11,048'4-1/2" & 4" measuredPlugs Junk measured N/A Length 112' 2,457' 5,989' Size Surface Production OA Liner 20" 13-3/8" 7-5/8" 4-1/2" NB Liner 4,424' 5,785' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-054 50-029-22561-01-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025518 & ADL0047437 MILNE POINT / SCHRADER BLUFF OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: MILNE PT UNIT E-20A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 272 2206 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 86 Gas-Mcf MD 112' 2,457' 5,989' 60 Conductor TVD 112' N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 182 Brian Glasheen brian.glasheen@hilcorp.com 907-564-5277Operations Manager Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 10:21 am, Nov 17, 2021 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.11.17 09:56:43 -09'00' David Haakinson (3533) RBDMS HEW 11/18/2021 DSR-11/17/21SFD 11/18/2021MGR29DEC2021 Well Name Rig API Number Well Permit Number Start Date End Date MP E-20 Slickline 50-029-22561-01-00 204-054 11/3/2021 11/3/2021 11/5/2021 - Friday No operations to report. 11/3/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/2,500H (set patch). SET 2-7/8" TS SLIP STOP (oal: 24", has 1.75" ext fn) & SET @ 2,965' SLM (2,976' MD). SET 2-7/8" D&D PACK OFF (oal: 24") ON SLIP STOP @ 2,963' SLM (2,974' MD). SET 20' D&D PATCH SECTION W/ STINGER (oal: 250") IN PACK OFF @ 2,961' SLM (2,972' MD). SET 2-7/8" D&D PACK OFF, 20' PATCH SECTION W/ STINGER (oal: 276") IN LOWER PATCH SECTION @ 2,940' SLM (2,951' MD). SET 2-7/8" TS SLIP STOP (oal: 18") IN UPPER D&D PACKOFF @ 2,918' SLM (2,929' MD). RAN 2-7/8" D&D HOLE FINDER DOWN TO TOP OF PATCH @ 2,917' SLM (2,928' MD), LRS PRESSURED UP TUBING TO 1500psi (pass), D&D ELEMENTS INTACT. PULLED BK-DGLV FROM ST# 2 @ 143' SLM (169' MD), ALL PACKING RECOVERED. SET BKP-DPSOV (5/16" ports) IN ST# 2 @ 143' SLM (169' MD), GOOD PULL TEST, SHEARED OFF CLEAN. WELL S/I ON DEPARTURE, DSO NOTIFIED. (lower element @ 2,973'md, upper element @ 2,928' md, lower ts slip stop has 1.75" external fn). 11/4/2021 - Thursday No operations to report. No operations to report. No operations to report. 11/6/2021 - Saturday No operations to report. 11/9/2021 - Tuesday 11/7/2021 - Sunday No operations to report. 11/8/2021 - Monday _____________________________________________________________________________________ Revised By: TDF 11/16/2021 SCHEMATIC Milne Point Unit Well: MPU E-20A Last Completed: 12/1/2016 PTD: 204-054 149jts -4” Excluder Screened Liner & Blanks 5,320’ to 11,006’ 89jts -4-1/2” Slotted Liner 6,149’ to 9,833’ 72’ Rat Hole 1’ Rat Hole TD =9,878’(MD) / TD =4,415’(TVD) 20” 13-3/8” Window 2,457’ to 2,481’ Orig KB-31.25 7-5/8” 8 3 6 7 9 10 11 12 13 13-3/8” 1 2 Holes found in TBG @ 2,954’, 2,947’, 2,941’ & 2,933’. Patch set 2,918’ to 2,965’ MD 11-3-2021 14 1516 17 MIN ID @ 4,956’ ID= 2.250” No-go “NB” Lateral 5 4 “OA” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / N/A 19.124 Surface 112' N/A 13-3/8” Surface 54.5 / K-55 / Btrc. 12.615 Surface 2,457’ 0.155 7-5/8" Intermediate 29.7 / L-80 / IBT-M 6.875 Surface 5,989’ 0.0459 LINER DETAIL 4” NB Liner 9.5 / L-80 / IBT 3.548 5,263’ 11,048’ N/A 4-1/2” OA Liner 12.6 / L-80 / IBT 3.958 5,453’ 9,877’ N/A TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 5,202’ 0.00579 JEWELRY DETAIL No Depth Item 1 169’ GLM: SWS 2-7/8” x 1” KBMM DPSOV set 11-3-21 2 4,817’ GLM: SWS 2-7/8” x 1” KBMM 3 4,956’ HES 2.313 XN Nipple – ID= 2.250” No-go 4 4,967’ Discharge Head: GPDIS Centrilift 5 4,972’ Pump Section: Centrilift 6 5,007’ Gas Separator: 400 series, PN 600503 7 5,009’ Shroud Hanger + 2 jts 5.5” csg 15.5# (Hanging off motor suspending sand control screens) 8 5,009’ Tandem Seal Section: Intake Sub 1’, Upper/Lower Seals 400 series, PN 501501 9 5,027’ Motor: Centrilift 456 Series, FMS, Pn 470680 10 5,048’ Centralizer -Bottom @ 5,050’ 11 5,059’ 4” Baker Wire Wrapped Screen (3 Joints):Bottom @ 5,202’ 12 5,269’ Hook Wall Hanger Above 7-5/8” Window 13 5,292’ Hook Wall Hanger Outside 7-5/8” Window 14 5,299’ Easy Well Solutions Swell Packer 15 5,453’ Baker Tie-back Sleeve 16 5,464’ Baker ZXP Liner Top Packer 17 5,470’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arctic set in 24” Hole 13-3/8" 784 sx PF ’L’, 371 sx Class “G”, Top Job 54sx PF ‘L’ in 16” Hole 7-5/8” 520 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 900’ MD Hole Angle Passes 50 Deg. @ 4,100’ Max Angle in Tubing = 68 Deg. Angle @ lower GLM= 68 Deg. TREE / WELLHEAD Tree 2-9/16” 5M CIW Wellhead FMC 11”x 2-7/8” Tubing Hanger, 2-7/8” EUE 8rd T&B 2.5” CIW- Type H BPV Profile GENERAL WELL INFO API: 50-029-22561-01-00 Sidetrack Prep by Nabors 4ES – 3/29/2004 Sidetrack and ESP Completion by Doyon 14 – 5/10/2004 ESP Changeout by Doyon 14 – 12/1/2016 NB LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 5,247’ to 5,286’(MD)/ 4,275’ to 4,286’(TVD) Well Angle @ window = 74 Deg. NOTE: 7-5/8” Casing Landed on Emergency Slips w/ 175k Down STATE OF ALASKA • ' AIL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations❑ Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Fill Clean-out ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: ESP Change-out ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 204-054 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22561-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025518/ADL0047437 MILNE PT UNIT SB E-20A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 9,878 feet Plugs measured N/A FlegC E I V E D true vertical 4,415 feet Junk measured N/A feet JAN 2 3 2017 Effective Depth measured 9,878 feet Packer measured 5,299/5,464 feet A- � true vertical 4,415 feet true vertical 4,289/4,330 feet Casing Length Size MD ND Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,457' 13-3/8" 2,457' 2,434' 3,730psi 1,130psi Production 5,989' 7-5/8" 5,989' 4,414' 6,890psi 4,790psi OA Liner 4,424' 4-1/2" 9,877' 4,415' N/A N/A NB Liner 5,785' 4-1/2"&4" 11,048' 4,251' N/A N/A Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 5,202' 4,227' Swell Packer Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A �� ® �irj'� •{+y d,'cu LC t7, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,280 0 Subsequent to operation: 382 89 405 260 178 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: j�Z1/ 316 572 Contact Ted Kramer Email tkramer(a�hilcorD.com Printed Name Bo York Title Operations Manager Signature ', G ,s Phone 777-8345 Date 2.? S c._, 13 74- .2-7- 17 Form 10-404 Revised 5/2015 1 - RB® s 0-1.1A 2 20Submit Original Only H . • Milne Point Unit .111 Well: MPU E-2OA Schematic Last Completed: 12/1/2016 PTD: 204-054 IliIron)Alaska,LLC TREE/WELLHEAD Tree 2-9/16"5M CIW OrigKB 31.25 Wellhead FMC 11"x 2-7/8"Tubing Hanger,2-7/8" EUE 8rd T&B 2.5"CIW-Type H BPV Profile OPEN HOLE/CEMENT DETAIL 20'41 -"; 20" 260 sx of Arctic set in 24"Hole 13-3/8" 784 sx PF l',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole 1 7-5/8" 520 sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40/N/A 19.124 Surface 112' N/A ' ' 13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface 2,457' 0.155 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' 0.0459 13-3/8"'a i LINER DETAIL 13-3/8"VUrxioyv 4" NB Liner 9.5/L-80/IBT 3.548 5,263' 11,048' N/A 2,457'to2,481' 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' N/A TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 5,202' 0.00579 WELL INCLINATION DETAIL KOP@900'MD IN 2 Hole Angle Passes SO Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. JEWELRY DETAIL No Depth Item 1 169' GLM:SWS 2-7/8"x 1"KBMM 2 4,817' GLM:SWS 2-7/8"x 1"KBMM 3 4,956' HES 2.313 XN Nipple-ID=2.250"No-go 4 4,967' Discharge Head:GPDIS Centrilift 5 4,972' Pump Section:Centrilift 6 5,007' Gas Separator:400 series,PN 600503 7 5,009' Shroud Hanger+2 jts 5.5"csg 15.5#(Hanging off motor suspending sand control screens) 8 5,009' Tandem Seal Section:Intake Sub 1',Upper/Lower Seals 400 series,PN 501501 9 5,027' Motor:Centrilift 456 Series,FMS,Pn 470680 MIN ID@4,956' 10 5,048' Centralizer-Botto@5,050' ID 2.250"No-go 3 11 5,059' 4"Baker Wire Wrapped Screen(3 Joints):Bottom @ 5,202' 12 5,269' Hook Wall Hanger Above 7-5/8"Window ( 14 13 5,292' Hook Wall Hanger Outside 7-5/8"Window ri14 5,299' Easy Well Solutions Swell Packer 5 15 5,453' Baker Tie-back Sleeve'. 6 16 5,464' Baker ZXP Liner Top Packer °0" 17 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 7 8 NB LATERAL WINDOW DETAIL 9 Window in 7-5/8"Casing @ 5,247 to 5,286'(MD)/4,275'to 4,28C(TVD) Well Angle @ window=74 Deg. 10 149jts-4"Excluder Screened Liner&Blanks GENERAL WELL INFO 11 12 5,320'to 11,006' _API:50-029-22561-01-00 tf '' 13 14 Sidetrack Prep by Nabors 4ES-3/29/2004 t,f:,;= Sidetrack and ESP Completion by Doyon 14-5/10/2004 Cl NEr later 72'Rat Hole ESP Changeout by Doyon 14-12/1/2016 16' 15 ..i?e'er_ ,� IVU E: 7-5/8" ^ T5/8"Casing Landed on Emergency Slips w/175k Down � „�,Lateral 1'Rat Hole 89jts-4-1/2"Slotted Liner TD=9,878'(MD)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:CJD 1/20/2017 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-20A Doyon 14 50-029-22561-01-00 204 054 11/28/2016 Future Daily Operations: 11/23/26/2016-Wednesday No activity to report. 11/24/2016-Thursday No activity to report. 11/25/2016-Friday No activity to report. 11/26/2016-Saturday No activity to report. 11/27/2016-Sunday No activity to report. 11/28/2016- Monday Continue to move Doyon 14 from S-pad to E-Pad. arrive E-Pad @ 08:00 hrs PJSM. Remove front and rear boosters. Continue mobilize equipment to E-Pad.Arrange rig mats.Spot Doyon 14 over E-20A. Rig up E-20 for work over operations. Skid rig floor into drilling position. Safe out cellar. Skid conveyor out into drilling position. Prep mud pits for sea water. Install boiler exhaust stack. R/U floor equipment, install cellar boards, Load 8.5 ppg 120 deg seawater into pits.Spot mud shack,finish up conveyor 2,spot rock washer into position. Mobilize lubricator to rig floor, R/U same. Pull BPV, 1,350psi on well. Shut in tree. R/U circulating lines in cellar, R/U rock washer, complete rig acceptance checklist. Test lines to 3,500psi, good. Blow down lines. PJSM for killing well circulating thru GLM @ 4,927' W/ 1,350psi on tbg and I/A, Bleed off I/A to Opsi, Bleed off tbg f/630psi to Opsi. No fluid bled back to flow back tank, all gas. Line up and pump down tbg start 2 bpm, 100psi increase to 3 bpm, 190psi, @ 110 bbl away seen some oil @ flow back tank. Increase to 4 bpm 590psi, minimal oil/gas returns. (Pumped 300 bbls of 120 deg 8.5 ppg seawater.) Note: monitor O/A building to 780psi, bleed off to 420psi. Pump 430 bbls total,shut down and monitor pressures for 30 min,gas flowing f/tbg and I/A, shut in and building to 15psi ea. Line up and pump 100 bbls down tbg 4 bpm, 610psi, no returns to flowback tank,shut down both tbg and I/A, monitor same, both on a brief slight vac,then flowing slight gas. Line up and pump 50 bbls seawater down tbg 4 bpm, 610psi with no returns, shut down and monitor for 10 min, both tbg and I/A on vac. Well is dead.Total pumped 580 bbls of 8.5 ppg seawater.Total returned 80 bbls of crude. Wellhead rep install BPV, bleed pressure off hanger void. Blow down and R/D lines, R/U line to fill I/A, N/D tree and adaptor flange, Wellhead rep inspect hanger threads 2-7/8" 8rd, 8-3/4 turns, R/U choke line on mud cross. N/U BOPE. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-20A Doyon 14 50-029-22561-01-00 204 054 11/28/2016 Future Daily Operations: 11/29/2016-Tuesday Continue N/U BOP. C/O top rams from 3-1/2"X 6"VBR's to 2-7/8"VBR's. C/O rubber elements on 2-7/8"VBR. Fill hole through IA @ 20 bph continual hole fill. Rig up BOPE Test Equipment.Attempt to pull BPV. Observe gas bleeding through BPV. Close Blinds and bullhead down tubing through BPV and IA. Bullhead total of 189 bbls. Well on vac, pull BPV Set TWC. R/U BOP test equipment.Test BOP equipment w/2-7/8"test jt with 300/3,000psi. 5 min hold on each.Chart and record same (see "0" drive). AOGCC waived witnessed by Lou Grimaldi. Koomey drawdown test-3,000psi start, 1,700psi drawdown,46 sec for 200psi inc, 189 secs for full charge. 6 bottles avg @ 2108psi. B/D and R/D test equipment Pull TWC. Well still on vac with no gas observed. Mobilize Weatherford casing tools to rig floor. Bring crossovers and associated handling equipment to rig floor. Stage protectors for 2-7/8" tbg. Install WOT 75 ton "YT" elevators. P/U 2-7/8" EUE 8rd landing jt and engage tbg hanger. BOLDS. Unseat hanger at calculated up wt (75K)with no issues. No gas present under hanger profile. Pull hanger to rig floor. Disconnect ESP connector from penetrator on hanger. B/O and laydown hanger. Perform continuity test on ESP connector(open circuit). Cut connector from ESP cable and re-test with same results(Open circuit). Mobilize Centrilift equipment to rig floor. Install dual sheave in derrick. Spot containment for spooler. Install containment trunk for ESP cable. Run feed rope from spooler to ESP cable via sheave. Pull out of hole with ESP on 2-7/8" EUE 8rd, 6.5 ppf, L-80 tubing from 5,169'to 2,575' MD. Found washout 1/4" hole 8'from pin end onit#83 out of the hole. Washout cut conductors inside ESP cable. Crimp and secure conductors for overhead sheave. s • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-20A Doyon 14 50-029-22561-01-00 204 054 11/28/2016 12/1/2016 Daily Operations: 11/30/26/2016-Wednesday Found washout 1/4" hole 8'from pin end on jt#83 out of the hole. Washout cut conductors inside ESP cable. Crimp and secure conductors for overhead sheave. Continue to POOH with ESP, laying down 2-7/8"tubing from 1800'to pump Assembly. Break down ESP assembly, Recovered all of assembly, 159 joints 2-7/8" tubing, 2-GLM's, 1 XN Nipple with 10' pup, 88 Cannon Clamps,4 flat clamps, 3 Centralizer Clamps, Recovered all clamps as per previous tally. Rig down Baker Centrilift ESP Equipment. Clear and clean rig floor. Remove all unneeded tool from rig floor. Rig up Summit ESP equipment. Stage Summit equipment on rig floor. M/U cable and chemical injection line. Run over sheaves in derrick to rig floor. Stage clamps on rig floor. M/U 4" Pump screens and 5.5"shroud. Stage in table. M/U summit ESP pump assy w/3/8" SS chemical injection line and 1/4"SS sensor line. Attempt to install pump assy into shroud but unable to install due to tolerance issues w/3/8" SS chemical line in shroud. XO @ check valve to 1/4" line and install pump assy into 5.5"shroud assy. Terminate ESP cable to motor assy. Fill pump assy w/oil (purge air from system). XO 1/4" injection line back to 3/8" after pump install in shroud. Run 400 series ESP pump assy F/256' -T/3,331' with 2-7/8"6.5 ppf, EUE, 8rd, L-80 tbg. 2,200 ft/lb make up tq. Perform continuity test every 1,000'. Continuity test showed failed pump gauge @ 3,331' MD. Decision made to pull out of hole and repair. Re-Test w/second Summit rep and verify same results. Pull out of hole F/3,331'to 2,589' MD racking back tubing. 12/1/2016-Thursday Continue to Pull out of hole F/2,589'to 1,750' MD racking back tubing,Summit C/O Test Panel while TOH.Stop @ 1,750. Test cable with good test. determined faulty test panel. RIH with ESP on 2-7/8"Tubing from the derrick to 3331,', installing cannon clamps every other joint. Continue to run ESP picking up new 2-7/8"tubing from pipe shed from 3,331'to 5,166'. installing cannon clamps every other joint.Testing cable every 1,000'. Make up Hanger and landing joint. Install penetrators. Clamp Count: Cannon Clamps 86/Pump Clamps 8/Splice Clamps 2.Total Joints New 2-7/8" tubing run 158, Make ESP Penetrator Splice. L/D ESP Cable and Cappilary Line back to Spooler Unit. Remove tools not needed from rig floor. Blow down lines, choke/Kill/hole fill lines. Make termination to tubing hanger. Make final test on cable. Good Test. Land Tubing hanger. Re-orient hanger to lineup production port and flowline. RILDS. PUW 80K/SOW 75k/Wt on Hanger 40K. Lay down Landing joint. Set BPV.Test hanger void 250 low/5,000psi high w/ 10 min hold (ok). Remove BPV and install TWC. Body test upper tree connection to 5,000 (ok). Remove TWC. Pump 2 bbls diesel down tubing.flood tree w/diesel. Secure well. N/D rig hardware from well. Clean cellar and prep for handover to production. Blowdown service lines to rig floor. disconnect service lines to rig floor,secure same for rig move. Skid rig floor. Demob Rockwasher. Demob ESP spooling unit.Continue Loading out peripheral equipment on location. Rig released @ 00:00 hrs. Notify Pad Operator of Demob from E-20A. Witness waived. Demob from E-20A and stage onsite. Install boosters for rig move. Pickup mats,Notify security, announcement made for Doyon 14 demob F/Echo pad to Sierra pad. Begin rig move F/E-pad. 12/2/2016-Friday No activity to report. i • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-20A Doyon 14 50-029-22561-01-00 204 054 11/28/2016 12/1/2016 Daily Operations: 12/3/2016-Saturday No activity to report. 12/4/2016-Sunday No activity to report. 12/5/2016- Monday No activity to report. 12/6/2016-Tuesday No activity to report. %,OF Tit y 1*Ii//�.'it THE STATE Alaska Oil and Gas �, of/� T /� c�`T /� Conservation Commission wIlLI1�7 \1`1 5f} t 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Q Main: 907.279.1433 L:510 Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCA%NE MAR 17 2017, Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-20A Permit to Drill Number: 204-054 Sundry Number: 316-572 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this/� day of November, 2016. RBDPAS 1.,---NOV 1 6 7016 • • • RECEIVED STATE OF ALASKA NOV 0 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ ESP Change-out Q 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC , Exploratory ❑ Development 2 . 204-054 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Dr,Suite 1400 50-029-22561-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT SB E-20A 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0025518/ADL0047437 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,878' • "4,415' , 9,878' . 4,415' 1,091 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,457' 13-3/8" 2,457' 2,434' 3,730psi 1,130psi Production 5,989' 7-5/8" 5,989' 4,414' 6,890psi 4,790psi OA Liner 4,424' 4-1/2" 9,877' 4,415' N/A N/A NB Liner 5,785' 4-1/2"&4" 11,048' 4,251' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic 1 See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 5,106 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Packer&ZXP Liner Top Packer and N/A • 5,299(MD)/4,289(TVD)&5,464(MD)/4,330(TVD)and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development Q- Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 12/1/2016 Commencing Operations: OIL Q ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Ted Kramer Email tkramer• hilcorp.com Printed Name Bo York Title Operations Manager . ' Signature L, -tr., -kr DY 4/ Phone 777-8345 Date 11/2/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: k Le — x72 Plug Integrity ❑ BOP Test u Mechanical Integrity Test 0 Location Clearance ❑ Other: , S ez 5.va.sk-4 13c f �n s9'4 3 d 0c) p --/'1't.�rJ'c," - A,,,) ,,,/,,,-.,,,,e_c/i s''‘ ✓`el l.t�../P�s!/ 0,A.., �S �'C•4n v►'�v n cam- .0 Post Initial Injection MIT Req d? Yes ❑ No 0 / 00� �� ` t I, 1,4,Spacing Exception Required. Yes ❑ No L14Subsequent Form Required: /® ,/0 RBDMS I,�-- NOV 1 6 2016 0APPROVED BY / / Approved by: COMMISSIONER THE COMMISSION Date: ///, /14 - i'2 11011(#-/i( OP D I SIN // !!!Submit Form and Form 10-403 Revised 11/2015 oei I r 12 mo the from the date of approv I. Attachments in Duplicate Aad • • • Well Prognosis Well: MPU E-20A HiIcorp Alaska.LL) Date: 11/3/2016 Well Name: MPU E-20A API Number: 50-029-22561-01 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: December 1, 2016 Rig: Innovation#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-054 First Call Engineer: Ted Kramer (907) 777-8320 (0) (985) 867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,513 psi @ 4,220'TVD (SBHP measured 9/19/2016 Slick line gauge) Maximum Expected BHP: 1,513 psi @ 4,220'TVD (No new perfs being added/ EMW= 6.89 ppg)) Max. Predicted Surf Pressure: 1,091 psi (Using 0.1 psi/ft gas gradient) Brief Well Summary: MPU E-20A ESP was replaced in September of 2015. The well performed well until a suspected MBE caused the ESP to fail in July of 2016. / 0 le— Casing was pressure tested to/ 2,240 psi on 9-16-2015. r✓ Objective: O t ricuX t ita If e‘' ki3O ( The purpose of this work is to pull the failed ESP, Check for fluid leak off, and run a replacement ES with a Shroud and sand screen. Brief Procedure: WO Rig Procedure: 1. MIRU Hilcorp Innovation#1 Rig. 2. Connect Lines from choke manifold to a 500 bbl returns tank. 3. Set BPV. Kill well with 8.5 ppg sea water. 4. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, re kill well w/8.5ppg seawater prior to pulling BPV. Set TWC. 5. NU BOP. -9-1:('();— 6. Test BOPE to 250.si Low 3 000•si Hi:h annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR rams on 2-7/8" test joint. Note: Have a set of 2-7/8" solid body rams on location as a backup in case variables have a problem sealing on the tubing. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. • • Well Prognosis Well: MPU E-20A rthkeu ) LL' Date: 11/3/2016 7. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure [tina c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 8. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 9. If able to circulate well, mix and pump caustic soda pill (^'5 Ib/bbl) ahead of Baraklean pill ("'4 gal/bbl) to clean oil of tubulars. Displace with 8.5 ppg seawater. 10. MU 2-7/8" landing joint and BOLDS. 11. Pull over string weight on tubing hanger to confirm free . LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 12. RU Spoolers, POOH with 2-7L8"ESP completion laying down 2-7/8"tubing. Note: Record any corrosion damage or solids on the exterior of pipe. Note approx.. depth of any holes in the tubing. 13. PU RIH with 2-7/8"Tubing to 5,120'. Close annular, establish PIR @ 2.5 bpm for 15 minutes to ensure laterals are not plugged. Record pressure pump pressure at the end of the 15 min. Shut down and record pressures at 0 min, 5 min, 10 min., and 15 min. If pressure goes to zero or if well does not hold a column of fluid, discontinue test. 14. POOH racking back 2-7/8" tubing. 15. MU RIH with new ESP on 2-7/8"tubing. Note: ESP will have sand control (screens) added to the bottom. 16. Land tubing hanger. RILDS. Lay down landing-joint.Test tubing hanger to 250psi low/5,000psi High. a. Note PU (Pick Up) and SO (Slack Off)weights on tally. 17. Set BPV. 18. ND BOP, NU wellhead and test same to 5,000 psi. 19. RDMO rig. Turn well over to Production. • ll • I Well Prognosis Well: MPU E-20A ►i��+�a,Fa;UaaNku.I i) Date: 11/3/2016 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. Blank RWO Changes Form S • Milne Point Unit 111 Well: MPU E-20A SCHEMATIC Last Completed: 9/16/2015 Hiker!)Alaska,ra.c PTD: 204 054 TREE/WELLHEAD Tree 2-9/16"5M CIW Wellhead FMC 11"x 2-7/8"Tubing Hanger,2-7/8" OrigK631.25 EUE 8rd T&B 2.5"CIW-Type H BPV Profile ' OPEN HOLE/CEMENT DETAIL 20 20" 260 sx of Arctic set in 24"Hole L^^» 13-3/8" 784 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole "1 1 !l 7-5/8" 520 sx Class"G"in 9-7/8"Hole ,., CASING DETAIL 9 ,, Size Type Wt/Grade/Conn ID Top Btm BPF F. 20" Conductor 94/H-40/N/A 19.124 Surface 112' N/A 13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface 2,457' 0.155 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' 0.0459 13-3/8" a LINER DETAIL 133/8"V‘Andow 4" NB Liner 9.5/L-80/IBT 3.548 5,263' 11,048' N/A 2,45T to2,481' 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' N/A TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 5,169' 0.00579 WELL INCLINATION DETAIL KOP@900'MD 2 Hole Angle Passes 50 Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. JEWELRY DETAIL No Depth Item 1 142' GLM:SWS 2-7/8"x 1"KBMM 2 4,927' GLM:SWS 2-7/8"x 1"KBMM 3 5,099' HES 2.313 XN Nipple-ID=2.250"No-go 4 5,111' Discharge Head:GPDIS Centrilift 5 5,112' Pump Section:Centrilift 119 Flex 10 6 5,135' Gas Separator: 7 5,140' Tandem Seal Section: 8 5,154' Motor:Centrilift 126hp,34amps MIN ID@5,099' 9 5,167' Pump MateSensor-Bottom @ 5,169' ID=2.2517 No-go ( 1,, 3 ,- 10 5,269' Hook Wall Hanger Above 7-5/8"Window ", 11 5,292' Hook Wall Hanger Outside 7-5/8"Window j 14 12 5,299' Easy Well Solutions Swell Packer € il4 13 5,453' Baker Tie-back Sleeve 14 5,464' Baker 2XP Liner Top Packer 5 15 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger Li I_ 1541, NB LATERAL WINDOW DETAIL 7 Window in 7-5/8"Casing @ 5,247'to 5,286'(MD)/4,275'to 4,28r(TVD)Well Angle @ window=74 Deg. GENERAL WELL INFO 8 API:50-029-22561-01-00 Sidetrack Prep by Nabors 4ES-3/29/2004 9 Sidetrack and ESP Completion by Doyon 14-5/10/2004 149jts-4"Excluder Screened Liner&Blanks NOTE: 10 5,320'to 11,006' �✓ A 11 7-5/8"Casing Landed on Emergency a t Slips w/175k Down 1:)11 � 72'Rat Hole 13 * g 14 15 7-5/8" .�1 „OA„Lateral Al 1'Rat Hole 89jts-4-1/2"Slotted Liner TD=9,878'(MD)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:TDF 12/4/2015(V) • ! Milne Point Unit H Well: MPU E-20A PROPOSED Last Completed: 9/16/2015 Hamra Alaska,LLC PTD: 204-054 TREE/WELLHEAD Tree 2-9/16"5M CIW Wellhead FMC 11"x 2-7/8"Tubing Hanger,2-7/8" Orig KB 3L25 EUE 8rd T&B 2.5"CI W-Type H BPV Profile rt cIt / OPEN HOLE/CEMENT DETAIL 20' 20" 260 sx of Arctic set in 24"Hole ,>a ri a; 13-3/8" 784 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole k 7-5/8" 520 sx Class"G"in 9-7/8"Hole CASING DETAIL '' Size Type Wt/Grade/Conn ID Top Btm BPF • i, 4; 20" Conductor 94/H-40/N/A 19.124 Surface 112' N/A ' 13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface 2,457' 0.155 t' 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' 0.0459 13-3/8"4 LINER DETAIL 133/8"Wei w 4" NB Liner 9.5/L-80/IBT 3.548 5,263' 11,048' N/A 2,457'to 2,481' 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' N/A TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface ±5,169' 0.00579 WELL INCLINATION DETAIL KOP@900'MD 2 Hole Angle Passes 50 Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. JEWELRY DETAIL No Depth Item 1 ±142' GLM:SWS 2-7/8"x 1"KBMM 2 ±4,840' GLM:SWS 2-7/8"x 1"KBMM 3 ±5,010' HES 2.313 XN Nipple-ID=2.250"No-go 4 ±5,011' Discharge Head:GPDIS Centrilift 5 ±5,012' Pump Section:Centrilift 6 ±5,037' Gas Separator: 7 ±5,042' Tandem Seal Section: 8 ±5,056' ESP Shroud,5.5"15.5#(Hanging off motor 9 ±5,056' Motor:Centrilift MNID@5,099 10 ±5,078' Pump Mate Sensor-Bottom @ 5,080' ID=2.250"No-go i » 3 11 5,269' Hook Wall Hanger Above 7-5/8"Window ': 12 5,292' Hook Wall Hanger Outside 7-5/8"Window r 4 13 5,299' Easy Well Solutions Swell Packer 14 5,453' Baker Tie-back Sleeve 5 15 5,464' Baker ZXP Liner Top Packer 444 4; az 16 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger s`8 tA s' 7 NB LATERAL WINDOW DETAIL 8 Window in 7-5/8"Casing @ 5,247'to 5,286'(M D)/4,275'to 4,286'(TVD) V Well Angle @ window=74 Deg. 9 GENERAL WELL INFO API:50-029-22561-01-00 10 Sidetrack Prep by Nabors 4ES-3/29/2004 11 149jts-4"Excluder Screened Liner&Blanks Sidetrack and ESP Completion by Doyon 14-5/10/2004 ' 5,320'to 11,006' ..* x.412 NOTE: t > ... + 0. .ariar' 7-5/8"Casing Landed on Emergency fig^Lateral 72'Rat Hole Slips w/175k Down 14 4i 15 `- 18 ► .+ 7-5/8" Ns., - _.....--- "OA'Latera -----4111'Rat Hole 89jts-4-1/2"Slotted Liner TD=9,878'(MD)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:TDF 11/3/2016 l 0 m m < N I O O O O La O `m 2 HJ 2 o p el On b Fr p 3 a wo loQom _ W a 2U alJ 1 N ILL F O C7 z S¢ oU U p� o, _ Q �_N Z z0 om ¢� p p O ao nU § 82 E Qti 0000�W oo 8`-"' 2p + < Z — ❑ LL J> Q LN ;i a X aN w Q ❑ •= iii a J ¢ W CO dr *: ¢ Q W Z o O sm C Z i O z N LitQ, ry O4 ❑ W F- Q BO il W How w LLooI<- J0< OW Z a Pi 2 ° 2, 0Owwa � r a z 0 z pzaZm D U N + X030 N Q (~ ~ J F oc, i 0 ¢ Or o > > N f '' M LL ❑ 0 Li (1/ X CII z LL ¢ a w m m g.,. ,.,41' i�.0: 1_ Nd•N J M J a W U W # W =QQ 4] U s Z 0 0 o Z Q o Q o P' t p e,v 0O ¢_ F. 0 O co ❑ 2 K 2 I CO — pNH m m , o 2 a_ N z co¢ ❑ a co❑ a 44,. # °m ': # i Q ?LL U A J 2 § U = U E °„Y N ` ZZWLL Cl) LL) J 2 M M Mrt' zWZO W A co E N Lo In In L° f - �l W� z Y ❑ a O a V) M M C6 pwr� ¢SN N N N N 0.116 Fm O O ® ® f=0§W Z N (h V N co t` oo O 0 0 0 0 0 0 0 ZNZS w WIDUW I- I- W(0°Ø ' = — — ZD¢LL o St 2F, w �n Y N O LL WaNM � LLO _ — I.�I NWZQQUW as F) 2L9A2_ ��,. Ql W F p-al ,` I-II-Ii ) O W r:1 00 IL41III_ liii2 o_ 103 �� o - -• 1 2 wo >U UI- WZ 1 g w0 N=0 LL �Z O � 1Ln _\ _� IFI' v am ��. Ii .IL _(E'�,I OT., ow — Iwoa � 1 IP C.-1 eZ o00o�ii A •■■i ■■i Y. - j0>1 O °°°i°°° 00 E H H H H U — w o0 _ I n US~S I I I � Wy 2 O O a ii .:: ::. ::. ::. Io z o o O ',I ;� z ¢•G w 0 °O I°° o H E f l _ _ p pi .0 II O. o — H H H H I Ii Ua '',,i ono Fish!! ', a0 p .. II�E �'I — ujg LLFZ 0 i DF NU Z§ Da ❑W N,,, =0 FZ w I 0 I - I m I < • • nn nn a p ,,((gy�p' `1 p 11 a P 4 q- -..• \�, p a p a €�I71 Iva cel o�� 1 =III na� 7 . L 11',—J IJ cn 0 CO 4 N N II s as 00 CD [t mCD __I I yin Ln aLI\ a a n nrm� ,o m I \ -CI _a LI a C•1 CE pil -.WI '-6 ?-1 o 'aaaa' as as cas a a Jaz' as a aal a) I I J 6 _,1_1, — Y — — _ p p O a •Op p b (:O _— p U11 _p � . . p q p q p q_— b —b b p b -- — I a a arras as as I n n nn nn as• N , -----------V a a i ' ba-a� a a 11=1a ae m IU I I nn nn m L. CD m> I LI; �m CO a roI .: rn a Iva 1==I _ nn nal � _d I�- p p— • �� p 41 , q p 4 q.--�•0. p I I as as . • • EXISTING TREE/WELLHEAD MPU E-20A Wellhead/Tree Milne Point Unit Hilcorp Alaska,ILL Tree Cap o Fl. rzo Tree Valve 2-9/16" 5M ��° OV0 Ii.—ISI Tree Cross 2-9/16" 5M II®('o)°€I Tree Valve 2-9/16" 5M SSV 2-9/16" 5M 0 i. Ii. ° 0 Heat Trace (Optional) Tree Valve 2-9/16" 5M Fkzi o 43 t0p4 _ ESP Cable ►a . ,! Tubing Adapter Tubing Head si gm 11" 5M Top x 11" 5M Bt •li Clii .->\ '' ;,: 1 '':eilti7fr, 9 I: _� = "' V Ili1!i el r+ I. 1 � Casing Headff. 1; milmi1 11" 5M Top x 11" 5M Btm _ ��► ��lv mita C • 0 co m P \ 0 £ tW2 o ai 0 w c 7 � Oo ° E / 2 0-J § ® « E £ o o -a2 % %� tJ -c:' § I a� \ a 0. >/ « m k / / 2 di % $ g2 k / � Xa) co 22 � m % to ■ a)2 \ k k Cl) -C _Ck U � CD t / CD < -0 / o k � & M \k § a. a _ = _ co \ C.) \ -D0 • 44. \ � 2 I- E § a. = 3 ® 2 -0 L § - I- a \ / a".•'Li; § c c _ # 2En . \ / LU 0 ■ CO co E. / - Cra . 0 t o_ k ° 0. § 4 Q • 0 c . a E 0 k c § X F 2 2 > � ) \ / ■ a 0 CIO V)6 0 .0 / U) u .. _ •• 5 : 0 R E0 0. \ 2 co. 0 2 k k / 0. 2 Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, November 02, 2016 3:46 PM To: Tom Fouts Cc: Stan Porhola;Carlisle, Samantha J (DOA) Subject: RE: Request to Withdraw Sundry# 315-733/PTD 204-054 Tom, AOGCC will withdraw sundry 315-733 as requested. Workscope was to re'race-EaP,an well.E-20A. (PTD 204-054) Guy Schwartz _ Sr. Petroleum Engineer SCANNED 1 '1� AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From:Tom Fouts [mailto:tfouts@hilcorp.com] Sent:Wednesday, November 02, 2016 2:54 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Stan Porhola<sporhola@hilcorp.com> Subject: Request to Withdraw Sundry#315-733/PTD 204-054 Guy, Hilcorp Alaska LLC requests to withdraw sundry number 315-733 for MP E-20A Thanks, Tom Fouts I Senior Ops/Reg Tech Hilcorp Alaska, LLC tfoutsPhilcarp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 1 RBDMS t; NOV - 3 2016 ti OF Tit, • • • �w \ , THE STATE Alaska Oil and Gas Ofa T c Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS' Fax: 907.276.7542 SCANNED - www.aogcc.alaska.gov Bo York `+— ©C Operations Manager J Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool,MPU SB E-20A Sundry Number: 315-733 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this/ y of December,2015 Encl. 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 2.1 L 4 JAS APPLICATION FOR SUNDRY APPROVALS .,SCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ ESP Change-out0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC • Exploratory ❑ Development la 204-054 3.Address: Stratigraphic EIService ❑ 6.API Number. 3800 Centerpoint Dr,Suite 1400 50-029-22561-01-00 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes ❑ No 0 J MILNE PT UNIT SB E-20A • 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0025518/ADL0047437 ' MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,878' 4,415' 9,878' 4,415' 1,230 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,457' 13-3/8" 2,457' 2,434' 3,730psi 1,130psi Production 5,989' 7-5/8" 5,989' 4,414' 6,890psi 4,790psi OA Liner 4,424' 4-1/2" 9,877' 4,415' N/A N/A NB Liner 5,785' 4-1/2"&4" 11,048' 4,251' N/A N/A Perforation Depth MD(ft): 'Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic ' See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 5,106 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Packer&ZXP Liner Top Packer and N/A • 5,299(MD)/4,289(TVD)&5,464(MD)/4,330(TVD)and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development M Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 12/18/2015 Commencing Operations: OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan `, �j Email pchan@hilcorp.com Printed Name 1/' Bo York Title Operations Manager p 9 Signature Phone 777-8345 Date 12/4/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 (6; —`j33 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: „AG 30`!70 trSi 64 e M f--- S''` SEC 17 'IDIS Post Initial Injection MIT Req'd? Yes ❑ No ❑ / RV Spacing Exception Required? Yes LI No V. Subsequent Form Required: /0 —L7 0+.-( APPROVED BY Approved by: � COMMISSIONER THE COMMISSION� �j//Dyate: /2—/ �_/5 .47/V Q R I G I A fica i'/7!v , l /t (/ Submit Form and Form 10-403 evised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU E-20A Hilcorp Alaska,Lb Date: 12/04/2015 Well Name: MPU E-20A API Number: 50-029-22561-01 Current Status: SI Oil Well [ESP] Pad: - Estimated Start Date: December 18th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-054 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,630 psi @ 4,000' TVD (BHP 9/02/2015/7.84 ppg EMW) --> ° Maximum Expected BHP: 1,630 psi @ 4,000' TVD (No new perfs being added) / MPSP: 1,230 psi (0.1 psi/ft gas gradient) ' '-� - �O3 o A Brief Well Summary: MPU E-20A was drilled as a sidetrack in 2004 using Doyon 14 and completed as an ESP dual lateral in the Schrader Bluff NB and OA sands. The original ESP installed in 2004 failed and was replaced in September 2015. The ESP has issues lifting fluid. Notes Regarding Wellbore Condition • Casing tested to 2,240 psi for 30 minutes down to 5,238' MD on 9/16/2015. & - Objective: Replace failed/failing ESP and run a new ESP. / Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services and 500 bbl returns tank with choke manifold. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing, taking returns up • casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. • 7. RD Little Red Services. 8. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane.• 9. NU BOPE house. Spot mud boat. • Well Prognosis Well: MPU E-20A liilcorp Alaska,LL, Date: 12/04/2015 WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. Y �u' b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure (6�y c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor A the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP E ipme t and list items, pressures and rates. "--5* iLy'--c ^ 1/44,',X B°, '7 14. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 15. MU 2-7/8" landing joint (EUE) and BOLDS. 16. Pull over string weight on tubing hanger to confirm free. LD tubing hanger.' Ita. Contin`: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. -. 17. POOH. Lay 2-7/8" tubing on the pipe rack. Tubing will be re-used. Lay down ESP. 18. PU new ESP and RIH with existing 2-7/8" 8RD EUE L-80 tubing a. Run 2-7/8" XN profile @ ± 5,010' MD b. Run Upper GLM @ ± 142' w/valve c. Run lower GLM @ ±4,840' w/valve. 19. Set base of ESP at+/-5,080' MD. • • Well Prognosis Well: MPU E-20A Hilcor)Alaska,L►; Date: 12/04/2015 20. Land tubing hanger. RILDS. Close pipe rams and test tubing hanger to 500 psi for 5 minutes. Lay down landing joint. a. Note PU (Pick Up) and SO (Slack Off)weights on tally. 21. Set BPV. 22. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. 2. RU crane. ND BOPE. 3. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5000 psi high. :'Contingency: If tree changed, pull BPV, set TWC, and test tree to 250 psi low/5,000 psi high. Pull TWC. 4. Pull BPV. RD crane. 5. Move 500 bbl returns tank and rig mats. 6. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 7. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form • • Milne Point Unit Well: MPU E-20A , ll SCHEMATIC Last Completed: 9/16/2015 Hilcorp Alaska,LLC PTD: 204-054 TREE/WELLHEAD Tree 2-9/16"5M CIW OrigK&31.25 Wellhead FMC 11"x 2-7/8"Tubing Hanger,2-7/8" EUE 8rd T&B 2.5"CIW-Type H BPV Profile i ,' OPEN HOLE/CEMENT DETAIL 20 ,� L20" 260 sx of Arctic set in 24"Hole li 1 13-3/8" 784 sx PF l',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole w 7-5/8" 520 sx Class"G"in 9-7/8"Hole CASING DETAIL Y,` Size Type Wt/Grade/Conn ID Top Btm BPF t +4 20" _ Conductor 94/H-40/N/A 19.124 Surface 112' N/A r, 1 13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface 2,457' 0.155 yl7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' 0.0459 13-3/8" 4 LINER DETAIL 13-3/8"Wrxlow 4" NB Liner 9.5/L-80/IBT 3.548 5,263' 11,048' N/A 2,457'to 2,481' 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' N/A TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 5,169' 0.00579 WELL INCLINATION DETAIL KOP@900'MD 2 Hole Angle Passes 50 Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. JEWELRY DETAIL No Depth Item 1 142' GLM:SWS 2-7/8"x 1"KBMM 2 4,927' GLM:SWS 2-7/8"x 1"KBMM 3 5,099' HES 2.313 XN Nipple-ID=2.250"No-go 4 5,111' Discharge Head:GPDIS Centrilift 5 5,112' Pump Section:Centrilift 6 5,135' Gas Separator: 7 5,140' Tandem Seal Section: 8 5,154' Motor:Centrilift MN ID@5,099' 9 5,167' Pump Mate Sensor-Bottom @ 5,169' I1:: 2.250 No-go '' 3 t 10 5,269' Hook Wall Hanger Above 7-5/8"Window tr. 11 5,292' Hook Wall Hanger Outside 7-5/8"Window I ,s 4 12 5,299' Easy Well Solutions Swell Packer 0 13 5,453' Baker Tie-back Sleeve 5 14 5,464' Baker ZXP Liner Top Packer 15 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger - JII_ �'6 NB LATERAL WINDOW DETAIL i 7 Window in 7-5/8"Casing @ 5,247'to 5,286'(MD)/4,275'to 4,286'(TVD) t: I Well Angle @ window=74 Deg. ti ' r GENERAL WELL INFO 8 API:50-029-22561-01-00 Sidetrack Prep by Nabors 4ES-3/29/2004 9 Sidetrack and ESP Completion by Doyon 14-5/10/2004 3 149jts-4"Excluder Screened Liner&Blanks NOTE: 10 5,320'to 11,006' ;� 11 7-5/8"Casing Landed on Emergency ,r ?ra 12 Slips w/175k Down ( • NB l Baal 72'Rat Hole 13 + 14: 15 7-5/8" .N...... "OA" ,1'Rat Hole Lateral ‘\89jts-4-1/2"Slotted Liner TD=9,878'(ND)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:TDF 12/4/2015(V) • at 0 . Milne Point Unit Well: MPU E-20A PROPOSED Last Completed: 9/16/2015 Hilcorp Alaska,LLC PTD: 204-054 TREE/WELLHEAD Tree 2-9/16"5M CIW OrigK63115 Wellhead FMC 11"x 2-7/8"Tubing Hanger,2-7/8" EUE 8rd T&B 2.5"CIW-Type H BPV Profile C Ca 44 ' OPEN HOLE/CEMENT DETAIL 20' 20" 260 sx of Arctic set in 24"Hole Y- 1 13-3/8" 784 sx PF l',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole 7-5/8" 520 sx Class"G"in 9-7/8"Hole t4 2 •.: DETAIL 'I ' ) „ Size Type Wt/Grade/Conn ID Top Btm BPF IA 20" Conductor 94/H-40/N/A 19.124 Surface 112' N/A 13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface _ 2,457' 0.155 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' 0.0459 133/g" 0 LINER DETAIL 133/8"Wrxlow 4" NB Liner 9.5/L-80/IBT 3.548 5,263' 11,048' _ N/A 2,457'to 2,481' . 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' N/A TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface ±5,169' 0.00579 WELL INCLINATION DETAIL KOP @ 900'MD 2 Hole Angle Passes 50 Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. JEWELRY DETAIL No Depth Item s i 1 ±142' GLM:SWS 2-7/8"x 1"KBMM 2 ±4,840' GLM:SWS 2-7/8"x 1"KBMM 3 ±5,010' HES 2.313 XN Nipple-ID=2.250"No-go 4 ±5,011' Discharge Head:GPDIS Centrilift 5 ±5,012' Pump Section:Centrilift 6 ±5,037' Gas Separator: 7 ±5,042' Tandem Seal Section: 8 ±5,056' Motor:Centrilift MN ID@5,099' 9 ±5,078' Pump Mate Sensor-Bottom @ 5,080' ID=2.250"No-go . % 3 -, 10 5,269' Hook Wall Hanger Above 7-5/8"Window 1 11 5,292' Hook Wall Hanger Outside 7-5/8"Window 4 12 5,299' Easy Well Solutions Swell Packer 13 5,453' Baker Tie-back Sleeve 5 14 5,464' Baker ZXP Liner Top Packer 15 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger JL 6 NB LATERAL WINDOW DETAIL 7 Window in 7-5/8"Casing @ 5,247'to 5,286'(MD)/4,275'to 4,286'(TVD) 9 Well Angle @ window=74 Deg. 1 1 GENERAL WELL INFO 8 API:50-029-22561-01-00 o Sidetrack Prep by Nabors 4ES-3/29/2004 9 Sidetrack and ESP Completion by Doyon 14-5/10/2004 A 149jts-4"Excluder Screened Liner&Blanks NOTE: -10 5,320'to 11,006' y ,,11 7-5/8"Casing Landed on Emergency ti:r 12 Slips w/175k Down f ,.NB"Laeral 72'Rat Hole 14 s ,_15 7-5/8" ` „CA''Lateral 11'RatHole 114'\89jts-4-1/2"Slotted Liner TD=9,878'(ND)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:TDF 12/4/2015(V) • • Milne Point 2015 ASR Rig 1 ii �i,. �M„�p,� . •1.IAKnight Oil Tools BOP A il Stripping Head . hafferi ° 11" - 5000 iii iii iii lii til ill 111 1 1 ill Iii i / C� -U i 2 7/8" —5" VBR 111111111111 w■_ ;Aga = 1 � ii" - 000 - Blind 2" Kill Line ® I 2" Choke Line 0..1 )2,..4 . it.:4,.141, 1 — — — — ill t t ;tv A_ :: 0 ' I t ! : ;. _ Manual Manual Manual HCR Updated 11/03/15 • 0 II Choke Manifold ASR#1 11/01/2015 na,„rp %I».Aa.I 1I Digital Reverse line back to Kill Manifold Pressure Readout ID WI C2 ...O C3 1 la Digital Pressure Transmitter I From Choke Line Manual Choke _® B Remote A Choke C4 C5 C6 C7 Ulm II II ,.. VO , ,., -- in II, III iii. 1.1 ® III , C9 0,1 - 41L All Valves HIMMINIF Piper Series PB Ball Valves 111111 , 6,170 psi Working 10,000 psi Tested R,h C8 (4 - C11 �O C10�0 r - ,t- a a. 'JI, I C13 C15 N 0 0 ` � O 0 i:ir �� .._ 0 $. ,iois a:0► 11 Iii o oO�O 1 W0 _ I 1I, I P C12 ,/, ,., mil ,_,_-; : C14 MIOI. C16 et) To Panic Line . mom 1502 Union Outside MB End Capped To Gas Buster HO • MPU E-20A EXISTING TREE/WELLHEAD' 14Wellhead/Tree Ilil.•orp Alaska,1,1,CMilne Point Unit Tree Cap I.. M ..i iiMillMi .I-"110 Tree Valve 2-9/16" 5M !°, Cl00 j0"G ,o e i®('oTree Cross 2-9/16" 5M )%II Tree Valve 2-9/16" 5M ;c> SSV 2-9/16" 5M 0 lelt -II. 431. 0 0 Heat Trace(Optional) Tree Valve 2-9/16" 5M R.46NLi ic, 0(0 _ ESP Cable •. Tubing Adaptera „11.s Tubing Head in gist 11" 5M Top x 11" 5M Bt ■•u l ��o li (-46Iaj241Iii ;� * ,ii _ I" Casing Head f°�t cam 11" 5MTop x11" 5MBtm IImoil L. 11 L) • en A CCA L s R 8? ? f7W W m . b > x m OTS TO a U o N: J (� a > > C7 n; V • « W e a Z u. 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O cc N Q N CL p O ti Q Ct Q V rL o E p Q 41 O va 3 0 co z cd H et Q E a 0 TO— cO v + ` COR K O a) ''+ o y D U oa U) It ii CO Oo .. U ami l , i V E0 a o = aC413 sp_ a) () o Cl) Cl)aQ CO Q a__ STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing U ASk-t Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing �` E❑ Fill Clean-out Plug for Redrill ❑ arforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ESP Change-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development 0Exploratory ❑ 204-054 + 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22561-01-00! 7. Property Designation(Lease Number): I 8.Well Name and Number: ADL0025518/ADL0047437 MILNE PT UNIT SB E-20A ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11. Present Well Condition Summary: RECEIVED Total Depth measured 9,878 • feet Plugs measured N/A feet true vertical 4,415 • feet Junk measured N/A feet 0 C T 15 2015 Effective Depth measured 9,878 feet Packer measured 5,299/5,464 feet i� CC true vertical 4,415 feet true vertical 4,289/4,330 feet t', I Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,457' 13-3/8" 2,457' 2,434' 3,730psi 1,130psi Production 5,989' 7-5/8" 5,989' 4,414' 6,890psi 4,790psi OA Liner 4,424' 4-1/2" 9,877' 4,415' N/A N/A NB Liner 5,785' 4-1/2"&4" 11048 4,251' N/A N/A Perforation depth Measured depth See Attached Schematic feet SCANNED AUG 1 7 2016 True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 5,106' 4,227' Swell Packer Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 360 0 Subsequent to operation: 147 9 478 220 181 14.Attachments(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory❑ Development❑✓ ' Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil U Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR Li WINJ ❑ WAG ❑ GINJ Li • SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-552 Contact Stan Porhola Email sporhola(C7hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ,*711A1/4.—_-- Phone 777-8412 Date 10/1/2015 Form 10-404 Revised 5/2015 RBDMSjOCT 2 1 2015 Submit Original Only . iti • • Milne Point Unit Well: MPU E-20A SCHEMATIC Last Completed: 9/16/2015 Mean)Alaska,LLC PTD: 204-054 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm OrigK&31.25 20" Conductor 94/H-40/N/A 19.124 Surface 112' 13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface 2,457' ;e ;e `ii. 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' e 20 , te s 0 LINER DETAIL 4" NB Liner 9.5/L-80/IBT 3.548 5,263' 11,048' 1 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' r .. TUBING DETAIL rr 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 5,169' t3 JEWELRY DETAIL 1 ;4 *P No Depth Item 3/g, .01 142' GLM:SWS 2-7/8"x 1"KBMM 4 64 1336 1Mrxiav 2 4,927' GLM:SWS 2-7/8"x 1"KBMM 2,457'to 2,481' 3 5,099' HES 2.313 XN Nipple-ID=2.250"No-go 4 5,111' Discharge Head:GPDIS Centrilift 5 5,112' Pump Section:Centrilift 6 5,135' Gas Separator: 7 5,140' Tandem Seal Section: 8 5,154' Motor:Centrilift 9 5,167' Pump Mate Sensor-Bottom @ 5,169' 2 10 5,269' Hook Wall Hanger Above 7-5/8"Window 11 5,292' Hook Wall Hanger Outside 7-5/8"Window 12 5,299' Easy Well Solutions Swell Packer 13 5,453' Baker Tie-back Sleeve 14 5,464' Baker ZXP Liner Top Packer 15 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger s NB LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 5,247'to 5,286'(MD)/4,275'to 4,286'(TVD) Well Angle @ window=74 Deg. WELL INCLINATION DETAIL KOP @ 900'MD Hole Angle Passes 50 Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. p- s "r OPEN HOLE/CEMENT DETAIL I t' 20" 260 sx of Arctic set in 24"Hole 4 13-3/8" 784 sx PF l',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole ' 7-5/8" 520 sx Class"G"in 9-7/8"Hole r05 4.9. TREE/WELLHEAD > _II_ r'6 Tree 2-9/16"5M CIW M 7 Wellhead FMC 11"x 2-7/8"Tubing Hanger,2-7/8" as 7 EUE 8rd T&B 2.5"CIW-Type H BPV Profile o ' GENERAL WELL INFO ` 8 API:50-029-22561-01-00 11 1 ,, VWSidetrack Prep by Nabors 4ES-3/29/2004 j 9 Sidetrack and ESP Completion by Doyon 14-5/10/2004 t 149jts-4"Excluder Screened Liner&Blanks "'10 5,320'to 11,006' NOTE: y ;11 7-5/8"Casing Landed on Emergency 1 12 Slips w/175k Down IKg Lateral 72'Rat Hole 14: _ 13 15 v 7-5/8" \\ Q4 Lateral '1'Rat Hole \` l '\89jts-4-1/2"Slotted Liner TD=9,878'(MD)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:TDF 10/1/2015 i ! Hilcorp Alaska, LLC Hiko,.,, ,iaska.tic Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP E-20A 50-029-22561-01-00 204-054 9/14/2015 9/17/2015 Daily Operations: 9/16/15-Wednesday PJSM, pump 40 bbls 2% BaraKlean displace w/tbg volume, prepare to POOH.Open bypass release pkr, POOH, BO/LD pkr & bha, (no pkr damage). Blind rams shut. PJSM, Prepare to MU ESP BHA, PU/MU ESP and service ESP assy.Splice ESP cable motor connection. Continue RIH w/ESP,test continuity every 2,000', PU MU hanger. Note: new to this operation ESP cable is exposed to cold from the spooler to all but the last 10'. Cold stiffness is already affecting handling. Build Hanger Splice and meg check,orient hanger. 9/17/15-Thursday PJSM. Complete Splice. Land Hanger PU,SO, Install BPV. Depths are as follows: Centralizer EOT 5,175',Gas Separator@ 5,142', Discharge head@ 5,118', 10' pup,XN 2.25 ID @ 5,107',5 jts 2-7/8" L-80 6.5#EUE,8' Pup,GLM @ 4,927', 7'pup, 151 jts,10' pup, GLM @ 141', 10' pup, 3 jts,4' pup and hanger(4 motor clamps&88 cable clamps installed). Continue RD, ND BOPE, NU tree RDMO Hand well over to production. 9/18/15-Friday No operations to report. 9/19/15-Saturday No operations to report. 9/20/15-Sunday No operations to report. 9/21/15-Monday No operations to report. 9/22/15-Tuesday No operations to report. • • Hilcorp Alaska, LLC ,,ileorp Alaska,,,U Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP E-20A 50-029-22561-01-00 204-054 9/14/2015 9/17/2015 Daily Operations: 9/9/15-Wednesday No operations to report. 9/10/15-Thursday No operations to report. 9/11/15-Friday No operations to report. 9/12/15-Saturday No operations to report. 9/13/15-Sunday MIRU ASR#1 9/14/15-Monday PJSM/prepare for BOPE test, RU Lil Red, P/T all lines 3,500 psi. BOPE test, BOPE 250psi low/3,000psi high annular, 250psi low/2,500psi high, accumulator draw down test.Test and calibrate gas detection equip(Total)HAK gas detection system repaired and put to test for 1 week with (Total)system simultaneoulsy operational. BO/LD tbg hanger and ESP penetrator 35K SW, pull 1 jt and thread cable through snorkel to spooler. POOH with 2-7/8" L-80 6.5#EUE production, BO/LD lea 10' pup, 2 singles, lea 10' pup,GLM, lea 10' pup, 108 jts, ESP cable is twisted and frequently balling, realign BOPs continue POOH 45 Jts, 10' pup, GLM, 10' pup, ljt, 10' pup,XN nipple, 1 jt, 10' pup. ESP splice on 10' pup. Decomplete cut cable BO/LD ESP assy clamps run 88 Clamps recovered 81, ESP pump assy on racks, blind rams shut. Prepare to pick up 7-5/8"scraper&mule shoe, move new production string to racks,strap pipe. PJSM change crews, PU scraper/mule shoe clean out assy. 13.28'YOAL RIH. Open blind rams. 9/15/15-Tuesday PJSM, RIH w/clean out assy to 5,238' 24'above liner. POOH with cleanout assembly. BO/LD scraper assy. PU MU 2-3/8" MS w/2-3/8" PH6 30.24',x-over to 2-7/8" EUE 1.45', Champ Packer assy 16.73', (seals 12.68'.) RIH w/165 jts 5,210.07' 2-7/8" EUE 6.5#L-80 production string.Attempt connection w/swivel, connection made.Set champ pkr @ 5,238'tubing tail @ 5,273', 20k on pkr,fill csg 126 bbls including POOH hole fill. P/T chart casing to ISIP 2,265psi for 30 minutes, FSIP, 2,240psi. Prepare BaraKlean pill to pump down tubing. i 2T c s� OF Tly • • e��\I//7;,,.:s, THE STATE Alaska Oil and Gas 4 ,~ � ofLASKA Conservation Commission -12___ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALASIIC.N' Fax: 907.276.7542 www.aogcc.alaska.gov Stan Porhola ;r , �� " �� '` _ Operations Engineer a(,� Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-20A Sundry Number: 315-552 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /0-711_ ,254.& Cathy P. Foerster Chair DATED this 16-ay of September, 2015 2015 Encl. RBDMS SEP 11 . • • RECEIVED • STATE OF ALASKA SEP 0 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION VI/f Os APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Fill Cleanout Q Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ ESP Change-out❑., • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC = Exploratory ❑ Development 2 • 204-054 • 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22561-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 7 MILNE PT UNIT SB E-20A ` 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518/ADL0047437 • MILNE POINT/SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,878 - 4,415 . 9,878 - 4,415 , N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,457' 13-3/8" 2,457' 2,434' 3,730psi 1,130psi Production 5,989' 7-5/8" 5,989' 4,414' 6,890psi 4,790psi OA Liner 4,424' 4-1/2" 9,877' 4,415' N/A N/A NB Liner 5,785' 4-1/2"&4" 11,048' 4,251' N/A N/A Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 5,106 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer&ZXP Liner Top Packer and N/A 5,299(MD)/4,289(TVD)&5,464(MD)/4,330(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development Q ` Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/12/2015 Commencing Operations: OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporholae.hilcorp.com Printed Name St n Porhola Title Operations Engineer 9 Si nature ,.- d•-•/.....----/.d•-•/.....---- Phone 777-8412 Date 9/3/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 15- 552 Plug Integrity ❑ BOP Test u Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3©©D e 5;_ .66v/ (e.s'T ( A ? - ?c/.s'- Spacing Exception Required? Yes ❑ No ff Subsequent Form Required: /0 —/Q It- APPROVED fAPPROVED BY Approved by: , ,.....j24.,14...„ COMMISSIONER THE COMMISSION Date: _/ Cdsik RBQM .kt 5 1 2U1 k•is Submit Form and orm 1 403 Re 01 o �21fi rr�v lid for 72 Li fr t f approval. II Attachments in Duplicate VVV �� i�,�'�G Y • S Well Prognosis • Well: MPU E-20A Hilcorp Alaska,LU Date:9/03/2015 Well Name: MPU E-20A API Number: 50-029-22561-01 Current Status: SI Oil Well [ESP] Pad: E- Estimated Start Date: September 12th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-054 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,630 psi @ 4,000'TVD (Last BHP measured 9/02/2015) Maximum Expected BHP: 1,630 psi @ 4,000'TVD (No new perfs being added) / Max.Allowable Surf Pressure: 90 psi (Based on SBHP taken 9/02/2015 and water cut �{. ivuks' of (0.385psi/ft) an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: 1•F• ) MPU E-20A was drilled as a sidetrack in 2004 using Doyon 14 and completed as an ESP dual lateral in the Schrader Bluff NB and OA sands. The original ESP installed in 2004 has had degrading performance and recently went offline. Notes Regarding Wellbore Condition 9> • Casing last tested to 3,500 psi for 30 min down to 5,906' MD on 4/27/2004. Objective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. / Brief Procedure: WO Rig Procedure: 1. Circulate well with 8.5 ppg sea water down tubing and fill casing. 2. RU crane.Set BPV. ND Tree. NU 11" BOPE. 3. MIRU Hilcorp ASR#1 WO Rig. 4. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each valve and test for 5-min). Recon accumulator pre-charge pressures and h t tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8" test joint. 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect 4l` to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor Cad the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) • • Well Prognosis Well: MPU E-20A Hilcorp Alaska,LL) Date:9/03/2015 d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. ee any pressure off tubing and casing. Pull BPV. 7. MU landing joint(2-7/8" EUE 8RD hanger thread)and pull over string weight(previous rig string weight 80k UWT with Doyon 14 includes 50K top drive weight) on tubing hanger to confirm free. 8. POOH. Lay 2-7/8"tubing on the pipe rack(utilize as workstring). a. Drift ID of 2-7/8" tubing is 2.347". 9. MU 6-5/8" bit and junk baskets and RIH to Baker Hook Wall Hanger at+/-5,269' MD. 10. Circulate bottoms up x 2 with 8.5 ppg sea water. 11. POOH. Lay down bit and junk baskets. Lay down 2-7/8" tubing. 12. PU RTTS and RIH w/2-7/8"tubing/workstring. 13. Set RTTS at+/-5,250' MD.Test casing to 2,000 psi for 30 min. M tT— ' • 14. Release RTTS. POOH. LD RTTS. Lay down 2-7/8"tubing/workstring. 15. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. 16. Set base of ESP at+/-5,100' MD(Pump intake around+/-5,060' MD). Land tubing hanger. 17. Lay down landing joint.Set BPV. ND BOPE. NU existing 2-7/8" 5,000#tree. Pull BPV. 18. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 19. RD Hilcorp ASR#1 WO Rig. 20. Replace IA x OA pressure gauge if removed (7-5/8"x 13-3/8"). 21. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic , 11 H . • Milne Point Unit Well: MPU E-20A - SCHEMATIC Last Completed: 5/10/2004 Hilcorp Alaska,LLC PTD: 204-054 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.KB-GL Elev=57,80/frig RT-GL Elev.33.12'(Doyon 14) 20" Conductor 94/H-40/N/A 19.124 Surface 112' :, ;...:j13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface 2,457' �% r 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' 2O' 4' LINER DETAIL 4" _ NB Liner 9.5/L-80/IBT 3.548 5,269' 11,048' 1 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' *.: TUBING DETAIL i 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 5,106 JEWELRY DETAIL 1 II M No Depth Item 1 118' GLM:SWS 2-7/8"x 1"KBMM 133/8 oj2 4,937' GLM:SWS 2-7/8"x 1"KBMM 13.3/8'VIAndow 2,45T to 2,481' ; 'I 3 4,994' HES 2.313 XN Nipple-ID=2.250"No-go 4 5,045' Discharge Head:GPDIS Centrilift ` 5 5,046' Pump Section:Centrilift GPMTAR 1:1 122 Stage GC2200 Js 6 5,066' Tandem Gas Separator:Centrilift GRSFXTBARH6 7 5,071' Tandem Seal Section:Centrilift GSB3 DB UT/LT IL H6 PFS AFLAS/HSN 8 5,085' Motor:Centrilift 114Hp/KMHG 2,330 V/30 Amp 9 5,101' Pump Mate Sensor-Bottom @ 5,106' 2 10 5,269' Hook Wall Hanger Above 7-5/8"Window 11 5,292' Hook Wall Hanger Outside 7-5/8"Window 12 5,299' Easy Well Solutions Swell Packer-Bottom @ 5,314' 13 5,453' Baker Tie-back Sleeve 14 5,464' Baker ZXP Liner Top Packer 15 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger NB LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 5,247'to 5,286'(MD)/4,275'to 4,286'(TVD) Well Angle @ window 74 Deg. WELL INCLINATION DETAIL KOP@900'MD Hole Angle Passes 50 Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. -.0 3 ; OPEN HOLE/CEMENT DETAIL 11 }'4V, tk20" 260 sx of Arcticset in 24"Hole t 13-3/8" 784 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole t'S 1„.� 7" 520 sx Class"G"in 9-7/8"Hole .„, ,"` TREE/WELLHEAD k+ _II_ %.6 Tree 2-9/16"5M CIW w` 7 FMC 11"x 2-7/8"Tubing Hanger,2-7/8" ' Wellhead '. EUE 8rd T&B 2.5"CIW-Type H BPV Profile GENERAL WELL INFO to v" API:50-029-22561-01-00 ill V ,. Sidetrack Prep by Nabors 4ES-3/29/2004 9 #; Sidetrack and ESP Completion by Doyon 14-5/10/2004 149jts-4"Excluder Screened Liner&Blanks NOTE: `'10 5,320'to 11,006' i11 7-5/8"Casing Landed on Emergency 12 Slips w/175k Down "NEC N,.,....LaN,.,....aal 72 'Rat Hole 13 ''' MI 14: _ 15 7-5/8" ` "OA Lataal `, 1'Rat Hole ‘89jts-4-1/2"Slotted Liner TD=9,878'(WD)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:TDF 9/3/2015 • • Milne Point Unit li Well: MPU E-20A PROPOSED Last Completed: 5/10/2004 Hilcorp Alaska,LLC PTD: 204-054 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm GrigKB-GL EIev=57.80'/OrigRT-GL EIev.3312'(Down 14) 20" Conductor 94/H-40/N/A 19.124 Surface 112' 13-3/8" Surface 54.5/K-55/Btrc. 12.615 Surface 2,457' -j , .' L447-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 5,989' I:. LINER DETAIL 4" NB Liner 9.5/L-80/IBT 3.548 5,269' 11,048' y 1 a 4-1/2" OA Liner 12.6/L-80/IBT 3.958 5,453' 9,877' TUBING DETAIL a 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface ±5,106 Pi 0! JEWELRY DETAIL No Depth Item 133/g,y ', V 1 ±118' GLM:SWS 2-7/8"x 1"KBMM 2 ±4,937' GLM:SWS 2-7/8"x 1"KBMM 1338 Window 3 ±4,994' HES 2.313 XN Nipple-ID=2.250"No-go 2,45T to 2,481' 4 ±5,045' Discharge Head:GPDIS Centrilift 5 ±5,046' Pump Section:Centrilift GPMTAR 1:1 122 Stage GC2200 6 ±5,066' Tandem Gas Separator:Centrilift GRSFXTBARH6 ' 7 ±5,071' Tandem Seal Section:Centrilift GSB3 DB UT/LT IL H6 PFS AFLAS/HSN 8 ±5,085' Motor:Centrilift 114Hp/KMHG 2,330 V/30 Amp 9 ±5,101' Pump Mate Sensor-Bottom @±5,106' 2 10 5,269' Hook Wall Hanger Above 7-5/8"Window 11 5,292' Hook Wall Hanger Outside 7-5/8"Window 12 5,299' Easy Well Solutions Swell Packer-Bottom @ 5,314' 13 5,453' Baker Tie-back Sleeve 14 5,464' Baker ZXP Liner Top Packer 15 5,470' Baker 7-5/8"x 5-1/2"HMC Liner Hanger NB LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 5,247'to 5,286'(MD)/4,275'to 4,286'(TVD) Well Angle @ window=74 Deg. WELL INCLINATION DETAIL '•. KOP@900'MD ' Hole Angle Passes 50 Deg.@ 4,100' Max Angle in Tubing=68 Deg. Angle @ lower GLM=68 Deg. 3 'w OPEN HOLE/CEMENT DETAIL ?" r4 20" 260 sx of Arcticset in 24"Hole ' 13-3/8" 784 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 16"Hole 5 7" 520 sx Class"G"in 9-7/8"Hole TREE/WELLHEAD Ar Iii_ 5.6 > �; Tree 2-9/16"SM CIW 7Wellhead FMC 11"x 2-7/8"Tubing Hanger,2-7/8" 1 Mt 1 EUE 8rd T&B 2.5"CIW-Type H BPV Profile GENERAL WELL INFO ;$ ',t,$ API:50-029-22561-01-00 „ Sidetrack Prep by Nabors 4ES-3/29/2004 11 9 1± Sidetrack and ESP Completion by Doyon 14-5/10/2004 `2] id' 149jts-4"Excluder Screened Liner&Blanks ' 4,10 NOTE: 5,320'to 11,006' s iffi 12 Slips w/175k Down V7l .. ., "N3'Feral 72'Rat Hole 13 kl 14t _ 15 7-5/8" -J' "U4"Lateral /11'Rat Hole 89jts-4-1/2"Slotted Liner TD=9,878'(MD)/TD=4,415'(TVD) 6,149'to 9,833' Revised By:TDF 9/3/2015 I Milne Point 2015 ASR Rig 1 •�P ��.•�A Knight Oil Tools BOP lia 11" BOPE Stripping Head r `1 3.98' Shaffe ° 11" - 5000 iii III iliilliII Ill III Ill III III 1�= CI _U _f1 4.54 I _—rr —= 2 7/8-5 variables Awl 5000 11"- =—`� Blind 11l fel ff�lffl 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves r imirogrierist 2.00 • •��j�� ,�^ • ''� III III I I I Manual Manual Manual HCR Updated 8/19/15 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 Lt - D 51+ Well History File Identifier o Two-sided 1111111111111111111 Organizing (done) o Rescan Needed 111111111111111I111 R'7CAN \Ø" Color Items: o Greyscale Items: DIGITAL DATA \Ø"biskettes, No. ~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date {g I~I 0 b o Other:: BY: ~ Is/ ~p Project Proofing BY: ~ 111111111111111111I Date b ~Ob /00 Date: 0 to V'Y)f + 3 = TOTAL PAGES {¡; 3 (Count does not include cover sheet) \A^P Isl V r I Isl Scanning Preparation BY: 11111111111I1111111 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: ~ Date: fol'3/0" NO 151 Mf NO Stage 1 BY: If NO in stage 1, page(s) discrepancies were found: YES Maria Date: 151 11111111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 11111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 a 2.07 V December 30, 2011 F E- aOn a j �-- OSLf 2 4 Mr. Tom Maunder r Alaska Oil and Gas Conservation Commission 333 West 7 Avenue .: Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -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, Gerald Murphy, at 659 -5102. Sincerely, • Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE -06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE -09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 ----) MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 02 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 FW: Epsom Salt Tracer on MPE-~LS to MPE-20A---WORKED PERFF~Y--Bad Ne... Page 1 of 3 Maunder, Thomas E (DOA) From: Longden, Kaity [Kaity.Longden@BP.com] Sent: Wednesday, March 31, 2010 10:38 AM To: Maunder, Thomas E (DOA); Roby, David S (DOA) Subject: FW: Epsom Salt Tracer on MPE-13BLS to PE-20A- WORKED PERFETLY--Bad News is 85-90% of the tracer was Immediately recovered. aoa-o~ a®y-os~ Good Morning Tom and Dave, We have completed the first Epsom Salt tracer test from MPE-136LS to MPE-20 ith great success. Below are the analyzed results, done by Bradley Brice, for your records. We plan re ing this surveillance sometime next month as well as another pair of wells coming sometime this summer (MPI-10 to MPI-06). Please let me know if you need anything else. .- --- - - ,-•-- Thanks, Kaity Longden Pad Engineer ~~ ,,,~~~~iy~ ~p~ ~ r ~(~~ Milne Point Viscous Oil Team BP Alaska ACT The Epsom Salt tracer on MPE-13BLS to MPE-20A was performed on 3/24/2010. Epsom Salt and Red Dye were added to 35 bbls of injection water to use as a tracer for evaluation of the water breakthrough. By using a material balance using both the Magnesium and Sulfate (which is the composition of Epsom Salt) there is a check on the tracer. Between 85% and 90% of the injected 35 bbls of water tracer into MPE-13BLS showed up at the Producer MPE- 20A in 3 1/2 hours after the injection. The following graphs shows the agreement of the two tracers. It is possible that the double peak of the tracer indicates that there is more than one direct route connecting the Injector (MPE-13BLS) and Producer (MPE-20A). 3/31/2010 FW: Epsom Salt Tracer on MPE-~LS to MPE-20A---WORKED PERFF~Y--Bad Ne... Page 2 of 3 -•- Magnesium MPE-20B Tracer Arrival ~-.Sulfate Tracer Injected into MPE-13BLS~ 250 c 200 ~ 150 c 0 v 100 .~ ~ 50 0 324110 19:00 600 500 dOD 0 300 ~o 200 ~ 100 v d 0 cn -100 -2110 325110 0:00 Following is a graph showing when the Tracer was Injected into MPE-13BLS and how it arrived at Producer MPE- 20A. Note that the scale on the right normalized the Recovery of tracer to 100% of the Injected Tracer Volume: +Tracer InjeQion a~ MPE-13BLS MPE-'13BLS to MPE~OB • Tracer (Magnesium) Recorrery MPE,20B Epson SaltTracer3124l2010 aTracer (Sulfate) Recorrery(~a MPE,20B L 0 35.0 31.5 2s.a 24.5 21.0 17.5 14.0 10.5 7.0 3.5 0.0 1 A ~, 09 0 OS ~ 0.7 oe 0 ~6 y d ~ V Q~ ~ 0~3 ~ 02 = 0.1 a_ OA ~ a ~~ ~~ L V O V H w 0 2r m p~~ p~ p pQ~ p~ p ~~ Q~ 4 p~ O 6 4 4 O 4 4 4 4 4 ~• Vii` ~, ~, W' ~, ~, ~• ht, ~, ~ ~ ri ~4 ~4 ~4 ~4 ~4 ~4 O 4 4 >~ ~ M M The Fleld did a really GREAT job in getting a uniform mixture of the tracer, and the sampling. And the NSK Lab did a GREAT job in their analysis. 3/31/2010 324110 32dI10 32dI10 32d/10 20:00 21 ~0 22:00 23:00 Page 1 of • • Maunder, Thomas E (DOA) From: Longden, Kaity [Kaity.Longden@BP.com] Sent: Friday, March 19, 2010 4:45 PM To: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Tom- This well is comingled downhole so we have no true way of monitoring one or the other. We will be taking the samples at surface. Technically, we will be injecting the tracer into the LS of MPE-136 which is completed in the OA sand so we expect that the magnesium we see will be coming from the mother bore (MPE-20A) which is the lateral in the OA sand. Hope this helps. Kaity Longden ~u''~:'~~:t~ ~~~ ~~ ~~ Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 19, 2010 4:28 PM To: Longden, Kaity Cc: Roby, David S (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Thanks Kaity. One question ... will you be monitoring the mother bore (MPE-20A) as well as the lateral (MPE- 20AL1)for increased Mg++? Tom Maunder, PE ~Q ~° ~~ Q.~-~. ~~ti-rJS AOGCC From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Friday, March 19, 2010 2:53 PM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA) 3-Q~ °py Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Thanks Tom for the response. We are planning to first try this tracer test on MPE-136LS to MPE-20 late next week. We will then re-do the test on those wells following an MBE treatment in April. The next set of wells for the Epsom Salt tracer test will be MPI-10 to MPI-06 sometime early summer this year. I would be happy to send you updates on our findings as we ge~the information Kaity Longden _ ~~ c~ `~~ _ ~~~ Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 19, 2010 9:00 AM To: Longden, Kaity Cc: Roby, David S (DOA) 3/22/2010 Page 2 of ~ ~ Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Kaity, Dave's interpretation is correct. By adding the Epson salt to the produced water you are creating the tracer fluid. Tracer fluids are clearly allowed by the injection order. Good luck with the trial. As the fluid movement information is quantified, we would appreciate a communication indicating the findings. Also, can you identify the possible candidate injection wells? Call or message with any questions. I will place a copy of this message in the Order file. Tom Maunder, PE AOGCC From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Wednesday, March 17, 2010 4:31 PM To: Roby, David S (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Sounds good Dave. Thanks for taking the time to make sure we have our bases covered. Kaity Longden Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT 5(4-5554 From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, March 17, 2010 4:22 PM To: Longden, Kaity Cc: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders I would say your interpretation of the rule is correct but I would like for Tom Maunder, our UIC program manager, to weigh in on this to make sure I'm not missing something. Dave Roby (907)793-1232 From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Wednesday, March 17, 2010 3:33 PM To: Roby, David S (DOA) Subject: Question on Milne Point Schrader Bluff Injection Orders Good Afternoon Dave, I was talking with Mike Bill here at BP yesterday about a tracer study we are looking to do here in the near future. We are looking to quantify the amount of injection water being cycled between injector and producer pre and post MBE treatment in order to judge success. In order to do this we will be increasing the Magnesium concentration in our normal produced water (by adding Epsom Salt) and injecting it in an injector while monitoring the concentration of Magnesium on the producer side. This will allow us to see what percentage of injected water is cycling directly through. We expect the tracer to come through in less than 6 hours. I believe this kind of study is authorized under the Area Injection Order No 10B, Part B: Schrader Bluff Oil Pool Authorized Fluids, section C) tracer survey fluid to monitor reservoir performance. Mike suggested that I confer with you prior to the job to make sure we do not need any additional notifications. Thank you in advance for your help on this. If you need addition information please write back or call my office 3/22/2010 ~ • -~ MICROFILMED 03!01/2008 DO NOT PLACE r' s: `~~;` ~. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc r D J~ .;L~\p DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040540 Well Name/No. MILNE PT UNIT SB E-20A Operator BP EXPLORATION (ALASKA) INC ;,4 2) A.rz. ~ i API No. 50-029-22561-01-00 MD 9878,/ TVD 4415 /' Completion Date 5/10/2004 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, ABI, IFR, CASANDRA, PWD Well Log Information: Directional surve~ (data taken from Logs Portion of Master Well Data Maint Electr Digital Dataset Med/Frmt Number D Asc Log/ Data Type Iffi)' I Rf)t IIZ6" D Asc ~ 4 D Lis (co Log Log Scale Media Run No Interval Start Stop Name Directional Survey Directional Survey Directional Survey Directional Survey Induction/Resistivity 0 0 0 0 2395 9825 0 0 12516 Induction/Resistivity 13540 Induction/Resistivity 2457 9878 Well Cores/Samples Information: OH/ CH Received Comments 6/9/2004 MWD Survey 6/9/2004 MWD 6/9/2004 IIFR Survey 6/9/2004 IIFR 6/28/2004 MWD EWR4 ABI ROP PWD 6/28/2004 Verification Listing for 12516 Open 2/22/2006 ROP DGR EWR plus Graphics . J Name Interval Start Stop Received Sample Set Number Comments . Sent ADDITIONAL INFORMATION Well Cored? .çç:;> Daily History Received? Ò)N (SìN Chips Received? -¥-.L.bI- Formation Tops Analysis Received? ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040540 Well Name/No. MILNE PT UNIT SB E-20A Operator BP EXPLORATION (ALASKA) INC MD 9878 TVD 4415 ompletion Date 5/10/2004 Completion Status 1-01L API No. 50-029-22561-01-00 Compliance Reviewed By: Date: Current Status 1-01L UIC N ! J~:uO Co . . . . L WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 /(547) RE: MWD Formation Evaluation Logs MPE-20A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPE-20A: LAS Data & Digital Log Images: 50-029-22561-01 Ä 04----- 054- 1 CD Rom ~ 2'/~9IDt/ . STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~/ Revision: 07/21/04, Start Production 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5-10-2004 204-054 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4-23-2004 50- 029-22561-01-00 4a. Location of Well (Governmental Section): 7. Date T.O. Reached 14. Well Name and Number: Surface: 4-30-2004 MPE-20A 3637' NSL, 1955' WEL, SEC. 25, T13N, R10E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4955' NSL, 4659' WEL, SEC. 25, T13N, R10E, (OA) KBE = 58.55' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 488' NSL, 2977' WEL, SEC. 23, T13N, R10E, (OA) 9878' + 4415' Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 569191 y- 6016175 Zone- ASP4 9878' + 4415' Ft ADL 047437 TPI: x- 566474 y- 6017467 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 562870 y- 6018249 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, ABI , IFR , CASANDRA , PWD 22. CASING, LINER AND CEMENTING RECORD OÄ$ING G~)e SETTING DIOP1"fiMD ::!E1T1t:lGI.JEPTH TVO i~~~ AMOUNT SIZE WT. PER Fr. TOP 6o'tTOM TOP 160TTOM CEMENTINGRECORI) PULLED 20" 91.1# H-40 32' 112' 32' 112' 24" 250 sx Arcticset I (Approx.) 13-3/8" 54.5# K-55 31' 2457' 31' 2434' 16" 784 sX PF 'E', 250 sX 'G', 150 sX PF 'E' 7-5/8" 29.7# L-80 33' 5989' 33' 4414' 9-7/8" 520 sx Class 'G' 4-112" 12.6# L~80 5453' 9877' 4327' 4415' 6-1/8" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of To,!? and 124. TUSINGRËCORD // Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 12.6#, L-80 5106' N/A MD TVD MD TVD 25. ·.ð.,..,n··"", - ·.¡ir¡·...¡.·¡.i r 6149' - 9833' 4433' - 4415' . -'''''''''. "',":'~;,":?' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls Crude and 2 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 8, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 6-29-2004 12 TEST PERIOD ... 1000 212 166 212 Flow Tubing Casing Pressure CALCULATED ... OIL -BBL GAs-MCF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 2001 424 332 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 ~S8ft JUt 22 ?nn" ORIGINAL Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE )~ G 28. GEOLOGIC MARKERS 29. t-ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC TUMA TUMB SBF2-NA SBF1-NB SBE4-NC SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBD-OA (2) TSBD-OA (3) TSBC TSBC (2) 4060' 4642' 4683' 5319' 5407' 5528' 5599' 5626' 5891' 6155' 7485' 7540' 9440' 9466' 3762' 4050' 4066' 4294' 4316' 4345' 4362' 4368' 4409' 4434' 4421' 4423' 4457' 4456' None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date 07'1- 1-0 MPE-20A Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Walter Quay, 564-4178 204-054 Permit No. / A roval No. 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only A STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , i', " 1a. Well Status: a Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well ClasS:'·' :. /.UU'+ 20MC 25.105 20MC25.110 a Development ," 0 E)(ploratprY OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic 0 Service' < 2. Operator Name: 5. Date Comp., Susp., or ~band. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5-10-2004 204-054 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4-23-2004 50-029-22561-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: . 4-30-2004 MPE-20A 3637' NSL, 1955' WEL, SEC. 25, T13N, R10E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4955' NSL, 4659' WEL, SEC. 25, T13N, R10E, (OA) KBE = 58.55' Milne Point Unit / Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 488' NSL, 2977' WEL, SEC. 23, T13N, R10E, (OA) 9878' + 4415' Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) ,,/ 16. Property Designation: 569191 ./ 6016175" Zone- ASP4 " 9878' + 4415' Ft ADL 047437 Surface: x- Y- -- 11. Depth where SSSV set 17. Land Use Permit TPI: x- 566474 Y- 6017467 Zone- ASP4 Total Depth: x- 562870 y- 6018249 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey aYes ONo N/A MSL 1800' (Approx.) 21. Logs Run: '17i-J,...:..dp "Ù 2.'¡S7'~Þ ,,6P MWD , GR , RES, ABI , IFR , CASANDRA , PWD 2V3¢ '?'V'þ 7,t, 22. CASING, liNER AND CEMENTING RECORD ç~~~~G EPTH.".Q ,."SErrINGDEPTH'I'IIq ~~g . pQC[ÊD ,WT.PI;R FT., GRADE - Top ,BO'r'rOM Top 'BOTTOM ',i 20" 91.1# H-40 32' 112' 32' 112' 24" 250 sx Arcticset I (Approx.) 13-3/8" 54.5# K-55 31' 2457' 31' 2434' 16" 784 sx PF 'E', 250 sx 'G'. 150 sx PF 'E' 7-5/8" 29.7# L-80 33' 5989' 33' 4414' 9-7/8" 520 sx Class 'G' 4-1/2" 12.6# L-80 5453' 9877' 4327' 4415' 6-1/8" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24" T JSING '" ii Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 12.6#, L-80 5106' N/A MD TVD MD TVD 6149' - 9833' 4433' - 4415' 25,.,. ACID, .......t:I\II~l'\It, :, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls Crude and 2 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF W A TER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach ~ arate sheet, if necessary). Submit core chips; if none, state "none". i, (~û¡:i:PŒnoH None - DATE >!i. 1 2 100~ n ! ! ¡ fl , $'/0,0. ~SfL JUt \ i ~ . . . ,\,']EO w..~TVhll ".>.-ôv<.. i h-<_ Øf Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE . ',,,,," L,' 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC TUMA TUMB SBF2-NA SBF1-NB SBE4-NC SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBD-OA (2) TSBD-OA (3) TSBC TSBC (2) 4060' 4642' 4683' 5319' 5407' 5528' 5599' 5626' 5891' 6155' 7485' 7540' 9440' 9466' 3762' 4050' 4066' 4294' 4316' 4345' 4362' 4368' 4409' 4434' 4421' 4423' 4457' 4456' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak-Off Test Summary. 31. I hereby certify that the fore ing is true and cç>rrect to the best of my knowledge. Signed Title Technical Assistant DateOGD· MPE-20A Well Number Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Walter Quay, 564-4178 204-054 Permit No. I A roval No. 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Tree: 2 9/16 " - 5M CIW .. Wellhead: FMC 11" x 27/8" Tb., Hanger, 2 7/8" EU 8rd T & B 2.5" CIW - Type H BPV profile Conductor Casing ŒÐ Window in 133/8" 2457 - 2481' 13 3/8" EZSV set @ 2489' 133/8" 54.5 ppf K-55 BTRC 1 2587' 1 KOP @ 900' Hole angle passes 50 degrees @ 4100' Max angle in tubing = 68 0 Angle at lower GLM = 680 27/8" 6.5# L-80 EUE 8rd (Drift ID= 2.347" ID, Cap = .0058 bpf) 75/8" 29.7# L-80 IBT-M casing (drift ID = 6.75", cap = .379 BPF wI tbg) Window in 7 5/8" Csg @ 5274' - 5286' Well Angle @ window = 740 Baker Tie Back Sleeve 5453' Baker ZXP Liner Top Packer 5464' Baker 75/8" x 5 1/2" HMC Liner Hanger 5470' 7 5/8" HES Float Collar 5902' (PBTD) 75/8" HES Float Shoe Btm. 5989' MPE 20A/L·' <&KB-GLelev.=57.80'(Doyon14) - WRT-GL. elev.= 33.12' (Doyon 14) SWS 2 7/8" X 1" KBMM GLM 1118' SWS 2 7/8" X 1" KBMM GLM 14937' I HES 2.313 XN Nipple 14994' I (2.250 No-go 10) Centrilift Discharge Head GPDIS 15045' I Centrilift Pump Section I GPMTAR 1:1 122 Stage GC2200 5046' Centrilift Tandem Gas Separator I GRSFXTBARH6 5066' Centrilift Tandem Seal Section I GSB3 DB UT/L T IL H6 PFS AFLAS/HSN 5071' Centrilift Motor 114 HP / KMHG 15085' 2330 Volt / 30 Amps Pump Mate Sensor (TVD 4226') 15101' Baker Hook Wall Hanger above 7 5/8" Window 5269' Baker Hook Wall Hanger outside 7 5/8" Window 5292' 61/8" Hole td @ 11078' (4247' tvd) NB Lateral 149 jts. - 4' Excluder Screened Liner & Blanks 72' 9.5 & 12.6# L-80 IBT (5320'-11006') Rat hole DATE REV. BY COMMENTS 9/02/95 JBF ESP / Frac Pack Completion - 4ES 3/29/04 MOO Sidetrack Prep - 4ES 5/10/04 Lee Hulme Sidetrack and ESP Completion - Doyon 14 I Btm. 41/2" Guide Shoe 11049' Easy Well Solutions Swell Pkr 5299 - 5314' 61/8" Hole td @ 9878' (4414' tvd) OA Lateral 89 jts - 4 1/2" Slotted Liner 12.6# L-80 IBT (6149' - 9833') l' Rat hole 8tm. Baker 4 1/2" Guide Shoe 9877' MILNE POINT UNIT WELL MPE-20A API NO: 50-029-22561-01 API NO: 50-029-22561-60 L 1 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 5/10/2004 Rig Number: 14 Spud Date: 5/21/1995 End: 4/21/2004 00:00 - 03:00 3.00 RIGU P PRE Skid rig floor in - Move rig MPE-25 to MPE-20 - Skid rig floor out to drilling position - Rig up 03:00 - 05:00 2.00 RIGU P PRE Accept rig 0300 hrs 4/21/04 - Check for pressure, none - Nipple down CIW 2 9/16 5k tree and FMC 11" x 2 9/16 tubing head adapter - Remove tubing hanger - Nipple down FMC 11" x 13 5/8 tubing head 05:00 - 09:30 4.50 BOPSU PRE Nipple up 13 5/8 Bop stack 09:30 - 14:30 5.00 BOPSU PRE Set lower test plug, Rig up lines, Test Bop: Test all lines valves and rams to 250 low 13500 psi high, Test hydrill 250/2500 spi, Test Floor valves and Top drive IBop to 250 13500 psi- ok 14:30 - 15:00 0.50 BOPSU PRE Pull test plug, Install wear bushing 15:00 - 15:30 0.50 BOPSU PRE Close blind rams, Attempt to test 13 3/8 54.5# K -55 casing to 2500 psi, started pumping in at 1800 psi, would not test 15:30 - 16:00 0.50 BOPSU PRE RIH to 100' Displace out diesel with seawater 16:00 - 18:30 2.50 BOPSU PRE Pick up 5" Hwt drill pipe and 4" HT-38 drill pipe and stand back in derrick while waiting on 13 3/8 RTTS tool 18:30 - 20:00 1.50 BOPSU HMAN PRE Pick up 6 - 6 1/4 drill collar and one stand of 5" Hwt drill pipe, Make up Halliburton 13 3/8 RTTS and by pass - 30,000 pounds below RTTS 20:00 - 23:00 HMAN PRE RIH with Rtts test casing on way down, Test casing on back side of Rtts to 1000 psi at 195, 962, 1922' & 2169' all good, Test below Rtts at 2169' pressure up to 1800 psi, will not hold pressure, bled off to zreo with in two minutes - Pooh 23:00 - 00:00 1.00 BOPSU HMAN PRE Make up 13 3/8 RTTS and By-Pass with drill collars on top of tool, RIH 4/22/2004 00:00 - 01 :30 1.50 BOPSU HMAN PRE RIH with Rtts, Tag EZSV at 2507' dpm, Pick up and set Rtts at 2,495' - Test back side 2,495' to surface to 1500 psi, good - attempt to test below Rtts by pumping down drill string, pressure up to 1200 psi, will not hold pressure, bled to zero in one minute. 01 :30 - 03:30 2.00 BOPSU HMAN PRE Pooh, stand back drill collars- Lay down 133/8 Rtts and by-pass 03:30 - 05:30 2.00 HMAN PRE Make dummy run through well head with running tool - Make up Halliburton 133/8 Fast drill (composite) bridge plug - TIH slowly 05:30 - 06:00 0.50 HMAN PRE Set Halliburton 13 3/8 fast drill bridge plug at 2,490' dpm, shear off with 50k up 06:00 - 07:00 1.00 HMAN PRE Test casing to 1500 psi for 30 minutes on chart - ok 07:00 - 08:00 HMAN PRE Pooh. Lay down running tool 08:00 - 12:00 INT1 Make up Baker 13318 Window master whipstock and milling assembly with 12 1/4" od upper mill, Pick up Sperry 6 3/4" MWD/GR/Res - Orient and program MWD 12:00 - 14:00 2.00 STWHIP P INT1 TIH with whipstock assembly slowly to 2,463' 14:00 - 15:00 1.00 STWHIP P INT1 Displace to 9.0 ppg LSND milling fluid, Orient whipstock with MWD to 76 deg left of high side, tag Bridge plug at 2,488' dpm - Set anchor with 20k, verify with 10k pick up, shear off whipstock with 45K down wt. 15:00 - 00:00 9.00 STWHIP P INT1 Mill window in 133/8 54.5# K-55 casing, top of window 2,457' - Pumping 600 gpm at 1050 psi, rotating at 95 rpm's with 4- 9,000 ftIlb torque - Maintain mud wt. 9.0 ppg with 50+ yield point for hole cleaning - good metal recovery over shakers - starter mill at 2,491' at 2400 hrs 4/23/2004 00:00 - 02:00 2.00 STWHIP P INT1 Finish milling 24' window in 13 3/8 casing - window 2,457 to ~ Printed: 5/17/2004 9:30:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 5/10/2004 Rig Number: 14 Spud Date: 5/21/1995 End: 4/23/2004 00:00 - 02:00 2.00 STWHIP P INT1 2,481' - Starter mill ended at 2,506' 02:00 - 03:00 1.00 STWHIP P INT1 Pump high vis sweep and circulate hole clean pumping 600 gpm, 1020 psi 03:00 - 03:30 0.50 STWHIP P INT1 FIT: Test Formation to 400 psi at 2,445'TVD with 9.0 ppg mud in hole, 12.1 ppg EMW. -ok - Middle of window 2,469' md, 2,445 TVD 03:30 - 08:00 4.50 STWHIP P INT1 Pooh, Lay down 6 1/4" steel drill collar and Milling assembly- upper mill 12 1/4" od, Clear rig floor 08:00 - 08:30 0.50 STWHIP P INT1 Flush bop stack with Wash tool, Function rams, flush stack 08:30 - 10:30 2.00 STWHIP P INT1 Pick up Drilling BHA with Re-Run 9 7/8" Smith S73 PDC bit, Sperry 7" motor set at 1.22 deg, MWD/GR/RES - Orient and program MWD 10:30 - 11 :30 1.00 STWHIP P INT1 TIH to 2,400' - window at 2,457' 11 :30 - 12:00 0.50 STWHIP P INT1 Orient to 75 deg left, slide through window with no problem, Tag bottom at 2,506' 12:00 - 00:00 12.00 DRILL P INT1 Directional drill as per directional plan 2,506 to 3,880' - Art 3.06 hrs, Ast 4.29 hrs, Average Rop 187 ftIhr - Pumping 500 to 550 gpm, Rotating at 120 rpm's with 5 - 8,000 ftllb torque - Back ream each stand slowly 4/24/2004 00:00 - 08:30 8.50 DRILL P INT1 Continue Directional drill 3,880 to 4,649' - Building angle and turn well bore to right - pumping 550 gpm at 2200 psi, rotating at 120 rpm's with 4 -6,000 ftIlb torque - Maintain mud wt. 9.0 to 9.1 ppg - finish building angle to 66 deg at 4490' - Art 1.28 hrs, Ast 3.55 hrs, Average Rop 159 ftIhr 08:30 - 10:00 1.50 DRILL P INT1 Circulate two bottom up pumping 588 gpm at 2350 psi, rotating 120 rpm's 10:00 - 11 :30 1.50 DRILL P INT1 Pump out of hole at 500 gpm to window at 2,457' 11 :30 - 12:30 1.00 DRILL P INT1 Service rig and top drive 12:30 - 13:30 1.00 DRILL P INT1 TIH to 4,555' no problem, Precautionary wash 4,555 to bottom at 4,649' 13:30 - 15:00 1.50 DRILL P INT1 Drill 4,649 to 4,679' - Gumbo plugging flow line and shaker, circulate and clean out gumbo 15:00 - 00:00 9.00 DRILL P INT1 Directional drill 4,679 to 5,495 - Art 3.34, Ast 2.62, Average rop 142 ftIhr - Build angle to 76 deg, add 2% Lubricant to aid sliding - Maintain mud wt. at 9.3 ppg - Pumping 544 gpm at 2500 psi, rotating at 120 rpm's 5 -8,000 ftIlbs torque 4/25/2004 00:00 - 12:00 12.00 DRILL P INT1 Continue directional drilling 5,495 to 7 5/8 casing point at 5,993' - start building angle for landing in 'OA' sand at 5,700' - Art 4.58 hrs, Ast 2.56 hrs, Average Rop 69 ftIhr - while drilling below 5800', BHA building angle as rotating ahead at 3 deg /100' 12:00 - 15:00 3.00 CASE P INT1 Circulate and condition mud, Consult with Geologist about possible sidetrack, Circulate three bottoms up pumping 560 gpm at 2600 psi, Rotate at 120 rpm's 15:00 - 16:30 1.50 CASE P INT1 Pump out of hole 5,993 to 4,555' for wiper trip 16:30 - 17:00 0.50 CASE P INT1 TIH - No problem - precautionary wash 5,899 to 5,993' 17:00 - 19:00 2.00 CASE P INT1 Pump high vis sweep, circulate three bottoms up at 600 gpm 2900 psi, rotate at 120 rpm's 19:00 - 22:00 3.00 CASE P INn Pump out of hole 5,993 to 2,541' - Pull into casing - Monitor well - ok 22:00 - 23:00 1.00 CASE P INT1 Circulate casing clean pumping 600 gpm 1950 psi 23:00 - 00:00 1.00 CASE P INT1 Pump slug, Pooh, Lay down BHA 4/26/2004 00:00 - 01 :30 1.50 DRILL P INT1 Finish laying down Bha, Bit in bad shape, Nose worn down to 8", Most of gauge down to 8" - 2" of upper gauge 9.5" od Printed: 5/17/2004 9:30:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 5/10/2004 Rig Number: 14 Spud Date: 5/21/1995 End: 4/26/2004 01 :30 - 03:00 1.50 CASE P INT1 Pull wear bushing, set test plug, change top rams to 7 5/8 - test door to 1500 psi 03:00 - 04:00 1.00 CASE P INT1 Rig up 350 ton casing tools, & Franks fill tool 04:00 - 04:30 0.50 CASE P INT1 Safety meeting with Doyon casing operator and drill crew 04:30 - 09:30 5.00 CASE P INT1 Run 145 jts 7 5/8 29.7# L-80 Btc-mod 5996.85' Intermediate casing set at 5988.72' - Make up Torque 9,000 ftllbs - Circulate bottoms up at window before going into open hole, 6 bpm 300 psi - No problem in open hole 09:30 - 10:00 0.50 CASE P INT1 Rig down franks fill up tool, Blow down top drive, Make up Dowell cement head. 10:00 - 12:30 2.50 CEMT P INT1 Circulate and condition hole for cement, stage up 2 bpm to 6 bpm at 360 psi - Reciprocate casing 20' stroke - p/u 190k. 510 135k - Circulate two casing volume 12:30 - 14:30 2.00 CEMT P INT1 Cement with Dowell as follows: pump 5 bbls of CW100, Test lines 3500 psi, Pump 20 bbls CW1 00 + 40 bbls of Mud push II mixed at 10.1 ppg, Drop bottom plug, Cement with 520 sx Class 'G' w/ .3% D-65 + .35% D167 + .05% B155 - Yield 1.16 cf/sx 106 bbls of slurry down hole mixed at 15.8 ppg on fly- Drop top plug and displace with 9.1 ppg oil base mud with dowell unit at 6 bpm at 300 to 700 psi - Bump plug to 1500 psi- check floats -ok- CIP at 1420 hrs 4/26/04 14:30 - 15:30 1.00 CEMT P INT1 Flush wellhead with water thru lower annulus valve, Rig down Cement head 15:30 - 16:30 1.00 CEMT P INT1 Break wellhead between casing head and drillling spool - Pick up Bop stack 16:30 - 17:30 1.00 CEMT P INT1 Set 12 x 7 5/8 slip with 175k net on slips 17:30 - 19:00 1.50 CEMT P INT1 Make up casing blow down tool, void 60' of oil base mud from 7 5/8 casing - Rig up Cameron cold cut casing cutter, cut & bevel 7 5/8 casing at 9" above slips 19:00 - 20:30 1.50 WHSUR P INT1 Remove 30.82' cut off jt. - Remove drilling spool and set back bop stack - Install 12 x 7 5/8 pack -off 20:30 - 22:30 2.00 WHSUR P INT1 Nipple up FMC 13 5/8 x 11" Gen 4 tubing head - Test pack-off to 3350 psi, 70% of collapse of 7 5/8 - 22:30 - 00:00 1.50 BOPSU P INT1 Nipple up 11 x 135/8 adapter spool, Nipple up Bop stack, Change out choke line spool 4/27/2004 00:00 - 01 :30 1.50 BOPSU P INT1 Finish nipple up Bop - Clean mud pits 01 :30 - 02:30 1.00 BOPSU P INT1 Change top rams to 3 1/2 x 6" variable bore rams 02:30 - 03:00 0.50 BOPSU P INT1 set upper test plug, Rig up lines 03:00 - 07:30 4.50 BOPSU P INT1 Test Bop: Test all rams, lines and valve to 250 low/3500 high- Test hydrill 250/2500 psi - Test Top drive IBOP and floor valves to 250 I 3500 psi 5min. per test, the right to witness test was wavier by John Crisp 07:30 - 08:00 0.50 BOPSU P INT1 Install wear ring 08:00 - 10:00 2.00 CASE P INT1 Picking up BHA 3 #. Bit PDC FM2643 with 3 X 12 jets, 43/4 Sperry drill 1.5 bend, Stab,float sub,4 3/4 Slim phase 4 with DGR & EWR,DM sub,PWD,Pulser,3 flex DC,Jars 10:00 - 10:30 0.50 CASE P INT1 Flush pumps with oil base mud. test MWD 10:30 - 16:30 6.00 CASE P INT1 Picking up 4 Drill pipe from shed 16:30 - 18:00 1.50 CASE P INT1 Slip and cut drill line, service top drive 18:00 - 19:00 1.00 CASE P INT1 Circ bottoms up with 246 gpm 2420 psi 19:00 - 20:00 1.00 CASE P INT1 Pressure test Csg to 3500 psi for 30 min., good test 20:00 - 21 :30 1.50 DRILL P INT1 Drill float, and shoe track and 20 ft of new hole to 6013', tag float @ 5906 Shoe 5991. Printed: 5/17/2004 9:30:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 5/10/2004 Rig Number: 14 Spud Date: 5/21/1995 End: 4/27/2004 21 :30 - 22:00 0.50 CASE P INT1 Circ bottoms up 22:00 - 23:00 1.00 DRILL P PROD1 FIT test with 9.1 mud wt. 800 psi, 4413 TVD= 12.5 EMW, Establish base line ECD of 9.8 23:00 - 00:00 1.00 DRILL P PROD1 Directional Drill 6013' to 6066' with 80 rpms, 256 gals per min, 2870 psi, Torque 4,000, ECD 10.0, ART .12, AST .34 4/28/2004 00:00 - 21 :30 21.50 DRILL P PROD1 Directional Drill 6066' to 7666' with 80 rpms, 270 gals per min, 3060 psi, Torque 4,000, ECD 10.2 Top of OA sand 6155 MD TVD 4433 21 :30 - 23:00 1.50 DRILL N SFAL PROD1 Circ, stand back one stand, repair Hydraulic line on top drive 23:00 - 00:00 1.00 DRILL P PROD1 Directional Drill 7666' to 7700' with 80 rpms, 270 gals per min, 3120 psi, Torque 4,000, ECD 10.2, AST 6.04 ART 5.34, ECD 10.3 4/29/2004 00:00 - 00:00 24.00 DRILL P PROD1 Directional Drill 7700' to 9764' with 100 rpms, 270 gals per min, 3350 psi, Torque 8,000, ECD 10.7, AST 4.98, ART 7.55 4/30/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Directional Drill 9764' to 9878' TD with 100 rpms, 270 gals per min, 3350 psi, Torque 8,000, ECD 10.7, build from 88 degree to 98 degrees in last 500 ft. 01 :00 - 03:00 2.00 CASE P PROD1 Circ, three bottoms up with 280 gals min., 3500 psi, 100 rpms, pump sweep, ECD 10.8 dropped to 10.7 03:00 - 04:30 1.50 CASE P PROD1 Pumping out with full drilling rate to 8600 ft. 04:30 - 05:00 0.50 CASE P PROD1 Tripping back to bottom 9878' 05:00 - 06:30 1.50 CASE P PROD1 Circ, two bottoms up, with 280 gals min. 3500 psi, 100 rpms 06:30 - 10:30 4.00 CASE P PROD1 Pump out to window @ 5993 with full drill rate 10:30 - 12:00 1.50 CASE P PROD1 Circ 2.5 bottoms up from 5993 12:00 - 14:30 2.50 CASE P PROD1 Trip out to BHA, pull string wet 14:30 - 16:00 1.50 CASE P PROD1 Stand back BHA, lay down MWD and motor 16:00 - 17:00 1.00 CASE P PROD1 Clean floor of oil base mud, rig up to run 4.5 liner,PJSM 17:00 - 21 :00 4.00 CASE P PROD1 Pick up total 1 06 jts 4.5 12.6# L-80 liner, 89 slotted, 17 solid, 7 5/8 Baker liner hanger, 75/8 ZXP liner top packer, setting tools 21 :00 - 00:00 3.00 CASE P PROD1 Tripping in with liner 5/1/2004 00:00 - 00:30 0.50 CASE P PROD1 Tripping in with liner, pickup wt 140K, slack off wt. 85K, tag bottom pickup 1 ft. shoe @ 9877, liner hanger 5470, packer 5463, top of tie back 5452', liner lap 525' 00:30 - 01 :00 0.50 CASE P PROD1 Circ, drill pipe volume 01 :00 - 01 :30 0.50 CASE P PROD1 Circ, Drop ball, Set hanger w/2500 psi, set packer w/3200 psi, shear ball with 4500 psi, 01 :30 - 02:00 0.50 CASE P PROD1 Test back side with 1,000 psi to test liner top packer, release from liner, flow check 02:00 - 04:30 2.50 CASE P PROD1 Tripping out w/ running tools, Lay down running tools, clean floor of oil base mud 04:30 - 09:30 5.00 STWHIP P PROD2 Picking up whipstock BHA #4, test MWD 09:30 - 12:00 2.50 STWHIP P PROD2 Tripping in with whipstock 12:00 - 13:00 1.00 STWHIP P PROD2 Orient whipstock to 23 degrees to left of high side, set anchor with 20 K shear off whi ,..- 13:00 - 18:30 5.50 STWHIP P PROD2 Mill window with 5 -90 rpms, 2-5K bit wt., 270 gals min., 196 t\ \,Ç. - ~Lt. psi top of window 5274', bottom window 5286', drill new hole to 5296' work window 18:30 - 19:30 1.00 STWHIP P PROD2 Circ and reciprocate pipe above window for bottoms up 19:30 - 21 :00 1.50 STWHIP P PROD2 Tripping out with Mills to BHA 21 :00 - 22:30 1.50 STWHIP P PROD2 Standing back HWP and 4 3/4 DC, lay down mills and Bumper jars Printed: 5/17/2004 9:30:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/1 0/2004 Rig Release: 5/10/2004 Rig Number: 14 Spud Date: 5/21/1995 End: 5/1/2004 22:30 - 23:00 0.50 STWHIP P PROD2 Clean floor of oil base mud 23:00 - 00:00 1.00 STWHIP P PROD2 pick up Johnny Wacker and flush BOP stack 5/2/2004 00:00 - 02:00 2.00 DRILL P PROD2 Picking up BHA #5,63/4 PDC Fm3643 with 3 x 12 jets,5" Sperry drill 1.5 bend,6 1/16 stab, float sub,4 3/4 Slimphase 4 w/DGRIEWR, 4 3/4 DM,4 3/4 PWD,4 3/4 pulser,3 Flex dc,jars, Surface test MWD 02:00 - 03:30 1.50 DRILL P PROD2 Tripping in to 3950' 03:30 - 05:00 1.50 DRILL N RREP PROD2 Repair chain in Draw works 05:00 - 07:00 2.00 DRILL N HMAN PROD2 Tripping back out to BHA, to pickup jars that were left out of BHA 07:00 - 08:00 1.00 DRILL N HMAN PROD2 Tripping in to 3950 08:00 - 08:30 0.50 DRILL P PROD2 Trip in from 3950 to 5200' 08:30 - 09:00 0.50 DRILL P PROD2 Orient and slide thru window @ 5274 to 5286 ß 'Ik~ 09:00 - 19:00 10.00 DRILL P PROD2 Directional Drill from 5288' to 6067' TVD 4297' with 250 gp 2500 psi, 1 00 rpms Pß1- S~<\ç - Ob'\ 19:00 - 19:30 0.50 DRILL N DPRB PROD2 Circ. bottoms up for side track 19:30 - 21 :00 1.50 DRILL N DPRB PROD2 Pump out to 5680, working trough 5680- 5695, side track well 5695, Tvd 4320 21 :00 - 00:00 3.00 DRILL N DPRB PROD2 Directional Drill from 5695' to 5875' with 250 gpm 2500 psi, 100 rpms AST 4.66, ART 2.46, Tq 3K, ECD 10.1 5/3/2004 00:00 - 00:00 24.00 DRILL P PROD2 Directional Drill from 5875' to 7900' with 250 gpm 2800 psi, 100 rpms ECD 10.3, AST 7.81, ART 5.02 TQ 6K, 5/4/2004 00:00 - 00:00 24.00 DRILL P PROD2 Directional Drill from 7900' to 9714' with 250 gpm 2800 psi, 100 rpms ECD 10.8, AST 7.32, ART 6.04, Tq 6K 5/5/2004 00:00 - 01 :00 1.00 DRILL P PROD2 Circ bottoms up 1.5 times to clean up hole with 256 gals min. 2750 psi, 100 rpms, ECD dropped from 10.8 to 10.4 01 :00 - 23:00 22.00 DRILL P PROD2 Directional Drill from 9714' to 11078' with 250 gpm 3200 psi, 100 rpms ECD 11.6 23:00 - 00:00 1.00 DRILL P PROD2 Circ. one bottoms up with 254 gals min. 3200 psi, 1 00 rpm ECD start 11.6 dropped to 11.3 5/6/2004 00:00 - 02:30 2.50 CASE P COMP Circ. 2.5 bottoms up with 275 gals min. 3500 psi,100 rpm ECD start 11.6 dropped to 11.2, total bottoms up 3.5 times 02:30 - 06:30 4.00 CASE P COMP Pumping out to 7410 with full drilling rate, packed off 06:30 - 09:00 2.50 CASE P COMP Reaming from 7410 to 6790 254 gals min 100 rpms 09:00 - 10:30 1.50 CASE P COMP Pumping out 6790 to 5334, pulled out with out pump to 5238 slight packing off 6360 to 6100 10:30 - 11 :00 0.50 CASE P COMP Circ to clear csg of cuttings 11 :00 - 12:30 1.50 CASE P COMP Slip and cut drilling line, service top drive 12:30 - 15:30 3.00 CASE P COMP Trip to bottom with no problems, washed 90 ft to bottom 15:30 - 18:00 2.50 CASE P COMP Circ two bottoms up with 280 gals min. 3580 psi, 100 rpms ECD 11.4 dropped to 11.0 18:00 - 00:00 6.00 CASE P COMP Circ at slower rate with 230 mesh screens on shakers to clean up oil mud for screen liner run, starting rate 131 gpm, 1500 psi, final rate 260 gals min,3,000 psi, (Mud still will not pass screen test) 5/7/2004 00:00 - 03:00 3.00 CASE P COMP Circ with 230 mesh screens on shakers to clean up oil mud for screen liner run, 260 gals min, 3,000 psi, Mud pass screen test @ 0100 behind shakers, circ one more round to get clean mud thru pits and coming up hole. ECD 10.9, P/U wt 135K,S/O wt Printed: 5/17/2004 9:30:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/1 0/2004 Rig Release: 5/10/2004 Rig Number: 14 Spud Date: 5/21/1995 End: 5/7/2004 00:00 - 03:00 3.00 CASE P COMP 75K 03:00 - 09:00 6.00 CASE P COMP Pumping out with full drilling rate to window, pull thru window with out pumping 09:00 - 10:00 1.00 CASE P COMP Circ bottoms up, 267 gals min. 2300 psi 10:00 - 12:00 2.00 CASE P COMP POH to BHA. 12:00 - 14:00 2.00 CASE P COMP Lay down BHA # 5 14:00 - 15:00 1.00 CASE P COMP Pickup BHA #6 whipstock reI. tool and MWD, shallow test MWD 15:00 - 16:30 1.50 CASE P COMP Trip in with whipstock pull tools to 5,265' 16:30 - 17:30 1.00 CASE P COMP Orient and circ, hooking whipstock, pulled free with 170K 17:30 - 18:30 1.00 CASE P COMP Circ bottoms up 18:30 - 20:30 2.00 CASE P COMP Trip out with whipstock 20:30 - 22:00 1.50 CASE P COMP Lay down whipstock, and space out jts 22:00 - 22:30 0.50 CASE P COMP Service rig, clear floor 22:30 - 23:00 0.50 CASE P COMP Rig up to run Iiner,PJSM 23:00 - 00:00 1.00 CASE P COMP Picking up 4 "C-27 Med. Excluder IBT Screen liner 5/8/2004 00:00 - 05:00 5.00 CASE P COMP Picking up 4 "C-27 Med. Excluder IBT Screen liner 05:00 - 07:00 2.00 CASE P COMP Cross over to drill pipe, Orient string and worKing thru window @ 5274' to 5286' went thru window on 4th try 07:00 - 10:00 3.00 CASE P COMP Picking up liner and swell packer and hook hanger, total One bend jt 4.5, 64 jts 4" screens, 62 its 4" blanks, 23 its 4.5 blanks 10:00 - 17:00 7.00 CASE P COMP Tripping in with liner on drill pipe, having lots of hang ups with centerilizers on bottom of window, got in to the first hole and went to 6079', pull out 4 sds. and turn liner 180 degrees and went in to the right hole, pick up wt 160K S/o 65K 17:00 - 18:00 1.00 CASE P COMP Hooked window with hanger, drop ball and release from liner with 3000psi, shear ball with 4500 psi P/U wt 115K, S/o 100k, Top of liner 5269', swell packer 5299, shoe 11,048 18:00 - 20:00 2.00 CASE P COMP Tripping out with running tools, lay down same 20:00 - 21 :30 1.50 CASE P COMP Tripping in with Johnny Wacker to 5240' to displace hole 21 :30 - 23:00 1.50 CASE P COMP Displace well with 40 bbls LVT, 25 bbls Hi Vis spacer, 40 bbls, safe surf, 25 bbls Hi Vis spacer, 288 bbls 9.1 Brine treat with corxit, 125 rpms 12 bbls min. 23:00 - 00:00 1.00 CASE P COMP Clean up Shakers/ Ditch take on brine returns 5/9/2004 00:30 - 08:30 8.00 CASE P COMP Laying down drill pipe and BHA from hole, lay down drill pipe in derrick in the mouse hole. (hole taking app. two bbls hr. of 9.1 brine) - 08:30 - 09:30 1.00 CASE P COMP Pulled wear ring, clear floor of oil base mud 09:30 - 10:00 0.50 CASE P COMP Service rig. 10:00 - 12:00 2.00 CASE P COMP Rig up to run tubing 12:00 - 12:30 0.50 RUNCO COMP Pjsm on picking up tubing 12:30 - 15:30 3.00 RUNCO COMP Picking up 152 hp 2325 volts motor and test same 15:30 - 17:00 1.50 RUNCO SFAL COMP Change out tubing tongs, to stack tubing tongs 17:00 - 23:00 6.00 RUNCO COMP Picking up 2 7/8 6.5# L-80 EUE 8 rd tubing, total Jts 157 its, motor @ 5105, XN nipple, 4994, GLM 4937, GLM 118', PIU wt 80K SIO 75K, blocks 50K, run with 88 clamps 23:00 - 00:00 1.00 COMP Making up hanger, circ 10 bbls of brine thru motor with 800 psi, 1 bbls min., install two way check 5/10/2004 00:00 - 02:30 2.50 COMP Rig up ESP cable to penetrator, and test same, install blass cap on penetrator, land Tubing with TWC in place. 02:30 - 03:00 0.50 RUNCO COMP Test TWC to 1000 psi 03:00 - 04:30 1.50 RUNCO COMP Nipple down BOP stack 04:30 - 06:00 1.50 RUNCO COMP Nipple up Fmc adapter 11" X 2 9/16 ESP, CIW 2 9/16 5,000# Printed: 5/17/2004 9:30:47 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: 4/1 0/2004 Rig Release: 5/10/2004 Rig Number: 14 Spud Date: 5/21/1995 End: Tree, test adapter and tree to 5,000 psi Pull TWC and install BPV, secure well.( rig release @07:30 5/10/2004 ) Printed: 5/17/2004 9:30:47 AM 2,469.0 (ft) 6,013.0 (ft) 2,445.0 (ft) 4,413.0 (ft) Printed: 5/17/2004 9:30:35 AM ~. . 24-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPE-20A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 2,416.98' MD 2,457.00' MD 9,878.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ", I A I, I Date q ~~ ~~ Signed~ ð~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ^ rs&i....;~{ 0 ~"~ Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPE MPE..20A Job No. AKZZ3034600, Surveyed: 30 April, 2004 Survey Report 20 May, 2004 Your Ref: API 500292256101 Surface Coordinates: 6016175.23 N, 569190.80 E (70027'16.3793" N, 149026' 07.3457" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1016175.23 N, 69190.80 E (Grid) Surface Coordinates relative to Structure Reference: 2378.77 N, 227.84 W (True) Kelly Bushing Elevation: 58. 55ft above Mean Sea Level Kelly Bushing Elevation: 58. 55ft above Project V Reference Kelly Bushing Elevation: 58. 55ft above Structure Reference SpE!r""'r""'Y-SUil DI?tIL..L..ING SEI?tVICES A Halliburton Company DEFINITIVE e e Survey Ref: svy1394 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A Your Ref: API 500292256101 Job No. AKZZ3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2416.98 12.940 321.400 2336.15 2394.70 77.04 N 210.12W 6016250.32 N 568979.98 E 89.29 Tie On Point AK-6 BP _IFR-AK - MWD+IIFR+M '-<... 2457.00 12.720 321.020 2375.17 2433.72 83.97 N 215.68 W 6016257.19 N 568974.34 E 0.589 88.12 Window Point 2477.13 14.400 317.040 2394.74 2453.29 87.52 N 218.78 W 6016260.72 N 568971.21 E 9.542 87.69 2572.20 17.530 302.430 2486.17 2544.72 103.86 N 238.94 W 6016276.87 N 568950.91 E 5.334 89.78 e 2669.25 19.600 291.430 2578.20 2636.75 117.65N 266.44 W 6016290.40 N 568923.28 E 4.183 98.78 2764.63 20.210 290.220 2667.88 2726.43 129.19N 296.79 W 6016301.66 N 568892.82 E 0.772 111.38 2859.63 23.080 283.630 2756.18 2814.73 139.26 N 330.30 W 6016311.41 N 568859.22 E 3.955 127.23 2954.02 25.680 278.010 2842.16 2900.71 146.47 N 368.54 W 6016318.27 N 568820.91 E 3.689 148.41 3050.73 28.890 277.270 2928.10 2986.65 152.35 N 412.48 W 6016323.74 N 568776.93 E 3.338 174.48 3147.15 31.800 278.820 3011.30 3069.85 159.19 N 460.70 W 6016330.14 N 568728.64 E 3.125 202.81 3242.64 34.840 280.790 3091.09 3149.64 168.16 N 512.37 W 6016338.62 N 568676.89 E 3.379 231.99 3337.26 34.940 280.320 3168.70 3227.25 178.07 N 565.57 W 6016348.04 N 568623.60 E 0.303 261.54 3434.31 37.410 282.570 3247.04 3305.59 189.47 N 621.70 W 6016358.92 N 568567.37 E 2.889 292.04 3530.07 37.690 281.940 3322.96 3381.51 201.85 N 678.73 W 6016370.77 N 568510.22 E 0.496 322.44 3626.12 39.810 284.900 3397.87 3456.42 215.84 N 737.18 W 6016384.21 N 568451.64 E 2.931 352.67 3721.28 40.690 286.060 3470.50 3529.05 232.25 N 796.43 W 6016400.08 N 568392.24 E 1.215 381.69 3817.14 45.190 290.640 3540.67 3599.22 252.90 N 858.33 W 6016420.15 N 568330.16 E 5.710 409.47 3913.87 47.770 292.660 3607.28 3665.83 278.80 N 923.50 W 6016445.44 N 568264.75 E 3.067 435.72 4009.65 49.090 298.020 3670.86 3729.41 309.48 N 988.20 W 6016475.52 N 568199.76 E 4.407 458.18 4106.48 51.010 298.290 3733.03 3791.58 344.50 N 1053.65 W 6016509.93 N 568134.00 E 1.994 478.01 4202.87 54.790 297.860 3791.16 3849.71 380.67 N 1121.47 W 6016545.47 N 568065.84 E 3.938 498.66 e 4298.47 59.150 299.360 3843.26 3901.81 419.06 N 1191.80 W 6016583.21 N 567995.16 E 4.746 519.42 4394.34 63.170 301.480 3889.50 3948.05 461.60 N 1264.18 W 6016625.07 N 567922.38 E 4.619 538.61 4490.35 66.1 00 302.120 3930.63 3989.18 507.31 N 1337.90 W 6016670.10 N 567848.24 E 3.111 556.41 4585.59 66.360 302.720 3969.02 4027.57 554.04 N 1411.48 W 6016716.14 N 567774.24 E 0.638 573.39 4682.94 67.240 303.060 4007.37 4065.92 602.63 N 1486.61 W 6016764.03 N 567698.65 E 0.959 590.09 4778.30 67.930 303.530 4043.73 41 02.28 651.02 N 1560.30 W 6016811.74 N 567624.52 E 0.855 605.94 4875.29 67.600 303.830 4080.43 4138.98 700.81 N 1635.01 W 6016860.83 N 567549.36 E 0.445 621.48 4971.54 67.650 303.950 4117.07 4175.62 750.44 N 1708.89 W 6016909.77 N 567475.02 E 0.126 636.57 5068.31 66.830 304.540 4154.51 4213.06 800.65 N 1782.65 W 6016959.29 N 567400.79 E 1.017 651.15 20 May, 2004·15:42 Page 2 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A Your Ref: API 500292256101 Job No. AKZZ3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northin9s Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5162.96 69.170 303.420 4189.96 4248.51 849.69 N 1855.42 W 6017007.65 N 567327.57 E 2.705 665.90 5257.76 73.730 303.120 4220.11 4278.66 898.98 N 1930.55 W 6017056.24 N 567251.99 E 4.819 682.09 5293.38 75.660 303.120 4229.51 4288.06 917.75 N 1959.32 W 6017074.74 N 567223.04 E 5.418 688.37 5355.18 75.840 302.300 4244.73 4303.28 950.12 N 2009.72 W 6017106.64 N 567172.34 E 1.319 699.74 5451.17 76.170 299.890 4267.94 4326.49 998.22 N 2089.47 W 6017154.00 N 567092.15 E 2.460 719.98 e 5548.31 76.170 299.710 4291.16 4349.71 1045.09 N 2171.32 W 6017200.11 N 567009.86 E 0.180 742.56 5644.28 76.220 298.100 4314.07 4372.62 1090.14N 2252.91 W 6017244.40 N 566927.87 E 1.630 766.28 5740.84 80.890 297.000 4333.22 4391.77 1133.89 N 2336.80 W 6017287.37 N 566843.58 E 4.964 792.53 5834.68 84.070 296.850 4345.50 4404.05 1176.01 N 2419.73 W 6017328.72 N 566760.25 E 3.392 819.30 5927.69 86.970 296.650 4352.76 4411.31 1217.74 N 2502.53 W 6017369.68 N 566677.07 E 3.125 846.25 5G~ ,., 5/C(j." Ç,tl--S' ~~ 5997.13 87.530 298.650 4356.10 4414.65 1249.93 N 2563.96 W 6017401.30 N 566615.34 E 2.988 865.37 6092.72 80.140 294.410 4366.36 4424.91 1292.36 N 2648.90 W 6017442.94 N 566530.01 E 8.899 893.29 6146.14 83.010 294.370 4374.19 4432.74 1314.18 N 2697.02 W 6017464.31 N 566481.69 E 5.373 910.72 6187.58 82.690 293.300 4379.34 4437.89 1330.80 N 2734.64 W 6017480.57 N 566443.92 E 2.676 924.66 6236.81 84.930 292.690 4384.65 4443.20 1349.92 N 2779.69 W 6017499.27 N 566398.70 E 4.714 941.92 6285.41 89.440 293.350 4387.04 4445.59 1368.89 N 2824.35 W 6017517.84 N 566353.86 E 9.378 959.02 6331.00 90.990 291.640 4386.87 4445.42 1386.33 N 2866.47 W 6017534.89 N 566311.58 E 5.062 975.47 6381.10 92.220 294.290 4385.46 4444.01 1405.87 N 2912.57 W 6017553.99 N 566265.30 E 5.829 993.16 6430.56 93.030 292.760 4383.20 4441.75 1425.59 N 2957.87 W 6017573.29 N 566219.81 E 3.497 1010.16 6477.99 94.510 293.080 4380.08 4438.63 1444.02 N 3001.46 W 6017591.32 N 566176.06 E 3.192 1026.91 6527.35 94.080 293.080 4376.38 4434.93 1463.32 N 3046.75 W 6017610.19 N 566130.60 E 0.871 1044.21 6574.34 92.040 288.550 4373.87 4432.42 1479.99 N 3090.59 W 6017626.45 N 566086.60 E 10.560 1062.41 e 6622.50 91.300 283.380 4372.47 4431.02 1493.22 N 3136.86 W 6017639.26 N 566040.21 E 10.840 1084.77 6670.44 91.540 276.260 4371.28 4429.83 1501.39 N 3184.05 W 6017646.99 N 565992.94 E 14.856 1111 .43 6715.05 90.990 272.1 00 4370.29 4428.84 1504.64 N 3228.52 W 6017649.82 N 565948.44 E 9.404 1139.78 6766.41 91.050 271.850 4369.38 4427.93 1506.41 N 3279.84 W 6017651.12 N 565897.11 E 0.501 1173.92 6810.35 90.860 272.030 4368.65 4427.20 1507.90 N 3323.75 W 6017652.20 N 565853.19 E 0.596 1203.16 6860.54 91.050 272.110 4367.81 4426.36 1509.71 N 3373.90 W 6017653.54 N 565803.02 E 0.411 1236.46 6905.33 92.280 271.470 4366.51 4425.06 1511.11 N 3418.65 W 6017654.53 N 565758.26 E 3.095 1266.34 6957.42 91.480 270.760 4364.80 4423.35 1512.12 N 3470.70 W 6017655.06 N 565706.20 E 2.053 1301.53 7007.92 93.950 271.320 4362.41 4420.96 1513.04 N 3521.13W 6017655.50 N 565655.77 E 5.015 1335.68 7053.66 94.080 270.660 4359.21 4417.76 1513.83N 3566.75 W 6017655.87 N 565610.14 E 1.467 1366.60 7104.13 89.810 271.790 4357.49 4416.04 1514.90N 3617.17 W 6017656.48 N 565559.72 E 8.751 1400.62 7149.75 88.390 272.400 4358.21 4416.76 1516.57N 3662.75 W 6017657.72 N 565514.12 E 3.388 1430.87 7199.35 88.400 272.650 4359.60 4418.15 1518.76N 3712.29 W 6017659.45 N 565464.57 E 0.504 1463.48 20 May, 2004 - 15:42 Page 3 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A Your Ref: API 500292256101 Job No. AKZZ3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7245.66 90.560 272.100 4360.02 4418.57 1520.67 N 3758.55 W 6017660.94 N 565418.29 E 4.813 1494.03 7295.96 89.690 271.460 4359.91 4418.46 1522.24 N 3808.83 W 6017662.03 N 565368.00 E 2.147 1527.60 7342.37 89.140 270.950 4360.38 4418.93 1523.21 N 3855.22 W 6017662.58 N 565321.60 E 1.616 1558.92 7393.33 88.210 270.560 4361.56 4420.11 1523.88 N 3906.16 W 6017662.77 N 565270.65 E 1.979 1593.60 7438.49 90.250 271.960 4362.17 4420.72 1524.88 N 3951.31 W 6017663.35 N 565225.50 E 5.4 78 1624.04 e 7482.08 88.830 273.570 4362.52 4421.07 1526.98 N 3994.84 W 6017665.05 N 565181.95 E 4.925 1652.57 7534.66 88.150 275.040 4363.90 4422.45 1530.93 N 4047.25 W 6017668.50 N 565129.50 E 3.079 1685.89 7584.84 85.180 279.060 4366.82 4425.37 1537.07 N 4096.95 W 6017674.19 N 565079.75 E 9.949 1715.75 7630.85 84.380 280.620 4371.01 4429.56 1544.90 N 4142.10 W 6017681.60 N 565034.53 E 3.798 1741.25 7677.84 87.040 280.560 4374.53 4433.08 1553.51 N 4188.15 W 6017689.78 N 564988.40 E 5.662 1766.81 7727.02 87.840 280.740 4376.72 4435.27 1562.59 N 4236.44 W 6017698.41 N 564940.03 E 1.667 1793.56 7774.49 87.720 281.150 4378.56 4437.11 1571.60 N 4283.01 W 6017706.98 N 564893.38 E 0.899 1819.19 7822.00 90.060 281.350 4379.48 4438.03 1580.86 N 4329.59 W 6017715.82 N 564846.71 E 4.943 1844.64 7871.81 90.620 284.010 4379.19 4437.74 1591.79 N 4378.18 W 6017726.30 N 564798.02 E 5.457 1870.27 7917.84 93.150 286.080 4377.67 4436.22 1603.73 N 4422.61 W 6017737.82 N 564753.49 E 7.100 1892.30 7963.40 92.470 285.110 4375.44 4433.99 1615.97 N 4466.44 W 6017749.65 N 564709.55 E 2.598 1913.70 8012.34 92.780 285.740 4373.20 4431.75 1628.97 N 4513.56 W 6017762.21 N 564662.30 E 1.433 1936.82 8060.85 92.660 285.000 4370.89 4429.44 1641.81 N 4560.28 W 6017774.62 N 564615.47 E 1.544 1959.78 8108.95 89.380 283.600 4370.04 4428.59 1653.69 N 4606.88 W 6017786.07 N 564568.76 E 7.414 1983.34 8156.41 89.260 281.230 4370.60 4429.15 1663.89 N 4653.22 W 6017795.84 N 564522.33 E 5.000 2007.95 8204.92 89.440 282.090 4371.15 4429.70 1673.70 N 4700.73 W 6017805.20 N 564474.73 E 1.811 2033.65 8252.96 88.950 281.970 4371.83 4430.38 1683.71 N 4747.71 W 6017814.77 N 564427.66 E 1.050 2058.83 e 8299.95 88.270 281.600 4372.97 4431.52 1693.30 N 4793.69 W 6017823.94 N 564381.59 E 1.647 2083.63 8349.02 89.810 281.480 4373.79 4432.34 1703.12 N 4841.76 W 6017833.31 N 564333.43 E 3.148 2109.71 8396.36 90.430 282.450 4373.69 4432.24 1712.93 N 4888.07 W 6017842.69 N 564287.03 E 2.432 2134.57 8444.58 89.380 282.450 4373.77 4432.32 1723.33 N 4935.16 W 6017852.65 N 564239.85 E 2.178 2159.55 8491.67 87.470 282.020 4375.06 4433.61 1733.30 N 4981.16 W 6017862.20 N 564193.76 E 4.157 2184.09 8540.83 88.770 280.990 4376.68 4435.23 1743.10 N 5029.31 W 6017871.55 N 564145.52 E 3.373 2210.23 8588.37 90.990 280.910 4376.78 4435.33 1752.13 N 5075.98 W 6017880.15 N 564098.77 E 4.673 2235.91 8637.02 90.490 280.180 4376.15 4434.70 1761.03 N 5123.80 W 6017888.60 N 564050.87 E 1.819 2262.48 8684.39 89.940 280.000 4375.97 4434.52 1769.33 N 5170.44 W 6017896.47 N 564004.15 E 1.222 2288.67 8732.64 89.440 279.760 4376.23 4434.78 1777.61 N 5217.97 W 6017904.31 N 563956.55 E 1.149 2315.49 8781.00 87.220 283.000 4377.64 4436.19 1787.15 N 5265.35 W 6017913.40 N 563909.08 E 8.119 2341 .29 8829.15 86.480 282.840 4380.29 4438.84 1797.90 N 5312.21 W 6017923.72 N 563862.12 E 1.572 2365.86 8876.47 87.220 284.540 4382.89 4441 .44 1809.08 N 5358.11 W 6017934.47 N 563816.12 E 3.913 2389.45 20 May, 2004 - 15:42 Page 4 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A Your Ref: API 500292256101 Job No. AKZZ3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8927.54 89.070 287.990 4384.54 4443.09 1823.37 N 5407.11 W 6017948.31 N 563766.99 E 7.662 2412.92 8972.27 89.940 291.270 4384.93 4443.48 1838.40 N 5449.23 W 6017962.94 N 563724.73 E 7.586 2431.13 9023.25 90.560 293.420 4384.70 4443.25 1857.78 N 5496.38 W 6017981.88 N 563677.41 E 4.389 2449.65 9067.04 90.430 293.700 4384.33 4442.88 1875.28 N 5536.51 W 6017999.01 N 563637.11 E 0.705 2464.69 9117.14 89.750 293.120 4384.25 4442.80 1895.18N 5582.49 W 6018018.49 N 563590.95 E 1.784 2482.02 e 9160.21 86.790 292.580 4385.55 4444.10 1911.90 N 5622.16 W 6018034.84 N 563551.13 E 6.986 2497.31 9213.89 86.290 292.290 4388.79 4447.34 1932.35 N 5671.68 W 6018054.82 N 563501.42 E 1.076 2516.70 9256.36 85.920 291.830 4391.67 4450.22 1948.26 N 5710.95 W 6018070.37 N 563462.00 E 1.388 2532.29 9311.16 86.660 290.160 4395.22 4453.77 1967.85 N 5762.01 W 6018089.49 N 563410.77 E 3.327 2553.35 9356.52 88.090 288.460 4397.30 4455.85 1982.84 N 5804.77 W 6018104.07 N 563367.87 E 4.894 2572.03 9404.86 88.520 286.310 4398.73 4457.28 1997.27 N 5850.88 W 6018118.08 N 563321.63 E 4.534 2593.41 9451.69 92.040 284.890 4398.50 4457.05 2009.86 N 5895.97 W 6018130.25 N 563276.42 E 8.105 2615.43 9502.97 94.390 286.230 4395.62 4454.17 2023.60 N 5945.29 W 6018143.53 N 563226.97 E 5.273 2639.53 9540.70 95.070 284.340 4392.51 4451.06 2033.51 N 5981.56 W 6018153.10 N 563190.61 E 5.308 2657.39 9599.00 95.810 286.130 4386.98 4445.53 2048.76 N 6037.56 W 6018167.83 N 563134.48 E 3.310 2685.01 9642.72 98.170 288.310 4381.66 4440.21 2061.60 N 6079.00 W 6018180.29 N 563092.92 E 7.323 2704.33 9692.37 97.670 288.300 4374.82 4433.37 2077.05 N 6125.69 W 6018195.30 N 563046.09 E 1.007 2725.38 9741.98 96.550 287.280 4368.68 4427.23 2092.09 N 6172.56 W 6018209.90 N 562999.08 E 3.043 2746.85 9807.25 94.940 287.510 4362.15 4420.70 2111.50 N 6234.53 W 6018228.74 N 562936.93 E 2.491 2775.58 --- 9878.00 94.940 287.510 4356.05 4414.60 ~ 2132.71 N 6301.75 W 6018249.32 N 562869.51 E 0.000 2806.63 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. e Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 223.650° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9878.00ft., The Bottom Hole Displacement is 6652.86ft., in the Direction of 288.697° (True). 20 May, 2004 -15:42 Page 50f6 DrillQuest 3.03.06.002 Milne Point Unit Comments Measured Depth (ft) 2416.98 2457.00 9878.00 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A Your Ref: API 500292256101 Job No. AKZZ3034600, Surveyed: 30 April, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2394.70 2433.72 4414.60 Comment 77.04 N 83.97 N 2132.71 N Tie On Point Window Point Projected Survey e 210.12W 215.68 W 6301.75 W Survey too/ørogram for MPE-20A From Measured Vertical Depth Depth (ft) (ft) 0.00 2416.98 0.00 2394.70 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 2416.98 9878.00 2394.70 MWD Magnetic (MPE-20) 4414.60 AK-6 BP _IFR-AK - MWD+IIFR+MS (MPE-20A) e 20 May, 2004 - 15:42 Page 60f6 Dri/lQuest 3.03.06.002 . . 24-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPE-20A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 2,416.98' MD 2,457.00' MD 9,878.00 I MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date <\ ~ --... ~ ~ Signed ~ ol1J Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager -~ v{...Q ~4 ,,¿t> AUachment(s) .. Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPE MPE-20A MWD e Job No. AKMW3034600, Surveyed: 30 April, 2004 Survey Report 21 May, 2004 Your Ref: API 500292256101 Surface Coordinates: 6016175.23 N, 569190.80 E (70· 27' 16.3793H N, 149· 26' 07.3457H W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1016175.23 N, 69190.80 E (Grid) Surface Coordinates relative to Structure Reference: 2378.77 N, 227.84 W (True) Kelly Bushing Elevation: 58. 55ft above Mean Sea Level Kelly Bushing Elevation: 58. 55ft above Project V Reference Kelly Bushing Elevation: 58. 55ft above Structure Reference Sp:E!I"""'I"""'Y-SUI! 6AIL.L.(NG seRVices A Halliburton Company Survey Ref: svy1395 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A MWD Your Ref: API 500292256101 Job No. AKMW3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 DOft) 2416.98 12.940 321.400 2336.15 2394.70 77.04 N 210.12W 6016250.32 N 568979.98 E 89.29 Tie On Point 2457.00 12.720 321.020 2375.17 2433.72 83.97 N 215.68 W 6016257.19 N 568974.34 E 0.589 88.12 Window Point 2477.13 14.400 317.040 2394.74 2453.29 87.52 N 218.78 W 6016260.72 N 568971.21 E 9.542 87.69 2572.20 17.530 311.890 2486.14 2544.69 105.74 N 237.51 W 6016278.76 N 568952.32 E 3.611 87.43 2669.25 19.600 291.540 2578.23 2636.78 121.49 N 263.56 W 6016294.27 N 568926.13 E 6.969 94.01 e 2764.63 20.210 290.720 2667.91 2726.46 133.20 N 293.85 W 6016305.69 N 568895.73 E 0.703 106.45 2859.63 23.080 284.170 2756.22 2814.77 143.56 N 327.26 W 6016315.75 N 568862.22 E 3.945 122.01 2954.02 25.680 278.540 2842.20 2900.75 151.13 N 365.44 W 6016322.96 N 568823.98 E 3.692 142.89 3050.73 28.890 277.830 2928.13 2986.68 157.43 N 409.31 W 6016328.85 N 568780.04 E 3.336 168.62 3147.15 31.800 279.460 3011.34 3069.89 164.78 N 457.46 W 6016335.75 N 568731.83 E 3.136 196.53 3242.64 34.840 281.440 3091.12 3149.67 174.33 N 509.02 W 6016344.82 N 568680.18 E 3.381 225.22 3337.26 34.940 280.740 3168.74 3227.29 184.74 N 562.14 W 6016354.74 N 568626.97 E 0.436 254.35 3434.31 37.410 283.070 3247.07 3305.62 196.58 N 618.17 W 6016366.07 N 568570.83 E 2.913 284.45 3530.07 37.690 282.370 3322.99 3381.54 209.43 N 675.10 W 6016378.38 N 568513.79 E 0.533 314.45 3626.12 39.810 285.380 3397.90 3456.45 223.88 N 733.43 W 6016392.29 N 568455.32 E 2.952 344.26 3721.28 40.690 286.630 3470.53 3529.08 240.84 N 792.53 W 6016408.70 N 568396.07 E 1.255 372.78 3817.14 45.190 290.600 3540.71 3599.26 261.76 N 854.35 W 6016429.05 N 568334.06 E 5.475 400.31 3913.87 47.770 293.530 3607.32 3665.87 288.14 N 919.32 W 6016454.82 N 568268.85 E 3.455 426.07 4009.65 49.090 298.850 3670.89 3729.44 319.77 N 983.56 W 6016485.85 N 568204.32 E 4.377 447.52 4106.48 51.010 298.320 3733.07 3791.62 355.28 N 1048.74 W 6016520.76 N 568138.81 E 2.027 466.82 4202.87 54.790 298.290 3791.20 3849.75 391.73 N 1116.41 W 6016556.57 N 568070.80 E 3.922 487.16 e 4298.47 59.150 299.550 3843.30 3901.85 430.50 N 1186.54 W 6016594.69 N 568000.31 E 4.692 507.52 4394.34 63.170 297.450 3889.54 3948.09 470.53 N 1260.33 W 6016634.04 N 567926.15 E 4.611 529.49 4490.35 66.100 302.690 3930.69 3989.24 514.02 N 1335.34 W 6016676.82 N 567850.74 E 5.798 549.80 4585.59 66.360 304.000 3969.08 4027.63 561.93 N 1408.15 W 6016724.05 N 567777.49 E 1.288 565.39 4682.94 67.240 304.360 4007.43 4065.98 612.19 N 1482.18 W 6016773.63 N 567703.00 E 0.966 580.11 4778.30 67.930 304.630 4043.79 4102.34 662.12 N 1554.83 W 6016822.88 N 567629.89 E 0.769 594.13 4875.29 67.600 304.630 4080.49 4139.04 713.14 N 1628.70 W 6016873.21 N 567555.54 E 0.340 608.21 4971.54 67.650 305.160 4117.13 4175.68 764.05 N 1701.70W 6016923.45 N 567482.07 E 0.512 621.76 5068.31 66.830 307.070 4154.57 4213.12 816.64 N 1773.79 W 6016975.36 N 567409.50 E 2.008 633.46 5162.96 69.170 304.310 4190.03 4248.58 867.82 N 1845.06 W 6017025.87 N 567337.76 E 3.663 645.63 5257.76 73.730 307.410 4220.19 4278.74 920.47 N 1917.85 W 6017077.85 N 567264.48 E 5.722 657.77 5293.38 75.660 306.570 4229.59 4288.14 941.14 N 1945.29 W 6017098.26 N 567236.85 E 5.876 661.76 5355.18 75.840 303.380 4244.80 4303.35 975.47 N 1994.37 W 6017132.14 N 567187.46 E 5.011 670.79 5451.17 76.170 301.280 4268.02 4326.57 1025.28 N 2073.06 W 6017181.21 N 567108.30 E 2.150 689.08 21 May, 2004 - 9:34 Page 2 of6 Dril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A MWD Your Ref: API 500292256101 Job No. AKMW3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 5548.31 76.170 305.770 4291.25 4349.80 1077.36 N 2151.67 W 6017232.56 N 567029.21 E 4.488 705.65 5644.28 76.220 297.850 4314.19 4372.74 1126.44 N 2230.80 W 6017280.90 N 566949.63 E 8.014 724.76 5740.84 80.890 298.710 4333.34 4391.89 1171.27 N 2314.12 W 6017324.96 N 566865.90 E 4.914 749.83 5834.68 84.070 289.640 4345.65 4404.20 1209.30 N 2398.90 W 6017362.20 N 566780.77 E 10.162 780.84 5927.69 86.970 302.250 4352.94 4411.49 1249.80 N 2482.10 W 6017401.92 N 566697.21 E 13.870 808.95 e 5997.13 87.530 304.240 4356.27 4414.82 1287.82 N 2540.10 W 6017439.40 N 566638.85 E 2.974 821.48 6092.72 80.140 297.740 4366.54 4425.09 1336.72 N 2621.45 W 6017487.55 N 566557.05 E 10.267 842.25 6146.14 83.010 296.520 4374.37 4432.92 1360.82 N 2668.48 W 6017511.21 N 566509.80 E 5.828 857.27 6187.58 82.690 299.690 4379.53 4438.08 1380.18 N 2704.74 W 6017530.24 N 566473.36 E 7.629 868.29 6236.81 84.930 299.240 4384.83 4443.38 1404.26 N 2747.35 W 6017553.91 N 566430.53 E 4.640 880.28 6285.41 89.440 302.000 4387.22 4445.77 1428.97 N 2789.11 W 6017578.24 N 566388.54 E 10.875 891.22 6331.00 90.990 302.300 4387.05 4445.60 1453.23 N 2827.70 W 6017602.14 N 566349.72 E 3.463 900.31 6381.10 92.220 289.290 4385.64 4444.19 1474.98 N 2872.70 W 6017623.47 N 566304.53 E 26.073 915.63 6430.56 93.030 290.190 4383.38 4441.93 1491.67 N 2919.20 W 6017639.72 N 566257.87 E 2.447 935.66 6477.99 94.510 295.740 4380.25 4438.80 1510.12 N 2962.76 W 6017657.77 N 566214.14 E 12.086 952.37 6527.35 94.080 286.630 4376.55 4435.10 1527.89 N 3008.61 W 6017675.11 N 566168.14 E 18.425 971.16 6574.34 92.040 284.430 4374.04 4432.59 1540.45 N 3053.81 W 6017687.26 N 566122.82 E 6.380 993.27 6622.50 91.300 276.380 4372.64 4431.19 1549.14N 3101.12 W 6017695.50 N 566075.43 E 16.778 1019.64 6670.44 91.540 276.970 4371.45 4430.00 1554.71 N 3148.72 W 6017700.63 N 566027.78 E 1.328 1048.47 6715.05 90.990 273.850 4370.46 4429.01 1558.91 N 3193.11 W 6017704.42 N 565983.35 E 7.100 1076.07 6766.41 91.050 273.760 4369.55 4428.10 1562.32 N 3244.35 W 6017707.35 N 565932.08 E 0.211 1108.97 e 6810.35 90.860 273.510 4368.82 4427.37 1565.11 N 3288.20 W 6017709.73 N 565888.21 E 0.715 1137.22 6860.54 91.050 273.070 4367.98 4426.53 1567.99 N 3338.30 W 6017712.15 N 565838.08 E 0.955 1169.72 6905.33 92.280 272.680 4366.68 4425.23 1570.23 N 3383.01 W 6017713.98 N 565793.35 E 2.881 1198.96 6957.42 91 .480 272.240 4364.97 4423.52 1572.47 N 3435.03 W 6017715.73 N 565741.32 E 1.753 1233.24 7007.92 93.950 272.780 4362.58 4421.13 1574.67 N 3485.42 W 6017717.47 N 565690.91 E 5.006 1266.43 7053.66 94.080 272.210 4359.37 4417.92 1576.66 N 3531.00 W 6017719.03 N 565645.31 E 1.275 1296.45 7104.13 89.810 273.790 4357.66 4416.21 1579.30 N 3581.36 W 6017721.20 N 565594.93 E 9.020 1329.30 7149.75 88.390 274.350 4358.38 4416.93 1582.54 N 3626.86 W 6017724.02 N 565549.40 E 3.346 1358.37 7199.35 88.400 274.640 4359.77 4418.32 1586.42 N 3676.29 W 6017727.45 N 565499.94 E 0.585 1389.67 7245.66 90.560 273.950 4360.19 4418.74 1589.89 N 3722.46 W 6017730.48 N 565453.74 E 4.896 1419.03 7295.96 89.690 273.380 4360.08 4418.63 1593.11 N 3772.66 W 6017733.23 N 565403.51 E 2.068 1451.36 7342.37 89.140 272.610 4360.55 4419.10 1595.53 N 3819.00 W 6017735.23 N 565357.15 E 2.039 1481.59 7393.33 88.210 272.280 4361.73 4420.28 1597.71 N 3869.90 W 6017736.93 N 565306.23 E 1.936 1515.15 7438.49 90.250 273.970 4362.34 4420.89 1600.17 N 3914.98 W 6017738.97 N 565261.12 E 5.866 1544.49 21 May, 2004 - 9:34 Page 3 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A MWD Your Ref: API 500292256101 Job No. AKMW3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7482.08 88.830 275.500 4362.69 4421.24 1603.77 N 3958.42 W 6017742.17 N 565217.66 E 4.789 1571.87 7534.66 88.150 277.050 4364.07 4422.62 1609.51 N 4010.67 W 6017747.42 N 565165.36 E 3.218 1603.77 7584.84 85.180 281.350 4366.99 4425.54 1617.51 N 4060.10 W 6017754.97 N 565115.85 E 10.402 1632.11 7630.85 84.380 282.900 4371.18 4429.73 1627.14 N 4104.90 W 6017764.18 N 565070.97 E 3.779 1656.06 7677.84 87.040 282.780 4374.69 4433.24 1637.55 N 4150.58 W 6017774.16 N 565025.19 E 5.667 1680.06 e 7727.02 87.840 282.950 4376.89 4435.44 1648.49 N 4198.48 W 6017784.66 N 564977.20 E 1.663 1705.21 7774.49 87.720 283.510 4378.73 4437.28 1659.34 N 4244.65 W 6017795.08 N 564930.92 E 1.206 1729.22 7822.00 90.060 283.460 4379.65 4438.20 1670.42 N 4290.84 W 6017805.73 N 564884.63 E 4.926 1753.09 7871.81 90.620 286.050 4379.35 4437.90 1683.10N 4339.00 W 6017817.97 N 564836.36 E 5.320 1777.16 7917.84 93.150 287.920 4377.84 4436.39 1696.54 N 4382.99 W 6017830.99 N 564792.24 E 6.833 1797.80 7963.40 92.470 287.240 4375.61 4434.16 1710.29 N 4426.37 W 6017844.34 N 564748.73 E 2.109 1817.80 8012.34 92.780 288.020 4373.37 4431.92 1725.09 N 4472.97 W 6017858.71 N 564702.01 E 1.713 1839.25 8060.85 92.660 287.430 4371.06 4429.61 1739.84 N 4519.12 W 6017873.03 N 564655.72 E 1.240 1860.43 8108.95 89.380 286.020 4370.21 4428.76 1753.68 N 4565.17 W 6017886.44 N 564609.54 E 7.422 1882.20 8156.41 89.260 283.600 4370.77 4429.32 1765.81 N 4611.05 W 6017898.14 N 564563.55 E 5.105 1905.09 8204.92 89.440 284.240 4371.32 4429.87 1777.48 N 4658.13 W 6017909.38 N 564516.36 E 1.370 1929.15 8252.96 88.950 284.040 4372.00 4430.55 1789.22 N 4704.71 W 6017920.68 N 564469.68 E 1.102 1952.81 8299.95 88.270 283.760 4373.14 4431.69 1800.50 N 4750.31 W 6017931.54 N 564423.97 E 1.565 1976.12 8349.02 89.810 283.600 4373.96 4432.51 1812.10N 4797.98 W 6017942.70 N 564376.20 E 3.155 2000.63 8396.36 90.430 284.700 4373.86 4432.41 1823.68 N 4843.88 W 6017953.84 N 564330.19 E 2.667 2023.94 8444.58 89.380 284.790 4373.94 4432.49 1835.95 N 4890.51 W 6017965.68 N 564283.45 E 2.186 2047.25 e 8491.67 87.470 284.670 4375.23 4433.78 1847.92 N 4936.04 W 6017977.23 N 564237.82 E 4.064 2070.01 8540.83 88.770 283.680 4376.85 4435.40 1859.95 N 4983.67 W 6017988.82 N 564190.07 E 3.323 2094.18 8588.37 90.990 283.010 4376.95 4435.50 1870.92 N 5029.93 W 6017999.36 N 564143.72 E 4.878 2118.17 8637.02 90.490 282.070 4376.32 4434.87 1881.48 N 5077.41 W 6018009.48 N 564096.14 E 2.188 2143.31 8684.39 89.940 281.770 4376.14 4434.69 1891.27 N 5123.76 W 6018018.83 N 564049.70 E 1.323 2168.22 8732.64 89.440 281.300 4376.40 4434.95 1900.91 N 5171.03 W 6018028.04 N 564002.34 E 1.422 2193.87 8781.00 87.220 284.520 4377.81 4436.36 1911.71 N 5218.14 W 6018038.40 N 563955.13 E 8.085 2218.57 8829.15 86.480 284.440 4380.46 4439.01 1923.73 N 5264.69 W 6018049.99 N 563908.47 E 1.546 2242.01 8876.47 87.220 286.540 4383.06 4441.61 1936.35 N 5310.22 W 6018062.18 N 563862.83 E 4.699 2264.30 8927.54 89.070 290.170 4384.71 4443.26 1952.42 N 5358.66 W 6018077.80 N 563814.24 E 7.974 2286.11 8972.27 89.940 294.000 4385.10 4443.65 1969.24 N 5400.10 W 6018094.23 N 563772.65 E 8.780 2302.54 9023.25 90.560 296.460 4384.87 4443.42 1990.96 N 5446.21 W 6018115.53 N 563726.34 E 4.976 2318.65 9067.04 90.430 297.290 4384.50 4443.05 2010.76 N 5485.27 W 6018134.96 N 563687.10 E 1.918 2331.29 9117.14 89.750 296.850 4384.42 4442.97 2033.56 N 5529.88 W 6018157.35 N 563642.28 E 1.617 2345.58 21 May, 2004 - 9:34 Page 4 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A MWD Your Ref: AP/500292256101 Job No. AKMW3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northin9s Eastings Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9160.21 86.790 296.360 4385.72 4444.27 2052.83 N 5568.36 W 6018176.26 N 563603.61 E 6.966 2358.20 9213.89 86.290 296.110 4388.96 4447.51 2076.52 N 5616.43 W 6018199.50 N 563555.33 E 1.041 2374.24 9256.36 85.920 295.590 4391.84 4450.39 2095.00 N 5654.56 W 6018217.62 N 563517.03 E 1.500 2387.19 9311.16 86.660 293.990 4395.39 4453.94 2117.92N 5704.20 W 6018240.09 N 563467.17 E 3.211 2404.87 e 9356.52 88.090 292.250 4397.47 4456.02 2135.71 N 5745.87 W 6018257.49 N 563425.34 E 4.962 2420.76 9404.86 88.520 289.990 4398.90 4457.45 2153.12 N 5790.94 W 6018274.48 N 563380.11 E 4.757 2439.27 9451.69 92.040 288.720 4398.67 4457.22 2168.64 N 5835.12 W 6018289.59 N 563335.79 E 7.991 2458.53 9502.97 94.390 290.040 4395.79 4454.34 2185.63 N 5883.41 W 6018306.13 N 563287.34 E 5.254 2479.58 9540.70 95.070 288.020 4392.68 4451.23 2197.89 N 5918.96 W 6018318.06 N 563251.69 E 5.632 2495.24 9599.00 95.810 287.650 4387.15 4445.70 2215.66 N 5974.21 W 6018335.32 N 563196.28 E 1.418 2520.52 9642.72 98.170 289.610 4381.83 4440.38 2229.52 N 6015.32 W 6018348.80 N 563155.03 E 6.995 2538.87 9692.37 97.670 289.530 4374.99 4433.54 2246.00 N 6061.66 W 6018364.84 N 563108.55 E 1.020 2558.93 9741.98 96.550 288.650 4368.85 4427.40 2262.09 N 6108.18 W 6018380.50 N 563061.88 E 2.863 2579.39 9807.25 94.940 288.610 4362.32 4420.87 2282.84 N 6169.71 W 6018400.68 N 563000.15 E 2.467 2606.86 9878.00 94.940 288.610 4356.22 4414.77 2305.33 N 6236.52 W 6018422.55 N 562933.14 E 0.000 2636.69 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 223.650° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9878.00ft., The Bottom Hole Displacement is 6648.96ft., in the Direction of 290.287° (True). e 21 May, 2004 - 9:34 Page 5 of6 Dril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-20A MWD Your Ref: API 500292256101 Job No. AKMW3034600, Surveyed: 30 April, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastin9s (ft) (ft) (ft) Comment 2416.98 2457.00 9878.00 2394.70 2433.72 4414.77 77.04 N 83.97 N 2305.33 N 210.12 W 215.68 W 6236.52 W Tie On Point Window Point Projected Survey e Survey too/prOf/ram for MPE-20A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 9878.00 4414.77 MWD Magnetic (MPE-20) e 21 May, 2004 - 9:34 Page 60f6 DrillQuest 3.03.06.002 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 16, 2004 RE: MWD Formation Evaluation Logs MPE-20A, AK-MW-3034600 1 LIS formatted Disc with verification listing. PùPI#: 50-029-22561-01 / .. C- ( (0 ).2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMfITAL LETTER TO THE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date:).~~. (~'-\ Signed: 1U oW I ~~~ - ~'11 · . Œ (ill ~ ~ ~ ~ ~ [{ ~ / FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA OIL AND GAS / CONSERVATION COJDIISSION / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Matt Green Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point Unit MPE-20A BP Exploration (Alaska) Inc. Permit No: 204-054 Surface Location: 3637' NSL, 1955' WEL, SEC. 25, T13N, RI0E, UM Bottomhole Location: 492' NSL, 2977' WEL, SEC. 23, T13N, RI0E, (OA) Dear Mr. Green: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill 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 North Slope petroleum field inspector at 3607 (pager). BY ORDER OF THE COMMISSION DATED this~ay of April, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · STATE OF ALASKA . ALAS~ OIL AND GAS CONSERVATION WMMISSION PERMIT TO DRILL 20 MC 25.005 ~) 1;;.: Æi;\ 1a. Type of work o Drill iii Redrill rb. Current Well Class o Exploratory iii Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Number: /" BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 MPE-20A 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9832' i TVD 4418' ' Milne Point Unit I Schrader Bluff '" 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 047437 3637' NSL~ 1955' WEL, SEC. 25, T13N, R10E, UM ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: " 4921' NSL, 4530' WEL, SEC. 25, T13N, R10E, (OA) 04/10104 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 492' NSL, 2977' WEL, SEC. 23, T13N, R10E, (OA) / 2560 10100' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE= 15. Distance to Nearest Well Within Pool Surface: X-569191 ,¡ y-6016175 ./ Zone-ASP4 (Height above GL): 57.80' feet MPE-20A is 350' away from MPC-41 16. Deviated Wells: / 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) 0 Kickoff Depth 2480 ft Maximum Hole Angle 92 Downhole: 1903 psig '" Surface: 1477 psig '" 113. Casing Program ...,..~ ,·,··Øl············ .... I' ..l&f:lIiI- Size tct). -"" ~r -·Bot om Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (includina staae data) 9-7/8" 7-5/8" 29.7# L-80 BTC-M 5983' Surface Surface 5983' 4443' ~76 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 BTC 3999' 5833' 4403' 9832' 4418' Uncemented Slotted Liner 19. PRt:$.E:NJ'.WELL~ØNDltIØN~~MMARY '(TPbe C()rripIØtøqJ()I'~~r.1IANDR$-E!ntrýº~~~iQIlS) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 4700' 4663' N/A 4637' 4600' N/A ,Ee"t\âth', '" ~i~Ø'i ." " " ..' , '1.¡1!;)' ... TV!;)' " ~"'''''''S ~ I Conductor 112' 20" 250 sx Arcticset I (ADProx.) 112' 112' Surface 2256' 13-3/8" 784 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 2587' 2561' Int tP. Prorh Ir.tion 4653' 9-5/8" 375 sx Class 'G' 4681' 4644' Linp.r Perforation Depth MD (ft): 4312' - 4528' perfOration Depth TVD (ft): 4275' - 4291' 20. Attachments 181 Filing Fee o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report o Drilling Fluid Program a 20 MC 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 Matt Green, 564-5581 Printed Name Matt Green 7ft/'/ Title Drilling Engineer Date 1)-;!.vú 'f Prepared By Name/Number: Signature /If f:?/?L~ Phone 564-5571 Sondra Stewman, 564-4750 ,. i ,f" 'i!'f-p,' " " " n¡¡;'¡i~ ,?""]' ':""·.;Ü' , '·i"'·! ii' '}'? " Permit To Drill . .--;t.j I API Number: Permit Approval I See cover letter for Number: ::J..OC¡-O<'"::> 50-029-22561-01-00 Date: other requirements Conditions of Approval: Samples Required DYes NNo Mud Log Required DYes J8No Hy en Sulfide Measures ~Yes D No Directional Survey Required ~es D No Other: ~()() S' ? -4.",> -\- 'A fA- f"\n\(,1t\IAI BY ORDER OF ¡(¡/~ðC¡ Aooroved THE COMMISSION Date Form 1 0-40'-Révis~2003 U i \'!,'! / \i 1L. ~ubmit/Jn Duþlicate · Milntoint MPE-20A Well Permit IWell Name: I MPE-20A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Multi Lateral Producer "NB" & "OA" Surface Location: 1642' FNL, (3638' FSL), 1955' FEL, (3325' FWL), SEC. 25, T13N, R10E E=569190.8 N=6016175.23 Target Location: 358' FNL, (4921' FSL), 4530' FEL, (750' FWL), SEC. 25, T13N, R10E TOP "OA" E=566604 N=6017435 Z=4385'TVD Target Location: 4788' FNL, (492' FSL);"2977' FE!:,' (2302' FWL), SEC. 23, T13N, R10E BHL "OA" Well TD E=562869 N=6018253 Z=4360' TVD Target Location: 351' FNL, (4928' FSL), 5079' FEL, (201' FWL), SEC. 25, T13N, R10E TOP "NB" E=566055 N=6017437 Z=4263'TVD Target Location: 4500' FNL, (7801' FSL), 4129' FEL, (1150' FWL), SEC. 23, T13N, R10E BHL "NB" Well TD E=561714 N=6018531 Z=4187'TVD t" I AFE Number: I TBD I Rig: I Doyon 14 I I Estimated Start Date: 11 0-Apr-2004 I Operating days to complete: 115.0 I [M[] 9832 I t" I TVD: 14418 r I Max Inc: [][] I KOP: 12480 I I KBE: 157.8 I Well Design (conventional, slimhole, etc.): 1 Conventional Grass Roots ML Producer 1--- I Objective: 1 Schrader Bluff NB & OA Sand I Mud Pro ram: 9.87S-in Intermediate Hole Mud Pro erties: LSND Freshwater Mud Densit PV YP HTHP H API Filtrate LG Solids 8.8 - 9.3 ¿ 10 - 20 25 - 30 10 - 11 9.0 - 9.5 < 6 < 15 6.12S-in Production Hole Mud Pro erties: OBM Densi PV YP HTHP O/w Ratio Elec Stab 9.0 - 9.2 / 15 - 25 18 - 28 < 4.0 80:20 650 - 900 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site ~ Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU IR. 1 . . Milne Point MPE-20A Well Permit Cement Program: Casing 7.625-in 29.7-lb/ft L-80 BTC-M intermediate casing Size Basis Top of lead cement 500-ft above top of Ugnu-sand. 40% excess over gauge. To of tail cement 500-ft MD above top of N-sand. 40% excess over gauge. Total Cement Wash 5-bbl Water Vol: 125-bbl Spacer 30-bbl 10.3-lb/gal un-viscosified Alpha Spacer Tail 125-bbl, 576-sx 15.6-lb/gal Premium G - 1.22 ft"/sx (top of tail at 3,716-ft MD) Temp BHST = 80°F from SOR, BHCT 70°F estimated by Schlumberger Evaluation Program: 9.875-in Hole Section: /" Open Hole: MWD/GRlRES,IFRlCASANDRA Cased Hole: N/A 6.125-in Hole section: Open Hole: MWD/GRlRES, ABIIIFRlCASANDRA Cased Hole: N/A 2 · Miln~int MPE-20A Well Permit Formation Markers Formation Tops MOrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (I b/gal) * Base Permafrost 1858 TUZC 4216 3798 8.35 1624 NA 5592 4318 8.59 1903 NB 5645 4338 8.59 1912 NC 5699 4358 8.59 1921 NE 5770 4383 8.59 1932 NF 5884 4418 8.59 1948 Top OA 5983 4443 8.59/ 1959 ./ v * Based on SS depths c IT b- p aSln~ U In~1 ro ~ram Hole Csg/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in 92# H-40 Welded 80-ft O-ft 113-ft / 113-ft 16.0-in 13.375-in 54.5# K-55 BTC-M 2,480-ft O-ft 2,480-ft / 2,456-ft 9.875-in 7.625-in 29.7# L-80 BTC-M 5,983-ft O-ft 5,983-ft / 4,443-ft 6.125-in 4.5-in 12.6# L-80 BTC 3,999-ft 5,833-ft / 9,832-ft / OA Slotted 4,403-ft 4,418-ft 6.75-in 4.5-in 12.6# L-80 BTC 5,424-ft 5,613-ft / 11 ,037-ft / NB Screens 4,326-ft 4,245-ft R d d B-t P ecommen e I rogram BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 9.875-in 2,480-ft - 5,983-ft Smith 3-15 & 1-1 0 FGXiCPS 2 6.125-in 5,983-ft - TO Secu rity 3-12 FM2643 3 6.75-in 5,6138-ft - TO Secu rity 3-12 FM2643 3 . Miln~int MPE-20A Well Permit Well Control: Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Integrity test: · Kick tolerance: · Planned completion fluid: ./ 1,903-psi @ 4,260-ft TVDrkb - Top of "NA" 1 ,477-psi @ surface (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) 3,500-psi. An FIT to 12.0-lb/gal will be made on the 13.375-in casing shoe. 53-bbl with 9.1-lb/gal mud. 9.1-lb/gal brine / 6.8-lb/gal Diesel (1 ,800-ft MD). Drilling Hazards & Contingencies: Hydrates · Light to moderate hydrates were encountered on several of the previous E-Pad wells. No drilling problems related to the hydrates were reported. /' · Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas or and/or hydrates. Use recommended practices for drilling hydrates. Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off v' within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing. · Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures / · Maximum reservoir pressure is expected to be (8.59-lb/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1-lb/gal mud. ,/ Pad Data Sheet · Please Read the E-Pad Data Sheet thoroughly. 4 . Milnlint MPE-20A Well Permit Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Sluff. Faults · A 20-ft DTW fault is expected at 4,200-ft MD in the Ugnu. · A 15-ft DTE fault is expected at 5,650-ft MD in the Schrader. · A 20-ft DTE fault is expected at 5,750-ft MD in the Schrader. Hydrogen Sulphide · MPE Pad is not designated as an H2S Pad. · First closest surface hole location H2S level MPE-09 5.8-ppm 2-Feb-2004. · Second closest surface hole location H2S level MPE-11 6.7-ppm 2-Feb-2004. · Third closest surface hole location H2S level MPE-14 <2.0-ppm 2-Feb-2004. · Maximum recorded H2S on Pad MPE-22 46-ppm 1-Feb-2001. /' Anti-collision Issues · There are no anti-collision issues on MPE-20A. Distance to Nearest Property · MPE-20A is 10,1 OO-ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPE-20A is 350-ft from the Schrader-sand penetration in MPC-41. '---t \(u~~~ ~~\\ 5 · Miln.int MPE-20A Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1 . P&A / decomplete well with Nabors 4ES. 2. Cut and pull 9.625-in casing. 3. Set bridge plug in 13.375-in casing at 2,520-ft Procedure 1. MI/RU Doyon 14 2. NU BOPE, PU 4.0-in drill pipe 3. Run whipstock and mill window in 13.375-in casing. 4. Drill 9.875-in intermediate hole 5. Run and cement 7.625-in casing 6. Drill 6.125-in OA horizontal production hole 7. Run 4.5-in slotted liner 8. Run whipstock and mill window for NB lateral 9. Drill 6.75-in NB horizontal production hole 10. Retrieve whipstock 11. Run 4.5-in screens and hang off in 7.625-in casing 12. Displace drilling mud to brine 13. Run 2.875-in ESP completion 14. ND BOPE / NU tree 15. Freeze protect well 16. RD/MO 6 COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Depth Fm Depth To SurveylPlan 2480.00 9831.70 Planned: MPE-20(OA) wp02 V2 PI",,: MPE-20(OA) wp02 (MPE-20/MPE-20A (OA Ln.» ~-1IUn .....'L ~ ;,~:..,,,,~':"~. v I <:.... BP Amoco Co-ordinate (NÆ) Relèrence; Well Centre: MPE-20, Tme North Vertical (TVD) Reference; D-14@34.30GL@23557.80 Section (VS) Reference; Slot· 20 (O.OON,O.OOE) Measu~aPc:f~io~e~:;d~ ~~~~~~@23.s 57.80 Tool MWD+IFR+MS Created By: Ken Allen Checked; Date: 2/11/2004 Calculation Method: Minimum Curvature ~~r ~~= ~~~~nderNorth Error Surface: Elliptical + Casing Warnin Method: Rules Based D'"' Reviewed: Date '2 :§ o ~ ..<:: Q. ~ Start Dir 12/100': 2480' MD, 2456.15'TVD Start Dir4/100': 2500' MD, 2475.65'TVD WELL DETAILS N_ +NI-S +FJ-W Northing E..tmg Latitude L_ Slot MPE-20 2378.22 -227.90 6016174.45 569190.69 70"27'16.372N 149°26'07.349W 20 TARGET DETAILS N_ TVD +NI-S +E/-W Northing Basting Shap" MPE-20 OA T4a 4417.80 2137.37 -6302.71 6018253.00 562869.00 Point MPE-20 OA LD 4442.80 1284.64 -2575.12 6017435.00 566604.00 Point MPE-20 OA 1'3 4442.80 1848.95 -5508.28 6017972.00 563666.00 Point ~t~~~~12 4442.80 1242.94 -2177.45 6017397.00 567002.00 Polygon 4447.80 1545.56 -4177.92 6017681.00 564999.00 Point MPE-20 OA T1 4457.80 1407.36 -2867.02 6017555.00 566311.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 2480.00 12.59 320.79 2456.15 88.01 -218.97 0.00 0.00 235.63 2 2500.00 13.02 310.1 I 2475.65 91.15 -222.07 12.00 -85.00 239.58 3 2550.00 13.34 301.45 2524.34 97.78 -231.30 4.00 -85.00 250.45 4 3197.50 38.00 280.67 3104.39 174.97 -495.4 I 4.00 -30.00 525.36 5 3497.50 38.00 280.67 3340.79 209.16 -676.92 0.00 0.00 708.23 6 4361.45 68.07 302.75 3858.31 483.51 -1294.13 4.00 37.93 1380.85 7 5693.53 68.07 302.75 4355.84 1151.89 -2333.43 0.00 0.00 2579.76 8 5983.14 77.00 295.00 4442.80 1284.64 -2575.12 4.00 -40.84 2851.27 MPE-20 OA LD 9 6003.14 77.00 295.00 4447.30 1292.87 -2592.78 0.00 0.00 2870.64 10 6116.15 90.55 294.41 4459.53 1339.70 -2694.60 12.00 -2.53 2982.11 11 6184.08 90.55 294.41 4458.88 1367.77 -2756.46 0.00 0.00 3049.71 '000 12 6301.65 90.50 285.00 4457.80 1407.36 -2867.02 8.00 -90.25 3167.13 MPE-20 OA T1 13 6557.45 90.44 274.77 4455.69 1451.21 -3118.68 4.00 -90.28 3419.54 .roOo 14 7490.06 90.44 274.77 4448.48 1528.72 -4048.04 0.00 0.00 4324.56 15 7621.07 90.15 280.00 4447.80 1545.56 -4177.92 4.00 93.19 4452.96 MPE-20 OA T2 <Ìho 4- 16 7680.07 90.09 282.36 4447.67 1556.99 -4235.78 4.00 91.34 4511.44 17 8792.17 90.09 282.36 4445.83 1795.02 -5322.11 0.00 0.00 5616.66 /000 ~ 18 8986.16 91.69 289.95 4442.80 1848.95 -5508.28 4.00 78.06 5810.29 MPE-20 OA T3 19 9831.70 91.69 289.95 4417.80 2137.37 -6302.71 0.00 0.00 6655.26 MPE-20 OA T4a CASING DETAILS '/~ No. TVD MD Name Size 4442.80 5983.14 7" 7.000 4417.80 9831.69 41/2" 4.500 o II ,I I' ~ I ~ #'# , #', , #' §' ;" ~ o .€ >- 2 f-< End Dir : 4361.45' MD, 3858.31' TVD End Dir : 5983.14' MD, 4442.8' TVD Start Dir 12/100': 6003.14' MD, 4447.3'TVD End Dir : 6116.15' MD, 4459.53' TVD Start Dir 8/100': 6184.08' MD, 4458.88'TVD Start Dir 4/100' : 6301.65' MD, 4457.8'TVD End Dir : 6557.45' MD, 4455.69' TVD Start Dir4/100': 7490.06' MD, 4448.48'TVD End Dir : 7680.07' MD, 4447.67' TVD FORMATION TOP DETAILS No. TVDPath MDPath F onnation I 3797.80 4215.92 TUZC 2 4072.80 4935.71 Ugnu-MA 3 4087.80 4975.87 Ugnu-MB1 4 4192.80 5257.00 Ugnu-MB2 5 4257.80 5431.03 Ugnu-MC 6 4317.80 5591.67 SBF2-NA 7 4337.80 5645.22 SBFI-NB 8 4357.80 5698.78 SBE4-NC 9 4382.80 5769.52 SBE2-NE 10 4417.80 5883.64 SBE1-NF 11 4442.80 5983.14 TSBD-OA(Top) EndDir : 3197.5'MD, 3104.39'TVD Start Dir 4/100' : 5693.53' MD, 4355.84'TVD Start Dir4/100': 3497.5' MD, 3340.79'TVD 800 1600 2400 3200 4000 4800 5600 6400 7200 Vertical Section at 288.73" [800ft/in] SURVEY PROGRAM PI"" MPE·20(OA) wp02 (MPE·201MPE·20A (OA Lot. Depth Fm Depth To SurveyIPlan Tool Created By: Ken Allen Date: 2/1112004 2480.00 9831.70 Planned: MPE.20(OA) wp02 V2 MWD+IFR+MS Checked: Date: Reviewed: Date_ - WELL DETAILS N~ +N/-S +EI-W Northing Hasting Latituœ Longitude Slot MPE-20 2378.22 ·227.90 6016174.45 569190.69 70027'16372N 149"26'U7349W 20 TARGET DETAILS !<uno TVD +N/-S +EI·W Northing Basting Shape MPE-200A T43 4417.80 213737 -6302.71 6018253.00 562869.00 Point MPE-200ALD 4442.80 1284.64 -2575.12 6017435.00 566604.00 Point MPE-20 OA T3 4442.80 1848.95 -5508.28 6017972.00 563666.00 Point MPE-20A Poly 4442.80 1242.94 ·2177.45 6Ot7397.00 567002.00 Polygon MPE-20 OA T2 4447.80 1545.56 4177.92 6017681.00 564999.00 Point MPE-20 OA TI 4457.80 140736 -2867.02 6017555.00 566311.00 Point - SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target I 2480.00 12.59 320.79 2456.15 88.01 -218.97 0.00 0.00 235.63 2 2500.00 13.02 310.11 2475.65 91.15 -222.07 12.00 -85.00 239.58 3 2550.00 13.34 301.45 2524.34 97.78 -231.30 4.00 -85.00 250.45 4 3197.50 38.00 280.67 3104.39 174.97 -495.41 4.00 -30.00 525.36 5 3497.50 38.00 280.67 3340.79 209.16 -676.92 0.00 0.00 708.23 6 4361.45 68.07 302.75 3858.31 483.51 -1294.13 4.00 37.93 1380.85 7 5693.53 68.07 302.75 4355.84 1151.89 ·2333.43 0.00 0.00 2579.76 8 5983.14 77.00 295.00 4442.80 1284.64 -2575.12 4.00 -40.84 2851.27 MPE-20 OA LD 9 6003.14 77.00 295.00 4447.30 1292.87 -2592.78 0.00 0.00 2870.64 10 6116.15 90.55 294.41 4459.53 1339.70 -2694.60 12.00 -2.53 2982.11 11 6184.08 90.55 294.41 4458.88 1367.77 -2756.46 0.00 0.00 3049.71 12 6301.65 90.50 285.00 4457.80 1407.36 -2867.02 8.00 -90.25 3167.13 MPE-20 OA Tl 13 6557.45 90.44 274.77 4455.69 1451.21 -3118.68 4.00 -90.28 3419.54 14 7490.06 90.44 274.77 4448.48 1528.72 -4048.04 0.00 0.00 4324.56 15 7621.07 90.15 280.00 4447.80 1545.56 -4177.92 4.00 93.19 4452.96 MPE-20 OA T2 16 7680.07 90.09 282.36 4447.67 1556.99 -4235.78 4.00 91.34 4511.44 17 8792.17 90.09 282.36 4445.83 1795.02 -5322.11 0.00 0.00 5616.66 18 8986.16 91.69 289.95 4442.80 1848.95 -5508.28 4.00 78.06 5810.29 MPE-20 OA T3 19 9831.70 91.69 289.95 4417.80 2137.37 -6302.71 0.00 0.00 6655.26 MPE-20 OA T4a CASING DETAILS No. TVD MD Name Size I 4442.80 5983.14 7" 7.000 2 4417.80 9831.69 41/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath F onnation I 3797.80 4215.92 TUZC 2 4072.80 4935.71 Ugnu-MA 3 4087.80 4975.87 Ugnu-MBI 4 4192.80 5257.00 Ugnu-MB2 5 4257.80 5431.03 Ugnu-MC 6 4317.80 5591.67 SBF2-NA 7 4337.80 5645.22 SBFI-NB 8 4357.80 5698.78 SBE4-NC 9 4382.80 5769.52 SBE2-NE 10 4417.80 5883.64 SBEI-NF 11 4442.80 5983.14 TSBD-OA(Top) REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: MPE-20, True North ¡ Vertical (fVD)Reference: D-14@34.30GL@23557.80 Section (\IS) Reference: Slot - 20 (O.OON,O.OOE) Measu~a~:io~~J:J~ ~~m~~~@23.5 57.: '000 ~ '"" ~ j!!'" COMPANY DETAILS llpemy--.n OP Amoco ;'iJ·ílI,:"~11J_I;.·f::.W1t.""'.Y.1~1f.l Calculation Method: Minimwn Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surlåce: Elliptical + Casing Wami~ Method: Rules Based l -I ,pP ~ I ¡P "#".j? #', , c§' ~ ø ~JV' .45' MD, 3858.31' TVD )' : 3497.5' MD, 3340.79'TVD 3197.5' MD, 3104.39' TVD 1) (MPE-20) ï~ Dir4/100': 2500' MD, 2475.65'TVD irt Dir 12/100': 2480' MD, 2456. 15'TVD T T -900 0 900 9831.7' MD, 4417.8' TVD -7200 -1800 -3600 -2700 West(-)/East(+) [900ft/in] MD, 4442.8' TVD : 8792.17' MD, 4445.83'TVD -4500 -5400 Depth Total -6300 90' " :¡3 o o ~ +' f ~ -" :; o '" spe""""y-sun DRILLING SERVICES "HU.LJ8I.-~CQNf'~ . . Sperry-Sun - Draft Copy KW A Planning Principal: Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M pt E Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: MPE-20 MPE-20 Well Position: +N/-S 2378.22 ft Northing: +E/-W -227.90 ft Easting: Position Uncertainty: 0.00 ft Wellpath: MPE-20A (OA Lat.) Current Datum: Magnetic Data: Field Strength: Vertical Section: D-14 @ 34.30 GL @ 23.5 1/12/2004 57556 nT Depth From (TVD) ft 34.30 Casing Points Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 6013798.68 ft Latitude: 70 26 52.982 N 569440.72 ft Longitude: 149 26 0.655 W North Reference: True Grid Convergence: 0.53 deg Slot Name: 20 ,/ 6016174.45 ft/ Latitude: 70 27 16.372 N 569190.69 ft Longitude: 149 26 7.349 W Height 57.80 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 MPE-20 2480.00 ft Mean Sea Level 25.10 deg 80.87 deg Direction deg 288.73 +N/-S ft 0.00 4215.92 3797.80 TUZC 0.00 0.00 4935.71 4072.80 Ugnu-MA 0.00 0.00 4975.87 4087.80 Ugnu-MB1 0.00 0.00 5257.00 4192.80 Ugnu-MB2 0.00 0.00 5431.03 4257.80 Ugnu-MC 0.00 0.00 5591.67 4317.80 SBF2-NA 0.00 0.00 5645.22 4337.80 SBF1-NB 0.00 0.00 5698.78 4357.80 SBE4-NC 0.00 0.00 5769.52 4382.80 SBE2-NE 0.00 0.00 5883.64 4417.80 SBE1-NF 0.00 0.00 5983.14 4442.80 TSBD-OA(Top) 0.00 0.00 0.00 TSBC-OA(Base) 0.00 0.00 Targets MPE-20 OA T4a MPE-20 OA LD 4417.80 4442.80 2137.37 -6302.71 6018253.00 562869.00 70 27 37.366 N 149 29 12.539 W 1284.64 -2575.12 6017435.00 566604.00 70 27 29.001 N 149 27 23.004 W " tt.U.lJ8\TJlcTON ("OMP..\N"ó . . Sperry-Sun - Draft Copy KW A Planning 5pE!~~Y-5un DRILLING SERVICES MPE-20 OA T3 4442.80 1848.95 -5508.28 6017972.00 563666.00 70 27 34.536 N 149 2849.191 W MPE-20A Poly 4442.80 1242.94 -2177.45 6017397.00 567002.00 70 27 28.593 N 149 27 11.321 W -Polygon 1 4442.80 1242.94 -2177.45 6017397.00 567002.00 70 27 28.593 N 149 27 11.321 W -Polygon 2 4442.80 1522.72 -2903.95 6017670.00 566273.00 70 27 31.342 N 149 27 32.668 W -Polygon 3 4442.80 1644.28 -4147.00 6017780.00 565029.00 70 27 32.531 N 149 28 9.191 W -Polygon 4 4442.80 2382.19 -6387.45 6018497.00 562782.00 70 27 39.773 N 149 29 15.035 W -Polygon 5 4442.80 2026.02 -6481.77 6018140.00 562691.00 70 27 36.269 N 149 29 17.798 W -Polygon 6 4442.80 1475.60 -4398.60 6017609.00 564779.00 70 27 30.871 N 149 28 16.580 W -Polygon 7 4442.80 1346.95 -2930.59 6017494.00 566248.00 70 27 29.613 N 149 27 33.448 W -Polygon 8 4442.80 975.25 -2322.96 6017128.00 566859.00 70 27 25.960 N 149 27 15.593 W MPE-20 OA T2 4447.80 1545.56 -4177.92 6017681.00 564999.00 70 27 31.560 N 149 28 10.098 W MPE-20 OA T1 4457.80 1407.36 -2867.02 6017555.00 566311.00 70 27 30.207 N 149 27 31.581 W Plan Section Information 2480.00 12.59 320.79 2456.15 88.01 -218.97 0.00 0.00 0.00 0.00 2500.00 13.02 310.11 2475.65 91.15 -222.07 12.00 2.13 -53.36 -85.00 2550.00 13.34 301.45 2524.34 97.78 -231.30 4.00 0.64 -17.33 -85.00 3197.50 38.00 280.67 3104.39 174.97 -495.41 4.00 3.81 -3.21 -30.00 3497.50 38.00 280.67 3340.79 209.16 -676.92 0.00 0.00 0.00 0.00 4361 .45 68.07 302.75 3858.31 483.51 -1294.13 4.00 3.48 2.56 37.93 5693.53 68.07 302.75 4355.84 1151.89 -2333.43 0.00 0.00 0.00 0.00 5983.14 77.00 295.00 4442.80 1284.64 -2575.12 4.00 3.08 -2.67 -40.84 MPE-20 OA LD 6003.14 77.00 295.00 4447.30 1292.87 -2592.78 0.00 0.00 0.00 0.00 6116.15 90.55 294.41 4459.53 1339.70 -2694.60 12.00 11.99 -0.53 -2.53 6184.08 90.55 294.41 4458.88 1367.77 -2756.46 0.00 0.00 0.00 0.00 6301.65 90.50 285.00 4457.80 1407.36 -2867.02 8.00 -0.04 -8.00 -90.25 MPE-20 OA T1 6557.45 90.44 274.77 4455.69 1451.21 -3118.68 4.00 -0.02 -4.00 -90.28 7490.06 90.44 274.77 4448.48 1528.72 -4048.04 0.00 0.00 0.00 0.00 7621.07 90.15 280.00 4447.80 1545.56 -4177.92 4.00 -0.22 3.99 93.19 MPE-20 OA T2 7680.07 90.09 282.36 4447.67 1556.99 -4235.78 4.00 -0.09 4.00 91.34 8792.17 90.09 282.36 4445.83 1795.02 -5322.11 0.00 0.00 0.00 0.00 8986.16 91.69 289.95 4442.80 1848.95 -5508.28 4.00 0.82 3.91 78.06 MPE-20 OA T3 9831.70 91.69 289.95 4417.80 2137.37 -6302.71 0.00 0.00 0.00 0.00 MPE-20 OA T4a Survey 2800.00 22.55 288.36 2762.01 2704.21 6016299.64 568887.97 326.71 92.52 4.00 338.99 2900.00 26.39 285.65 2853.02 2795.22 6016311.31 568848.25 368.10 133.94 4.00 342.49 3000.00 30.27 283.60 2941.02 2883.22 6016322.81 568802.23 415.41 181.39 4.00 344.96 3100.00 34.18 281.97 3025.61 2967.81 6016334.08 568750.13 468.43 234.70 4.00 346.77 3197.50 38.00 280.67 3104.39 3046.59 6016344.80 568693.73 525.36 292.12 4.00 348.15 3200.00 38.00 280.67 3106.36 3048.56 6016345.07 568692.21 526.88 293.66 0.00 0.00 MWD+IFR+ 3300.00 38.00 280.67 3185.16 3127.36 6016355.90 568631.61 587.84 355.22 0.00 0.00 MWD+IFR+ 3400.00 38.00 280.67 3263.96 3206.16 6016366.74 568571.01 648.80 416.79 0.00 0.00 MWD+IFR+ 3497.50 38.00 280.67 3340.79 3282.99 6016377.30 568511.93 708.23 476.81 0.00 0.00 MWD+IFR+ 3500.00 38.08 280.77 3342.76 3284.96 6016377.57 568510.41 709.76 478.36 4.00 37.93 MWD+IFR+ sper"r"y-sun DRIL-L-ING SERVIc:es AHU.LJIItJRTONI.':f)Mt';\N\" . . Sperry-Sun - Draft Copy KW A Planning 4100.00 58.60 297.77 3741.05 3683.25 6016529.86 568094.60 1152.37 922.82 4.00 27.50 4200.00 62.20 299.77 3790.44 3732.64 6016571.01 568018.04 1237.96 1009.75 4.00 26.32 4215.92 62.78 300.08 3797.80 3740.00 6016577.94 568005.74 1251.82 1023.87 4.00 25.33 4300.00 65.83 301.65 3834.26 3776.46 6016616.20 567940.37 1325.87 1099.62 4.00 25.19 4361.45 68.07 302.75 3858.31 3800.51 6016645.88 567892.25 1380.85 1156.16 4.00 24.51 4400.00 68.07 302.75 3872.71 3814.91 6016664.94 567862.00 1415.55 1191.92 0.00 0.00 4500.00 68.07 302.75 3910.06 3852.26 6016714.39 567783.52 1505.56 1284.69 0.00 0.00 4600.00 68.07 302.75 3947.41 3889.61 6016763.83 567705.05 1595.56 1377.45 0.00 0.00 4700.00 68.07 302.75 3984.76 3926.96 6016813.27 567626.57 1685.56 1470.21 0.00 0.00 4800.00 68.07 302.75 4022.11 3964.31 6016862.72 567548.09 1775.56 1562.98 0.00 0.00 4900.00 68.07 302.75 4059.46 4001.66 6016912.16 567469.62 1865.57 1655.74 0.00 0.00 4935.71 68.07 302.75 4072.80 4015.00 6016929.82 567441.59 1897.71 1688.86 0.00 0.00 4975.87 68.07 302.75 4087.80 4030.00 6016949.68 567410.08 1933.85 1726.12 0.00 0.00 5000.00 68.07 302.75 4096.81 4039.01 6016961.61 567391.14 1955.57 1748.50 0.00 0.00 5100.00 68.07 302.75 4134.16 4076.36 6017011.05 567312.66 2045.57 1841.27 0.00 0.00 5200.00 68.07 302.75 4171.51 4113.71 6017060.50 567234.19 2135.58 1934.03 0.00 0.00 5257.00 68.07 302.75 4192.80 4135.00 6017088.68 567189.46 2186.87 1986.90 0.00 0.00 5300.00 68.07 302.75 4208.86 4151.06 6017109.94 567155.71 2225.58 2026.79 0.00 0.00 5400.00 68.07 302.75 4246.21 4188.41 6017159.39 567077.23 2315.58 2119.56 0.00 0.00 5431.03 68.07 302.75 4257.80 4200.00 6017174.73 567052.88 2343.51 2148.34 0.00 0.00 5500.00 68.07 302.75 4283.56 4225.76 6017208.83 566998.75 2405.58 2212.32 0.00 0.00 MWD+IFR+ 5591.67 68.07 302.75 4317.80 4260.00 6017254.16 566926.82 2488.09 2297.35 0.00 0.00 SBF2-NA 5600.00 68.07 302.75 4320.91 4263.11 6017258.28 566920.28 2495.59 2305.08 0.00 0.00 MWD+IFR+ 5645.22 68.07 302.75 4337.80 4280.00 6017280.63 566884.79 2536.28 2347.03 0.00 0.00 SBF1-NB 5693.53 68.07 302.75 4355.84 4298.04 6017304.52 566846.88 2579.76 2391.84 0.00 0.00 MWD+IFR+ 5698.78 68.23 302.60 4357.80 4300.00 6017307.12 566842.75 2584.50 2396.72 4.00 319.16 SBE4-NC 5700.00 68.26 302.56 4358.25 4300.45 6017307.71 566841.79 2585.60 2397.85 4.00 319.22 MWD+IFR+ 5769.52 70.38 300.64 4382.80 4325.00 6017341.27 566786.09 2649.00 2462.89 4.00 319.23 SBE2-NE 5800.00 71.32 299.81 4392.80 4335.00 6017355.52 566761.08 2677.21 2491.68 4.00 319.91 MWD+IFR+ 5883.64 73.90 297.58 4417.80 4360.00 6017393.17 566690.72 2755.82 2571.49 4.00 320.18 SBE1-NF 5900.00 74.41 297.15 4422.27 4364.47 6017400.28 566676.68 2771.38 2587.23 4.00 320.85 MWD+IFR+ 5983.14 77.00 295.00 4442.80 4385.00 6017435.00 566604.00 2851.27 2667.79 4.00 320.97 MPE-20 OA 6003.14 77.00 295.00 4447.30 4389.50 6017443.07 566586.26 2870.64 2687.28 0.00 0.00 MWD+IFR+ 6025.00 79.62 294.88 4451.73 4393.93 6017451.91 566566.78 2891.92 2708.68 12.00 357.47 MWD+IFR+ 6050.00 82.62 294.75 4455.59 4397.79 6017462.07 566544.27 2916.48 2733.38 12.00 357.49 MWD+IFR+ 6075.00 85.61 294.62 4458.15 4400.35 6017472.24 566521.58 2941.21 2758.24 12.00 357.51 MWD+IFR+ 6100.00 88.61 294.49 4459.41 4401.61 6017482.40 566498.78 2966.05 2783.21 12.00 357.52 MWD+IFR+ 6116.15 90.55 294.41 4459.53 4401.73 6017488.95 566484.02 2982.11 2799.35 12.00 357.53 MWD+IFR+ 6184.08 90.55 294.41 4458.88 4401.08 6017516.44 566421.91 3049.71 2867.28 0.00 0.00 MWD+IFR+ 6200.00 90.54 293.13 4458.73 4400.93 6017522.72 566407.28 3065.57 2883.20 8.00 269.75 MWD+IFR+ 6250.00 90.52 289.13 4458.26 4400.46 6017540.31 566360.50 3115.51 2933.20 8.00 269.74 MWD+IFR+ 6301.65 90.50 285.00 4457.80 4400.00 6017555.00 566311.00 3167.13 2984.85 8.00 269.71 MPE-20 OA 6400.00 90.48 281.07 4456.96 4399.16 6017576.28 566215.01 3264.97 3083.19 4.00 269.72 MWD+IFR+ 6500.00 90.46 277.07 4456.14 4398.34 6017591.11 566116.15 3363.52 3183.19 4.00 269.69 MWD+IFR+ 6557.45 90.44 274.77 4455.69 4397.89 6017596.50 566058.96 3419.54 3240.64 4.00 269.66 MWD+IFR+ 6600.00 90.44 274.77 4455.36 4397.56 6017599.65 566016.54 3460.83 3283.19 0.00 180.00 MWD+IFR+ 6700.00 90.44 274.77 4454.59 4396.79 6017607.03 565916.82 3557.87 3383.18 0.00 180.00 MWD+IFR+ 6800.00 90.44 274.77 4453.81 4396.01 6017614.42 565817.11 3654.91 3483.18 0.00 180.00 MWD+IFR+ 5pa""""y-5un DRILLING seRVices AJi.UJ.J8l'IITQN~0I\01l'~ . . Sperry-Sun - Draft Copy KW A Planning 7100.00 90.44 274.77 4451.49 4393.69 6017636.57 565517.97 3946.03 3783.17 0.00 180.00 7200.00 90.44 274.77 4450.72 4392.92 6017643.95 565418.25 4043.08 3883.17 0.00 180.00 7300.00 90.44 274.77 4449.95 4392.15 6017651.34 565318.54 4140.12 3983.17 0.00 180.00 7400.00 90.44 274.77 4449.17 4391.37 6017658.72 565218.82 4237.16 4083.16 0.00 180.00 7490.06 90.44 274.77 4448.48 4390.68 6017665.38 565129.02 4324.56 4173.22 0.00 180.00 7500.00 90.42 275.16 4448.40 4390.60 6017666.14 565119.11 4334.21 4183.16 4.00 93.19 7600.00 90.20 279.16 4447.86 4390.06 6017677.68 565019.81 4432.15 4283.16 4.00 93.19 7621.07 90.15 280.00 4447.80 4390.00 6017681.00 564999.00 4452.96 4304.23 4.00 93.21 7680.07 90.09 282.36 4447.67 4389.87 6017691.90 564941.03 4511.44 4363.22 4.00 91.34 7700.00 90.09 282.36 4447.64 4389.84 6017695.98 564921.52 4531.25 4383.16 0.00 0.00 7800.00 90.09 282.36 4447.48 4389.68 6017716.47 564823.66 4630.63 4483.16 0.00 0.00 7900.00 90.09 282.36 4447.31 4389.51 6017736.97 564725.79 4730.01 4583.16 0.00 0.00 8000.00 90.09 282.36 4447.14 4389.34 6017757.46 564627.92 4829.39 4683.16 0.00 0.00 8100.00 90.09 282.36 4446.98 4389.18 6017777.95 564530.05 4928.77 4783.16 0.00 0.00 8200.00 90.09 282.36 4446.81 4389.01 6017798.45 564432.19 5028.16 4883.16 0.00 0.00 8300.00 90.09 282.36 4446.65 4388.85 6017818.94 564334.32 5127.54 4983.16 0.00 0.00 8400.00 90.09 282.36 4446.48 4388.68 6017839.43 564236.45 5226.92 5083.16 0.00 0.00 8500.00 90.09 282.36 4446.32 4388.52 6017859.93 564138.58 5326.30 5183.16 0.00 0.00 8600.00 90.09 282.36 4446.15 4388.35 6017880.42 564040.71 5425.68 5283.16 0.00 0.00 8700.00 90.09 282.36 4445.99 4388.19 6017900.92 563942.85 5525.06 5383.16 0.00 0.00 8792.17 90.09 282.36 4445.83 4388.03 6017919.80 563852.64 5616.66 5475.33 0.00 0.00 8800.00 90.16 282.67 4445.82 4388.02 6017921.43 563844.98 5624.45 5483.16 4.00 78.06 8900.00 90.99 286.58 4444.82 4387.02 6017945.77 563748.03 5724.17 5583.15 4.00 78.06 8986.16 91.69 289.95 4442.80 4385.00 6017972.00 563666.00 5810.29 5669.29 4.00 78.10 9000.00 91.69 289.95 4442.39 4384.59 6017976.60 563652.96 5824.12 5683.12 0.00 180.00 9100.00 91.69 289.95 4439.43 4381.63 6018009.83 563558.70 5924.05 5783.08 0.00 180.00 9200.00 91.69 289.95 4436.48 4378.68 6018043.06 563464.44 6023.98 5883.03 0.00 180.00 9300.00 91.69 289.95 4433.52 4375.72 6018076.30 563370.18 6123.92 5982.99 0.00 180.00 9400.00 91.69 289.95 4430.56 4372.76 6018109.53 563275.92 6223.85 6082.95 0.00 180.00 9500.00 91.69 289.95 4427.61 4369.81 6018142.76 563181.66 6323.79 6182.90 0.00 180.00 9600.00 91.69 289.95 4424.65 4366.85 6018176.00 563087.40 6423.72 6282.86 0.00 180.00 MWD+IFR+ 9700.00 91.69 289.95 4421.69 4363.89 6018209.23 562993.14 6523.65 6382.81 0.00 180.00 MWD+IFR+ 9800.00 / 91.69 289.95 4418.74 4360.94 6018242.46 562898.88 6623.59 6482.77 0.00 180.00 MWD+IFR+ 9831.70 91.69 289.95 4417.80 .¡ 4360.00 6018253.00 562869.00 6655.26 6514.46 0.00 180.00 MPE-20 OA a · TREE: Cameron 2-9/16" 5M WELLHEAD: FMC Gen 5 11",5M Tubing Head: FMC 11-in x 2.875-in 113' 20" 92 Ib/ft, H-40 Welded Insulated 13.375-in 54.5-lblft, K-55, BTC Casing Drift: 12.459-in Casing 10: 12.615-in Coupling 00: 14.375-in Burst: 2,730-psi Collapse: 1, 130-psi 2.875-in 6.5-lblft, L-80, 8rd, EUE Tubing ID: 2.441-in Tubing Capacity: 0.00579-bbl/ft Tensile (100%): 145-k.lbf Burst: 10,570-psi Collapse: 13,870-psi 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75-in Casing 10: 6.875-in Coupling 00: 11. 75-in Burst: 6,890-psi Collapse: 4,790-psi Window in 7.625-in casing @ 5,613-ft MD Well Inclination @ Window = 68 Degrees KB. (N22E) ELEV = 53.8-ft Cellar Box ELEV = 24.7-ft 42" Hole 2.875-in x 1.0-in Gas Lift Mandrel @ 116-ft TVD 16" Hole 13.375-in Window @ 2,480-ft MD, 2,456-ft TVDrkb 2.875-in x 1.0-in GLM Î 2.975-in XN nipple (ID 2.205") Pump, 122 stg. GC2200 Tandem Gas Separator Tandem Seal Section GS83 08 UT/L T IL H6 PFS Aflas/HSN Motor, 171 HP KMH 2390 volt, 44 amp PumpMate Sensor w/6 fin Centralizer 6.75-in NB Lateral 11,037-ft MDI ...... """"- - - -- - - "__.,""_ß'''~W_, r- _ _ -- ---- 7.625" Casing Shoe @ ,983-ft MD, 4,443-ft TVD Well Inclination @ S e = 77 Degrees DATE 24 Mar 2004 REV. BY MDG COMMENTS Level 3 Multi-Lateral, 2.875-in ESP Completion 9.875-in Hole k?~-dO Þ-: 6.125-in OA Lateral - -- ---- - - -- - - 4.5-in Slotted Liner & Hanger WELL: MPE-20A API NO:50-029-????? BP Conductor Casing ~ KOP @ 1200" Max Hole Angle: 13.40 @ 2300 MD 13-3/8" , 54.5 ppf, K-55, Btrc. 2587' 2-7/8" , 6.5 ppf, EUE 8rd tbg. ( capacity = 0.00579 bpf ) 9 5/8" . L-80 production casing 40 ppf NSCC above 4637' MD 47 ppf Btrc below 4637' MD Stimulation Summary: 'N' Sands: 26,900 Ibs.16-20 '0' Sands: 73,000 Ibs 16-20 Perforation Summary: Ref. Log: DLL 6 /6 / 95 Siz Interval 4312' - 4332' 4332' - 4357' 4440' - 4465' 4487' - 4490' 4502' - 4528' 4.5" 4.5" 4.5" 4.5" 4.5" Jumbo Jet ("big hole") 26 gr. charges, 135/45 deg phasing, EHD = 0.74", TIP = 5.8" except for 4487' to 4490' which were 32gm., Alpha Jetw/TIP = 32.1" 0.44" EHD DATE .BY 091 021 95 09/05/96 JBF MPE-20 Proposed B = 53.8' (N22E) GL = 24.7' RKB (N22E) to 9 5/8" Hng. = 30.8' Existing Cement 133/8" EZSV Cement Retainer I -2500' Top of 9 5/8" Casing I -2550' Bottom of Cement 9 5/8"" CIBP 9 5/8"" EZSV Cement Retainer RA Collar at 4229' WLM RKB 9-5/8" Halliburton "VTL" Pkr 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen 9-5/8" Halliburton "VTL Pkr 4.5" Otis X nipple 3.813" id 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen 9-5/8" x 4" bore HES "BWD" 4.5" Otis XN nipple 3.75" Id 4.5" WLEG PBTD COMMENTS ESP I Frac Pack Completion by N 4ES diagram update: MILNE POINT UNIT Well E-20 API NO: 50-029-22561 M. Linder BP EXPLORATION (AK) -2600' -2600' I -4190' -4230" 4249' 4310' 4365' 4366' 4432' 4537' 4553' 4556' 4637' 4681' MPE-20A Cement Program Subject: MPE-20A Cement Program From: "Green, Matt D" <GreenMD@BP.com> Date: Fri, 02 Apr 2004 10:27:39 -0900 To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> J-Ol-\-OS~ Tom, To clarify the cement program for the intermediate casing on MPE-20A; A single slurry of 125-bbl, 576-sx, 15.6-lb/gal Premium G cement will be pumped with a TOC at 500-ft MD above the top Ugnu sand. The lead and tail slurry mentioned in the permit essentially will be the same slurry. Thank you for picking this up. Cheers, .' Matt. Matthew D Green J Drilling Engineer BP Exploration Alaska, MB 4-1 PO Box 196612 Anchorage AK 99519-6612 (W) +1 (907) 564 5581 (M) +1 (907) 529 8501 (F) +1 (907) 564 4441 . 1 of 1 4/2/2004 10:40 AM 6 p 055260 DATE 3/2/2004 . INVOICE I CREDIT MEMO GROSS DESCRIPTION PR022604B PERMIT TO DRILL PPLlCATIONS POUCH TO TERRI UBBLE MB7-5 . -()'¡ I, !~~ I THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE:, AK99519-6612 PAY: . TO THE ORDER OF: NATIONAL CITY BANK Ashland, Ohio ·8... . .......p> tF '.a"· "llhl . ..~..(f.. \,,11'/ STATE OFALASKA AOGCC 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 1110 5 5 2 b 0 III I: 0 ~ . 20 :. B t1 5 I: O. 2 ? B t1 bill DATE 3/2/2004 DATE 3/2/2004 1~~~~~60 I VENDOR DISCOUNT NET H 56-389 4"1"2 No. p 055260 CONSOLIDATED COMMEI~CIAl ACCOUNT I .il AMOUNT "~****$1 OO,OO*****r NOT VALID AFTER 120 DAYS C;·\;:~::;::~;::;~f~ ~..,..",1;".'~"~'T_;",.",,"._,~.' . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHSTO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /1'lPd E-ZDÆ PTD# 20c/ - ôs-L( / Development Service ~~Ñ '--\ Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a Dew wellboresegment of LATERAL existing well . Permit No, API No. . (If API Dum ber Production. sbould continue to be reported as last two (2) digits a function· of tbe original API number. stated are between 60-69) above. PILOT BOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Companv Name) assumestbe liability of any protest 10 tbe spaCÎngexception tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals tbrough target zones. w~ Cf/¡/1- Geologic Commissioner: Date: Engineering Commissioner: Date b Appr SFD Date 3/31/2004 35 36 37 38 39 Contact namelphoneJorweelsly progress reports [exploratory 9nlYl Setsmic.analysis of shaJlow gas zones .Seabed .condition survey (if Off-shore) No Yes NA NA NA Hydrates e.xpected Producer in a maturing S6 d , Expected pressure-9ra.dient.~ .... y" .....-v I:, JromJ80Q' TVDss.to 3QOO'; ,~o "'I:. nnn EMW;.wil! be.driUedwith.9, p-pg mud diSGussed in. driJling bazar.ds section. 1 Geology Date TEM 3/31/2004 ~~, Appr 8 9 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Permit Data presented on pote.ntial oveJpressure .zones can be tssued w/o hydrogen sulfide measures wells within AOR yertfied (for.s.ervjce wel) onJy) Js pres.ence. of Meçha.nical condit[on of H2$ gas. prob.able .BOPEs,do .B.OPE.presstest to.(pu.t .C.hokemanifold compJies w/APIRP-53 (May 84) Work wíll occur withOyt rating appropriate; .they meet Jf.djverter Jequired, does jt .meet reguJations. .DJiUing fluid program sGhematic.& equip Jistadequate .Adequate .tankage. OJ Rare-drilL hasa 1.0-403 for abandonment .Adequate well bore sepªratjo.n .proposed been apPJoved re.serye pit coyer.aU .C.asing designs ªdeQya.te for koo.wnproductiye borizons C,T, B.& permafr.ost CMT CMT .CMTwill v.ol adeq u.ate. to tie-tnJong .string to surf csg. known. USDWs v.ol adequate. to Ci rc.u late. on .cond.uctor. 8< surf csg Yes NA Yes No No. Yes Yes Yes Yes NA Yes Yes Yes Yes Yes No NA Rig ts.eQyipped with sensors and.aJarms. .operation .shutdown Mud should preclude. any H2S 00 rig. reguJatioo psig tn.comments) CalcuJated.MASP 1.477 psi. Surface Maximum BHP 8..6EMW. Plaon.ed m.ud weight9.3. p-pf. Plaon.ed .Bpp.test pressure 3500 psi. castn9 alre.ady in place. Rig js equipped with steelpjts. 3Q4~0.56, approve.d .2/2.5l04 .well(s) No rese.rve.pit-planned. All waste to.Class I slotted liner completioo planned in orjginal well, Surface castng weJI. aquifers ecempted 40 cm :147..1.02 cemented .to surface .(b) (3) Engineering . Appr SFD 3/31/2004 Date Administration 2 3 4 5 6 7 8 9 10 11 12 13 14 5 6 7 .C.onductor string. .Surfacecasing. pJotects all .AII welJs. withtn J l4.mile.area.of reyiew jdentified (For servic.e .we Pre-produ.ced injector; duration.of pre--production less thªn 3 months ACMP findjng .of Con.sistency has bee.n issued. for. tbis project PJovided # (puUOil only). . _ (forserytce well only) Permit c.an be tssued wjthout Permit can be tssued wjthout Can permit Well located wtthin area and. strata .authortzed bY.lnjectioo Prder be approved before ªdmioistratille. approvaJ bas. appropriate. bond tnJorce co.nserva.tion order .O-perator .O-perator .S.ufficient If.deviªted, is. weJlbore platiocJuded only affected party other welJs acreage.ayªilable indJílIing unit Well Well Well located proper distance. located proper distance. from from driJling unit boundary .U.nique welt located Permit fee ªttached Lease number .appropriate n.ame .and numb.er ina defined -pool INC MILNE POINT, SCHRADER BLFF OIL - 525140 15-day wait nitial ClasslType Yes .Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA NA Conductor set All Re-drj of existing well in ongjn.al in. comments). (For $Ghra.der. 61yff Oil F'ool: 1 Q-acre spaciog (Quarter-quarter~quarteJ section) Lieswithin area affected.by CPA}? Lies inside.Schrader.BJuffPA. Surface an.dTop Prod Interval in.ADL2551.8; Well Name: MILNE PT UNIT SB E-20A DEV / PEND GeoArea 890 TD [nADLAl437 Unit 11328 Program DEV ~__~ Well bore seg On/Off Shore On Annular Disposal o o e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 11 10:21:31 2004 Reel Header Service name...... . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name.. . . . . .UNKNOWN Comments................ .STS LIS Writing Library. )? ~- ( ~ Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPE-20A 500292256101 B.P. Exploration (Alaska) rInc. Sperry-Sun Drilling Services 11-JUN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003034600 C.A. DEMOSKI E. VAUGHN MWD RUN 3 MW0003034600 C.A. DEMOSKI E. VAUGHN MWD RUN 2 MW0003034600 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 25 UN 10E 3637 1955 58.55 24.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 9.875 6.125 DRILLERS DEPTH (FT) 2457.0 5993.0 CASING SIZE (IN) 13.375 7.625 # ?-()'-l~ ()-) '-1 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK; MILL THE WINDOW; AND DRILL OUT. THE TOP OF THE WHIPSTOCK WAS AT 2457'MD AND THE BOTTOM WAS AT 2481'MD. UPHOLE TIE-IN SGRC DATA WERE ACQUIRED WHILE RIH FOR THIS RUN. 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD); AND AT-BIT INCLINATION (ABI). 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 3' DOWNHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 3 JUNE 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL MPE-20A WITH API#: 50-029-22561-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9878'MD/4415'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/06/11 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2395.5 STOP DEPTH 9825.5 ROP FET RPD RPM RPS RPX $ 2460.0 2467.5 2467.5 2467.5 2467.5 2467.5 9881.0 9832.5 9832.5 9832.5 9832.5 9832.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 2395.5 9881.0 $ GR 2392.5 9878.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 2392.5 2506.0 5993.0 MERGE BASE 2506.0 5993.0 9878.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................. ...60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2395.5 9881 6138.25 14972 2395.5 9881 ROP MWD FT/H 0.06 821. 89 201.331 14843 2460 9881 GR MWD API 12.73 128.07 68.4184 14797 2395.5 9825.5 RPX MWD OHMM 1. 37 1786.81 12.0986 14731 2467.5 9832.5 RPS MWD OHMM 1. 37 2000 12.8624 14731 2467.5 9832.5 RPM MWD OHMM 0.76 2000 15.9764 14731 2467.5 9832.5 RPD MWD OHMM 1. 32 1847.15 14.5312 14731 2467.5 9832.5 FET MWD HOUR 0.09 60.34 1.16054 14731 2467.5 9832.5 First Reading For Entire File......... .2395.5 Last Reading For Entire File.......... .9881 File Trailer Service name............ .STSLIB.001 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .04/06/11 Maximum Physical Record..65535 File Type............... .LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 2392.5 2457.0 STOP DEPTH 2441.0 2506.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 23-APR-04 Insite 66.37 Memory 2506.0 2457.0 2506.0 12.9 12.9 TOOL NUMBER 53519 11 . 625 .0 LSND 9.00 82.0 8.3 2850 5.0 .000 .000 .000 .0 77.0 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units....... ....Feet Data Reference Point...... ...... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2392.5 2506 2449.25 228 2392.5 2506 ROP MWD010 FT/H 0.06 12.09 6.02939 99 2457 2506 GR MWD010 API 12.73 18.48 15.2604 98 2392.5 2441 First Reading For Entire File......... .2392.5 Last Reading For Entire File.......... .2506 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ header data for each bit run in separate files. 2 .5000 START DEPTH 2464.5 2464.5 2464.5 2464.5 2464.5 2473.5 2506.5 STOP DEPTH 5949.5 5949.5 5949.5 5949.5 5949.5 5957.5 5993.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down 25-APR-04 Insite 66.37 Memory 5993.0 2506.0 5993.0 12.7 87.0 TOOL NUMBER 120558 134760 9.875 2481.0 LSND 9.30 59.0 9.0 3050 5.8 .700 .490 1.300 1. 450 77.0 113.0 70.0 65.0 Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2464.5 5993 4228.75 7058 2464.5 5993 ROP MWD020 FT/H 0.57 821. 89 226.495 6974 2506.5 5993 GR MWD020 API 14.77 123.41 63.3036 6969 2473.5 5957.5 RPX MWD020 OHMM 1. 37 53.21 6.66119 6971 2464.5 5949.5 RPS MWD020 OHMM 1. 37 63.31 7.53993 6971 2464.5 5949.5 RPM MWD020 OHMM 1. 39 123.4 8.01874 6971 2464.5 5949.5 RPD MWD020 OHMM 1. 43 204.76 8.45503 6971 2464.5 5949.5 FET MWD020 HOUR 0.09 35.83 0.985884 6971 2464.5 5949.5 First Reading For Entire File......... .2464.5 Last Reading For Entire File.......... .5993 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/06/11 Maximum Physical Record. .65535 File Type........ ....... .LO Next File Name.... .... ...STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/06/11 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 4 header data for each bit run in separate files. 3 .5000 START DEPTH STOP DEPTH RPD RPM RPS RPX FET GR ROP $ 5950.0 5950.0 5950.0 5950.0 5950.0 5958.0 5993.5 9829.5 9829.5 9829.5 9829.5 9829.5 9822.5 9878.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing............. ...... ..60 .1IN Max frames per record......... ....Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...o 30-APR-04 Insite 66.37 Memory 9878.0 5993.0 9878.0 80.1 98.2 TOOL NUMBER 129046 162742 6.125 5993.0 Oil Based 9.10 78.0 .0 34000 .0 .000 .000 .000 .000 .0 122.8 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5950 9878 7914 7857 5950 9878 ROP MWD030 FT/H 3.02 457.07 181.232 7770 5993.5 9878 GR MWD030 API 37.3 128.07 73.7036 7730 5958 9822.5 RPX MWD030 OHMM 4.58 1786.81 16.9831 7760 5950 9829.5 RPS MWD030 OHMM 4.68 2000 17.6437 7760 5950 9829.5 RPM MWD030 OHMM 0.76 2000 23.125 7760 5950 9829.5 RPD MWD030 OHMM 1. 32 1847.15 19.9896 7760 5950 9829.5 FET MWD030 HOUR 0.2 60.34 1.31744 7760 5950 9829.5 First Reading For Entire File......... .5950 Last Reading For Entire File.......... .9878 File Trailer Service name........ .... .STSLIB.004 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .04/06/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.. ........ .STSLIB.005 Physical EOF Tape Trailer Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........ ....... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number.... ..01 Next Reel Name.......... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File