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Home My WebLink About205-067CAUTION: 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: PWI MPE-12 (PTD #2050670) Missed 4-year MIT-IA Date:Tuesday, September 30, 2025 3:18:36 PM From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Tuesday, September 30, 2025 2:09 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: NOT OPERABLE: PWI MPE-12 (PTD #2050670) Missed 4-year MIT-IA Mr. Wallace PWI MPE-12 (PTD #2050670) is currently shut in and was not brought online for its scheduled 4-year MIT-IA that was due in September. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank You. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-12 (PTD 205-067) Coil 08/13/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/14/2021 By Abby Bell at 3:24 pm, Oct 14, 2021 MEMORANDUM TO: Jim Regg P.I. Supervisor J "K �I ,,/�� FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 5, 2021 SUBJECT: Mechanical Integrity Tests NIcorp Alaska, LLC E-12 MILNE PT UNIT E -I2 Src: Inspector Reviewed By: P.I. Supry Comm Well Name MILNE PT UNIT E-12 API Well Number 50-029-23262-00-00 Inspector Name: Lou Laubenstein Permit Number: 205-067-0 Inspection Date: 9/28/2021 ✓ Insp Num: mitLOL210928112002 Rel Insp Num: Notes: Tuesday, October 5, 2021 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-12 T e In W - TVD 4325 Tubing867 868 872 873 PTD 2050670 Type Test', SPT -Test psi 1500 IA 142 1812 1735 1735 j BBL Pumped: 1.9 - BBL Returned: 1.9 QA 336 341 342 342 - Interval) 4YRTST P/F-- P Notes: Tuesday, October 5, 2021 Page 1 of I 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: Set Cement Retainer 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 9,297 feet N/A feet true vertical 4,451 feet N/A feet Effective Depth measured 7,480 feet feet true vertical 4,476 feet 4,301, 4,325 & 4,435 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 / TC-II 6,633' 4,439' Packers and SSSV (type, measured and true vertical depth)Baker Premier x 2 & ZXP 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: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 6,226, 6,288 & 6,614 777-8343 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 2,670psi 3,090psi 5,410psi 7,500psi Burst 5,380psi 5,750psi 7,240psi 8,430psi Surface Production 13-3/8" 9-5/8" 7" 3,246' 115' measured N/A Liner Casing Conductor Size Junk Length 6,761' MILNE PT UNIT E-12 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Casing Pressure Tubing Pressure 0 N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-382 727 Authorized Signature with date: David Haakinson dhaakinson@hilcorp.com 580 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-067 50-029-23262-00-00 Plugs ADL0025518 / ADL0028231 / ADL0047437 / ADL0047438 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 351232 measured 3,246' 2,703' 140 WINJ WAG 0 Water-Bbl MD 115' 2,653' 4,461' 4,451' Hilcorp Alaska LLC TVD 115' Oil-Bbl measured true vertical Packer 9,297'4-1/2" 6,761' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:37 am, Sep 02, 2021 Chad Helgeson (1517) 2021.09.02 07:42:47 - 08'00' RBDMS HEW 9/2/2021 SFD 9/2/2021DSR-9/2/21MGR11OCT2021 Well Name Rig API Number Well Permit Number Start Date End Date MP E-12 CTU 50-029-23262-00-00 205-067 8/13/2021 8/14/2021 No operations to report. Cement retainer set @ 7,595' MD. Pumped 5 bbls FW spacer, 11 bbls of 12 ppg cement, and 5 bbls of FW spacer. Chase cement w/KCI. Pumped 10 bbls of cement below retainer @ 7,595' MD. Unsting from retainer and layed in 1 bbl of cement, estimated TOC = 7,480' MD. Pooh w/BHA pumping pipe displacement. Freeze protected tubing while Pooh w/28 bbls of diesel 3,222' MD / 2,650' TVD. RDMO CTU9. E-12 & E-32 left S/I on departure, cement wet time = 23:44 pm on 8/13/21, 100 psi compressive strength = 16 hours, 24 minutes as per HES lab report. 8/14/2021 - Saturday No operations to report. 8/17/2021 - Tuesday 8/15/2021 - Sunday No operations to report. 8/16/2021 - Monday 8/13/2021 - Friday MIRU, MU BOT MHA and Read logging tools. RIH to 8,000', Log from 8,000-6,300'. Painted White flag at 7,595' while logging OOH. POOH with logging tools and download data. +20' correction verified by OE. Corrected EOP = 7,604.39'. MU BHI Cement Retainer BHA. RIH to flag, correct counter to COE. Set BHI Cement Retainer COE @ 7,595' MD. Establish baseline injection down coil through retainer .5 bpm @ 830 psi. Pad op shut in E-32 producer for cement job. Continued on 8/14/21 WSR. 8/11/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/12/2021 - Thursday No operations to report. _____________________________________________________________________________________ Revised By: DH 8/31/2021 SCHEMATIC Milne Point Unit Well: MPU E-12 Last Completed: 9/14/2005 PTD: 205-067 TD =9,297 (MD) / TD =4,415’(TVD) 13-3/8” Cement Retainer set @ 7,595’ MD on 8/14/2021 Estimated TOC @ 7,480’ Orig.DF Elev.: 57.35’/ GL Elev.: 33.95’ (Doyon 14) 7” 3 9 8 7 11, 12 & 13 4 14, 15, 16 & 17 9-5/8” 1 2 PBTD = 9,253’(MD) / PBTD =4,457’(TVD) 6 ‘OA’ Sands 4-1/2” 5 10 ‘ND’ Sands ‘NC’ Sands CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 72 / K-55 / N/A N/A 0 112’ 9-5/8" Surface 40 / L-80 / Btc. 8.679 0 3,246’ 7" Intermediate 26 / L-80 / BTC Mod 6.276 0 6,761’ 4-1/2” Liner 12.6/ L-80 / IBT 3.958 6,594’ 9,297’ TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / TC-II 2.992 0 6,633’ JEWELRY DETAIL No Depth Item 1 2,494’ 3.5”HES X Nipple, ID= 2.813” 2 6,176’ 3.5”HES X Nipple, ID= 2.813” 3 6,226’ 7” x 3.5” Baker Premier Packer 4 6,251’ 3.5”HES X Nipple, ID= 2.813” 5 6,267’ Unique Machine Overshot 6 6,276’ Top of cut – Pup joint stub 7 6,288’ 7” x 3.5” Baker Premier Packer 8 6,370’ 3.5” x 1.5” Camco MMG (RK) / (DGLV),set 2/23/16 9 6,430’ 3.5” x 1.5” Camco MMG-W (RK) / DGLV set 6-12-21 10 6,583’ 3.5”HES XN Nipple,ID= 2.750” 11 6,600’ Baker Locator Sub 12 6,602’ Baker 806-40 Seal Assembly -Bottom @ 6,633’ 13 6,606 Baker Tie Back Sleeve 14 6,614’ Baker ZXP Packer 15 6,616’ Baker “RS” Nipple 16 6,623’ Baker HMC Liner Hanger 17 6,643’ Baker 80-40 Seal Bore Ext. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ND Sands 6,375’ 6,390’ 4,358’ 4,363’ 15 6/6/2005 Open NC Sands 6,410’ 6,437’ 4,371’ 4,381’ 17 6/6/2005 Open OA Sands 6,828’ 6,888’ 4,470’ 4,472’ 60 7/9/2016 Open 6,918’ 6,948’ 4,472’ 4,472’ 30 7/9/2016 Open 7,638’ 7,698’ 4,474’ 4,472’ 60 7/8/2016 Isolated 7,718’ 7,778’ 4,472’ 4,470’ 60 7/8/2016 Isolated 8,668’ 9,168’ 4,477’ 4,467’ 500 6/6/2005 Isolated ND & NC Sands perfed with 4.5” HSD 6 SPF PJ4505 / OA Sands perfed with 2-7/8” HSD 6spf PJ2906 OPEN HOLE / CEMENT DETAIL 13-3/8" 260 sx of Arcticset I in 18” Hole 9-5/8" 384 sx AS Lite, 408 sx Class “G” in 12-1/4” Hole 7” 351 sx Class “G” in 8-1/2” Hole 4.1/2” 315 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 250’ Angle passes 50 deg. @ 2,400’ Max Hole Angle in Tubing = 79 deg. @ 6,659’ Angle through Liner = 90+ deg. TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 3-1/8” 5M FMC Gen 5 Tubing Hgr. 11” x 3-1/8” TC-II T&B 3” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23262-00-00 Drilled, Cased and Completed by Doyon 14 - 6/8/2005 RWO to Correct Tbg Leak By Nabors 4ES – 9/14/2005 CT FCO & Perf Add – 7/9/2016 Lower perfs isolated – 8/14/2021 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/06/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL MPU E-12 (PTD 205-067) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 08/10/2021 37' (6HW By Abby Bell at 4:04 pm, Aug 06, 2021 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: Set Cement Retainer 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,297'N/A Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng David Haakinson 477.05 Baker Premier x 2 & ZXP and N/A 6,226 MD / 4,301 TVD, 6,288 MD / 4,325 TVD & 6,614 MD / 4,435 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 9,297'4-1/2" 3-1/2" Perforation Depth MD (ft): See Schematic 4,461' 4,451' 9.2# / L-80 / TC-II 2,703' 6,761' 2,653' Tubing Grade: 3,246' 6,761' See Schematic 115' 13-3/8" 9-5/8" 7" 3,246' 115' 115' TVD Burst 6,633 MD N/A 8,430psi 5,750psi 7,240psi 205-067 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23262-00-00 Hilcorp Alaska LLC MILNE PT UNIT E-12 4,457' 1,158 N/A MILNE POINT / SCHRADER BLUFF OIL PRESENT WELL CONDITION SUMMARY Length Size 4,451' 9,253' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025518 / ADL0028231 / ADL0047437 / ADL0047438 COMMISSION USE ONLY Authorized Name: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: Authorized Signature: 8/8/2021 ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 10:24 am, Jul 30, 2021 321-382 Digitally signed by Tom Fouts (1614) DN: cn=Tom Fouts (1614), ou=Users Date: 2021.07.30 10:17:09 -08'00' Tom Fouts (1614) 10-404 DSR-8/2/21SFD 7/30/2021MGR02AUG2021 dts 8/2/2021 JLC 8/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.02 14:14:50 -08'00' RBDMS HEW 8/3/2021 CT Memory IPROF Well: MPU E-12 7-29-2021 Well Name:MPU E-12 API Number: 50-029-23262-00-00 Current Status:Water Injector Pad:Milne Point E-Pad Estimated Start Date:August 8th, 2021 Rig:Coiled Tubing Unit Reg.Approval Req’std?No Date Reg. Approval Rec’vd:N/A Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:205-067 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE: Job Scope:MBE Remediation Current Bottom Hole Pressure:1,558 psi @ 4,000’ TVD SBHP 03/11/2019 |7.5 PPGE Maximum Expected BHP:1,558 psi @ 4,000’ TVD MPSP:1,158 psi (Based on 0.1 psi/ft) MIN ID:2.75” @ 6,583’ MD Max Inclination 90-97° Horizontal Liner Brief Well Summary: MPU E-12 was drilled with Doyon #14 in 2005 as a horizontal injector in the Schrader Bluff ND/NC and OA sands and provides support in hydraulic unit 17 for offset producers MPU E-31 and MPU E-32. The well developed a tubing leak and was repaired in 2005 by RWO. The well has had several MBE treatments that have been treated with limited success. The last MBE treatment was in 2014. In 2016, CT performed FCO with motor & mill and cleaned out the liner to 8,491’ MD and added 210’ perfs in OA sand. In October 2019, with NC/ND sands isolated, red dye was injected into OA only. The dye showed up at E-32 in 5 hours, indicating a new MBE has formed. Subsequent IPROFs and packer testing identified the MBE and >90% of the injection flow to be exiting through the toe of the liner below the perforations at 7,778’ MD. Packer isolation tests identified possible flow behind the liner up-hole through the perforations at 7,638’ MD. Thus, the plan is to isolate the additional perforations to increase the probability of success. The expected post-work injectivity is ~400 BWPD at 700 psi injection pressure. Additional perforations can be added later if an increase in injectivity is needed. Well-work Objective: 1. Set Cement Retainer and Isolate Notes Regarding the Well x Obstruction at 8,100’ CTMD. Initial 06/2021 IPROF set down at 8,021’ MD. x Confirmed MBE between MPE-12 and MPE-32 (ESP Oil Producer) using Red Dye Test. o Present analysis suspects the MBE to be between 7,638’ to 7,698’ MD. x Previous MBE treatment was found between 8,810’ and 8,850’ MD in 2012. o Additional perforations were added up-hole after two failed cement squeeze treatments x IPROF indicated MBE location is below the perforations at 7,778’ MD, but likely flow behind pipe to the MBE feature exists through the perforations to 7,638’ MD. x A 12 PPG cement is requested to reduce the potential for exceeding frac pressure. Coiled Tubing Procedure CT Memory IPROF Well: MPU E-12 7-29-2021 Run 1: Cleanout / SBG Treatment Run 1. Make sure E-12 is shut-in 48 hours in advance of wellwork. 2. MIRU Coiled Tubing Unit and spot auxiliary equipment. 3. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min High, 5 min Low each test. a. If BOPE test has not been completed in last 7 days, test BPE to 250 psig low / 2,500 psig high. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. e. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 4. Well is to remain shut-in for the duration of the job. 5. RIH with 2” CT and memory GR/CCL to 8,000’ MD. 6. Pull up-hole to 7,600’ MD. 7. Paint Flag 8. POOH to surface and review the log with the engineer for any depth adjustments. 9. Confirm cement mixing unit is ready for pumping. 10. Shut in and freeze protect offset producer E-32. 11. MU cement retainer BHA. 12. RIH and set Cement Retainer at 7,600’ MD, 38’ up-hole from the perforations at 7,638’ MD. 13. Inject down coiled tubing string at 0.3 BPM and establish a baseline injection and treatment pressure. 14. Mix 11 bbls of 12.0 PPG Cement (Fine-Cem or equivalent) a. Collect Cement Sample to hold for setup time and quality. 15. Pump cement treatment volumes as outlined below. a. Pump cement treatment volumes as outlined below i. Source (Fresh) Water Spacer ii. 10 bbls of 12.0 PPG Fine-Cem Cement. iii. Source (Fresh) Water Spacer b. Volume Assumptions: i. CT Capacity: 2” x 0.175” WT = .002645 BBL/FT ii. Pipe/Hole Volumes: 1. 7.6 bbls to 8,100’ MD Tag/Obstruction 2. 13.6 bbls to known bottom at 8,491’ MD. 16. When cement hits the nozzle, pump at minimum rate (0.25-0.3 BPM) to allow cement to find path of least resistance and not be forced into the rock matrix. a. Max treatment pressure: 1200 psi 17. Pick up and un-sting from cement retainer. a. If cement retainer is un-stung early, contaminate cement with at least 3x bottoms up. 18. Pump remaining 1 bbl of cement on top of retainer as CT pulls out ~65’ at 15 FPM. a. Trap CT x Tubing pressure as the 1-bbl of cement is pumped. 19. Pick up to 7,500’ MD. 20. Allow cement to gain compressive strength. 21. Slowly pressure up CT and T by 100 psi to compress cement plug. CT Memory IPROF Well: MPU E-12 7-29-2021 22. POOH, jetting liner and tubing to surface. 23. RD CTU and auxiliary equipment. 24. Turn well over to operations. 25. Leave MPU E-12 and E-32 shut in for 48 hours. _____________________________________________________________________________________ Revised By: TDF 7/30/2021 SCHEMATIC Milne Point Unit Well: MPU E-12 Last Completed: 9/14/2005 PTD: 205-067 ± TD =9,297(MD) / TD =4,415’(TVD) 13-3/8 ” CT FCO to 8,491’ 7/7/2016 Orig.DF Elev.: 57.35’/ GL Elev.: 33.95’ (Doyon 14) 7” 3 9 8 7 11, 12 & 13 4 14, 15, 16 & 17 9-5/8 ” 1 2 PBTD =9,253’ (MD) / PBTD = 4,457’(TVD) 6 4-1/2” 5 10 ‘OA’ Sands ‘ND’ Sands ‘NC’ Sands CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 72 / K-55 / N/A N/A 0 112’ 9-5/8" Surface 40 / L-80 / Btc. 8.679 0 3,246’ 7" Intermediate 26 / L-80 / BTC Mod 6.276 0 6,761’ 4-1/2” Liner 12.6/ L-80 / IBT 3.958 6,594’ 9,297’ TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / TC-II 2.992 0 6,633’ JEWELRY DETAIL No Depth Item 1 2,494’ 3.5”HES X Nipple, ID= 2.813” 2 6,176’ 3.5”HES X Nipple, ID= 2.813” 3 6,226’ 7” x 3.5” Baker Premier Packer 4 6,251’ 3.5”HES X Nipple, ID= 2.813” 5 6,267’ Unique Machine Overshot 6 6,276’ Top of cut – Pup joint stub 7 6,288’ 7” x 3.5” Baker Premier Packer 8 6,370’ 3.5” x 1.5” Camco MMG (RK) / (DGLV),set 2/23/16 9 6,430’ 3.5” x 1.5” Camco MMG-W (RK) / DGLV set 6-12-21 10 6,583’ 3.5”HES XN Nipple,ID= 2.750” / 11 6,600’ Baker Locator Sub 12 6,602’ Baker 806-40 Seal Assembly -Bottom @ 6,633’ 13 6,606 Baker Tie Back Sleeve 14 6,614’ Baker ZXP Packer 15 6,616’ Baker “RS” Nipple 16 6,623’ Baker HMC Liner Hanger 17 6,643’ Baker 80-40 Seal Bore Ext. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ND Sands 6,375’ 6,390’ 4,358’ 4,363’ 15 6/6/2005 Open NC Sands 6,410’ 6,437’ 4,371’ 4,381’ 17 6/6/2005 Open OA Sands 6,828’ 6,888’ 4,470’ 4,472’ 60 7/9/2016 Open 6,918’ 6,948’ 4,472’ 4,472’ 30 7/9/2016 Open 7,638’ 7,698’ 4,474’ 4,472’ 60 7/8/2016 Open 7,718’ 7,778’ 4,472’ 4,470’ 60 7/8/2016 Open 8,668’ 9,168’ 4,477’ 4,467’ 500 6/6/2005 Open ND & NC Sands perfed with 4.5” HSD 6 SPF PJ4505 / OA Sands perfed with 2-7/8” HSD 6spf PJ2906 OPEN HOLE / CEMENT DETAIL 13-3/8" 260 sx of Arcticset I in 18” Hole 9-5/8" 384 sx AS Lite, 408 sx Class “G” in 12-1/4” Hole 7” 351 sx Class “G” in 8-1/2” Hole 4.1/2” 315 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 250’ Angle passes 50 deg. @ 2,400’ Max Hole Angle in Tubing = 79 deg. @ 6,659’ Angle through Liner = 90+ deg. TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 3-1/8” 5M FMC Gen 5 Tubing Hgr. 11” x 3-1/8” TC-II T&B 3” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23262-00-00 Drilled, Cased and Completed by Doyon 14 - 6/8/2005 RWO to Correct Tbg Leak By Nabors 4ES – 9/14/2005 CT FCO & Perf Add – 7/9/2016 _____________________________________________________________________________________ Revised By: TDF 7/30/2021 PROPOSED Milne Point Unit Well: MPU E-12 Last Completed: 9/14/2005 PTD: 205-067 TD =9,297(MD) / TD =4,415’(TVD) 13-3/8 ” Cement Retainer set @ 7,600’ MD Orig.DF Elev.: 57.35’/ GL Elev.: 33.95’ (Doyon 14) 7” 3 9 8 7 11, 12 & 13 4 14, 15, 16 & 17 9-5/8 ” 1 2 PBTD =9,253’ (MD) / PBTD = 4,457’(TVD) 6 ‘OA’ Sands 4-1/2” 5 10 ‘ND’ Sands ‘NC’ Sands CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 72 / K-55 / N/A N/A 0 112’ 9-5/8" Surface 40 / L-80 / Btc. 8.679 0 3,246’ 7" Intermediate 26 / L-80 / BTC Mod 6.276 0 6,761’ 4-1/2” Liner 12.6/ L-80 / IBT 3.958 6,594’ 9,297’ TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / TC-II 2.992 0 6,633’ JEWELRY DETAIL No Depth Item 1 2,494’ 3.5”HES X Nipple, ID= 2.813” 2 6,176’ 3.5”HES X Nipple, ID= 2.813” 3 6,226’ 7” x 3.5” Baker Premier Packer 4 6,251’ 3.5”HES X Nipple, ID= 2.813” 5 6,267’ Unique Machine Overshot 6 6,276’ Top of cut – Pup joint stub 7 6,288’ 7” x 3.5” Baker Premier Packer 8 6,370’ 3.5” x 1.5” Camco MMG (RK) / (DGLV),set 2/23/16 9 6,430’ 3.5” x 1.5” Camco MMG-W (RK) / DGLV set 6-12-21 10 6,583’ 3.5”HES XN Nipple,ID= 2.750” / 11 6,600’ Baker Locator Sub 12 6,602’ Baker 806-40 Seal Assembly -Bottom @ 6,633’ 13 6,606 Baker Tie Back Sleeve 14 6,614’ Baker ZXP Packer 15 6,616’ Baker “RS” Nipple 16 6,623’ Baker HMC Liner Hanger 17 6,643’ Baker 80-40 Seal Bore Ext. PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ND Sands 6,375’ 6,390’ 4,358’ 4,363’ 15 6/6/2005 Open NC Sands 6,410’ 6,437’ 4,371’ 4,381’ 17 6/6/2005 Open OA Sands 6,828’ 6,888’ 4,470’ 4,472’ 60 7/9/2016 Open 6,918’ 6,948’ 4,472’ 4,472’ 30 7/9/2016 Open 7,638’ 7,698’ 4,474’ 4,472’ 60 7/8/2016 Isolated 7,718’ 7,778’ 4,472’ 4,470’ 60 7/8/2016 Isolated 8,668’ 9,168’ 4,477’ 4,467’ 500 6/6/2005 Isolated ND & NC Sands perfed with 4.5” HSD 6 SPF PJ4505 / OA Sands perfed with 2-7/8” HSD 6spf PJ2906 OPEN HOLE / CEMENT DETAIL 13-3/8" 260 sx of Arcticset I in 18” Hole 9-5/8" 384 sx AS Lite, 408 sx Class “G” in 12-1/4” Hole 7” 351 sx Class “G” in 8-1/2” Hole 4.1/2” 315 sx Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 250’ Angle passes 50 deg. @ 2,400’ Max Hole Angle in Tubing = 79 deg. @ 6,659’ Angle through Liner = 90+ deg. TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 3-1/8” 5M FMC Gen 5 Tubing Hgr. 11” x 3-1/8” TC-II T&B 3” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23262-00-00 Drilled, Cased and Completed by Doyon 14 - 6/8/2005 RWO to Correct Tbg Leak By Nabors 4ES – 9/14/2005 CT FCO & Perf Add – 7/9/2016 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type MPU B-13 500292134800 185-093 6/25/21 IPROF MPU E-12 500292326200 205-067 6/21/21 IPROF MPU J-27 500292355700 215-153 6/4/21 Multi Finger Caliper MPU K-06 500292272500 196-191 3/14/21 Leak Detect Log MPU L-29 500292254300 195-009 6/23/21 Multi Finger Caliper Please include current contact information if different from above. Received By: 07/14/2021 37' (6HW By Abby Bell at 2:44 pm, Jul 14, 2021 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/13/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type MPU L-06 50029220030000 190010 5/26/21 Caliper Survey MPU J-23A 50029229700100 215154 7/3/21 Injection Profile MPU E-12 50029232620000 205067 6/26/2021 Coil Flag MPU J-24A 50029229760100 216120 7/4/21 Injection Profile Please include current contact information if different from above. eived By: 07/13/2021 37' (6HW By Abby Bell at 3:30 pm, Jul 13, 2021 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,October 03,2017 Jim Regg P.I.Supervisor .&� 10/4l/ l 7 SUBJECT: Mechanical Integrity Tests ( HILCORP ALASKA LLC E-12 FROM: Chuck Scheve MILNE PT UNIT E-12 Petroleum Inspector Src: Inspector Reviewed By: pp P.I.Supry ,jp`— — NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT E-12 API Well Number 50-029-23262-00-00 Inspector Name: Chuck Scheve Permit Number: 205-067-0 Inspection Date: 9/18/2017 Insp Num: mitCS170918142508 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j E-12 Type Inj W TVD 4325 Tubing 1126 1126" 1126 ' 1125 PTD 2050670 Type Test SPT Test psi 1500 " IA 458 2104 2018 1996 BBL Pumped: 1L5 BBL Returned: 1.6 OA 312 316 - 315" 315 - Intervale 4YRTST P/F P Notes: SCANNEC/ 4 "" Tuesday,October 03,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg q DATE: Thursday,September 21,2017 P.I.Supervisor ' `4q "( ''(1 7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC E-12 FROM: Chuck Scheve MILNE PT UNIT E-12 Petroleum Inspector Src: Inspector Reviewed P.I.Supry— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT E-12 API Well Number 50-029-23262-00-00 Inspector Name: Chuck Scheve Permit Number: 205-067-0 Inspection Date: 9/18/2017 Insp Num: mitCS170918142508 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-12 1Type Inj W TVD 4265 " Tubing 1126 - 1126 • 1126 - 1125 - PTD 2050670 - Type Test SPT Test psi 1500 IA 458 2104 - 2018 • 1996 - BBL Pumped: 1.5 - BBL Returned: 1.6 - OA 312 316 315 315 - Intervall 4YRTST P/F P ✓� Notes: SCANNEDTE 14 2O<<3 Thursday,September 21,2017 Page 1 of 1 STATE OF ALASKA Al OIL AND GAS CONSERVATION COM SION e REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool Li Repair Well Li Re-enter Susp Well ❑ Other: CT FCO ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory❑ 205-067 3.Address: Stratigraphic❑ Service Q 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23262-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 1 ADL0047438 I ADL0047437 I ADL0025518 MILNE PT UNIT SB E-12 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 9,297 feet Plugs measured N/A RECEIVED true vertical 4,451 feet Junk measured N/A feet y 2Q16 6,226,6,288& AUG 1 Effective Depth measured 9,253 feet Packer measured 6,614 feet 4,301,4,325& AOGCC true vertical 4,457 feet true vertical 4,435 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' Surface 3,246' 9-5/8" 3,246' 2,653' 5,750psi 3,090psi Intermediate 6,761' 7" 6,761' 4,461' 7,240psi 5,410psi Liner 2,703' 4-1/2" 9,297' 4,451' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematicfeet �� I 3 201? scANNTubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/TC-Il 6,633' 4,439' Baker Premier x 2 Packers and SSSV(type,measured and true vertical depth) &ZXP 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 0 210 0 912 Subsequent to operation: 0 0 346 0 800 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development❑ Service Q Stratigraphic Li Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas U WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 316-342 Contact Ted Kramer Email tkrameranhilcorp.com Printed Name Bo York Title Operations Engineer A Signature / Phone 777-8345 Date 8/30/2016 fr'''. /.1. /6- sl. /4, 4 10'4 Form 10-404 Revised 5/2015 RBDMS L, ` '' - Submit Original Only 1 2016 , tii • • Milne Point Unit Well: MPU E-12 • SCHEMATIC Last Completed: 9/14/2005 Ilileor„Alaska,LLC PTD: 205-067 TREE&WELLHEAD Orig.DF Elev.:57.35'/GL Elev.:33.95'(Doyon 14) Tree 3-1/8"5M FMC j t rt '3 11"x 3-1/8"5M FMC Gen 5 Tubing Hgr.11" Wellhead r i x 3-1/8"TC-II T&B 3"CIW-H BPV Profile 13-3/8' r OPEN HOLE/CEMENT DETAIL �� 13-3/8" 260 sx of Arcticset I in 18"Hole "ii. 3 9-5/8" 384 sx AS Lite,408 sx Class"G"in 12-1/4"Hole 3 7" 351 sx Class"G"in 8-1/2"Hole t 1 4.1/2" 315 sx Class"G"in 6-1/8"Hole 1,4 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 9-5/g fi4 ` 13-3/8" Conductor 72/K-55/N/A N/A 0 112' ± 9-5/8" Surface 40/L-80/Btc. 8.679 0 3,246' 7" Intermediate 26/L-80/BTC Mod 6.276 0 6,761' 4-1/2" Liner 12.6/L-80/IBT 3.958 6,594' 9,297' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/TC-II 2.992 0 6,633' WELL INCLINATION DETAIL KOP©250' Angle passes 50 deg.@ 2,400' Max Hole Angle in Tubing=79 deg.@ 6,659' } ',3 Angle through Liner=90+deg. JEWELRY DETAIL No Depth Item 1 2,494' 3.5"HES X Nipple,ID=2.813" 2 6,176' 3.5"HES X Nipple,ID=2.813" 2 3 6,226' 7"x 3.5"Baker Premier Packer I - 4 6,251' 3.5"HES X Nipple,ID=2.813" w,; , , 3 5 6,267' Unique Machine Overshot 1 6 6,276' Top of cut-Pup joint stub ;�- 7 6,288' 7"x 3.5"Baker Premier Packer 8 6,370' 3.5"x 1.5"Camco MMG(rk)/SPM-RK-*DGLV* 9 6,430' 3.5"x 1.5"Camco MMG-W(rk)/SPM-RK-*DGLV* IV 10 6,583' 3.5"HES XN Nipple,ID=2.750"/*No Valve* m1" 11 6,600' Baker Locator Sub 1 # 12 6,602' Baker 806-40 Seal Assembly- Bottom @ 6,633' PD Sands A, 13 6,606 Baker Tie Back Sleeve " 14 6,614' Baker ZXP Packer s t 15 6,616' Baker"RS"Nipple 'NC Sands 41 " 16 6,623' Baker HMC Liner Hanger 4 17 6,643' Baker 80-40 Seal Bore Ext. L fA. L. all 12&13 PERFORATION DETAIL 1"x4,,14,15,16&17 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7"'`6 ND Sands 6,375' 6,390' 4,358' 4,363' 15 6/6/2005 Open NC Sands 6,410' 6,437' 4,371' 4,381' 17 6/6/2005 Open 6,828' 6,888' 4,470' 4,472' 60 7/9/2016-" Open 'NC/&'NC Sands - 6,918' 6,948' 4,472' 4,472' 30 7/9/2016' Open OA Sands 7,638' 7,698' 4,474' 4,472' 60 7/8/2016 Open 7,718' 7,778' 4,472' 4,470' 60 7/8/2016 Open OA'Sands -------4; 8,668' 9,168' 4,477' 4,467' 500 6/6/2005 Open ND&NC Sands perfed with 4.5"HSD 6 SPF PJ4505/OA Sands perfed with 2-7/8"HSD 6spf PJ2906 CT FCA to 8,491' GENERAL WELL INFO 7/7/2016 ► API:50-029-23262-00-00 4-1/2"1 A Drilled,Cased and Completed by Doyon 14 -6/8/2005 TD=9,297(MD)/TD=4,415'(TVD) RWO to Correct Tbg Leak By Nabors 4ES-9/14/2005 PBTD=9,253'(MD)/PBTD=4,457'(TVD) CT FCO&Perf Add-7/9/2016 Revised By:TDF 8/30/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-12 CTU 50-029-23262-00-00 205-067 7/6/16 7/9/16 Daily Operations, 14ri 0?-1- 7/6/2016 n97/6/2016-Wednesday Hold safety meeting. Discuss JSA and job procedure. Install p subs, BOPE, Rig up flow back. Start BOPE test. Test all rams and valves to 250/3,000 psi. BOPE test complete. 24 Hr notice submitted. 7/5/16 @ 1400 hrs. Witness waived by Guy Cook 7/5/16 @ 1550. Pop off well. Stab 10' lubricator.Trim 30' CT make up Statewide internal dimple connector, MHA(dfcv, disco,). Pressure test MHA to 250/3,500 psi. Small leak on Coil connector threads. Bleed down. Install 0-ring and thread sealant. Make up and re test. Good to go. Stab on well. PT stack to 250/3,500 psi. Master swab open. RIH.0 psi WHP. Dry f6, tag at 8,120'. Pick up and come online at 1.5 bbls/min. Pull up to tubing tail at 6,633'. Increase pump rate to 2.6 bbls/min. Pump Tubing bottoms up of 32 bbls. Start RIH stack weight at 8,120'. Weight not breaking back. Set down 15k making hole stack hard at 8,253'. Pick up and RIH to tag hard spot at 100 ft/min 8,253' not breaking back or washing off. 8 bbl gel sweep pumped. Gel at nozzle circulate 10 bbls post gel sweep. Start POOH to surface while circulating out Gel sweep from 8,253'. POOH shut down fluid pump at 6,000'. Continue to POOH. 286 bbls pumped for FCO. At surface. Swab master closed. Pop off. Break down tools. Stack back injector head. SDFN. Wellsite secure. 7/7/2016-Thursday Hold safety meeting. Discuss job procedure and review JSA. Fire equipment. Pick injector head and stab 20' of lubricator. Make up state wide dimple connector. Pull test 25k. Install MHA(DFCV, DISCO,9/16 ball) Pressure test 250/3,500 psi. Make up 2.125" motor and 2.6" Mill.Total BHA length 16.2'.Stab on well. Pt stack 250/3,500 psi. Open master swab.SSV blocked and capped. RIH.Tagged up on well head x over below BOPE min rate through motor and popped off ledge. Continue RIH. 3,430'wt check 4,500Ibs. RIH,set down weight at 6,276' (cut pup joint) min rate through motor. RIH,wt check 8,153' 20k. Stacked weight at 8,153'. Online down CT to start milling 1.7 bbls/min 3,200psi. Stacking weight at 8,153' no motor work and weight not breaking off. PU and slack off. Worked coil to 8,290', 8,320', 8,403'. Pu to 7,720'. RIH slack of stack weight-20k but making hole. No motor work. Made it to 8,454' Pick up and Rlh at-20k to 8,491'. Multiple attempts to clear 8,491' no luck. choke looks to be plugging. Choke hand heard something large drop into tank and hit the bottom. Possibly rocks. Pick up from 8,491' at Pulling heavy from 8,491'to 7,600' and over pulled to 40k, 20 over string weight. Motor stalled out at 4,500psi. CT stuck. Can't RIH. Still have circulation to surface.Sent gel sweep. End of sweep ct pump shut down. coil surged and CT was free. Start POOH. Pump online. PU to tubing tail at 6,633' send 8 bbl gel sweep. Circulate bottoms up. Shut down pump. RIH to drift with 2.6 mill to achieve perf depth interval. Stacking weight at 7,660'. Pick up. Online down CT and CT x Tubing annuli. Choke closed. 1 bbl/min injecting at 1200 psi. Push debris to 8,015'.Shut down pumps. Pick up to 6,000' and RIH dry to 8,015' clean RIH and PU weights. POOH to surface. Tagged up master swab closed. Pop off break down motor and mill. Make up sucker rod x over. Install batter, Memory tool, Gamma/CCL. X over and 22'spent 2.63" Gun. Stab on well. PT stack to 250/3,500 psi. RIH at 80 ft/min.Stop every 1,000'to adjust Memory counter. Counter on depth to the tenth of a foot at 6,000'. RIH to 8012.6'. Pick up to 7,999.4' paint flag( Blue). Continue logging OOH to 7,296.2' stop for 5 minutes. Paint 2nd flag. LOG OOH to 6,200' Stop for 3 minutes. POOH to surface at 100 ft/min.Tagged up at surface. Break down Memory tools. Downloading data. Stack back lubricator and injector head. Wellsite secure. Data recovered. 310 bbls of 1% KCL pumped for Mill run.CT depth of by-9'. Correlate logs to MPU E-12 PDS Jewelry Log 11-19-05. 7/8/2016-Friday S •A Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-12 CTU 50-029-23262-00-00 205-067 7/6/16 7/9/16 Daily Operations: 1144. Hold safety meeting. Review and discuss JSA. Pick injector head, stab 35' of lubricator. Make up MHA and pt 250/3,500psi Stab on well. PT lubricator 250/3,500psi. Break connection at quick test sub. Pop off. Make up 2.5"x 30' Millenium charges 6 spf, 60 degree phasing.Stab on well. Pressure test break at quick test sub 250/3,500 psi. Open master swab. RIH. Opsi initial WHP. Pick up to flat at 8,005.9'. Correct to top shot at flag. Input depth of 7,988.23'. PU OOH and stop at 7,748'. Drop ball. Pump 50 bbls. Guns fired at 4,100psi. Shot perfs from 7,748'-7,778' POOH to surface. Tagged up. Break spent guns.All shots fired. Ball recovered. Make up 30' of same TCP guns. stab on well pt quick test sub to 250/3,500psi. RIH for gun run#2. Pick up in tension to flag. 8,008.0'. Correct depth to 7,988.23'. Pick up to 7,718' shoot guns from 7,718-7748'. Pooh to surface. Make up Gun Run#3 30' of same. Stab on well PT 250/3,500 psi. RIH. Pick up in tension to flag 8,006.3' correct depth to 7,988.23'. POOH to 7,668. Drop ball. Pressure up to 3,890psi. Guns fired from 7,668'-7,698'. POOH to surface. Make up 4th gun run 30' of same. Stab on well. PT quick test sub to 250/3,500psi. RIH. PU to flag 8,009.4' correct depth to 7,988.73'. PU drop ball and fire guns from 7,638'-7,668'. POOH to surface.All guns fired. Break down gun and firing head. Stack down lubricator. Wellsite secure. Crews off locatoin. 7/9/2016-Saturday Hold safety meeting. Discuss JSA and Review job procedure. Pick injector head. Make up 35' lubricator and quick test sub. Stab on well. Pressure test stack to 250/3,500psi. Bleed down. Blow down. Pop off well at quick test sub. Make up 2.125" OD MHA( DFCV,DISCO). Pressure test MHA to 250/3,500psi. Make up Firing head. Install 30' 2.5" guns loaded with Millenium charges 6 spf/60° phasing. Stab on well. PT quick test sub 250/3,500. RIH to 8,015'. Pick up to flag at 8,005'. Correct depth to 7,988.23' put to 6,918'. Drop 1/2 in ball. Launch and follow with 50 bbls of 1% KCL. Ball on seat. Pressure up to 4,100psi. Guns fired. Perforated 6,918-6,948'. POOH to surface. Close master swab. Pop off well. Guns confirmed fired. Break down spent guns. 1/2" ball recovered in firing head. Make up 30'guns of same. Stab on well. Pt quick test sub to 250/3,500psi. Open master swab. RIH. Pick up to flag at 8,009'. Correct depth to 7,988.23 to top shot. POOH to 6,858'. Launch 1/2" ball 47 bbls away. Pressure up to 4,050psi. Guns fired. Perforated from 6,858-6,888'. POOH to surface. Tagged up. Master swab closed. Break down spent guns.All shots fired ball recovered. Make up 30' of 2.5" guns. Stab on well. PT quick test sub to 250/3,500 psi. RIH Pu to flag at 8,007'. Correct depth to 7,988.23. POOH to 6,828'. Drop 1/2" ball circulated 47 bbls. ball on seat. Pressure up to 4,050 psi. Guns fired. POOH to surface. No increase in WHP on any shot. Perforated 6,828'-6,858'. POOH to surface.Tagged up. Guns fired.Ball recovered. RDMO. 368 bbls pumped. No increase in WHP-on any-gun run. RDMO CTU.Turn well over to production Zones shot from bottom up. 7,718-7,778',7,638-7,698', _6,9181-6,948', 6,828'_6,888'."7 total gun runs for CTU/TCP job. 7/10/2016-Sunday No activity to report. 7/11/2016- Monday No activity to report. 7/12/2016-Tuesday No activity to report. • SOF Tyi -0\1//yy'* THE STATE Alaska Oil and Gas ufALA S KA Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 •*h.r GOVERNOR BILL WALKER g �^ ...,' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York some . � v 2 7 2u10 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Unit Field, Schrader Bluff Oil Pool, MPU SB E-12 Permit to Drill Number: 205-067 Sundry Number: 316-342 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 Ay Chair DATED this of June, 2016. RBDMS (A/in L 4 2016 • • RECEIVED • STATE OF ALASKA JUN 2 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A00CC 20 AAC 25.280 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: a1 civ x 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development L ' 205-067 3.Address: Stratigraphic ❑ Service .04) uf 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 �" 50-029-23262-00-00 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 V MILNE PT UNIT SB E-12 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0028231 I ADL0047438 I ADL0047437 I ADL0025518 • 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): 9,297' ' 4,451' ' 9,253' . 4,457' 2,148 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 3,246' 9-5/8" 3,246' 2,653' 5,750psi 3,090psi Intermediate 6,761' 7" 6,761' 4,461' 7,240psi 5,410psi Liner 2,703' 4-1/2" 9,297' 4,451' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 3-1/2" 9.2#/L-80/TC-II 6,633 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Premier x 2&ZXP and N/A 6,226/4,301,6,288/4,325&6,614/4,435 and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory El Stratigraphic ❑ Development L Service d 14. Estimated Date for 15.Well Status after proposed work: 7/6/2016 Commencing Operations: OIL ❑ WINJ o WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved l fr. . herein will not be deviated from without prior written approval. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name ,_o York Title Operations Manager Signature / / Phone 777-8345 Date 6;22/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\lam _3 2.4 2 Plug Integrity ❑ BOP Test a Mechanical Integrity Test ❑ Location Clearance ❑ Other: .-'C 3t'f.,f, pr-, � 60n .1--; '!" CL 11 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 4:47 Subsequent Form Required: r'0._dici RBDMS JUN 4 2016 APPROVED BY Approved by:(°,,, COMMISSIONER THE COMMISSION Date: 6_ 24L-./A , 4 4241A;e'4 1-7 I 0 Submit Form ane Form 10-403 Revised 11/2015 4Gim i I for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU E-12 1I,k+orp Alaska,Lb Date:6/22/2016 Well Name: MPU E-12 API Number: 50-029-23262-00 Current Status: Active Water Injector Pad: Milne Point E-Pad Estimated Start Date: July 6, 2016 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 205-067 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (907) 867-0665 (M) AFE Number: Current Bottom Hole Pressure: 2,548 psi @ 4,000' TVD (Last BHP measured 7/10/2013) Maximum Expected BHP: 2,548 psi @ 4,000' TVD (New perfs being added to existing zone) i Current Surface injection Pressure: 788 psi (Based on SBHP taken 7/10/2013 and water cut of 100% (0.440psi/ft)) Max. Anticipated Surface Pressure: 2,148 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU E-12 was drilled with Doyon #14 in 2005 as a horizontal injector in the Schrader Bluff Nc/Nd and OA sands and provides support in hydraulic unit 17 for offset producers MPU E-31 and MPU E-32. The well developed a tubing leak and was repaired in 2005 by cutting the tubing and running an overshot and an additional packer. The well has had several MBE treatments that have been treated with some limited success, the most recent being done in September 2015. Notes Regarding Wellbore Condition • Well is a horizontal water injector(horizontal 90°section begins @ 6,900'). • Shut-in water injection due to recent MBE (Matrix Bypass Event). • Confirmed MBE between MPU E-12 and MPU E-32 (ESP Oil Producer) using Red Dye Test. Objective: The purpose of this work is to cleanout the wellbore and add perforations in the OA sand near the heel of the well. Area Review In looking at the impacted area of a one quarter mile radius of the E-12 (See attached Map), three wells penetrate the 1/4 mile cylinder other than E-12 itself (B-15, E -30A, and E-8). A fourth well, B-27 comes close from the Northeast and is also an OA injector in the same interval. B-15 is a Kuparuk well that although it appears on the map to enter the 1/4 mile cylinder, the vertical displacement is approximately 3,000 feet deeper and therefore it is not a factor. Where it penetrates the OA is the green dot on the B-15 line well to the-n-61'6-6f the cylinder. The E-8 is also a Kuparuk well drilled to a deeper horizon. However, where it penetrates the OA of the Schrader does fall within the X mile Cylinder so it was included within this review. • • Well Prognosis Well: MPU E-12 Flilcorp Alaska,LL) Date:6/22/2016 E-30A is a coil tubing drilled 2-7/8" slotted liner drilled from the 5-1/2" parent production casing. The liner is un-cemented. B-27 is a dual injector with the long string providing injection into the OA sand and the short string providing injection support into the N sand. Well Surface Shoe Cement Cmt Prod. Cement TOC Name Casing Depth (ft) Description to Casing Description MD/TVD Surf. Md/TVD E-12 E-8 9-5/8" 5,947'/4,590' 700 Sx Permafrost Y 7" 26# 650 sx`G' Est TOC 36# `E' 12.3 ppg F/B L-80 8,500 ft K-55 350 sx'G' 15.8 ppg E-30A 13-3/8 120' 250 Sx.Arctic Set 1 5-1/2" 747 TOC 150' sx Coldset by CBL III, 158 sx foamed, 70 sx 'G' B-27 9-5/8" 3,593'/2,863' 443 SX as Lite F/B 7" 26# 370 sx. 'G' 40# 372 sx`G' 7,614 / 4,520 Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.4 ppg 1% KCI. 2. Notify AOGCC of upcoming BOP test 3. Pressure test BOPE to 3,000 psi Hi 250 Low. r A 4. RIH w/2.00" coil w/2.5" wash nozzle and cleanout to PBTD at+/-9,253' MD. POOH. r L a. Note: Min ID is 2.750" thru XN profile at 6,583' MD. N rue ,4—Tk40.3_+ 0'1-, 5. RIH w/2.00" coil w/GR/CCL logging tools to 7,800 ft CTD. Flag coil and log up to well above 6,700' MD. POOH with logging tools. 6. PU Perf Gun number One. RIH with perf gun to flagged depth.Tie into Memory GR/CCL log.Shoot first interval starting with the deepest shots and working upward. POOH with perf gun. Perforate the following (multiple runs will be required): a. 6,810'-6,870' (60') b. 6,900'-6,930' (30') c. 7,620'-7,680' (60') d. 7,700'-7,760' (60') � f 7. RD Coiled Tubing and ancillary equipment. 8. Turn well over to production. • • II Well Prognosis • Well: MPU E-12 Ililcorp Alaska,LL Date:6/22/2016 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. AOR Map • Milne Well: Point MPU E-12Unit II 0 SCHEMATIC Last Completed: 9/14/2005 nikoru Alaska,LLC PTD: 205-067 TREE&WELLHEAD Orig.DF Elev.:57.35'/GL Elev.:33.95'(Doyon 14) Tree 31-11,/x8"35- . -1/8"SM FMC 11"x 3 1/8"SM FMC Gen 5 Tubing Hgr.11" &# Wellhead x 3-1/8''TC-IIT&B 3"CIW-H BPV Profile 13 3/8" OPEN HOLE/CEMENT DETAIL :y 13-3/8" 260 sx of Arcticset I in 18"Hole 9-5/8" 384 sx AS Lite,408 sx Class"G"in 12-1/4"Hole 7" 351 sx Class"G"in 8-1/2"Hole {'' 1 c: 4.1/2" 315 sx Class"G"in 6-1/8"Hole 5; CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 9-5/g, A te13-3/8" Conductor 72/K-55/N/A N/A 0 112' 9-5/8" Surface 40/L-80/Btc. 8.679 0 3,246' 7" Intermediate 26/L-80/BTC Mod 6.276 0 6,761' 4-1/2" Liner 12.6/L-80/IBT 3.958 6,594' 9,297' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/TC-II 2.992 0 6,633' WELL INCLINATION DETAIL KOP@250' Angle passes 50 deg.@ 2,400' Max Hole Angle in Tubing=79 deg.@ 6,659' Angle through Liner=90+deg. JEWELRY DETAIL No Depth Item 1 1 2,494' 3.5"HES X Nipple,ID=2.813" 2 6,176' 3.5"HES X Nipple,ID=2.813" .: w 3 6,226' 7"x 3.5"Baker Premier Packer 4 6,251' 3.5"HES X Nipple,ID=2.813" _. r-. 3 5 6,267' Unique Machine Overshot 6 6,276' Top of cut-Pup joint stub - 4 7 6,288' 7"x 3.5"Baker Premier Packer i 8 6,370' 3.5"x 1.5"Camco MMG(rk)/SPM-RK-*DGLV* 9 6,430' 3.5"x 1.5"Camco MMG-W(rk)/SPM-RK-*DGLV* 5 ‘' 10 6,583' 3.5"HES XN Nipple,ID=2.750"/*No Valve* 6 7 11 6,600' Baker Locator Sub ;. 12 6,602' Baker 806-40 Seal Assembly- Bottom @ 6,633' 'ND'Saids s 8 z' 13 6,606 Baker Tie Back Sleeve 4, 14 6,614' Baker ZXP Packer sr' 15 6,616' Baker"RS"Nipple 'NC Sands-a 9 y 16 6,623' Baker HMC Liner Hanger ar- _ 10 ` 17 6,643' Baker 80-40 Seal Bore Ext. "tw. X11 12&13 PERFORATION DETAIL "14,15,16&17 - / Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7" • ND Sands 6,375' 6,390' 4,358' 4,363' 15 6/6/2005 Open NC Sands 6,410' 6,437' 4,371' 4,381' 17 6/6/2005 Open OA Sands 8,668' 9,168' 4,477' 4,467' 500 6/6/2005 Open ND&NC Sands perfed with 4.5"HSD 6 SPF PJ4505/OA Sands perfed with 2-7/8"HSD 6spf PJ2906 GENERAL WELL INFO 'OA'Sands, - API:50-029-23262-00-00 Drilled,Cased and Completed by Doyon 14 -6/8/2005 RWO to Correct Tbg Leak By Nabors 4ES-9/14/2005 4-1/Y'/ ii TD=9,297(MD)/TD=4,415'(TVD) PBTD=9,253'(MD)/PBTD=4,457'(TVD) Revised By:TDF 6/21/2016 111 • • Milne Well: Point MPU E-12Unit PROPOSED Last Completed: 9/14/2005 Ilileorp Alaska,LLC PTD: 205-067 TREE&WELLHEAD Orig.DF Elev.:57.35'/GL Elev.:33.95'(Doyon 14) Tree 3-1/8"5M FMC Wellhead 11"x 3-1/8"5M FMC Gen 5 Tubing Hgr.11" ' 4C x 3-1/8"TC-II T&B 3"CIW-H BPV Profile (4 ISM" 13-3/8' t OPEN HOLE/CEMENT DETAIL A. 13-3/8" 260 sx of Arcticset I in 18"Hole ,� 9-5/8" 384 sx AS Lite,408 sx Class"G"in 12-1/4"Hole 7" 351 sx Class"G"in 8-1/2"Hole 4.1/2" 315 sx Class"G"in 6-1/8"Hole I 4 A? CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 9-5/8" a ie13-3/8" Conductor 72/K-55/N/A N/A 0 112' ± 9-5/8" Surface 40/L-80/Btc. 8.679 0 3,246' ' 7" Intermediate 26/L-80/BTC Mod 6.276 0 6,761' 4-1/2" Liner 12.6/L-80/IBT 3.958 6,594' 9,297' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/TC-II 2.992 0 6,633' WELL INCLINATION DETAIL KOP @ 250' Angle passes 50 deg.@ 2,400' Max Hole Angle in Tubing=79 deg.@ 6,659' Angle through Liner=90+deg. JEWELRY DETAIL No Depth Item 1 2,494' 3.5"HES X Nipple,ID=2.813" 2 6,176' 3.5"HES X Nipple,ID=2.813" a 2 3 6,226' 7"x 3.5"Baker Premier Packer 4 6,251' 3.5"HES X Nipple,ID=2.813" 7,4 3 5 6,267' Unique Machine Overshot 6 6,276' Top of cut-Pup joint stub ,,;,; 4 7 6,288' 7"x 3.5"Baker Premier Packer i 8 6,370' 3.5"x 1.5"Camco MMG(rk)/SPM-RK-*DGLV* ,% : 9 6,430' 3.5"x 1.5"Camco MMG-W(rk)/SPM-RK-*DGLV* 5 4* 10 6,583' 3.5"HES XN Nipple,ID=2.750"/*No Valve* (* 6 r11 6,600' Baker Locator Sub 12 6,602' Baker 806-40 Seal Assembly- Bottom @ 6,633' 'ND'Sands 8 r" 13 6,606 Baker Tie Back Sleeve 14 6,614' Baker ZXP Packer sr 15 6,616' Baker"RS"Nipple Sands W e , 16 6,623' Baker HMC Liner Hanger j A 17 6,643' Baker 80-40 Seal Bore Ext. �_i 10 r '°, a' &11 ,12&13 PERFORATION DETAIL 4= A14,15,16&17 Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status L,71,v" • ND Sands 6,375' 6,390' 4,358' 4,363' 15 6/6/2005 Open NC Sands 6,410' 6,437' 4,371' 4,381' 17 6/6/2005 Open ...- ±6,810' ±6,870' ±4,468' ±4,472' 60 Future Future 0k,J5-� ±6,900' ±6,930' ±4,472' ±4,472' 30 Future Future P41 = OA Sands ±7,620' ±7,680' ±4,474' ±4,473' 60 Future Future ±7,700' ±7,760' ±4,472' ±4,471' 60 Future Future OA'Sands _ 8,668' 9,168' 4,477' 4,467' 500 6/6/2005 Open ND&NC Sands perfed with 4.5"HSD 6 SPF PJ4505/OA Sands perfed with 2-7/8"HSD 6spf PJ2906 GENERAL WELL INFO API:50-029-23262-00-00 4-1/2"/ Drilled,Cased and Completed by Doyon 14 -6/8/2005il RWO to Correct Tbg Leak By Nabors 4ES-9/14/2005 TD=9,297(MD)/TD=4,415'(ND) PBTD=9,253'(MD)/PBTD=4,457'(TVD) Revised By:TDF 6/21/2016 • • Milne Point Unit COIL BOPE MPU E-12 6/17/2016 itil.wp tLL..j,a.LI.( MPU E-12 13% x9% x7x3% Coil Tubing BOP To injection head I i 2.00"Double Stripper Lubricator 1c' aiee C= Blind '11/16 15M Bind = t= Shear _ Shear .--1 1' - - ® - __ t- __ Slip :____ =^ Slip 11114 y c_ —— Pipe Pipe =_/ 9-71 Crossover spool 41/16 15M X 41/16 10M lel wr tint Crossover spool .rn 41/16 10M X 4 1/16 5M ria el Pump-In Sub nm la rt t 4 1/16 5M (°) 3 : ',4e �� 1110 1502 Union 4 Manual Gate Manual Gate It Crossover spool rM' 2 1/8 SM 2 1/8 5M 41/165MX31/85M a , , 111 ,,,I Valve,Swab,WKM-M, 2 " 3 1/8 5M FE -`---J, \O�� i i G Ja\J ',37,� (1 i I C °)011 Valve,Upper Master,Baker, loN 3 1/8 5M FE,w/Hydraulic Vve Valve,Lower Master,WKM-M, Fr oma ' 3 1/8 5M FE — Iil 1\I a. i' i=Tubing Adapter,3 1/8 5M h..r . • • _______ _________ .... .. ..... ... . _ W li h. N co _�� '": • I // ,/J 77/ m .-J ' `Y' LO OMCO W La1 • N Oo M M N O W N W CO W CI • W __ .. LU \J vtO N `') w �, N W MO A N W ' _J � n LI, \N LU o s. , Mme Nw-a � I I � W a rn a W1-1-\\ ------- \ 0 ow Wa O i3i i 1-$L me�d� R c 1::: \I 0 ii Z w w ;6 y S 8gaw6 N WN°Oay W 211 3adm s STATE OF ALASKA • A*KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ____1❑ Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: MBE Treatment E 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 205-067 3.Address: Stratigraphic❑ Service Li 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23262-00-00 ' 7.Property Designation(Lease Number): , , '8.Well Name and Number: ADL0028231 I ADL0047438 I ADL0047437 I ADL0025518 MILNE PT UNIT SB E-12 ' 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 9,297 • feet Plugs measured N/A feet`E C E I V E ' true vertical 4,451 + feet Junk measured N/A feet OCT 15 ?fl15 6,226,6,288& Effective Depth measured 9,253 feet Packer measured 6,614 feet (��^yJ�/.�� `[I � 4,301,4,325& �V G�V true vertical 4,457 feet true vertical 4,435 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' Surface 3,246' 9-5/8" 3,246' 2,653' 5,750psi 3,090psi Intermediate 6,761' 7" 6,761' 4,461' 7,240psi 5,410psi Liner 2,703' 4-1/2" 9,297' 4,451' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/TC-II 6,633' 4,439' Baker Premier x 2 Packers and SSSV(type,measured and true vertical depth) &ZXP 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 8 40 223 Subsequent to operation: 0 0 214 40 614 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 ❑ Gas H WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-452 Contact Stan Porhola Email sporhoIatahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 777-8412 Date 10/6/2015 /0.Z2--r j RBDMS jCT 2 1 2015 A.Form 10-404 Revised 5/2015 A. /4,/4 j Submit Original Only • Milne Point Unit 14 • Well: MPU E-12 SCHEMATIC Last Completed: 9/14/2005 HIIcorp Alaska,LLC PTD: 205-067 CASING DETAIL Orig.DF Elev.:57.35'/GL Elev.:33.95'(Doyon 14) Size Type Wt/Grade/Conn Drift ID Top Btm sj ;''' 13-3/8" Conductor 72/K-55/N/A N/A 0 112' 9-5/8" Surface 40/L-80/Btc. 8.679 0 3,246' 13-3/%' 7" Intermediate 26/L-80/BTC Mod 6.276 _ 0 6,761' j v 4-1/2" Liner 12.6/L-80/IBT 3.958 6,594' 9,297' TUBING DETAIL '; 3-1/2" Tubing 9.2/L-80/TC-II 2.992 0 6,633' JEWELRY DETAIL , No Depth Item 9-5/g o1 1 2,494' 3.5"HES X Nipple,ID=2.813" 2 6,176' 3.5"HES X Nipple,ID=2.813" 3 6,226' 7"x 3.5"Baker Premier Packer 4 6,251' 3.5"HES X Nipple,ID=2.813" 5 6,267' Unique Machine Overshot 6 6,276' Top of cut—Pup joint stub 7 6,288' 7"x 3.5"Baker Premier Packer 8 6,370' 3.5"x 1.5"Camco MMG(rk)/SPM—RK—*DGLV* 9 6,430' 3.5"x 1.5"Camco MMG-W(rk)/SPM—RK—*DGLV* 10 6,583' 3.5"HES XN Nipple,ID=2.750"/*No Valve* 11 6,600' Baker Locator Sub 12 6,602' Baker 806-40 Seal Assembly- Bottom @ 6,633' 13 6,606 Baker Tie Back Sleeve 14 6,614' Baker ZXP Packer 15 6,616' Baker"RS"Nipple 16 6,623' Baker HMC Liner Hanger 17 6,643' Baker 80-40 Seal Bore Ext. PERFORATION DETAIL 2 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status ND Sands 6,375' 6,390' 4,358' 4,363' 15 6/6/2005 Open " "` 3 NC Sands 6,410' 6,437' 4,371' 4,381' 17 6/6/2005 Open IN OA Sands 8,668' 9,168' 4,477' 4,467' 500 6/6/2005 Open 4 ND&NC Sands perfed with 4.5"HSD 6 SPF PJ4505/OA Sands perfed with 2-7/8"HSD 6spf P12906 5 WELL INCLINATION DETAIL :,, 6 KOP @ 250' -, .-< 7 Angle passes 50 deg.@ 2,400' Sands "s 6 Max Hole Angle in Tubing=79 deg.@ 6,659' III <P Angle through Liner=90+deg. A.` 'NC Sands a 9 % OPEN HOLE/CEMENT DETAIL i 13-3/8" 260 sx of Arcticset I in 18"Hole t 10 , 9-5/8" 384 sx AS Lite,408 sx Class"G"in 12-1/4"Hole • '411,12&13 7" 351 sx Class"G"in 8-1/2"Hole 1, $ 4.1/2" 315 sx Class"G"in 6-1/8"Hole .1*, = .14,15,16&17 7" + TREE&WELLHEAD Tree 3-1/8"5M FMC 11"x 3-1/8"5M FMC Gen 5 Wellhead Tubing Hgr.11"x 3-1/8"TC-Il T&B 3"CIW-H BPV Profile 'OA'Sax's{ GENERAL WELL INFO API:50-029-23262-00-00 Drilled,Cased and Completed by Doyon 14 -6/8/2005 RWO to Correct Tbg Leak By Nabors 4ES—9/14/2005 4-1/2" 6 TD=9,297(MD)/TD=4,415'(TVD) PBTD=9,253'(MD)/PBTD=4,457'(TVD) Revised By:TDF 10/2/2015 Hilcorp Alaska, LLC ,,iIcor') „..ka,, ,, Weekly Operations Summary Well Name API Number •Well Permit Number Start Date End Date MP E-12 50-029-23262-00-00 205-067 9/16/2015 9/19/2015 Daily Operations: 9/16/15-Wednesday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 1,500 psi-test OK. Perform injectivity test at 2.0 bpm @ 1,100 psi. Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/ 68.5 bbl of 1%KCI water.Switch to Little Red Pump Unit and pump 21 bbl of diesel.SD Pumps. Monitor well. Final SITP of 900 psi. RDMO Cement Pump Unit&Little Red Pump Unit. Move to MPU S-02. 9/17/15-Thursday No operations to report. 9/18/15-Friday No operations to report. 9/19/15-Saturday MIRU Cement Pump Unit& Little Red Pump Unit. PT lines to 4,000 psi-test OK. Perform injectivity test at 2.0 bpm @ 1,300 psi. Mix and pump 5 bbl of HEC, 10 bbl of 15.8 ppg cement,and 5 bbl of HEC. Drop foam ball. Displace w/68.5 bbl of 1%KCI water.Switch to Little Red Pump Unit and pump 21 bbl of diesel.SD Pumps. Monitor well. Final SITP of 1,350 psi. RDMO Cement Pump Unit&Little Red Pump Unit. Move to MPU S-02. 9/20/15-Sunday No operations to report. 9/21/15-Monday No operations to report. 9/22/15-Tuesday No operations to report. of Ty Alaska Oil and Gas \� I yjjs THE STATE of HA, ASJ(A Conservation Commission I- x=_= 333 West Seventh Avenue • GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 ALAS*"' Fax 907 276 7542 www aogcc.alaska goy Stan Porholaabs- c' 17 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-12 Sundry Number: 315-452 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, Cathy P oerster �,p - Chair DATED this!—a day of July, 2015 Encl. RECEIVED STATE OF ALASKA MI, 2 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION rn s 7 Z ') is s APPLICATION FOR SUNDRY APPROVALS AOG(C 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redril❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: MBE Treatment ❑., 2 Operator Name. 4.Current Well,Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑ 205-067 3.Address. Stratigraphic ❑ Service 2_ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23262-00-00 • 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 ❑' / MILNE PT UNIT SB E-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 I ADL0047438 I ADL0047437 I ADL0025518 . 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): 9,297 - 4,451 - 9,253 ' 4,457 • N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' Surface 3,246' 9-5/8" 3,246' 2,653' 5,750psi 3,090psi Intermediate 6,761' 7" 6,761' 4,461' 7,240psi 5,410psi Liner 2,703' 4-1/2" 9,297' 4,451' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic J See Attached Schematic 3-1/2" 9.2#/L-80/TC-II 6,633 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Premier x 2&ZXP and N/A 6,226/4,301,6,288/4,325&6,614/4,435 and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q 14.Estimated Date for 15.Well Status after proposed work. 8/6/2015 Commencing Operations: OIL 0 WINJ D- 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 sporholat@hilcorp.com Printed Name Stan P rhola Title Operations Engineer Signature >14 /mac,./L______. Phone 777-8412 Date 7/24/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316-sf t Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No (✓J Subsequent Form Required. i Q--410 y aa) � ,/� APPROVED BY Approved by: .7' COMMISSIONER THE COMMISSION Date: 7— Zg—r! ��3 z/ -7- 1S- 7-27-/b OpFlivicGpicNnAtiLl 1 /m�s� -72e V Submit Form and Form 10-403 Revised 5/2015 for 12 months rom the date of approval. RBDMS�h ents in Duplicate AUG 2 2015 • Well Prognosis Well: MPU E-12 llilcora Alaska,LLQ Date:7/22/2015 Well Name: MPU E-12 API Number: 50-029-23262-00 Current Status: SI Water Injector Pad: Milne Point E-Pad Estimated Start Date: August 5th, 2015 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 205-067 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: 2,548 psi @ 4,000' TVD (Last BHP measured 7/10/2013) Maximum Expected BHP: 2,548 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surf Pressure: 788 psi (Based on SBHP taken 7/10/2013 and water cut of 100% (0.440psi/ft)) Brief Well Summary: MPU E-12 was drilled with Doyon #14 in 2005 as a horizontal injector in the Schrader Bluff Nc/Nd and OA sands and provides support in hydraulic unit 17 for offset producers MPU E-31 and MPU E-32. The well developed a tubing leak and was repaired in 2005 by cutting the tubing and running an overshot and an additional packer.The well has had several MBE treatments that have been treated with some limited success. Notes Regarding Wellbore Condition • Well is a horizontal water injector(horizontal 90°section begins @ 6,900'). • Shut-in water injection due to recent MBE (Matrix Bypass Event). • Confirmed MBE between MPU E-12 and MPU E-32 (ESP Oil Producer) using Red Dye Test. Arae,., Objective: The purpose of this work/sundry is to pump a MBE treatment and place well back on water injection. Brief Procedure: Wireline Procedure 1. MIRU Slickline, PT lubricator to 1,500 psi Hi 250 Low. 2. RIH and pull live gaslift valve from WFV mandrel @ 6,4303 c"" 3. RIH and set dummy valve in WFV mandrel @ 6,430'. "r- 4. RIH and pull live gaslift valve from DV mandrel @ 6,3 5. RIH and set dummy valve in DV mandrel @ 6,370'. j 6. RIH and pull live gaslift valve from RMX profile @ 6,583'. 7. RIH and make drift run down to 6,600' (max deviation 77°, min ID= 2.75"). 8. RD Slickline. Pumping Procedure: 9. Production to SI offset producers up to 5 days prior to treatment. 10. Production to SI offset injectors up to 2 days prior to treatment. 11. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#1] 12. Perform injectivity test w/8.4 ppg lease water at rates from 0.25—3.0 bpm. II Well Prognosis Well: MPU E-12 Micas')Alaska.LL) Date:7/22/2015 a. Do not exceed 1,250 psi for injectivity test. 13. Mix and bullhead the following fluids: a. 10 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. 15 bbl of 15.8 ppg acid soluble cement. c. 5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. e. 65 bbl of 1% KCL water. f. 22.4 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 14. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 15. RDMO Cement Pumping Unit. 16. WOC 48 hours. 17. MIRU Hot Oil Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#1] 18. Mix and bullhead the following fluids: a. 5 bbl of 60/40 McOH/Water(to ensure injectivity). b. 40+ bbl of 8.4 ppg lease water or until injection rate stabilizes(same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. l' i. Increase injection pressure, do not exceed 3,600 psi. d. 20 bbl of 50/50 McOH/Water(freeze protection; after stable injection achieved). 19. RDMO Hot Oil Unit. 1, 20. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#2] 21. Fluid-pack and maintain tubing pressure on offset well affected by MBE (MPU E-32). 7c i, 22. Mix and bullhead the following fluids: a. 10 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. 15 bbl of 15.8 ppg acid soluble cement. c. 5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. e. 65 bbl of 1% KCL water. f. 22.4 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset well affected by MBE (MPU E-32). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 25. RDMO Cement Pumping Unit. 26. WOC 48 hours. 27. MIRU Hot Oil Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. 5 bbl of 60/40 McOH/Water(to ensure injectivity). b. 40+ bbl of 8.4 ppg lease water or until injection rate stabilizes(same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 3,600 psi. d. 20 bbl of 50/50 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Hot Oil Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic Milne Point Unit . lii Well: MPU E-12 SCHEMATIC Last Completed: 9/14/2005 'Ekon)Alaska,LLC PTD: 205 067 CASING DETAIL Orig.DF Elev.:57.35'/GL Elev.:33.95'(Doyon 14) Size Type Wt/Grade/Conn Drift ID Top Btm j 13-3/8" Conductor72/K-55/N/AN/A0112' k k 9 5/8" Surface 40/L-80/Btc. 8.679 0 3,246' 13-3/8" 7" Intermediate 26/L-80/BTC Mod 6.276 0 6,761' 3' 4-1/2" Liner 12.6/L-80/IBT 3.958 6,594' 9,297' 14 TUBING DETAIL e- 3-1/2" Tubing 9.2/L-80/TC-II 2.992 0 6,633' • 1• F I JEWELRY DETAIL No Depth Item 95/8" 1 2,494' 3.5"HES X Nipple,ID=2.813" 2 6,176' 3.5"HES X Nipple,ID=2.813" 3 6,226' 7"x 3.5"Baker Premier Packer 4 6,251' 3.5"HES X Nipple,ID=2.813" 5 6,267' Unique Machine Overshot 6 6,276' Top of cut-Pup joint stub 7 6,288' 7"x 3.5"Baker Premier Packer NNS8 6,370' 3.5"x 1.5"Camco MMG(rk)/SPM-RK-DGLV • 9 6,430' 3.5"x 1.5"Camco MMG-W(rk)/SPM-RK-P-15 10 6,583' 3.5"HES XN Nipple,ID=2.750"/RMX w/p-15 11 6,600' Baker Locator Sub 12 6,602' Baker 806-40 Seal Assembly- Bottom @ 6,633' 13 6,606 Baker Tie Back Sleeve 14 6,614' Baker ZXP Packer 15 6,616' Baker"RS"Nipple 16 6,623' Baker HMC Liner Hanger 17 6,643' Baker 80-40 Seal Bore Ext. PERFORATION DETAIL 2 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7.1.-. _ ND Sands 6,375' 6,390' 4,358' 4,363' 15 6/6/2005 Open ` 3 NC Sands 6,410' 6,437' 4,371' 4,381' 17 6/6/2005 Open �_ OA Sands 8,668' 9,168' 4,477' 4,467' 500 6/6/2005 Open 6 411 ND&NC Sands perfed with 4.5"HSD 6 SPFP.14505/OA Sands perfed with 2-7/8"HSD 6spf P12906 5 WELL INCLINATION DETAIL N 6 KOP@250' i. -a II":i 7 Angle passes 50 deg.@ 2,400' ND Sands g i " Max Hole Angle in Tubing=79 deg.@ 6,659' 2Angle through Liner=90+deg. 'NC Sands OE 9 ."O OPEN HOLE/CEMENT DETAIL '` 13-3/8" 260 sx of Arcticset I in 18"Hole f 19 9-5/8" 384 sx AS Lite,408 sx Class"G"in 12-1/4"Hole " lin 11,12&13 7" 351 sx Class"G"in 8-1/2"Hole S t t d 4.1/2" 315 sx Class"G"in 6-1/8"Hole A+4 _ A',14,15,16&17 7" il TREE&WELLHEAD Tree 3-1/8"5M FMC _ ; 11"x 3-1/8"5M FMC Gen 5 Gent�.t '5/40-1, Wellhead Tubing Hgr.11"x 3-1/8"TC-II T&B F. D, 3"CIW-H BPV Profile 'OA'Sands{ ' GENERAL WELL INFO API:50-029-23262-00-00 Drilled,Cased and Completed by Doyon 14 -6/8/2005 RWO to Correct Tbg Leak By Nabors 4ES-9/14/2005 4-1/2" 4 TD=9,297(MD)/TD=4,415'(TVD) PBTD=9,253'(MD)/PBTD=4,457'(TVD) Revised By:STP 7/23/2015 Image p~ect Well History File co!r 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. Q OS - 0 10 7 Well History File Identifier Organizing (done) o Two-sided 11111111111 III" III o Rescan Needed 11111111111" II /III R78CAN ~ Color Items: ~reYSCale Items: o Poor Quality Originals: DIGITAL DATA ~skettes, No. I o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: Dale 7/10/07 o Other:: BY: ~__ Isl ~p Dale 7/iO/D7 ~ X 30 = &0 Date: 7//D / D7 11111111111111" III Project Proofing BY: ~_._ Isl MP Scanning Preparation BY: ~ + ft = TOTAL PAGES ~ (p (Count does not include cover sheet) 1/1 A P. ~I rv~ . Production Scanning Stage 1 Page Count from Scanned File: ~ 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: 7/10/D7 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111" III NO 151 wtp NO BY: Maria Date: 151 1/111111111I" " III Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111" III BY: Maria Date: Isl Comments about this file: Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc or T • • w� I%%�s9 THE STATE T Alaska Oil and Gas fl L 1S JL'�l 1 " `� o C seI v io 1 Commission * GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF`"�+�+° ti Q. Anchorage, Alaska 99501-3572 ALAS T- Main: 907.279.1433 Fax: 907.276.7542 Alecia Wood SCANNED Production Engineer � BP Exploration (Alaska), Inc. o,j ' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Schrader Bluff Oil Pool, SBL MPE-12 Sundry Number: 313-595 Dear Ms. Wood: 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 P. oerster Chair, Commissioner DATED this w of of November, 2013. Encl. • • • • "�� RECEIVED STATE OF ALASKA \,,,, NOV 14 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �� 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other MBE Treatment ' SI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 205-067-0 " 3.Address: Stratigraphic ❑ Service IS ' 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23262-00-00 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? SBL MPE-12 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): fP45 10.Field/Pool(s): L47-`133 ADL0028231/ ./ S1?1 4/74.13?. MILNE POINT,SCHRADER BLFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9297 4451 6583 4428 6583 None Casing Length Size MD TVD Burst Collapse - Structural Conductor 115 13-3/8"72#L-80 35-150 35-150 Surface 3211 9-5/8"40#L-80 35-3246 35-265261 5750 3090 Intermediate None None None None None None Production 6728 7"26#L-80 33-6761 33-4461.45 7240 5410 Liner 2703 4-1/2"12.6#L-80 6594-9297 4430.39-4451.02 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment - See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed • 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program El • BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 , GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Alecia.Wood @BP.Com Printed Name Alecia Wood Title Production Engineer Signature Phone 564-5492 Date Prepared by Gany Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. %V2J 454:k S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: ` —41 0 C 467 APPROVED BY Approved by: ( ` COMMISSIONER THE COMMISSION Date: /1- (3?PtZ 040 Form 10-403 Revised 10/2012 , p�p�b iGpiiNnkii for 12 months from the ate of approve` " SubmitAoAnAnsi Opchinls ii[up i rim.imz: Nu • Perforation Attachment ADL0028231 Well Date Pert Code MD Top MD Base TVD Top TVD Base MPE-12 12/2/12 STO 6375 6390 4358 4363 _ MPE-12 12/2/12 STO 6410 6437 4371 4381 MPE-12 12/2/12 STO 8668 9168 4477 4467 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED 1 FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing Summary ADL0028231 Casing Length Size MD Top MD Base ND Top TVD Base Burst Collapse Grade CONDUCTOR 115 13-3/8" 72# L-80 35. 150 35 150 4930 2670 L-80 LINER 2703 4-1/2" 12.6# L-80 6594 9297 4430 4451 8430 7500 L-80 PRODUCTION 6728 7"26# L-80 33 6761 33 4461 7240 5410 L-80 SURFACE 3211 9-5/8"40# L-80 35 3246 35 2653 5750 3090 L-80 TUBING 6243 3-1/2" 9.3# L-80 30 6273 30 4320 10160 10530 L-80 TUBING 360 3-1/2" 9.3# L-80 6273 6633 4320 4439 10160 _ 10530 L-80 • • • • by To: Mark O'Malley/Rob Handy Date: November 11, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPE-12 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPE-12 2 F Bullhead treatment down MPE-12 (OA sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. 3 C Pending the post cement injectivity tests, perform a fill clean out and possible (Pending) 15bbl HCL acid soak to attempt to regain injectivity. OBJECTIVE Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Should the cement or gel lock up the wellbore, a contingent acid job will be performed. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPE-12 was drilled and completed as an Nc/Nd and OA regulated injector in the Schrader Bluff in 2005. MPE-12 provides injection support for three producers in hydraulic unit 17: MPE-30A, MPE-31 and MPE-32. Shortly after being completed a tubing leak was discovered. The leak was repaired during a RWO by cutting and pulling tubing and running new tubing with an overshot. This overshot has resulted in slickline intervention problems in the past. In 2009 a drastic watercut increase in producer MPE-32 indicated an MBE from MPE-12. Red dye tests were performed and the MBE was confirmed in the OA. Since the formation of the MBE, injection has been cycled on and off in the OA but has continued to show a direct connection with MPE-32. MPE-12 is horizontal in the OA sand and injects through 500' of perforations. A coil tubing'- O and IPROF was performed in December 2011 to determine the location of the MBE within the horizontal section. Following the IPROF the OA sand was dummied off in MPE-32 and will remain shut in until an MBE treatment is performed. Cumulative injection in MPE-12 totals 1.471 mmbbl combined between the Nc/Nd and OA. • • • PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump a produced water pre-flush followed by cement acting fluid treatment and diesel or methanol displacement. Allow setup time. 7. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 8. Pump a produced water pre-flush followed by a second stage of cement acting fluid treatment, holding pressure on the offset Producer connected by the Matrix Bypass Event. Attempt to squeeze second stage of cement and displace with diesel or methanol. Allow setup time. 9. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 10. Pump a produced water or KCL pre-flush followed by high volume gel treatment and diesel or methanol over flush. 11. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 12. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 13. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • TREE-3-1/8--5M FMC Ong_OF Eiev.=57.35 Cvyon 14 WEW-EAD:11 x 3-1,0"SN FMC Gen 5 MPE-12 Orig.GL Elev.=3395 Dorn 14 Tubligr 11'x 3-118'TO-ITAB 3'CeN-Ft BPVT Conductor 112' KOP 250' Angle passes 50" 2400' 3.5°HES X-Nipple 2.813" 2,494' Max Angle in Tbg=79° 6659' Angle thru liner=90+' a- 4001-03 BTC Csg. 3,246' Gas Lin Valve Arravement 6370'SPM-RK-DGLV 3_5 92#111 L-80 TC-It 6430'SPM R1(-P-15 (Drift id=.0087 BO,) 65133'XN-RMX wi P-15 4.5"12.6 ittft L-80,IBT On 1211112 (Drift id=.IX1152 bpf.) 7 26 ppt,1-80,BTC-Mod casing (drift II)=6276,cap.=0.0383 bpf) 3_5°HES X-Pdpple 2.813' 6,176' (cap el 3 1/2*tbg inside=0.0264 bpf) rgalshiammiih*it r x 3 5'Baker Piernier plir 1 - 6,226' • NCIND=21711past43741rTifft 04;‘,11130iisfal442,110 IT HES X-Ntiple 2_813" 6,251' Unique Machine Overshot/ 6,267' Top of cut Pup Jt Stub 6276' r x 3.5°Baker Premier Pb. 6.288- mm Schrader "NON D'Pelts ; Pr 0 SPF MD TVD pi 3.5"x 1_5*Ounce&SAG(rk) 6.370' 5 5.375'-6,3130' 4.35T-4,390 I- .5 6 410-5,437 4,371'-4,38V 45 #-ED s SPF. Or.PJ4505 ti 3.5"x 1.5°Camco MMG-W(rk) 6,430' 3.5"HES XN-Nipple 2.750*id. 6,583' (2.813'pkg.bore) Baker Tie back sly. 6,606' Baker Locator sib 6,600'•6614' Baker Z.XP Packer , Baker 806-40 Seal Assy bottom 6,633' Baker'RS"Nipple 6,616' Baker HMG Liner Hgr. 623' 7"float colar(PBTD) 6,675' 6, A Baker 80-40 Seal Bore ext. 6,643' 7 Weatherford float shoe 6,761' Schrader-0A-Reefs t,A,g6 SPF MD TVD 0 I% 9,108`41,058-4,465 9,212' 4.5'Baker Lending Collar 9,253' Flaeiburtun Float mbar 2-18'156 SPF PACO 1 9,297' 4.5^13eker float shoe DATE REV.BY COMMENTS MILNE POINT UNIT 06436105 MOO Drllled&Completed Doyon-14 WELL MPE-12 09114105 Lee Hutime RWO to correct tbg leak 4ES API NO: 50-029-2326240 BP EXPLORATION (AK) • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,October 03,2013 TO: Jim Regg Mechanical Integrity Tests P.I.Supervisor l)l7 113 SUBJECT: BP EXPLORATION(ALASKA)INC (l C E-12 FROM: Chuck Scheve MILNE PT UNIT SB E-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry iis NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB E-12 API Well Number 50-029-23262-00-00 Inspector Name: Chuck Scheve Permit Number: 205-067-0 Inspection Date: 9/30/2013 Insp Num: mitCS131001082426 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well - - iT e In" ITVD I 4325 '1 IA o 2193 , 2113 • 2106 YP J T P PTD 2050670 !Type Test SPT Test psi 1500 1 OA 433 , 437 437 437 E 12 i Yp 1 ■ — Interval 14YRTST P/F P - L Tubing 941 940 Sao Sao - Notes: C141`4 Thursday,October 03,2013 Page 1 of 1 STATE OF ALASKA ALIA OIL AND GAS CONSERVATION COMIAIIIION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well Lf Plug Perforations U Perforate U Other U MBE Treatment Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory ❑ 205 -067 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service Ei 6, API Number: Anchorage, AK 99519 -6612 m f 50- 029 - 23262 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: 6 - fl /137 ADL0028231 •I 4 *All MPE -12 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 9297 feet Plugs measured None feet true vertical 4451.02 feet Junk measured None feet Effective Depth measured 6583 feet Packer measured See Attachment feet true vertical 4427.77 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 115 13 -3/8" 72# L -80 33 - 148 33 - 148 4930 2670 Surface 3214 9 -5/8" 40# L -80 32 - 3246 32 - 2652.61 5750 3090 Intermediate None None None ,r_ r" - "` r oRT n� a None None Production 6730 7" 26# L -80 31 - 6761 31 - 4461.45 7240 5410 Liner 2703 4-1/2" 12.6# L -80 6594 - 9297 4430.39 - 4451.02 8430 7500 Perforation depth Measured depth See Attachment feet RECEIVED depth feet SCANNED MAR 2013. DE C 8 2012 True Vertical de p See Attachment Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment AOGCC Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None - - None "" SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 65 0 Subsequent to operation: 0 0 211 20 14. Attachments: 15. Well Class after work: y Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service IS Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: r Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 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: 312 -281 Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 E -mail Nita.Summerhays @bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician _ Signatu ��/� &�� Phone 564 -4035 Date 12/14/2012 r. a i t DEC 1 9 20 = 4� ,Z.z /L 1 tg- v Form 10 -404 Revised 11/2011 6 Submit Original Only • • Daily Report of Well Operations ADL0028231 -, U + MA' Y erma e rea men , • 1 ' equip , 'e orme• passing ow an. ig • . 'umpe• bbls MEOH & 66 bbls produced water for injectivity test final rate and pressure 1.5 bpm @ 470 psi. Performed Thermatek treatment with 5.5 bbls Kmax gel, 10 bbls Thermatek, 5 bbls Kmax gel, followed by 56.6 bbls produced water & 30.8 bbls diesel to freeze protect well. Pressure responses noted with Kmax and Thermatek at perfs and MBE. 11/11/2012 «<Job in progress cont' on 11 -12 -12 for injectivity test and possible H2O gel treatment »> HES MBE treatment: Injectivity test post Thermatek treatment. Continuation of job from WSR 11 -11- 12. Perform successful high and low PT, pumped 35 bbls of MEOH to determine final injection rate and pressure of 1.0 bpm @ 950 psi as opposed to 1 bpm @ 450 psi prior to MBE treatment. 11/12/2012 « «Job in progress, will continue H2Zero treatment on 11/13/12 »» HES MB treatment: H2Zero gel. Continuation of job from WSR 11- 12 -12. Perform successful high and low PT, pumped 5 bbls of MEOH to catch fluid swapped to PW and pumped 39 bbls to confirm injection rate of 1 bpm @ 1300 psi, swapped to H2Zero gel and pumped 402 bbl treatment, displaced with 80 bbls PW and then 25 bbls MEOH to freeze protect tubing and surface lines. 11/13/2012 « «Job complete »» FLUIDS PUMPED BBLS 30.8 DIESEL 104 METH 402 H2ZERO 10 THERMATEK 10.5 KMAX GEL 11 60/40 METH 568.3 TOTAL • • Perforation Attachment ADL0028231 Perf Opera Meas Meas Operation tion Depth Depth TVD Depth TVD Depth SW Name Date Code Top Base Top Base MPE -12 6/7/05 STC 6288 6614 4325.38 4434.84 MPE -12 7/30/05 STO 6288 6614 4268.03 4377.49 MPE -12 8/7/05 STC 6288 6614 4268.03 4377.49 MPE -12 8/11/05 STO 6288 6614 4268.03 4377.49 MPE -12 8/15/05 STC 6288 6614 4268.03 4377.49 MPE -12 9/15/05 STC 6288 6614 4268.03 4377.49 MPE -12 10/9/05 STO 6288 6614 4268.03 4377.49 MPE -12 1/2/06 STC 6288 6614 4268.03 4377.49 MPE -12 1/3/06 STO 6288 6614 4268.03 4377.49 MPE -12 2/23/06 STC 6288 6614 4268.03 4377.49 MPE -12 3/19/06 STO 6288 6614 4268.03 4377.49 MPE -12 6/15/06 STC 6288 6614 4268.03 4377.49 MPE -12 7/2/06 STO 6288 6614 4268.03 4377.49 MPE -12 8/19/06 STO 6288 6614 4268.03 4377.49 MPE -12 11/4/07 STO 6288 6614 4268.03 4377.49 MPE -12 12/4/09 STC 6288 6614 4268.03 4377.49 MPE -12 12/9/09 STO 6288 6614 4268.03 4377.49 MPE -12 12/14/09 STC 6288 6614 4268.03 4377.49 MPE -12 2/16/10 STO 6288 6614 4268.03 4377.49 MPE -12 8/27/12 STC 6288 6614 4268.03 4377.49 MPE -12 12/2/12 STO 6288 6614 4268.03 4377.49 MPE -12 6/6/05 PER 6375 6390 4300.4 4306 MPE -12 6/6/05 PER 6410 6437 4313.46 4323.53 MPE -12 8/19/06 STC 6583 9297 4370.42 4393.67 MPE -12 2/16/10 STO 6583 9297 4370.42 4393.67 MPE -12 9/15/05 STC 6614 9297 4377.49 4393.67 MPE -12 9/21/05 STO 6614 9297 4377.49 4393.67 MPE -12 2/12/06 STC 6614 9297 4377.49 4393.67 MPE -12 2/23/06 STO 6614 9297 4377.49 4393.67 MPE -12 6/16/06 STC 6614 9297 4377.49 4393.67 MPE -12 7/3/06 STO 6614 9297 4377.49 4393.67 MPE -12 10/23/06 STO 6614 9297 4377.49 4393.67 MPE -12 10/24/06 STC 6614 9297 4377.49 4393.67 MPE -12 1/21/07 STO 6614 9297 4377.49 4393.67 MPE -12 11/3/07 STO 6614 9297 4377.49 4393.67 MPE -12 12/5/09 STC 6614 9297 4377.49 4393.67 MPE -12 12/15/09 STO 6614 9297 4377.49 4393.67 MPE -12 3/16/11 STO 6614 9297 4377.49 4393.67 MPE -12 12/20/11 STC 6614 9297 4377.49 4393.67 MPE -12 8/28/12 STO 6614 9297 4377.49 4393.67 MPE -12 12/1/12 STC 6614 9297 4377.49 4393.67 MPE -12 12/2/12 STO 6614 9297 4377.49 4393.67 MPE -12 6/6/05 PER 8668 9168 4419.83 4409.15 AB ABANDONED MIR REMOVED • • APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028231 SW Name Type MD TVD Depscription MPE -12 PACKER 6226 4244.35 3 -1/2" Baker Premier TCII Packer MPE -12 PACKER 6281 4265.44 3 -1/2" Baker Premier TCII Packer 1 MPE -12 PACKER 6614 4377.49 4 -1/2" Baker ZXP Packer Casing / Tubing Attachment ADL0028231 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 13 -3/8" 72# L -80 33 - 148 33 - 148 4930 2670 LINER 2703 4 -1/2" 12.6# L -80 6594 - 9297 4430.39 - 4451.02 8430 7500 PRODUCTION 6730 7" 26# L -80 31 - 6761 31 - 4461.45 7240 5410 SURFACE 3214 9 -5/8" 40# L -80 32 - 3246 32 - 2652.61 5750 3090 TUBING 6243 3 -1/2" 9.3# L -80 30 - 6273 30 - 4319.82 10160 10530 TUBING 6243 3 -1/2" 9.3# L -80 30 - 6273 30 - 4319.82 10160 10530 TUBING 360 3 -1/2" 9.3# L -80 6273 - 6633 4319.82 - 4438.74 10160 10530 • 0 TREE: 3 -118" - SM FMC � 2 Or' Elev. = 57.35 Doyon 14 WELLHEAD: 11" x 3-1/8" 5M M P E � Gen 5 OriligL Elev. = 33.95 Doyon 14 + Tub Hgr. 11" x 3 -1/8" TC -II T &B 3" CIW -H BPVT Conductor 112' Al KOP @ 250' Angle passes 50° @ 2400' 15" HES X- Nipple 2.813" 1 2,494' Max Angle in Tbg = 79° @ 6659' Angle thru liner = 90 +° ;.r 1 - ,,C." ' ' ' ' 9 - 5/8" 40# L -80 BTC Csg. I 3,246' I A 1 Gas Lift Valve Arrangement 1± , 6370' SPM - RK -DGLV 3.5" 9.2 #/ft L -80 TC -II 6430' SPM - RK -P -15 ( Drift id = .0087 Bpf.) 6583' XN - RMX w/ P -15 4.5" 12.6 #/ft L -80, IBT On 12/1/12 ( Drift id = .00152 bpf. ) 7 " 26 ppf, L -80, BTC -Mod casing ( drift ID = 6.276 ", cap. = 0.0383 bpf) 3.5" HES X- Nipple 2.813" 6,176' I (cap w/ 3 1/2" tbg inside = 0.0264 bpf) IIII 1111 7" x 3 .5" Baker Premier pkr I 6,226' I a � 6,251' ° 3 HES X- Ni 2 Unique Machine Overshot 6,267' At Top of cut Pup Jt Stub 6,276' I 7" x 3.5" Baker Premier pkr. 6,288' I Schrader "NC /ND" Perfs SPF MD TVD N� 1 0 3.5" x 1.5" Camco MMG (rk) 6,370' 5 6,375'- 6,390'14,357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 149 i 3.5" x 1.5" Camco MMG -W (rk) 1 6,430' I 4.5" HSD 6 SPF. PJ4505 ' ' 17 ��, 3.5" HES XN- Nipple 2.750" id. ( 6,583' I ( 2.813" pkg. bore ) 6,606' 6 I Baker Tie back sly. Baker Locator sub 6,614' B aker 806-40 Seal Ass bottom 6,633' I Baker ZXP Packer y Baker "RS" Nipple 6,616' — Baker HMC Liner Hgr. 6,623` — 7 " float collar (PBTD) 6,675' Baker 80-40 Seal Bore ext. 6,643' 7 " Weatherford float shoe 6,761' i Schrader "OA" Perfs { SPF MD TVD 0 M ,R 6 9,168' - 8,668' 14,466' - 4,477' 1 9,212' I 4.5" Baker Landing Collar 1 9,253` 1 Halliburton Float collar 2 - 7/8" HSD 6 SPF. PJ906 ,) 9,297 I 4.5" Baker float shoe DATE REV. BY COMMENTS MILNE POINT UNIT 06/08/05 MDO Drilled & Completed Doyon - 14 WELL MPE -12 09/14/05 Lee Hulme RWO to correct tbg leak 4ES API NO: 50- 029 - 23262 -00 BP EXPLORATION (AK) • • id F A , SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Alecia Wood Production Engineer a BP Exploration (Alaska), Inc. 'O P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPE -12 Sundry Number: 312 -281 Dear Ms. Wood: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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 S DATED this / day of August, 2012. Encl. 1 4 r .1/ RECEIVED • STATE OF ALASKA b JUL 2 5 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations • 0" ,iv Perforate ❑ Pull Tubing ❑ TAF ension ❑ Operations Shutdown ❑ Re -enter Susp. Well Li 113 ‘ St imulate ❑ Alter Casing ❑ Other. tigct f'yiy 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: -11 1 7 \ \ *(v BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 205 -067 -0 ' 11 3. Address: Stratigraphic ❑ Service © • 6. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 23262 -00 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El MPE -12 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0028231 • MILNE POINT, SCHRADER BLFF 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): 9297 • 4451. 6583 4428 6583 None Casing Length Size MD TVD Burst Collapse Structural Conductor 115 13 -3/8" 72# L -80 33 - 148 33 - 148 4930 2670 Surface 3214 9 -5/8" 40# L -80 32 - 3246 32 - 2652.61 5750 3090 Intermediate None None None None None None Production 6730 7" 26# L -80 31 - 6761 31 - 4461.45 7240 5410 Liner 2703 4 -1/2" 12.6# L -80 6594 - 9297 4430.39 - 4451.02 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSV Installed No SSV Installed 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 8/21/12 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ IN • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Prepared by Garry Catron 564 -4424 Printed Name Alecia Wood Title Production Engineer Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2 • 2)' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: sy '�� lljll �„ t/ "� COMMISSIONER Fi gIfi gISSION Auk a 1 2012 Date: e i '- l Z ��`"^ g rl/la ti y Form 10-403 R vised 1/2010 /' 4/7/ in Duplate / � , ORIGINAL. � � • S Packers and SSV's Attachment ADL0028231 Well Facility Type MD Top Description TVD Top MPE -12 PACKER 6226 3 -1/2" Baker Premier TCII Packer 4302 MPE -12 PACKER 6281 3 -1/2" Baker Premier TCII Packer 4323 MPE -12 PACKER 6614 4 -1/2" Baker ZXP Packer 4435 • 0 Casing Summary ADL0028231 Casing Length Size MD Top MD Base ND Top ND Base Burst Collapse CONDUCTOR 115 13 -3/8" 72# L -80 33 148 33 148 4930 2670 LINER 2703 4 -1/2" 12.6# L -80 6594 9297 4430 4451 8430 7500 PRODUCTION 6730 7" 26# L -80 31 6761 31 4461 7240 5410 SURFACE 3214 9 -5/8" 40# L -80 32 3246 32 2653 5750 3090 TUBING 360 3 -1/2" 9.3# L -80 6273 6633 4320 4439 10160 10530 TUBING 6243 3 -1/2" 9.3# L -80 30 6273 30 4320 10160 10530 • • Perforation Attachment ADL0028231 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPE -12 2/16/10 STO 6375 6390 4358 4363 MPE -12 2/16/10 STO 6410 6437 4371 4381 MPE -12 12/20/11 BPS 8668 9168 4477 4467 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • bp To: Mark O'Malley /Rob Handy Date: July 17, 2012 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPE -12 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPE -12 2 F Bullhead treatment down MPE -12 (OA sand). Keep well and offset producers , and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPE -12 was drilled and completed as an Nc /Nd and OA regulated injector in the Schrader Bluff in 2005. MPE -12 provides injection support for three producers in hydraulic unit 17: MPE -30A, MPE -31 and MPE -32. Shortly after being completed a tubing leak was discovered. The leak was repaired during a RWO by cutting and pulling tubing and running new tubing with an overshot. This overshot has resulted in slickline intervention problems in the past. In 2009 a drastic watercut increase in producer MPE -32 indicated an MBE from MPE -12. Red dye tests were performed and the MBE was confirmed in the OA. Since the formation of the MBE, injection has been cycled on and off K in the OA but has continued to show a direct connection with MPE -32. MPE -12 is horizontal in the OA sand and injects through 500' of perforations. A coil tubing FCO and IPROF was performed in December 2011 to determine the location of the MBE within the horizontal section. Following the IPROF the OA sand was dummied off in MPE -32 and will remain shut in until an MBE treatment is performed. Cumulative injection in MPE -12 totals 1.471 mmbbl combined between the Nc /Nd and OA. i i PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • 40 7REE 3- '3' - 90 fii4C Ong OF Sew = 57,35 DPW 11 ViSLL:r1E,K3 ti• x 3 Af Re( Ger 5 MPE-12 Org CxL Elev, = 33.gf, Boyce q4 ruit rIgr 11' x 3-11 TC-4 Tiff 3 C1W-1-1 OP , 1 CdrastroT ' _ Li 2400' li 5" HE -e 2l3 I 24g4 &11"C Cg 2,245 A 1 0C-57 3.5' HES X-Nipple 2 813' • 7 ' $ 3 e Baker Premier ok • 5' 225 C-- , Eill 7 3 5* ` HES X- : : 5 25'1 i.lnique Mad Oiersr or Top of cut Pup It Stub Il 7' x 3.5 Baker rerik ier pkr_ 1 F.: 2 ' 7 : : _ q " x 1 5" Carrico ktik413 Ali 1 1 ., -. 5i -: . i : - . : : - i : -" I P:444. 3 5 HES 04-Nipple 2.7.5C' is ( 2 813' pkg bore i 5 if:: fi Baker Tie back sty Baker Locator sub 5 5,14 Saker 2X.P Packer ill I 7.: .-- r sr 805-40 Seal Ass), oettorr 5 51:3i a her 'RS' Nipple 5 61 t. Eiaker Hk1C Liner Hgri 7 ' float collar (P131 '- 52iii E.. •a ke e3-43 s A eat Bore =.:i.rt 4- 7 • Weatherford Moat shoe e,761 643 Schrader `CA ,= 1 NO 'P.M dc - a-r .5 9 108'-8,15153 448 - 4 ' ' - - 1 I g 2 i 2 , ' 1 4 5 ' E 3 :i r i p i i n g ai a a Ca iir sh PAGE COMMENTS MILNE POINT UNIT MOO piped & Completed Door - 14 WELL MPE Lee HuIrre RitiVO to corre-::t tog: 'e.71; 4ES API NO: 50 BP EXPLORATION (AK) e • • bp BP Exploration (Alaska) Inc. 4. Attn: Well Integrity Coordinator, PRB -20 - Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 k f W EB 2 2 a(J1Z " ... r Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad (D s-- 067 Dear Mr. Maunder, f/ E-- L 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 - 138 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 0.2 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 20- DEC -2011 Sch Winner 5843 Alaska Data & Consulting Services Company: State of Alaska 2625 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 09 -18 BVYC -00017 SLIM CEMENT MAP TOOL 26- Nov -11 1 1 MPS -01A BY05 -00003 ISOLATION SCANNER 25- Nov -11 1 1 F -05A BINC -00084 LEAK DETECTION LOG 19- Nov -11 1 1 P1 -03 BINC -00082 PPROF W/ DEFT & GHOST 17- Nov -11 1 1 17 -19A BJGT -00082 SBHPS 17- Nov -11 1 1 09 -12 BD88 -00183 MEMORY LDL 28- Nov -11 1 1 C -02 BYS4 -00005 PRIMARY DEPTH CONTROL 16- Nov -11 1 1 • 04 -350 BYS4 -00006 USIT 16- Nov -11 1 1 GC -2E BYS4 -00011 RST WATERFLOW 6- Dec -11 1 1 15 -09A BINC -00085 PRIMARY DEPTH CONTROL 8- Dec -11 1 1 09 -17 BAUJ -00104 MEMORY INJECTION PROFILE 30- Nov -11 1 1 MPE -12 BD88 -00185 MEMORY INJECTION PROFILE a Os-- C1 6 7 14- Dec -11 1 1 A 16-03 BG4H -00099 INJECTION PROFILE 28- Oct -11 1 1 MPL -24 BUTT -00004 MEMORY INJECTION PROFILE 6- Aug -11 1 1 2- 50 /U -08 BD88 -00184 MEMORY IPROF W /DEFT GHOST 11- Dec -11 1 1 A -11 BSM4 -00018 INJECTION PROFILE 30- Oct -11 1 1 s PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; tom.maunder~a~sKa.ganr;bob.ftecker~tein@alaska.gov;doa.aogcc.prudhoe.bay~alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Explaration (Alaska), Inc. Miline Point / MPU / E Pad 10/05109 Anna ~ube Jeff Jones Packer Peetest Initial 15 Min. 3Q Min. Well MPE-12 T tn. W TV~ 4,3Q'1' TuE~ t,f~? 1,14E} 1,140 1,140 Intenral 4 P.T.D. 2050670 T test P Test ` 'lSQQ C~i 2Q 2,W0 7,920 1,930 P!F P Notes: MIT-IA for 4 year regulatoryoomptiarrae OA 42'~ ~F20 42~ 420 Extended test addidonal 15 min d~e to iAP ~ ~ t~o furtl~er ~ res. Well T In". TYD ' T~ "' Irrterval P.T.D. T test Test ' P/F Notes: OA We11 T In. NQ T' Interval P.T.D. T te~ Te~ ~ C' P!F Notes: OA Well T In'. T'W~ T' Interval P.T.D. T test ~esk ~ PIF Notes: OA Well T In". TVD Tubi Irrterval P.T.D. T test Test ~ Casi P/F Notes: Ol# TYPE INJ Codes D = Driiling Waste G=Gas I =lndustrial Wastewater N = Not Injecting W = Water TYPE TEST Codes N! = Annulus INo~ni~arir~g P = Standard PressuEe ~'est R =lrrterna! ` Traeer &uevcy A = T S~rey D = Te~p~rature Test ~., ~~~~~-~°'~` ~~r~,! ~° `` LCO~ ~}~r. ~~ f~ ~ ~~~~ INTERVAL Codes I = Initial Test 4 = Four Year Cycfe V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT MPU E-12 10-05-09.x~s ozJZO/os Schf~mberger NO. 4590 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ~y~y g~~ pp , Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 {+J6~lI1f~~~ ~EC~ ~ ~ L/QCU Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Milne Pt,Endicott,Borealis,Polaris,Lisburne Wwll Inh $ 1 nn rlnerrintinn I'hIn RI Rnlnr Rr1 18-32A 11968923 SCMT / - ~ 02112/08 1 MPE-12 11978438 MEM INJ PROFILE U=C~-c,~US - C3Co'~ 02108108 1 4-14/R-34 11996383 USIT (, 02/12108 1 V-07 40016096 OH MWDILWD EDIT '~ - L ~ Lac 12/04/07 2 1 L1-14 11626482 RST ~ "- / j s'9~/3 05109/07 1 1 L2-18A 11657124 RST ~ 05/10/07 1 1 L2-33 11626484 RST ~ (p- ~ `njG 05/11/07 1 1 G-31A 11962778 RST - vS ~j ~j 01/01108 1 1 V-111 11978439 MEM GLS ~ 02/10/08 1 W-216 12031441 CH EDIT PDC GR ~US17) ~j 01111/08 1 W-214 40016055 OH MWDILWD EDIT V= _ I 11115/07 2 1 Y-07A 11962576 USIT '' 12/18/07 1 C-35B 11978432 _ MEM DDL ~ / 01/02/08 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIN.G,~O~E„COPY EACH TO: BP Exploration (Alaska) Inc. f Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 r 1 1 ~ ~ , , i. ; 9 ._. ,.. > ; ~~, i.., Date Delivered: a ~,;}~.,~ i :: Alaska Data & Consulting Services 2525 Gambelf Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: • • ~y MPE-12 (PTD #2050670) Reclas~ed as OPERABLE • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, February 07, 2008 11:55 AM <~~ ~~~(~~ To: 'NSU, ADW Well Integrity Engineer' 1 1 Cc: Maunder, Thomas E (DOA) Subject: RE: MPE-12 (PTD #2050670) Reclassified as OPERABLE 1 agree with removing this from monthly well integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 c~~i~tltlltl~ F~D ~ ® 2~U0 Page 1 of 2 From: NSU, ADW Weli Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, February 05, 2008 2:34 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; Green, Matt D; MPU, Area Manager; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; MPU, Field Lead Tech Cc: Townsend, S. Eliot; Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: MPE-12 (PTD #2050670) Reclassified as OPERABLE All, An IA bleed was performed on MPE-12 on 01116108. As evidenced by the attached TIO plot; the IA pressure has / remained stable since that time. The well has been reclassified as Operable and removed from the Monthly Injection report. «MPE-12 30-day TIO PIot.BMP» Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Friday, January 18, 2008 4:48 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; MPU, Well Operations Supervisor; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; Green, Matt D; MPU, Area Manager; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; MPU, Field Lead Tech Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION -MPE-12 (PTD #2050670) for Possible Slow TxIA Comm Hi all, A plot of well MPE-12 (PTD #2050670) wellhead pressures indicates possible slow TxIA communication. The well has been reclassified as Under Evaluation and may stay on injection while being evaluated. Please note that injection rates 2/7/2008 MPE-12 (PTD #2050670) Reclaed as OPERABLE . Page 2 of 2 show a similar trend over the same ~unt of time. The plan forward includes: 1. Oper: Bleed IAP -DONE 2. Oper: Monitor IAP build-up rate 3. WIC: Review pressure trends to determine if an AA is needed 4. FB: AOGCC MITIA if it is decided to request an AA A wellbore schematic, TIO plot, and Injection Plot have been included for reference. This well has been added to the Monthly Injection report while it is being evaluated. 2/7/2008 ~,ooo IVIPE-12 TICI Plod + Tbg • 3,000 -~~- IA 2,000 ~ 11-, !-A~4R'S~ -f- ~A 1,000 'y C~OA ~ ~- ~~~~ a ~~o ~ rsrzoos ~ M orzooo ~ ~t sr~oos ~ rzo~2ooe ~ r~sr~oos ~ raor~oos ~rsrzaos ~r~ arzooe ~n srzoos ~rzor~oos zr~~r~ooa 3~1 r 008 UNDER EVALUATION - MPE~(PTD #2050670) for Possible Slow T~ Comm Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ ~~~~ i~~ Sent: Friday,. January 18, 2008 4:48 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; Green, Matt D; MPU, Area Manager; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; MPU, Field Lead Tech Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION -MPE-12 (PTD #2050670) for Possible Slow TxIA Comm Attachments: MPE-12.pdf; MPE-12 TIO PIot.BMP; MPE-12 Injection PIot.BMP ~' Hi all, A plot of well MPE-12 (PTD #2050670) wellhead pressures indicates possible slow TxIA communication. The well has been reclassified as Under Evaluation and may stay on injection while being evaluated. Please note that injection rates show a similar trend over the same amount of time. The plan forward includes: ~ SAN ~ .~ 2Q~~ 1. Oper: Bleed IAP -DONE 2. Oper: Monitor IAP build-up rate 3. WIC: Review pressure trends to determine if an AA is needed 4. FB: AOGCC MITIA if it is decided to request an AA A wellbore schematic, TIO plot, and Injection Plot have been included for reference. «MPE-12.pdf» «MPE-12 TIO PIot.BMP» «MPE-12 Injection PIot.BMP» This well has been added to the Monthly Injection report while it is being evaluated. 1 /24/2008 'si OO b'O ~- 'si'I -!- 000' 4 000' Z 000' £ s 6ql -#- ~~Ic~ C~Il ~ 4-~dllll ooo'tr ~ rrnri0 414 0 L ~o-Sl~. ~d SOOZIS 414 LOOZ~B ~ 4 4 L00~10 416 LOOZJ6 41L L00~16 41S L~OZJ6 41£ _. -~= _ - ~ ~s-~-~ a a u, m O LL ~..a O ~ ~2 ~ a tl'1 Q°, D + o ~ a ~ o a ~ ~ C7 0 111812007 N1PE-1~ wily Allocated Injection Plot 311812007 5!1812007 7M 82007 ~ - ,!SNIP • 0 0 v o 0 _ S~IVI o cra ~ ~ tg o - Ph!'++I+DhlVl o ~ cv 'a ~_ o ~ - MGI a ,~ GAS • 9M 812007 1111812007 1118008 TREE: 3-1/8" - 5M FMC WELLHEAD: f 1" x 3-1/8" 5M en 5 Tub Hgr. 11" x 3-1/8° TC-11 T&B 3" CIW-H BPVT Conductor 112' KOP @ 250` Angle passes 50° @ 2400' Max Angie in Tbg = 79° @ 6659' Angle thru liner = 90+° 9 - 518" 40# L-80 BTC Csg. 3,246` Schrader "NC/ND" Perfs SPF MD TVD 5 5 6,375`- 6,390' 6,410'- 6,437' 4,357` - 4,390' 4,371 ` - 4,381' 4.5" HSD 6 SPF. PJ4505 Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ext. 2-7/8" HSD 6 SPF. PJ906 DATE REV. BY COMMENTS 06/08/05 MDO Drilled & Completed Doyon - 14 09/14/05 Lee Hulme RWO to correct tbg leak 4ES Schrader "OA" Perfs SPF MD TVD 6 9,168`-8,668' 4,466'-4,477' Or Elev. = 57:35 Doyon 14 Or~ Elev. = 33.95 Doyon 14' 3.5" HES X-Nipple 2.813" 2,494' 3.5" HES X-Nipple 2.813" 7" x 3.5" Baker Premier pkr 3.5" HES X-Nipple 2.813" Unique Machine Overshot Top of cut Pup Jt Stub 7" x 3.5" Baker Premier pkr 3.5" x 1.5" Camco MMG (rk) 6,176` 6,226` 6,251' 6,267` 6,276` 6,288` 6,379` 3.5" x 1.5" Camco MMG-W (rk) 6,439` 3.5"HES XN-Nipple 2.750" id. 6,585` ( 2.813" pkg. bore ) Baker Locator sub 6,600` Baker 806-40 Seal Assy bottom 6,633' 7 "float collar (PBTD) 6,675` " 7 "Weatherford float shoe 6,761` 4.5" Baker Landing Collar Halliburton Float collar 4.5" Baker float shoe MILNE POINT UNIT WELL"MPE-42 API NOt 50-0.29-23262-00 BP EXPLORATION g j~l DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050670 Well Name/No. MILNE PT UNIT SB E-12 Operator BP EXPLORATION (ALASKA) INC MD 9297 -' TVD 4451 /" Completion Date 6/8/2005"; Completion Status 1WINJ REQUIRED INFORMATION Samples No Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GYRO, DIR, GR, RES, IFR/CASANDRA, SCMT, CCL, USIT Well Log Information: Log/ Data Digital TypyMed/Frmt ~ D Asc ¡6 D Lis ~ c..E!D C Pdf ~ vA-0g ~ C Lis Electr Dataset Number Log Log Scale Media Run No Name Directional Survey 13215 Induction/Resistivity 13215 LIS Verification 13470 Injection Profile 5 13470 Injection Profile 5 Blu Sonic 5 Blu 13534 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? ylf) Chips Received? n-/ N Analysis Received? Daily History Received? Formation Tops ~ Current Status 1WINJ API N~~~~2~~~ M \\~- ~ ... Directional Surçy Yes => (data taken from Logs Portion of Master Well Data Maint INJECTION PROFILE GRlCCUSPINITEMP/PRE SS INJECTION PROFILE GRlCCUSPINITEMP/PRE SS ULTRASONIC IMAGER LOG CEMENT MODE USIT-B 9297 Open 2/22/2006 ROP DGR EWR SLD CTN plus Graphics Interval OH/ Start Stop CH Received 0 7070 Open 7/29/2005 104 9240 Open 7/7/2005 104 9240 Open 7/7/2005 6120 6648 2/2/2006 6120 6648 2/2/2006 3900 6565 2/22/2006 143 Sample Set Number Comments ~N ~/N - Comments GR EWR4 ABI MRIL CNP SLD ROP ACAL e DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050670 Well Name/No. MILNE PT UNIT SB E-12 Operator BP EXPLORATION (ALASKA) INC MD 9297 TVD 4451 Completion Date 6/8/2005 Completion Status 1WINJ Current Status 1WINJ Comments: Compliance Reviewed By: )h Date: API No. 50-029-23262-00-00 UIC Y or JCA~ .2..o~ 7 e - c/ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Febmary 16, 2006 RE: MWD Formation Evaluation Logs MPE-12, )~5~ 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-12: LAS Data & Digital Log Images: 50-029-23262-00 DIC, ;)06 .- tx.Ó7 1 CD Rom ~lUn ~lg~/lJp . STATE OF ALASKA . Alt\. Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS D D D Stimulate 0 . Other D Waiver D Time Extension D Re-enter Suspended Well D ,... 5. Permit to Drill Numb. ~ CI') 205-0670 :- M 6. API Number: S? 50-029-23262-00-00 ¡zo 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic D Exploratory Service :s: ...u J> m ,L' c ) t-..::1 m ~ "-.: < m er, 0 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: :::r ~/ -g..", MPE-12 Q n 10. Field/Pool(s): ::: ~ Milne Point Field/ Schrader Bluff Oil Pool SO ~ ª ¡;¡. '" õ' :::I 9. Well Name and Number: KB 57.35 8. Property Designation: ADL-028231 "APt., ~1t{'3!> )Þ,¡.'S.Þ' 11. Present Well Condition Summary: Plugs (measured) Junk (measured) None None feet feet Total Depth measured 9297 true vertical 4451.02 feet feet Effective Depth measured 9212 true vertical 4462.27 TVD Burst Collapse 32 - 112 1490 470 31 - 2652.61 5750 3090 30 - 4461.45 7240 5410 4433.1 - 4451.02 8430 7500 Size 20" 91.5# H-40 9-5/8" 40# L-80 7" 26# L-80 4-1/2" 12.6# L-80 MD 32 - 112 31 - 3246 30 - 6761 6606 - 9297 Casing Conductor Surface Production Liner Length 80 3215 6731 2691 8668 - 9168 4477.18-4466.5 Perforation depth: Measured depth: 6375 - 6390 True Vertical depth: 4357.75 - 4363.35 6410 - 6437 4370.81 - 4380.88 30 - 6633 3-1/2" 9.3# L-80 Tubing: (size, grade, and measured depth) 6226 6288 6614 3-1/2" Baker Premier TCII Packer 3-1/2" Baker Premier TCII Packer Baker ZXP Pkr Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 373 420 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil D Gas D WAG 13. Tubing pressure 1030 926 Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations M Service x GINJ WINJ M WDSPL SUndry Number or N/A if C.O. Exempt: 306-052 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal ~ 7k OR/GlrVAL Title Data Mgmt Engr Printed Name Sharmaine Vestal Date 3/21/2006 Phone 564-4424 RBDMS m-l MAR 2:3 ZffiJH~~(.' Submit Original Only ,A?>b~7P?/C6 Form 10-404 Revised 04/2004 ' · MPE-12 . DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMM'ARY 2/16/2006 Injectivity Test Into NC/ND Sands. (Pre Acid Treatment). 351 BPD @ 1000 psi. 376 BPD @ 1106 psi. 714 BPD@ 1191 psi. BBLS 252 79 143 474 T/I/0=900/0/200 Acid Teatment. Pumped 5 bbls meoh, 20 bbls 12% HCL ACID, 3 bbls meoh, 5 bbls diesel, 42 bbls produced water, and 5 bbls meoh down tbg. Pumped at 0.5 bpm <1200 psi. Final WHP=1000/0/200. Injectivity Test Into NC/ND Sands. (Post Acit Treatment). 387 BPD @ 1005 psi. 677 BPD @ 1095 psi. 1048 BPD @ 1202 psi. 3/1/2006 CTU #4, Acid Stirn; ... Cont' from WSR 02/28/06... MU 2.0" OD JSN. Fluid pack coil with 35 bbls of 60/40 meth. RIH with JSN nozzle. Tag TD at 9194' ctmd. PUH to 8400' and standby for pump truck and acid transport. RU Dowell pump truck and PT lines. Began pumping 2% KCL heat up lines prior to pumping acid and coil pressure immediately began fluctuating from 3000 to 3800 psi at 0.4 bpm; 5 bbls of 2% KCL was pumped. Determined that slush/ice was forming in coil due to low ambient (-37F) and lower than expected temperature of KCL in upright (45F). Immediately swapped back to coil pump and freeze protected coil with 60/40 meth; coil pressures continued to fluctuate while pumping meth and finally stabilized once water in coil made it over the goose neck. Vac truck pulled 80 bbls out of upright in an attempt to get to warmer fluid but temperature stayed only lukewarm. Decision made to POOH due to hours, ambient temp, and fluid temp in upright. Well is secure. Called LRS to heat upright to 150F. Coil unit and Dowell pump truck still on location and crews will return in AM to finish job ... Job in Progress - Cont' on WSR 03/02/06... 3/4/2006 CTU #4, Acid Stirn; ... Cont' from WSR 03/01/2006... Perform weekly BOP test. MU 2.0" OD JSN. RIH and tag TD at 9196' ctmd. PUH to 8600' ctmd. Establish baseline injectivity of 0.6 bpm at 1400 psi with 2% KCL. Begin pumping 12% HCL 90:10 DAD acid and reciprocate across perfs. While RIH at 10 fpm, injectivity dropped to 0.3 bpm at 1500 psi. Set down at 9030' ctmd and could go no further. PUH to 8600' ctmd and shut down pumps to let HCL soak for 15 mins. RBIH while acid was soaking and attempt to get back down to btm of perfs. Tag 9060 and could go no further. Begin pumping 0.3 bpm at 1500 psi and PUH. Saw large overpulls (20- 30K) around 8800' ctmd. Park coil at 8600' ctmd and injectivity returned to 0.6 bpm at 1400 psi. Decided to try reciprocating across perfs again; RIH and at 8820' ctmd and WHP came up to 1600 psi almost instantaneously. PUH to 8600 and saw overpulls again. It appears we were being differentially stuck across the section of perfs that was taking a majority of the injection. This would also explain why injectivity would drop off when we ran in hole. Pumped a total of 143 bbls 12% HCL 90:10 DAD acid followed by 50 bbls 2% KCL. Freeze protected coil with 35 bbls 60/40 meth and POOH. *** Job Complete *** Initial injectivity: 0.6 bpm at 1420 psi. Final injecivity: 0.6 bpm at 1420 psi. FLUIDS PUMPED KCL 60/40 Meth 12% DAD acid TOTAL tCHANI CAL INTEGRITY REPORT.... è10S-()~ ( S-r""'lL-o~ _. =- ? U D Iì .~. '!:: : 'd-o ~ - -c "~,,... ~ - Ct:,1c---'"' ~ :.~.. r...::..1.....:..r_.:~:· I~o· \J ~ ~~t\c~, C-\ (l....-OS- -~t:.LL DATi-. TD: ~C;~ .MD. 4'--\5\ TVD; :?BTD: ~)Sl.\ MD 44S~ TVD '\ \\ l,,",-^ Cê.si~g: Shoe: G:>"\C-l till 4'-\~\ TVD¡ DV: 1-J~.. HI) ,~ ·TVD _::":Je::-: L\ '1 J Shoe: ~;}<;'\ MD 4~~ \ TVD j :CP: ~-<;.~ l·m '-\~~G ::TQ - .,jQ '-.:; 5: ?:/ (-;,. Packer brd(,., HI) Tv'TI í Set ê. t: ~ b "'S ~ ::ale Size <ts\l~ ê.nci (p'$~ j Perf.s '=>-Š~S- to "?~~\(t: CP~ \<ë~'o", <; \ Co 8;. :'SC?..Þ.lECf...L INTEGRITY - PART /l OPER [. FIELD -\6V K\\~ \>rcJ\~ M \? \=. - \ d-.. l ~'-~~'\ ì..:"ELL NUME ER l-_nnulus Press Test: :;:P (}ör::,O: 15 min \<;50 Corrroents: c..~'C..\L~~~-..)Q \O{";)~-QC:S- 30 min lq S'lj ,-.- :-ŒeHÞ_¡qIe¿.~ INTEGRITY - PART 12 ¡-==t ~~\.>b \ r"'S~$\ i Csg 3S\~~ ; DV ~ ~ ;}(,.. ~~\~.\" ,\'\ é ~'Ç ~~\~\" \,~\'" C e~en C Volumes:· Þ..mt. Liner S\S~"IC e~t: ~ol Co cover Der=.s c: Š~(o ~ '-> Theorecical TOC Q ~G~o ~<> '\'" \Dc.... ~~d"\D ~f-t\.-\~~d\~~\"-~\J ~~..\'\~ç-~{) ~ {(Jto S-. Cement Bond Log (Yes or No) '(<!:::s ; In AOGCC File .\{€-~ eBL !::valuation, ::one ¿Dove perfs \D~~<C~\'i \f\.. ~.. 'ß(:)'~\~ '\ "'> O",CJè\\~~ ~~oc)\.\-o T\) \ø~~: Prociuction Log: Type Evaluation CONC.LUSIONS: ? ar ~ t 1 : " \ ~~~ ~CVC)('...s~\..~ , ? ar~ ; 2 : K '\ '\ "? '\ ~ ~c C(\~ . JLJ<11V{ -S¡ .-00 F)- \ . . ~m" '~'rr r ~ ß" c: ¡: l ~ ,I' ~ ¡ f ¡;. iU."¡ ~;! r? ¡, ljl' \~! ¡ t! !: (: uU L!:::a rm WJ FRANK H. MURKOWSKI, GOVERNOR A"/A~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Matt Green Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, MPE-12 Sundry Number: 306-052 Dear Mr. Green: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisL!Íday of February, 2006 Encl. Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 1. Type of Request: Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: ADL-028231 11. Total Depth MD (ft): 9297 Casing Conductor Surface Production Liner Perforation Depth MD (ft): 6375 - 6390 6410 - 6437 8668 - 9168 Packers and SSSV Type: 12. Attachments: 57.35 KB ITotal Depth TVD (ft): 4451.02 Length _ STATE OF ALASKA aiI~.-/~,()~II1Ä~ RECEIVED A~ OIL AND GAS CONSERVATION COMM N . j(t ~ FEB 1 4 APPLICATION FOR SUNDRY APPROVAL A 2006 20 AAC 25.280 taska Oil & Ga~ Co "'. Operational shutdown U Perforate U Waiver U A h ~f¡&~ IIISSIon . D S . I í7l . E . D nc orage Plug Perforations tlmu ate ~ Time xtenslon Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill ~mber: Development D Exploratory D 205-0670 V Stratigraphic D Suspend U Repair well D Pull Tubing D Service ~ 6. API Number: ./ 50-029-23262-00-00 9. Well Name and Number: MPE-12 10. Field/Pools(s): Milne Point Field / Schrader Bluff Oil Pool PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): IEffective Depth TVD (ft): 9297 4451.02 Size MD TVD IJUnk (measured): None Collapse 470 3090 5410 7500 IPlugs (measured): None Burst 80 20" 91.5# H-40 32 112 32 112 1490 3215 9-5/8" 40# L-80 31 3246 31 2653 5750 6731 7" 26# L -80 30 6761 30 4461 7240 2691 4-1/2" 12.6# L-80 6606 9297 4433.1 4451 8430 Perforation Depth TVD (ft): 4357.75 - 4363.35 4370.81 - 4380.88 4477.18 - 4466.5 3-1/2" Baker Premier TCII Packer 3-1/2" Baker Premier TCII Packer Tubing Size: 3-1/2" 9.2# Tubing Grade: L-80 Tubing MD (ft): 30 - 6633 Packers and SSSV MD (ft): 6226 6288 Date: 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D Plugged 0 WAG D GINJ D WINJ ~ Abandoned D WDSPL D Descriptive Summary of Proposal ~ Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ~~reen Title Production Engineer Signature /f/I ¿ /\tì~ Phone 564-5581 Date COMMISSION USE ONLY 2/23/2006 Service ~ Prepared by Sharmaine Vestal 564-4424 Matt Green 2/9/2006 Conditions of approval: Notify Commission so that a representative may witness SUndry Number: ?SOlo - 05:J Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: \1\)~c.5:>"~ '- ~ ':'''Q ~Ä ~\ àO~b..,C~~, J~ ~ a-<&-ì. , ~OO ~S\ :\-'~"'""'-~'t?~c::.\-r R' BDMS BFl . " "" FEB 1 5 2006 7\ Form 10-403 Revised 7/2005 V 0 ---- APPROVED BY THE COMMISSION Date: tR- If - ()¡, COMMISSIONER (;INAL Submit in Duplicate . . From: Matthew Green Milne Point Production Engineer To: Clint Spence I John Cubbon Wells Operations Supervisor CC: Danielle Ohms Milne Point Lead Production Engineer Date: Subject: MPE-12 Acid Stimulation lOR: 1000-BOPD Estimated Cost: $60K AFE: E-Pad Wellwork 9 Feb 2006 Step Unit Operation 1 S Set plug in XN-nipple @ 6,585-ft. 2 0 Injectivity test into NC/ND-sand. 3 0 Bullhead 20-bbI12% 90:10 DAD acid into NC/ND-sand. 4 0 Injectivity test into NC/ND-sand. 5 S Pull plug from XN-nipple @ 6,585-ft. 6 C Acid stimulation OA-sand 4.5-in cmt/perf liner. 7 0 Injectivity test into combined NC/ND and OA-sands. OBJECTIVE To improve the injectivity into both the NC/ND-sands and the OA-sand in order to adequately support MPE-32. Measure of success The current injection rate is 460-bbl/day @ 1, 130-psi Oust under the fracture gradient @ 1, 150-psi) with approximately 75% into NC/ND and 25% into OA. The ideal injection rates, operating below fracture pressure, are 1,200-bbllday into NC/ND and 400-bbl/day into OA. Any improvement in injectivity would constitute some measure of success. CRITICAL ISSUES Sand may be present in the lateral due to cross-flow when shut-down. . . BACKGROUND MPE-12 was drilled to provide injection support to MPE-32 via a horizontal cemented 1 perforated liner for the OA-sand, and via perforated casing for the NC/ND-sands. A P-15 WFR (22/64" port) was set in the MMG-W @ 6,439-ft MD and the OA-Iateral was left fully open to flow. The well was put on injection on 90ct05. From start-up, the injection rates have been disappointing and in fact dropped significantly over several weeks. The fracture pressure for the well is estimated to be 1, 150-psi based on injection pressure versus rate data, which is equivalent to a 0.70-psilft fracture gradient. Current operation at 1,200-psi wellhead pressure only injects 580-bbllday produced water. Off-take from MPE-32 could be 1 ,500-bbl/day although the well has been choked back and was shut-in from 80ct05 to 10Nov05 because the GOR>1,100 and FBHP<1,200-psi. MPE-32 was shut-in again on 29Dec05 because of GOR>600 and FBHP<1 ,1 OO-psi. Inadequate voidage replacement from MPE-12 is the cause of the enforced choke back and shut-in of MPE-32. The desired injection targets for MPE-12 are 1,200-bbl/day to the NC/ND-sand and 400-bbl/day to the OA-sand. The well is thus significantly under-injecting with current operation parameters. An IPROF was conducted on 19Nov05. Preliminary analyses of the data indicate that the upper NC/ND-sands are taking 75% and the OA-sands are taking 25% of the injected fluid. After the IPROF, the injectibility further declined and on 12:00 22Nov05 the well was only able to take 300-bbl/day at 1, 170-psi. An 80-bbl Schmoo-Be-Gone job was pumped on 24Nov05. After the job, the injection pressure decreased by roughly 50-psi to 1,240-psi @ 600-bbl/day. On 25Nov05 a tubing tail plug was pulled from MPE-05 and the plug was severely packed off with hard injection schmoo. It is conjectured that perhaps MPE-12 was affected in a similar manner. The purpose of the current wellwork is thus to investigate the possibility that the WFRV in MPE-12 is packed off. The IPROF, however, indicates that it is working adequately. Replacement of the WFRV with an orifice valve will only help to improve the injectivity. On 3Jan06, the WFRV was pulled from the MMG-W @ 6,439-ft MD and a dummy valve was set in its place. The dummy valve @ 6,379-ft MD was then pulled and a CV flow-sleeve with a 0.5-in port was set in its place. The injectivity improved to a limited extent after the change but has since deteriorated further. An acid stimulation treatment similar to that recently performed on MPS-10A is proposed. Possible further actions might also include under-balanced re-perforation of the OA-sand lateral using PURE charges. . . If the NC/ND-sands take excess fluid after the stimulation, then a choke in the OA-sand lateral may be considered. Last well test (rate/date): Tubing size and type: Minimum 10 and depth: Last TO tag (depth/date): Maximum deviation in well: Well deviation at top perforations: Recent H2S data for well: Highest H2S on pad: Last SBHP: SCOPE 460-bbl/d water @ 1, 130-psi (06Feb06). 3.5-in 9.3-lb/ft L-80 TC-II 2.75-in @ XN-nipple, 6,585-ft MD. N/A 79° @ 6,659-ft MD in tubing. 68° N/A 53-ppm on MPE-17 in Feb01. 1,849-psi Initial SBHP 140ct05. Note that the order of the slickline and coil-tubing work is arbitrary and should be based on the availability of the equipment and acid. If slickline is not available in a reasonable time frame and if acid and coil tubing are available, then a hydraulic set GS-plug could be set in the XN-nipple with coil tubing, then a sleeve could be opened with a dropped ball to bullhead acid into the NC/ND-sands. 1. Set plug in XN-nipple @ 6,585-ft 2. Injectivity test into NC/ND-sands. · Slowly ramp up well until injection pressure is 1,OOO-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. · Increase rate until injection pressure is 1,1 OO-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. · Increase rate until injection pressure is 1,200-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. 3. Bullhead 20-bbI12% 90:10 DAD acid into NC/ND-sand. · Pump acid. · Displace with 55-bbl produced water (tubing volume). · Allow acid to soak perforations for 15-min. · Flush with at least 20-bbl produced water to flush acid precipitates away from wellbore. 4. Injectivity test into NC/ND-sands. · Slowly ramp up well until injection pressure is 1,OOO-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. · Increase rate until injection pressure is 1,1 OO-psi. . . · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. · Increase rate until injection pressure is 1,200-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. 5. Pull plug from XN-nipple @ 6,585-ft MD. 6. Acid stimulation OA-sand 4.5-in cmt/perf liner. · RU 1.75-in CT with a slim BHA wI side jetting nozzle. The No-Go has an 10 of 2.75-in at 6,585-ft. · SI well at lateral and wing valves. · RIH and tag TO @ 9,212-ft MD. While slowly reciprocating across perforation interval from 8,668 to 9,168-ft MO, wash perforations with acid followed by 2% KCI. Report pump rate, CT, and WHP at least every 10 to 20-bbl. Attempt to keep treating WHP below 1, 150-psi by controlling pump rate. However, this pressure may be exceeded to a maximum of 1,500-psi if necessary to get reasonable treatment rates (>0.75-bbl/min). o Reciprocate 143-bbl of 12% 90:10 DAD acid (12-gal/ft) across 8,669 to 9,168-ft. o Shut down for a 15 minute soak period after first complete pass with acid. Continue acid wash. Flush perforations with at least 50-bbl produced water or 2% KCI. Do not POOH until the total over- flush volume is behind pipe. · Please note the initial and final injectivity in the WSR summary. · POOH. If possible, immediately put well on injection to flush acid precipitates away from wellbore. 7. Injectivity test into combined NC/NO and OA-sands. · Slowly ramp up well until injection pressure is 1,OOO-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. · Increase rate until injection pressure is 1,1 OO-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. · Increase rate until injection pressure is 1,200-psi. · Allow well to stabilise for at least 15-min. · Record injection rate and pressure. · Put well on injection @ 1,1 OO-psi. . . Check acid additive packages for BHST of 77°F and 12-hr protection time for L-80. Acceptable acid concentrations +/-1 % for HC!. Fluids should be 90 to 110°F. Total Fluid 90:10 DAD Acid 2% KCI* 163 50 bbl bbl 90:10 DAD acid additives Corrosion A261 Inhibitor 0.6% 41 gal Corrosion A 153 Inhibitor 8 55 Ib Corrosion A 179 Inhibitor 4 27 Ib U74 Dispersant 1.5% 103 gal W54 NonEmulsifier 0.5% 34 gal W60 Anti-Sludge 0.5% 34 gal F103 Surfactant 0.2% 14 gal L58 Iron Stabilizer 20 137 Ib (*KCI volume here does not include injectivity tests or displacing coil volume). Contacts: Matt Green 564-5581 (W) or 770-1984 (H) Danielle Ohms 564-5759 (W), 345-2477 (H) or 440-9082 (M) TREE: 3-1/8" - 5M FMC . WELLHEAD: 11" x 3-1/8" 5M n 5 Tub Hgr. 11" x 3-1/8" TC-II T&B 3" CIW-H BPVT Conductor ~.. KOP @ 250' Angle passes 50° @ 2400' Max Angle in Tbg = 79° @ 6659' Angle thru liner = 90+0 9 - 5/8" 40# L-80 BTC Csg. I 3,246' 1 . 3.5" 9.2 #/ft L-80 TC-II ( Drift id = .0087 Bpf. ) 4.5" 12.6 #/ft L-80, IBT ( Drift id = .00152 bpf. ) 7" 26 ppf, L-80, BTC-Mod casing ( drift ID = 6.276", cap. = 0.0383 bpf ) (cap w/ 3 1/2" tbg inside = 0.0264 bpf) Schrader "NC/ND" Perfs SPF MD TVD 516'375'- 6'390'14'357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 4.5" HSD 6 SPF. PJ4505 Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ext. 6,606' 6,614' 6,616' 6,623' 6,643' Schrader "OA" Perfs SPF MD TVD 619, 168'-8,668'14,466' - 4,477' 2-7/8" HSD 6 SPF. PJ906 DATE MPE-12 - w; it' 12 ... . I I J. I .. 06/08/05 09/14/05 REV. BY COMMENTS MDO Drilled & Completed Doyon - 14 Lee Hulme RWO to correct tbg leak 4ES ori.Elev. = 57.35 Doyon 14 Ori Elev. = 33.95 Doyon 14 3.5" HES X-Nipple 2.813" I 2,494' 1 3.5" HES X-Nipple 2.813" 6,176' I 7" x 3.5" Baker Premier pkr. I 6,226'1 I 6,251' I I 6,267' 1 I 6,276' I I 6,288'1 3.5" HES X-Nipple 2.813" Unique Machine Overshot . Top of cut Pup Jt Stub 7" x 3.5" Baker Premier pkr. 3.5" x 1.5" Camco MMG (rk) I 6,379' 1 3.5" x 1.5" Camco MMG-W (rk) I 6,439' 1 3.5" HES XN-Nipple 2.750" ¡d. I 6,585' 1 (2.813" pkg. bore) Baker Locator sub I 6,600' 1 Baker 806-40 Seal Assy bottom I 6,633' I 7" float collar (PBTD) 16,675' ~ 7" Weatherford float shoe 6,761' 1 9,212' I I 9,253' I I 9,297' I ~ 4.5" Baker Landing Collar Halliburton Float collar 4.5" Baker float shoe MILNE POINT UNIT WELL MPE-12 API NO: 50-029-23262-00 CD ¡::VDI f'\D ^ TIf'\M I ^ 1.('\ MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: J ' Jim Regg ~t. II! c>lûS P.I. Supervisor -[ l DATE: Monday, October 24,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA)!NC E-12 MILNE PT UNIT SB E-12 ~.......~~ . '~ ~" .. .. .,.,."" '.. ,_,,' .ft ;.'fL -'~_é 'J- -v FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:JJz..f:-- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB E-12 Insp Num: mitCS051016150958 Rei Insp Num API Well Number 50-029-23262-00-00 Permit Number: 205-067-0 Inspector Name: Chuck Scheve Inspection Date: 10/16/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-12 ¡Type Inj. I w TVD 4302 I IA 840 2000 1950 1950 2050670 jTypeTest I SPT i P.T. Test psi 1075.5 I OA 200 240 230 230 I Interval !NIT AL PIF P Tubing 900 900 900 900 Notes Monday, October 24, 2005 Page 1 of 1 Kt:L;I:I\' i . STATE OF ALASKA I OCT I 4 Z005 ALASKA~L AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND Ldéì!lka Oil & Gas Cons. COffiiiii';'ác1Ìi Revision: 1aMOOgr~¥Grt Injection .. No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: GYRO, DIR , GR , RES, IFRlCASANDRA , SCMT , CCL , USIT CASING, LINER AND CEMENTING RECORD SeTTING DePTH MD SeTTING DEPTH TVO HOLE lOP BoTTOM lOP BoTTOM SIZE CEMEN'TINQRECOFJO 35' 115' 35' 115' 42" x 18" 260 sx Arctic Set (Approx.) 35' 3246' 35' 2653' 12-1/4" 384 sx AS Lite, 408 sx Class 'G' 33' 6761' 33' 4461' 8-1/2" 351 sx Class 'G' 6594' 9297' 4430' 4451' ~ '315 sx Class 'G' ,,~.£.~ ~~lc..t"'h\\-.~. '\.\\.~~~~\ !\)J'Yl ~''-t -0 fo "\" 1ft.. ~~..., ~ TUalNGRECORD DEPTH SET (MD) 6633' o GINJ IS! WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3688' FSL, 1794' FEL, SEC. 25, T13N, R1OE, UM Top of Productive Horizon: 4861' FSL, 1482' FEL, SEC. 30, T13N, R11E, UM Total Depth: 4858' FSL, 1422' FEL, SEC. 30, T13N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 569351 y- 6016227 Zone- ASP4 TPI: x- 574888 y- 6017453 Zone- ASP4 Total Depth: x- 574948 y- 6017451 Zone- ASP4 ~~--------------- 18. Directional Survey 0 Yes IS! No ----------------- 22. CASING SIZE 20"x 13-3/8" 9-518" Wr. PER FT. 92# x 72# 40# 26# 12.6# GRADE H-40 x K-55 L-80 L-80 L-80 7" 4-1/2" 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Diameter, 5 SPF 2-7/8" Diameter, 6 SPF MD TVD MD TVD NC/ND 6375' - 6390' 6410' - 6437' NC/ND 4358' - 4363' 4371' - 4381' Q8 8668' - 9168' Q8 4467' - 4477' 26. Date First Production: September 24, 2005 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 24-HoUR RATE One Other 5. Date Comp., Susp., or Aband. 61812005 6. Date Spudded 5127/2005 7. Date T.D. Reached 6/4/2005 8. KB Elevation (ft): 57.35' 9. Plug Back Depth (MD+ TVD) 9254 + 4457 10. Total Depth (MD+ TVD) 9297 + 4451 11. Depth where SSSV set NIA MD 19. Water depth, if offshore NIA MSL 24. SIZE 3-1/2",9.2#, L-80 TCII 1 b. Well Class: o Development 0 Exploratory o Stratigraphic IS! Service 12. Permit to Drill Number 205-067 305-270 13. API Number 50- 029-23262-00-00 14. Well Name and Number: MPE-12i 15. Field I Pool(s): Milne Point Unit I Schrader Bluff Ft Ft 16. Property Designation: ADL 028231 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PULLED PACKER SET (MD) ~ <O»CÆ@~ ~¡,'{~~ DEPTH INTERVAL (MD) ACID, FRACTURE, CEMENT SaUEEZE, ETC. 25. AMOUNT & KIND OF MATERIAL USED Freeze Protected with 88 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-BBl GAs-McF WATER-BBl Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-all RATIO all GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ORIGINAL FW1 v(l?lJJ 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". MA MB1 MB2 NA NB NC ND NE NF OA OA 5753' 5767' 5912' 6250' 6302' 6363' 6408' 6445' 6565' 6717' 9237' 4083' 4090' 4161' 4311' 4330' 4353' 4370' 4384' 4424' 4454' 4459' None 30. List of Attachments: Summary of Daily Drilling Reports. Well Schematic Diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra ~Å- Title Technical Assistant Date~O -[ Z - oS MPE-12i 205-067 305-270 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number Drilling Engineer: David Reem, 564-5743 Permit No. I Approval 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 1 0-407 Revised 12/2003 Submit Original Only TREE: 3-1/8" - SM FMC WElLHEAD: 11" x 3-1/8" S. Gen S Tub Hgr. 11" X 3-1/8" TC-II 3" CIW-H BPVT Conductor ~. KOP @ 250' Angle passes 50° @ 2400' Max Angle in Tbg = 79° @ 6659' Angle thru liner = 90+0 9 - S/8" 40# L-80 BTC Csg. I 3,246' I .. 3.5" 9.2 #/ft L-80 TC-II ( Drift id = .0087 Bpf. ) 4.5" 12.6 #/ft L-80, IBT ( Drift id = .00152 bpf. ) 7 " 26 ppf, L-80, BTC-Mod casing ( drift 10 = 6.276", cap. = 0.0383 bpf ) (cap w/3 1/2" tbg inside = 0.0264 bpf) Schrader "NC/ND" Perfs SPF MD TVD 516'375'- 6,390'14,357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 4.S" HSD 6 SPF. PJ4S0S Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ex!. 6,606' 6,614' 6,616' 6,623' 6,643' Schrader "OA" Perfs SPF MD TVD 619,168'-8,668'/4,466'-4,477' 2-7/8" HSD 6 SPF. PJ906 DATE 06/08/05 09/14/05 MPE-12 II. I I .OF Elev. = 57.35 Doyon 14 GL Elev. = 33.95 Doyon 14 3.5" HES X-Nipple 2.813" I 2,494' I 3.5" HES X-Nipple 2.813" I 6,176' I '. 7" x 3.5" Baker Premier pkr. I 6,226'1 I 6,251' I I 6,267' I I 6,276' I I 6,288' I 3.5" HES X-Nipple 2.813" Unique Machine Overshot Top of cut Pup Jt Stub 7" x 3.5" Baker Premier pkr. 3.5" x 1.5" Camco MMG (rk) I 6,379' I 3.5" x 1.5" Camco MMG-W (rk) 6,439' I 3.5" HES XN-Nipple 2.750" id. I 6,585' I ( 2.813" pkg. bore) I 6600' I . W. ~:~:; ~:'.: ~~~, As'y bottom I .:.33' I ~ ..:.......:. 7 " float collar (PBTD) 16,675' ... 7" Weatherford float shoe 6,761' I .. REV. BY COMMENTS MDO Drilled & Completed Doyon - 14 Lee Hulme RWO to correct tbg leak 4ES I 9,212' I 19,253' I I 9,297' I II. 4.5" Baker Landing Collar Halliburton Float collar 4.5" Baker float shoe MILNE POINT UNIT WELL MPE-12 API NO: 50-029-23262-00 BP EXPLORATION (AK) .~ ~""- ~~. . . BP AMERICA Operations Summary Report Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/12/2005 Rig Release: 9/16/2005 Rig Number: 4ES Spud Date: 5/27/2005 End: 9/16/2005 Date From - To Hours Task Code NPT Phase Description of Operations 9/12/2005 06:00 - 11 :00 5.00 MOB P DECOMP WO BP to prep Location. WO WX to install BPV. 11 :00 - 12:30 1.50 MOB P DECOMP Scope and Lower derrick 12:30 - 14:00 1.50 MOB P DECOMP Spot Rig over Well 14:00 - 16:00 2.00 RIGU P DECOMP Raise and Scope Derrick 16:00 - 17:00 1.00 RIGU P DECOMP Take on 9.4 Ib/gal Brine in Pits. Rig-Up lines to Tree and Tiger Tank, Test lines 4000 psi / Rig Accepted at 16:00 hrs 17:00 - 17:30 0.50 WHSUR P DECOMP Rig-Up lubricator Pull BPV 17:30 - 19:00 1.50 KILL P DECOMP Circulate 9.4 ppg kill fluid around at 4 bbls/min 220 blls 19:00 - 19:30 0.50 WHSUR P DECOMP Rig-Up lubricator Set TWC 19:30 - 20:00 0.50 WHSUR P DECOMP N/D Tree 20:00 - 22:00 2.00 BOPSUF P DECOMP N/U BOPE 22:00 - 00:00 2.00 BOPSUR P DECOMP Test BOPE as per AOGCC and BP requirements 250 psi low / 4000 psi high charted. Test witness waived by AOGCC John Spalding, Test witnessed by S. Bounds Nabors and D. Felder BP-Rep. 9/13/2005 00:00 - 01 :30 1.50 BOPSUF P DECOMP Continue testing of BOPE 01 :30 - 02:00 0.50 PULL P DECOMP Rig-Up Lubricator pull TWC 02:00 - 03:00 1.00 PULL P DECOMP P/U Pulling Jt tie into Hanger and pull to surface 03:00 - 06:00 3.00 PULL P DECOMP R/U Torque Turn equipment and Compensator. POOH and Lay-Down 3-1/2" Tbg Completion by singles 06:00 - 14:00 8.00 PULL P DECOMP Continue to POOH w/3 1/2" TCII tubing. NOTE: Numbered joints backwards starting w/ #206 as first it out. Pin end of # 139 / box end of # 138 was very loose, (able to unscrew by hand). Also, #45 pin x #44 box was loose as well, (able to unscrew by hand). Then from #43 to cut off joint, connections were very tight w/ galded threads on several. Had to hammer on numerous connections as tongs were initially unable to break connections. 14:00 - 00:00 10.00 PULL P DECOMP Clean and inspect threads on 31/2" TCII tubing that was laid down. There where 38 Jts, 3 Pup Jts, and Hes 2.813 "X" Nipple with damaged threads. 9/14/2005 00:00 - 01:00 1.00 CLEAN P DECOMP Load and strap 3-1/2" DP in pipe shed 01:00 - 02:00 1.00 CLEAN P DECOMP Pick-Up BHA #1 Shoe Dress Off, Wash Pipe, Tbg. Dress Mill, Top Sub, XIO, &' Scraper, 2x Junk Baskets, Bit Sub, Bumper Sub, Oil Jar, 9x 4-314" Drill Collars 02:00 - 06:00 4.00 CLEAN P DECOMP RIH BHA #1 on 3-1/2" DP. 06:00 - 08:00 2.00 CLEAN P DECOMP Continue to RIH w/ BHA #1 on 3-1/2" DP. 08:00 - 08:30 0.50 CLEAN P DECOMP PJSM. Perfrom string weight check at 6200' md. RIH and tag 3-12" TC II chemically cut Tbg stump at 6273' md. Layout tag int and install kelly. 08:30 - 09:00 0.50 CLEAN P DECOMP PJSM. Circulate down on top of stump at 6273' md using 9.4 Ib/gal. brine, pump pressue at 750psi, seen pressure increase when going over stump. Dress 3-112" TC II Tbg stump. 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM. Mix 20 bbl hi-vis pill and reverse circ. well clean from 6265' md, circ. at 1000 psi and 4.5 bbl/min. Minimal amount of debris upon bottoms-up, circulated till retums were clean. No fluid lost or gained. 10:00 - 10:30 0.50 CLEAN P DECOMP Break out, blow down & stand back kelly. Prepare handling equipment to POOH. 10:30 - 14:30 4.00 CLEAN P DECOMP PJSM. POOH and LD 187 jts of 3-1/2" IF drill pipe. Layout 9 x 4-3/4" DC's. Layout BHA #1, visual inspection of mill showed good indications of being over Tbg stump. 14:30 - 15:30 1.00 CLEAN P DECOMP Clean & clear rig floor, ready equipment to run 3-1/2" TC II Tbg. Printed: 9/19/2005 8:03:00 AM . . BP AMERICA Operations Summary Report Page 2 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/12/2005 Rig Release: 9/16/2005 Rig Number: 4ES Spud Date: 5/27/2005 End: 9/16/2005 Date From - To Hours Task Code NPT Phase Description of Operations 9/14/2005 15:30 - 16:00 0.50 RUNCOM:' RUNCMP Tally 3-1/2" TC II tubing. 16:00 - 18:00 2.00 RUNCOrvP RUNCMP PJSM. Rig up to run 3 1/2" TCII completion string. 18:00 - 00:00 6.00 RUNCOrvP RUNCMP RIH completion hardware per program and 31/29.2# L80 TC II tubing. Torque turned tubing connections to minimum 2300 ft.lbs. Torque turn connections witnessed by Grant-Prideco service technician. Test tubing every 2000 ft. to 3500 psi for 30 minutes and charted same per program. 9/15/2005 00:00 - 06:00 6.00 RUNCOrvP RUNCMP RIH completion hardware and 31/29.2# L80 TC II tubing per program. Torque turned tubing connections to minimum 2300 ft.lbs. Torque turn connections witnessed and approved by Grant-Prideco service technician. Test tubing every 2000 ft. to 3500 psi for 30 minutes and charted same per program. 06:00 - 07:30 1.50 RUNCOrvP RUNCMP RIH w/ a total of 199 jts of 3-1/2" TC II Tbg. 07:30 - 08:00 0.50 RUNCOrvP RUNCMP Pressure test Tbg to 35oopsi/30min. using 9.4# brine, record results on chart. All pressure tests held 100%. 08:00 - 13:00 5.00 RUNCOrvP RUNCMP PJSM. Rig up Schlumberger slickline. Perform the following SL ops. using 0.125" line: Run #1: RIH w/2" RS tool, pull ball & rod from "X" nipple at 6181'. POOH Run #2: RIH w/3" GR tool, pull RHC-M plug body from "X" nipple at 6181'. POOH Rig down slickline equipment. 13:00 - 14:00 1.00 RUNCOrvP RUNCMP Perform string weight check. 48K up WI, 32K down WI. RIH w/ tag jts, pumping at 3bpm / 220psi.Locate over tubing stub and seen pressure increase to 270psi. Swallow stub & located shear pins of Unique Overshot - seen pins shear with 10K of string weight. Locate out 19' in on Jt #201. UD 201,200 & 199. 14:00 - 15:00 1.00 RUNCOrvP RUNCMP PJSM. Space out: Above Jt 198 add (3) pups, 15.02',7.73', & 2.05', bury pups under jt # 199 & make up hanger & pup. 15:00 - 19:00 4.00 RUNCOrvP RUNCMP PJSM. Reverse círc. from 6270' using 125bbl of 125'F seawater followed by 165bbl of 120'F seawater w/1 bbl of Nalco EC1124A corrosion inhibitor at 3bpm /220 psi. Use hot oiler to reverse circ. 100 bbl of diesel for freeze protection Tbg & lA, allow diesel to U-tube. 19:00 - 19:30 0.50 RUNCOrvP RUNCMP Land and test FMC Tbg Hanger 19:30 - 21 :00 1.50 RUNCOrvP RUNCMP Drop Rod Ball, Apply setting pressure of 4000 psi on Tbg and hold for 30 min 21 :00 - 22:00 1.00 RUNCOrvP RUNCMP Test Packer and 7" Csg to 3500 psi for 30 minlcharted Good test 22:00 - 22:30 0.50 RUNCOrvP RUNCMP Set TWC 22:30 - 00:00 1.50 RUNCOrvP RUNCMP N/D BOPE 9/16/2005 00:00 - 00:30 0.50 RUNCOrvP RUNCMP N/U Tree 00:30 - 01 :00 0.50 RUNCOrvP RUNCMP Clean and secure rig Rig released @ 01 :00 hrs, 09/16/2005. 01 :00 - 06:00 5.00 RIGD P RUNCMP Rig Down Primary Unit. Printed: 9/19/2005 8:03:00 AM I STATE OF ALASKA . RECEIVED ALASKA AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS OCT 14 Z005 Alaska Oíl & Gas Cons. Commission RePlach~g "' 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. -3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028231 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 1m Repair Well 1m Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver 1m Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 1m Service 5. PermitTo Drill Number: 205-067 6. API Number: 50-029-23262-00-00 99519-6612 57.35' 9. Well Name and Number: MPE-12i 10. Field / Pool(s): Milne Point Unit I Schrader Bluff 9297 4451 9254 4457 feet feet Plugs (measured) NIA feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" x 13-3/8" 115' 115' 9-518" 3246' 2653' 5750 3090 7" 6761' 4461' 7240 5410 4-1/2" 6594' - 9297' 4430' - 4451' 8430 7500 80' 3211' 6728' 2703' 6375' - 9168' 4358' - 4467' 3-1/2·,9.2# L-80 TC II 6633' Tubing Size (size, grade, and measured depth): 7· x 3-1/2" Baker Premier Packer 6288' Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: .1 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure 15. Well Class after proposed work: o Exploratory 0 Development 1m Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 305-270 o Copies of Logs and Surveys run 1m Daily Report of Well Operations 1m Well Schematic Diagram Title Technical Assistant Printed Name Sondra Stewman Signa~~....Í'--- Form 10-404 Revised 04/2004 l t> Prepared By NamelNumber: 564-5254 Date /2 -OC) Sondra Stewman, 564-4750 o RIG \ N A L -=rìtl flll{)¡(Jj lô l r(tlY~al CTn1y Phone TREE: 3-1/8" - 5M FMC . WELLHEAD: 11" x 3-1/8" 5M F 5 Tub Hgr. 11" x 3-1/8" TC-II T&B 3" CIW-H BPVT Conductor ~ at KOP @ 250' Angle passes 50° @ 2400' Max Angle in Tbg = 79° @ 6659' Angle thru liner = 90+0 9 - 5/8" 40# L-80 BTC Csg, I 3,246' I .. 3.5" 9,2 #/ft L-80 TC-II ( Drift id = ,0087 Bpf. ) 4.5" 12,6 #/ft L-80, IBT ( Drift id = .00152 bpf. ) 7 " 26 ppf, L-BO, BTC-Mod casing ( drift 10 = 6.276", cap. = 0.0383 bpf) (cap w/3 1/2" tbg inside = 0.0264 bpf) Schrader "NC/ND" Perfs SPF MD TVD 5 16,375'- 6,390'14,357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 4.5" HSD 6 SPF. PJ4505 Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ext. 6,606' 6,614' 6,616' 6,623' 6,643' Schrader "ON' Perfs SPF MD TVD 619,168'-8,668'14,466' - 4,477' 2-7/8" HSD 6 SPF. PJ906 DATE MPE-12 - I I OrigAI:lev. = 57.35 Doyon 14 Ori9W=lev. = 33.95 Doyon 14 3.5" HES X-Nipple 2.813" I 2,494' I 3.5" HES X-Nipple 2.813" 6,176' I T' x 3.5" Baker Premier pkr. I 6,226' I I 6,251' I I 6,267' I I 6,276' I I 6,288' I 3.5" HES X-Nipple 2.813" Unique Machine Overshot Top of cut Pup Jt Stub T' x 3.5" Baker Premier pkr. 3.5" x 1.5" Camco MMG (rk) I 6,379' I 3.5" x 1.5" Camco MMG-W (rk) I 6,439' I 3.5" HES XN-Nipple 2.750" id. I 6,585' I ( 2.813" pkg. bore) I 6,600' I II all ~:~:~ ~~~~~~r ~~:I Assy bottom I 6,633' I ~ ~ 7 " float collar (PBTD) 16,675' .. 7" Weatherford float shoe 6,761' ~ .... 06/08/05 09/14/05 REV. BY COMMENTS MOO Drilled & Completed Doyon - 14 Lee Hulme RWO to correct tbg leak 4ES I 9,212' I I 9,253' I 10.1 9,297' I 4.5" Baker Landing Collar Halliburton Float collar 4.5" Baker float shoe MILNE POINT UNIT WELL MPE-12 API NO: 50-029-23262-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/12/2005 Rig Release: 9/16/2005 Rig Number: 4ES Spud Date: 5/27/2005 End: 9/16/2005 9/12/2005 06:00 - 11 :00 5.00 MOB P DECOMP WO BP to prep Location. WO WX to install BPV. 11 :00 - 12:30 1.50 MOB P DECOMP Scope and Lower derrick 12:30 - 14:00 1.50 MOB P DECOMP Spot Rig over Well 14:00 - 16:00 2.00 RIGU P DECOMP Raise and Scope Derrick 16:00 - 17:00 1.00 RIGU P DECOMP Take on 9.4 Ib/gal Brine in Pits. Rig-Up lines to Tree and Tiger Tank, Test lines 4000 psi / Rig Accepted at 16:00 hrs 17:00 - 17:30 0.50 WHSUR P DECOMP Rig-Up lubricator Pull BPV 17:30 - 19:00 1.50 KILL P DECOMP Circulate 9.4 ppg kill fluid around at 4 bbls/min 220 blls 19:00 - 19:30 0.50 WHSUR P DECOMP Rig-Up lubricator Set TWC 19:30 - 20:00 0.50 WHSUR P DECOMP N/D Tree 20:00 - 22:00 2.00 BOPSUP P DECOMP N/U BOPE 22:00 - 00:00 2.00 BOPSUP P DECOMP Test BOPE as per AOGCC and BP requirements 250 psi low / 4000 psi high charted. Test witness waived by AOGCC John Spalding, Test witnessed by S. Bounds Nabors and D. Felder BP-Rep. 9/13/2005 00:00 - 01 :30 1.50 BOPSUPP DECOMP Continue testing of BOPE 01 :30 - 02:00 0.50 PULL P DECOMP Rig-Up Lubricator pull TWC 02:00 - 03:00 1.00 PULL P DECOMP P/U Pulling Jt tie into Hanger and pull to surface 03:00 - 06:00 3.00 PULL P DECOMP R/U Torque Turn equipment and Compensator. POOH and Lay-Down 3-1/2" Tbg Completion by singles 06:00 - 14:00 8.00 PULL P DECOMP Continue to POOH w/3 1/2" TCII tubing. NOTE: Numbered joints backwards starting w/ #206 as first jt out. Pin end of # 139/ box end of # 138 was very loose, (able to unscrew by hand). Also, #45 pin x #44 box was loose as well, (able to unscrew by hand). Then from #43 to cut off joint, connections were very tight w/ galded threads on several. Had to hammer on numerous connections as tongs were initially unable to break connections. 14:00 - 00:00 10.00 PULL P DECOMP Clean and inspect threads on 3 1/2" TCII tubing that was laid down. There where 38 Jts, 3 Pup Jts, and Hes 2.813 "X" Nipple with damaged threads. 9/14/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP Load and strap 3-1/2" DP in pipe shed 01 :00 - 02:00 1.00 CLEAN P DECOMP Pick-Up BHA #1 Shoe Dress Off, Wash Pipe, Tbg. Dress Mill, Top Sub, XIO, &' Scraper, 2x Junk Baskets, Bit Sub, Bumper Sub, Oil Jar, 9x 4-3/4" Drill Collars 02:00 - 06:00 4.00 CLEAN P DECOMP RIH BHA #1 on 3-1/2" DP. 06:00 - 08:00 2.00 CLEAN P DECOMP Continue to RIH w/ BHA #1 on 3-1/2" DP. 08:00 - 08:30 0.50 CLEAN P DECOMP PJSM. Perfrom string weight check at 6200' md. RIH and tag 3-12" TC II chemically cut Tbg stump at 6273' md. Layout tag jnt and install kelly. 08:30 - 09:00 0.50 CLEAN P DECOMP PJSM. Circulate down on top of stump at 6273' md using 9.4 Ib/gal. brine, pump pressue at 750psi, seen pressure increase when going over stump. Dress 3-1/2" TC II Tbg stump. 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM. Mix 20 bbl hi-vis pill and reverse circ. well clean from 6265' md, circ. at 1000 psi and 4.5 bbl/min. Minimal amount of debris upon bottoms-up, circulated till returns were clean. No fluid lost or gained. 10:00 - 10:30 0.50 CLEAN P DECOMP Break out, blow down & stand back kelly. Prepare handling equipment to POOH. 10:30 - 14:30 4.00 CLEAN P DECOMP PJSM. POOH and LD 187 jts of 3-1/2" IF drill pipe. Layout 9 x 4-3/4" DC's. Layout BHA #1, visual inspection of mill showed good indications of being over Tbg stump. 14:30 - 15:30 1.00 CLEAN P DECOMP Clean & clear rig floor, ready equipment to run 3-1/2" TC II Tbg. Printed: 9/19/2005 8:03:00 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 WORKOVER NABORS ALASKA DRilLING I NABORS 4ES Start: 9/12/2005 Rig Release: 9/16/2005 Rig Number: 4ES Spud Date: 5/27/2005 End: 9/16/2005 9/14/2005 15:30 - 16:00 0.50 RUNCOMP RUNCMP Tally 3-1/2" TC II tubing. 16:00 - 18:00 2.00 RUNCOMP RUNCMP PJSM. Rig up to run 3 1/2" TCII completion string. 18:00 - 00:00 6.00 RUNCOMP RUNCMP RIH completion hardware per program and 31/29.2# L80 TC II tubing. Torque turned tubing connections to minimum 2300 ft.lbs. Torque turn connections witnessed by Grant-Prideco service technician. Test tubing every 2000 ft. to 3500 psi for 30 minutes and charted same per program. 9/15/2005 00:00 - 06:00 6.00 RUNCOMP RUNCMP RIH completion hardware and 3 1/2 9.2# L80 TC II tubing per program. Torque turned tubing connections to minimum 2300 ft.lbs. Torque turn connections witnessed and approved by Grant-Prideco service technician. Test tubing every 2000 ft. to 3500 psi for 30 minutes and charted same per program. 06:00 - 07:30 1.50 RUNCOMP RUNCMP RIH w/ a total of 199 jts of 3-1/2" TC II Tbg. 07:30 - 08:00 0.50 RUNCOMP RUNCMP Pressure test Tbg to 3500psi/30min. using 9.4# brine, record results on chart. All pressure tests held 100%. 08:00 - 13:00 5.00 RUNCOMP RUNCMP PJSM. Rig up Schlumberger slickline. Perform the following SL ops. using 0.125" line: Run #1: RIH w/2" RS tool, pull ball & rod from "X" nipple at 6181'. POOH Run #2: RIH w/3" GR tool, pull RHC-M plug body from "X" nipple at 6181'. POOH Rig down slickline equipment. 13:00 - 14:00 1.00 RUNCOMP RUNCMP Perform string weight check. 48K up wt, 32K down wt. RIH w/ tag jts, pumping at 3bpm / 220psi.Locate over tubing stub and seen pressure increase to 270psi. Swallow stub & located shear pins of Unique Overshot - seen pins shear with 10K of string weight. Locate out 19' in on Jt #201. UD 201, 200 & 199. 14:00 - 15:00 1.00 RUNCOMP RUNCMP PJSM. Space out: Above Jt 198 add (3) pups, 15.02',7.73', & 2.05', bury pups under jt # 199 & make up hanger & pup. 15:00 - 19:00 4.00 RUNCOMP RUNCMP PJSM. Reverse circ. from 6270' using 125bbl of 125'F seawater followed by 165bbl of 120'F seawater w/1 bbl of Nalco EC1124A corrosion inhibitor at 3bpm /220 psi. Use hot oiler to reverse circ. 100 bbl of diesel for freeze protection Tbg & lA, allow diesel to U-tube. 19:00 - 19:30 0.50 RUNCOMP RUNCMP Land and test FMC Tbg Hanger 19:30-21:00 1.50 RUNCOMP RUNCMP Drop Rod Ball, Apply setting pressure of 4000 psi on Tbg and hold for 30 min 21 :00 - 22:00 1.00 RUNCOMP RUNCMP Test Packer and 7" Csg to 3500 psi for 30 min/charted Good test 22:00 - 22:30 0.50 RUNCOMP RUNCMP Set TWC 22:30 - 00:00 1.50 RUNCOMP RUNCMP N/D BOPE 9/16/2005 00:00 - 00:30 0.50 RUNCOMP RUNCMP N/U Tree 00:30 - 01 :00 0.50 RUNCOMP RUNCMP Clean and secure rig Rig released @ 01 :00 hrs, 09/16/2005. 01 :00 - 06:00 5.00 RIGD P RUNCMP Rig Down Primary Unit. Printed: 9/19/2005 8:03:00 AM , e e rE ir 1.b FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PaulChan Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~ ,-' '," ", -', - -..' ·/i~.'\ ::~" c· .....,..."., ,. f;;J:~, ',', ,-: . Re: MPE-12i Sundry Number: 305-270 Dear Mr. Chan: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. John K. Norman Chairman DATED thisß day of September, 2005 Encl. .) C¡tl- 9-13-êJS tit STATE OF ALASKA ~r¡/13/S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 &Jt3 > " 1. Type of Request: o Abandon o Alter Casing o Change Approved Program o Suspend II Repair Well II Pull Tubing o Operation Shutdown 0 Perforate 0 Other o Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 1m Service 5. Permit To DrjJl Number 205-067 V 6. API Number: . ./ 50- 029-23262-00-00 V 99519-6612 57.35' 9. Well Name and Number: MPE-12i 8. Property Designation: 10. Field I Pool(s): ADL 028231 11. Total Depth MD (ft): 9297 Casing Structural Conductor Surface Intermediate Production Liner Milne Point Unit I Schrader Bluff PRESENT WELL CONDITION SUMMARY Total Depth rvD (ft): Effective Depth MD (ft): Effective Depth rvD (ft): 4451 9254 4457 Length Size MD rvD Plugs (measured): NIA Burst Junk (measured): N/A COllapse 80' 20" x 13-318" 115' 115' 3211' 9-5/8" 3246' 2653' 5750 3090 6728' 7" 6761' 4461' 7240 5410 2703' 4-1/2" 6594' - 9297' 4430' - 4451' 8430 7500 Perforation Depth MD (ft): I Perforation Depth rvD (ft): I 6375' - 9168' 4358' - 4467' Packers and SSSV Type: 7" x 3-1/2" Baker Premier Packer Tubing Size: 3-1/2",9.2# Tubing Grade: L-80 Packers and SSSV MD (ft): 6281' Tubing MD (ft): 6633' 12. Attachments: 1m Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: . _ ~eptember 12, 2005 0 Oil 0 Gas 16. Verbal Approval: W/TV\ Date: 9/12/2005 0 WAG 0 GINJ Commission Representative: [Tom Maunder 17. I herebY~. hat the f..orLO.in is true and correct to the b est of my knowledge. Printed e Pa ~n , Title Drilling Engineer Signature \:-. ~ Phone 564-5254 Date er( r!>/ 0<' Commission Use Only 13. Well Class after proposed work: o Exploratory 0 Development 1m Service o Plugged 1m WINJ o Abandoned o WDSPL Contact Paul Chan, 564-5254 Prepared By NamelNumber: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity '¢..BOP Test JiÍ14echanicallntegrity Test 0 Location Clearance Other. \J\ \ ,"'-'/ I"S\,~·b <:.\\~ , W<i.\\ \"úS ~\ <-. \s \ \, 2.f. SJ RBDMS BFL I Sundry Number:!iJ5- ,170 1 4 2005 Subsequent Form Required: \.-\ C Approved By. (/) Form 10-403 Re-:;:r~1/ 00 COMMISSIONER APPROVED BY THE COMMISSION Date 1//315 Submit In Duplicate ORIGI~JAL ';<I e e E-12 proposed Riq Workover Procedure 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean brine through the cut. 2. Pull and LD 3-1/2" tubing string to the cut at +/- 6273' MD. 3. RIH with cleanout assembly and dress off tubing stub. 4. Run 3-1/2" L-80 TC-II premium connection completion with Baker Premier packer and Unique Machine overshot. Set packer at -6220' MD. 5. Displace the IA to packer fluid, freeze protect the well, and set the packer. 6. Test tubing to 3500 psi, test annulus to 3500 psi. 7. Set BPV. NO BOPE. NU and test tree. RDMO. '.. TREE: 3-1/8" - SM FMC a WELLHEAD: 11" x 3-1/8" SM F~n S Tub Hgr. 11" x 3-1/8" TC-II T&B 3" CIW-H BPVT Conductor ~. KOP @ 250' Angle passes 500 @ 2400' Max Angle in Tbg = 79° @ 6659' Angle thru liner = 90+0 9 - S/8" 40# L-80 BTC Csg. I 3,246' I . 3.5" 9.2 #/ft L-80 TC-II ( Drift id = .0087 Bpf. ) 4.5" 12.6 #/ft L-80, IBT ( Drift id = .00152 bpf. ) 7 " 26 ppf, L-80, BTC-Mod casing ( drift ID = 6.276", cap. = 0.0383 bpf) (cap w/ 3 1/2" tbg inside = 0.0264 bpf) Schrader "NC/ND" Perfs SPF MD TVD 516'375'- 6'390'14'357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 4.S" HSD 6 SPF. PJ4S0S Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ex!. 6,606' 6,614' 6,616' 6,623' 6,643' Schrader "OA" Perfs SPF MD TVD 619,168'-8,668'14,466' - 4,477' 2-7/8" HSD 6 SPF. PJ906 DATE REV. BY 06/08/05 MDO MPE-12 I I I······'w·;y'",·,··: :: :: ....... ...: ::: ·,c, > ._,_>e_,_,,_,?;' J, ~ .... COMMENTS Drilled & Completed Doyon - 14 OrigA Elev. = 57.35 Doyon 14 OrigW Elev. = 33.95 Doyon 14 3.5" HES X-Nipple 2.813" I 2,522' I 3.5" x 1" Camco KBUG I 2,548' I 3.5" HES XD Sleeve I 6,241' I 1 6,262' I 1 6,288' I 3.5" HES X-Nipple 2.813" 7" x 3.5" Baker Premier pkr. 3.5" x 1.5" Camco MMG (rk) I 6,379' I 3.5" x 1.5" Camco MMG-W (rk) I 6,439' I 3.5" HES XN-Nipple 2.750" id. (2.813" pkg. bore) Baker Locator sub Baker 80-40 Seal assy I 6,585'1 I 6,600' I I 6,633' 6,675'1 6,761' 7 " float collar (PBTD) .. 7" Weatherford float shoe I 9,212' I I 9,253' I ..I 9,297' I 4.5" Baker Landing Collar Halliburton Float collar 4.5" Baker float shoe MILNE POINT UNIT WELL MPE-12 API NO: 50-029-23262-00 BP EXPLORATION (AK) 'III TREE: 3-1/8" - 5M FMC . WELLHEAD: 11" x 3-1/8" 5M n 5 Tub Hgr. 11" x 3-1/8" TC-II T&B 3" CIW-H BPVT MPE-12 Pro po. Conductor ~.. KOP @ 250' Angle passes 50° @ 2400' Max Angle in Tbg = 79° @ 6659' Angle thru liner = 90+0 9 - 5/8" 40# L-80 BTC Csg. I 3,246' I . 3.5" 9.2 #/ft L-80 TC-II ( Drift id = .0087 Bpf. ) 4.5" 12.6 #/ft L-80, IBT ( Drift id = .00152 bpf. ) 7 " 26 ppf, L-80, BTC-Mod casing ( drift ID = 6.276", cap. = 0.0383 bpf) (cap w/ 3 1/2" tbg inside = 0.0264 bpf) Schrader "NC/ND" Perfs SPF MD TVD 5\6'375'- 6,390'4,357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 4.5" HSD 6 SPF. PJ4505 Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ex!. 6,606' 6,614' 6,616' 6,623' 6,643' Schrader "OA" Perfs SPF MD TVD 619,168'08,668'14.466' - 4,4 77' 2-7/8" HSD 6 SPF. PJ906 DATE REV. BY 06/08/05 MDO - ... ,., I I ð ,"F·_I' :- "-..; ~ r .. COMMENTS Drilled & Completed Doyon - 14 3.5" HES X-Nipple 2.813" I 3.5" HES X-Nipple 2.813" 7" x 3.5" Baker Premier pkr. 3.5" HES X-Nipple 2.813" Unique Machine Overshot 7" x 3.5" Baker Premier pkr. I 6,288' I 3.5" x 1.5" Camco MMG (rk) I 6,379' I 3.5" x 1.5" Camco MMG-W (rk) I 6,439' I 3.5" HES XN-Nipple 2.750" ¡d. (2.813" pkg. bore) Baker Locator sub Baker 80-40 Seal assy 7 " float collar (PBTD) ~ 7" Weatherford float shoe I 9,212' I 4.5" Baker Landing Collar I 9,253' I Halliburton Float collar ~ I 9,297' I 4.5" Baker float shoe I 6,585' I I 6,600' I I 6,633' I 6,675' I 6,761 ' MILNE POINT UNIT WELL MPE-12 API NO: 50-029-23262-00 BP EXPLORATION (AK) Re: MPE-12 (205-067) RWO . . Paul, Beginning the workover is acceptable. You indicated that 4ES is the rig. 3500 psi BOP test is acceptable. I look forward to the sundry tomorrow. Tom Maunder, PE AOGCC Chan, Paul (PRA) wrote, On 9/12/2005 4:09 PM: Tom Wou]d it be possib]e to get a verbal to start the weU and submit the sundry tomorrow? I cannot find our tech aide tòr the sundry. I have enclosed the scope of work and schematics for your review. Please can if you have any questions. Thanks Paul x5254 From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Monday, September 12, 2005 1:52 PM To: Chan, Paul (PRA) Subject: Re: MPE-12 RWO Paul, Thanks for the information. Yes, on retrospect filing the sundry is probably appropriate since the completion will be changed. Tom Maunder, PE AOGCC Chan, Paul (PRA) wrote, On 9/12/2005 11 :23 AM: Tom PTD: 2058067 The 10-407 has been filed. «MPE-12 WBS.ZIP» Enclosed is the current completion. The plan is to cut the tubing at 6273' MD and run a stacker packer completion with the new packer -6223' MD. I talked to Sondra Stewman and paperwork wiše, it may be better to submit a sundry application today for your approval. Thanks 10f2 9/13/2005 12:28 PM TREE: 3-1/8" - 5M FMC . WELLHEAD: 11" x 3-1/8" 5M FMC Gen 5 -1/8" TC-II T&B Conductor ~ a KOP @ 250' Angle passes 50° @ 2400' Max Angle in Tbg = 79° @ 6659' Angle thru liner = 90+0 9 - 5/8" 40# L-80 BTC Csg. I 3,246' I . 3.5" 9.2 #/ft L-80 TC-II ( Drift id = .0087 Bpf. ) 4.5" 12.6 #/ft L-80, IBT ( Drift id = .00152 bpf. ) 7 " 26 ppf, L-80, BTC-Mod casing ( drift ID = 6.276", cap. = 0.0383 bpf ) (cap w/ 3 1/2" tbg inside = 0.0264 bpf) Schrader "NC/ND" Perfs SPF MD TVD 516'375'- 6'390'14'357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 4.5" HSD 6 SPF. PJ4505 Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ex!. 6,606' 6,614' 6,616' 6,623' 6,643' Schrader "OA" Perfs SPF MD TVD 619,168'-8,668'14,466' - 4,477' 2-7/8" HSD 6 SPF. PJ906 DATE REV. BY 06/08/05 MDO MPE-12 I i a COMMENTS Drilled & Completed Doyon - 14 Orig. .Iev. = 57.35 Doyon 14 Orig. GL Elev. = 33.95 Doyon 14 ~5"'06l 3.5" HES X-Nipple 2.813" I 2,522' I 3.5" x 1" Camco KBUG I 2,548' I 3.5" HES XD Sleeve 3.5" HES X-Nipple 2.813" 7" x 3.5" Baker Premier pkr. I 6,241' I I 6,262' I I 6,288' I 3.5" x 1.5" Camco MMG (rk) I 6,379' I 3.5" x 1.5" Camco MMG-W (rk) I 6,439' I 3.5" HES XN-Nipple 2.750" id. (2.813" pkg. bore) I Baker Locator sub Baker 80-40 Seal assy ........ 7" 'oal roll" (PBTO) I ~ 7" Weatherford float shoe I 9,212' I I 9,253' I ~ I 9,297' I 4.5" Baker Landing Collar Halliburton Float collar 4.5" Baker float shoe I 6,585' I I 6,600' I I 6,633'1 6,675' I 6,761' MILNE POINT UNIT PE-12 -23262-00 BP EXPLORATION (AK) . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPE-12 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,070.22' 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 ~~~~~;:::. ~~~9518 /7/ ¡1 n / ¡ ;/ Date J I fJ.>; ~ r Signed J.!r....,~ Uk/,¿JIi Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 18-Jul-05 \ I ~~ç- Otc7 F:J1 _ STATE OF ALASKA _ ALASKA ðll'AND GAS CONSERVATION COMMI.,:>N 0 WELL COMPLETION OR RECOMPLETION REPORT AND LOfi{ECE\VE JUl 0 8 2005 1b. Well Class: r..nn CnmmíssiQ(\ ^c~.~ --olxploratory 1:J"'S'tratigraøbtØ~rvice 12. Permit to Drill Number 205-067 13. API Number 50- 029-23262-00-00 14. Well Name and Number: MPE-12i / 15. Field / Pool(s): Milne Point Unit I Schrader Bluff . No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 21. Logs Run: GYRO, DIR , GR , RES, IFRlCASANDRA , SCMT , CCL , US IT CASING, LINER AND CEMENTING RECORD SETTING DEPTHMO SETTINGDEPTHTVD HOLE Top BOTTOM Top BoTTOM SIZE 35' 115' 35' 115' 42" x 18" 260 sx Arctic Set (Approx.) 35' 3246' 35' 2653' 12-1/4" 384 sx AS Lite, 408 sx Class 'G' 33' 6761' 33' 4461' 8-1/2" 351 sx Class 'G' 6594' 9297' 4430' 4451'. ~ 315 sx Class 'G'. . ( ;J \/'\ ~~/L.t'\ID~\\\. t-.C::i'" ·~.···~~.~.it~I~~coR51~~~~'~.~.·..~~~~ SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2",9.2#, L-80 6633' 6281' o GINJ 181 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3688' FSL, 1794' FEL, SEC. 25, T13N, R10E, UM Top of Productive Horizon: 4861' FSL, 1482' FEL, SEC. ft, T13N, R11E, UM Total Depth: 4858' FSL, 1422' FEL, SEC. 30, T13N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 569351 /_ y- 6016227 'Zone- ASP4 TPI: x- 574888 y- 6017453 Zone- ASP4 Total Depth: x- 574948./ y- 6017451, Zone- ASP4 18. Directional Survey 181 Yes ONo 22. CASING SIZE 20"x 13-3/8" 9-518" Wi. PER FT. 92# x 72# 40# 26# 12.6# GRAPE H-40 x K-55 L-80 L-80 L-80 7" 4-1/2" 23. Perforations open to Production (MD + TVD of TOE and ./ Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Diameter, 5 SPF 2-7/8" Diameter, 6 SPF MD TVD MD TVD NC/ND 6390' - 6375' 6437' - 6410' NC/ND 4363' - 4358' 4381' - 4371' OA 9168'='8668' OA 4467':""4477' 26. Date First Production: / Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .-a.. Press. 24-HoUR RATE""'" One Other 5. Date Comp., Susp., or Aband. 6/8/2005 6. Date Spudded 5/27/2005 ~ 7. Date T.D. Reached 6/412005 8. KB Elevation (ft): 57.35' '" 9. Plug Back Depth (MD+ TVD) 9254 + 4457 10. Total Depth (MD+TVD) 9297 + 4451 / Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore NI A MSL 24. ./ Ft 16. Property Designation: ADL 028231 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 88 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bal GAs-McF WATER-Bal Oll-Bal 27. GAs-McF WATER-Bal CHOKE SIZE I GAS-a,l RATIO all GRAVITY-API (CORR) 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 RBDMS BFl JUL 1 2 2005 Form 10-407 Revised 12/2003 OR\G\NAL CONTINUED ON REVERSE SIDE ~ r ~C-;!0' n!ON t ¡ V"'" '.,. , \. " DAJI: r.Ç\ ~ \ VERìF.iED \ Ii . -Z~___ ¡ ;--~~~~ .¡._......~ GF - 28. . GEOLOGIC MARKERS 29. aATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". MA MB1 MB2 NA NB NC ND NE NF OA OA 5753' 5767' 5912' 6250' 6302' 6363' 6408' 6445' 6565' 6717' 9237' 4083' 4090' 4161' 4311' 4330' 4353' 4370' 4384' 4424' 4454' 4459' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak-Off Test Report Summary. 31. I hereby certify that the foregoing is true and çorrect to the best of my knowledge. Signed Title Technical Assistant Date OI-lJ~-OS Son Permit No.1 Approval 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. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 David Johnson, 564-4171 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 TREE: 3-1/8" - 5M FMC . WELLHEAD: 11" x 3-1/8" 5M FM 5 Tub Hgr. 11" x 3-1/8" TCIIT&B 3" CIW-H BPVT Conductor ~. KOP @ 250' Angle passes 50° @ 2400' Max Angle in Tbg = 7f1' @ 6659' Angle thru liner = 90+0 9 - 5/8" 40# L-80 BTC Csg. I 3,246' I . 3.5" 9.2 #/ft L-80 TCII ( Drift id = .0087 Bpf. ) 4.5" 12.6 #/ft L-80, IBT ( Drift id = .00152 bpf. ) 7 " 26 ppf, L-80, BTC-Mod casing ( drift ID = 6.276", cap. = 0.0383 bpf ) (cap wi 3 1/2" tbg inside = 0.0264 bpf) Schrader "NC/ND" Perfs spf. MD TVD 516'375'- 6,390'14,357' - 4,390' 5 6,410'- 6,437' 4,371' - 4,381' 4.5" HSD 6 SPF. PJ4505 Baker Tie back slv. Baker ZXP Packer Baker "RS" Nipple Baker HMC Liner Hgr. Baker 80-40 Seal Bore ex!. 6,606' 6,614' 6,616' 6,623' 6,643' Schrader "OA" Perfs spf. MD TVD 619,168'-8,668'14,466' - 4,477' 2-7/8" HSD 6 SPF. PJ906 MPE-12 I I 1.<'j.I··.??'.'.'.··.··.;.;.! "·:c":"':""""""'" ""è,,_x ~ ~ ... DATE REV. BY COMMENTS Drilled & Completed Doyon - 14 06/08/05 MDO Orig. DF Elev. = 57.35 Doyon 14 orig.e1ev. = 33..95 Doyon 14 3.5" Hes X-Nipple 2.813" I 2,522' I 3.5"x 1" Camco KBUG I 2,548' I 3.5" HES XD Sleeve 3.5" Hes X-Nipple 2.813" 1"x 3.5" Baker Premier pkr. 3.5"x1.5 Camco MMG (rk) 3.5"x1.5 Camco MMG-W (rk) 3.5" Hes XN-Nipple 2.750" id. (2.813" pkg. bore) Baker Locator sub Baker 80-40 Seal asby 7 " float collar (PBTD) ... 7" Weatherford float shoe - I 9,212' I I 9,253' I I 9,291' I 10. 4.5" Baker Landing Collar Halliburton Float collar 4.5" Baker float shoe 6,241'1 6,262'1 6,288'1 6,379' I 6,439' I 6,585' I 6,600'\ 6,633'1 6,675'1 6,761' MILNE POINT UNIT WELL MPE-12 API NO: 50-029..23262-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/18/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 5/27/2005 End: 6/8/2005 5/26/2005 04:00 - 04:30 0.50 MOB P PRE PJSM, Skid rig floor, prepare to move 04:30 - 07:30 3.00 RIGU P PRE PJSM, Move rig from MPE-32 to MPE-12 07:30 - 08:00 0.50 RIGU P PRE PJSM, Skid rig floor 08:00 - 09:00 1.00 RIGU P PRE PJSM, Rig up floor, spot tiger tank, rock washer 09:00 - 11 :00 2.00 RIGU P PRE PJSM, Nipple up Diverter, Mixing spud mud, Rig accept @ 09:005/26/2005 11 :00 - 12:00 1.00 RIGU P PRE PJSM, Load pipe shed, Inspect derrick 12:00 - 13:00 1.00 RIGU P PRE PJSM, Picking up pipe from pipe shed and standing in derrick 13:00 - 14:00 1.00 RIGU P PRE PJSM, Picking up bit, tag ice @ 36 ft. 14:00 - 14:30 0.50 RIGU P PRE PJSM, Function test Diverter system, gas, PVT, Flow Alarms, test was witness by John Crisp AOGCC and WSL 14:30 - 15:30 1.00 DRILL P SURF Pre-Sud meeting with crews, washed out ice plug to 102' 15:30 - 16:00 0.50 DRILL P SURF PJSM, Stand back drill pipe, clear floor 16:00 - 20:30 4.50 DRILL P SURF PJSM, Picking up pipe from pipe shed and standing in derrick 20:30 - 21 :30 1.00 DRILL P SURF PJSM, Picking up HWDP and Jars stand in derrick 21 :30 - 23:30 2.00 DRILL P SURF PJSM, change out Saver sub on topdrive 23:30 - 00:00 0.50 DRILL P SURF PJSM, make up BHA #1 5/27/2005 00:00 - 01 :00 1.00 DRILL P SURF PJSM, Making up BHA #1 01 :00 - 03:00 2.00 DRILL P SURF Spud well, Drilling 112 to 263' with 50rpms, 400 gpm, 700 psi, Running Gyros ever 100 ft. 03:00 - 04:00 1.00 DRILL P SURF Stand back HWDP and pick up DCs 04:00 - 23:15 19.25 DRILL P SURF Drilling 263' to 2350' with 65 rpms, 525 gpm, 2300 psi, Running Gyros ever 100 ft. to 450', check shot Gyro @ 900' 23: 15 - 00:00 0.75 DRILL P SURF Circ, Two bottoms up with 525gpm, 2300psi, 65 rpms 5/28/2005 00:00 - 01 :00 1.00 DRILL P SURF PJSM, Pumping out to 1200' with full drilling rate 01 :00 - 01 :30 0.50 DRILL N RREP SURF PJSM, Top drive repair 01 :30 - 02:00 0.50 DRILL P SURF PJSM, Finish pumping out to HWDP 02:00 - 02:30 0.50 DRILL P SURF PJSM, RIH, wash last stand to bottom 02:30 - 10:30 8.00 DRILL P SURF Drilling 2350' to 3255' with 80 rpms, 550 gpm, 2500 psi 10:30 - 11 :30 1.00 CASE P SURF Circ, Two bottoms up with 550 gpm, 2500 psi, 80 rpms 11 :30 - 13:30 2.00 CASE P SURF PJSM, Pump out to HWDP with full drilling rate 13:30 - 14:30 1.00 CASE P SURF PJSM, Rih, wash last stand to bottom 14:30 - 16:30 2.00 CASE P SURF Circ, Three bottoms, 550 gpm, 2500 psi, 80 rpms 16:30 - 18:30 2.00 CASE P SURF PJSM, Pump out to HWDP with full drilling rate 18:30 - 21 :00 2.50 CASE P SURF PJSM, stand back HWDP, lay down BHA 21 :00 - 21 :30 0.50 CASE P SURF Clear floor 21 :30 - 23:00 1.50 CASE P SURF PJSM, Rig up to run csg, made dummy run with landing ring 23:00 - 00:00 1.00 CASE P SURF PJSM, Picking up 9 5/8 40#, L-80 csg 5/29/2005 00:00 - 02:00 2.00 CASE P SURF PJSM, Picking up 9 5/8, 40#, L-BO csg, total 77 jts, shoe 3245', float collar 3159', P/u 180K, S/O 112K 02:00 - 02:30 0.50 CASE P SURF PJSM, Rig down Franks tool, rig up cement head 02:30 - 03:45 1.25 CASE P SURF Circ, Thin mud for cement job 7.5 bbls min. 300 psi, PJSM on cementing 03:45 - 05:30 1.75 CEMT P SURF Cement with Schlumberger, 5 bbls water, test lines 3000 psi, 15 bbls CW -100, 50 bbls Mud-Push 10.1, drop bottom plug, 384 sx ASL, yield 4.44,303 bbls mixed @ 10.7, tail 405 sx, B5 bbls, Class G, mixed @ 15.8, yield 1.17, drop top plug, kicked out with 30 bbls water, cement was mixed and pumped 6-7 bbls min. 05:30 - 06:30 1.00 CEMT P SURF Displace with rig pumps, 8 bbls min, 210 bbls mud, 155 bbls good cement to surface, bump plug with 1700 psi, floats held 06:30 - 08:30 2.00 CEMT P SURF PJSM, rig down cement head, flush diverter, lay down landing jt. Printed: 6/13/2005 11 :09:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/18/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 5/27/2005 End: 6/8/2005 5/29/2005 08:30 - 09:30 1.00 CASE P SURF PJSM, Rig down diverter and diverter line 09:30 - 10:30 1.00 CASE P SURF PJSM, Nipple up starting head, test metal to metal seals to 1000 psi for 10 min. 10:30 - 12:30 2.00 CASE P SURF PJSM, Nipple up BOPS 12:30 - 17:00 4.50 CASE P SURF PJSM, Rig up and test BOPS and manifold, 250-3,500 psi for 5 min per test, hydril 250 - 2500 psi 5 min. per test the right to witness test was wavier by Lou Grimauldi AOGGC, test was witness by WSL 17:00 - 17:30 0.50 CASE P SURF PJSM, Rig down test eq., Install wear ring 17:30 - 22:30 5.00 CASE P SURF PJSM, Picking up BHA # 2 22:30 - 23:00 0.50 CASE P SURF PJSM, RIH to 3081' 23:00 - 00:00 1.00 CASE P SURF PJSM, Slip and cut drill line, service top drive 5/30/2005 00:00 - 01 :00 1.00 CASE P SURF PJSM, Slip and cut drill line, service top drive 01 :00 - 02:00 1.00 CASE P SURF PJSM, Rig up and test Csg to 1000 psi for 30 min. 02:00 - 03:00 1.00 CEMT P SURF PJSM, Drill cement float and shoe, 20 ft of new hole to 3275' 03:00 - 03:30 0.50 CEMT P SURF PJSM, Displace well with new 9.1 LSD mud 03:30 - 04:00 0.50 DRILL P INT1 PJSM, FIT test with 9.1# MWT,3275 MD, 2651 TVD, 200 psi= 10.5 EMwt 04:00 - 00:00 20.00 DRILL P INT1 Drilling 3275 to 4987' with 80 rpms, 550 gpm, 3500 psi 5/31/2005 00:00 - 03:30 3.50 DRILL P INT1 Drilling 4987' to 5255' with 80 rpms, 550 gpm, 3200 psi 03:30 - 04:30 1.00 DRILL P INT1 Circ, two bottoms up with 550 gpm, 3200 psi, 80 rpms 04:30 - 06:30 2.00 DRILL P INT1 PJSM, Pumping out to 3245' with full drilling rate 06:30 - 07:00 0.50 DRILL P INT1 Circ, out clay balls 07:00 - 07:30 0.50 DRILL P INT1 PJSM, Rih washed last stand to bottom 07:30 - 00:00 16.50 DRILL P INT1 Drilling 5255' to 6488' with 80 rpms, 550 gpm, 3000 psi 6/1/2005 00:00 - 05:00 5.00 DRILL P INT1 Drilling 6488' to 6771' Td with 80 rpms, 550 gpm, 3000 psi 05:00 - 06:30 1.50 DRILL P INT1 Circ, Two bottoms up with 550 gpm, 3000 psi, 80 rpms 06:30 - 08:00 1.50 CASE P INT1 PJSM, Pump out to 4500' with full drilling rate 08:00 - 08:30 0.50 CASE P INT1 PJSM, Rih wash last stand to bottom 08:30 - 10:30 2.00 CASE P INT1 Circ Three bottoms up with 550 gpm, 3000 psi, 80 rpms 10:30 - 13:30 3.00 CASE P INT1 PJSM, pumping out to 3177' with full drilling rate 13:30 - 14:00 0.50 CASE P INT1 Circ. bottoms up from 3177' 14:00 - 15:00 1.00 CASE P INT1 PJSM, Poh to BHA 15:00 - 18:30 3.50 CASE P INT1 PJSM, Laying down 5" HWDP, jars,Flex DC,down load MWD tool, lay down same 18:30 - 19:00 0.50 CASE P INT1 PJSM, Clear floor 19:00 - 21 :00 2.00 CASE P INT1 PJSM, Pull wear ring, set test plug, change top rams to 7', test door seals 1500 psi for 5 min. 21 :00 - 00:00 3.00 CASE P INT1 PJSM, Rig up, Picking up 7' 26# L-80 csg to 2910' 6/2/2005 00:00 - 00:30 0.50 CASE P INT1 PJSM, Picking up 7' 26# L-80 csg to 3220' 00:30 - 01 :00 0.50 CASE P INT1 Circ, one csg volume 01 :00 - 03:30 2.50 CASE P INT1 PJSM, Picking up 7' 26# L-80 csg to 6720'" total jts run 162, marker jt with pip tag 6243, shoe 6760', float 6675' 03:30 - 04:30 1.00 CASE P INT1 Wash last jt to 6760, circ. one bottoms with franks tool, reciprocating csg., P/U 200k, S/O 95k, 5 bbls min, 900 psi 04:30 - 05:00 0.50 CASE P INT1 PJSM Rig down Franks tool. Rig up cement head 05:00 - 06:30 1.50 CASE P INT1 Circ bottoms up, reciprocating csg., P/U 200k, S/O 95k, 5 bbls min, 900 psi 06:30 - 08:30 2.00 CEMT P INT1 PJSM, Cement with Schlumberger, with5 Bbls water, Test lines to 3500 psi, 15 Bbls CW-100, 35 Bbls Mud Push @ 10.5, drop bottom plug, 73 Bbls, 351 sxs Class G mixed @ 15.8 yield 1.17, Drop top plug, Kick out with 20 bbls water, Displace with rig pumps 236 bbls mud, cement was mixed and displace @ 5 Printed: 6/13/2005 11 :09:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/18/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 5/27/2005 End: 6/8/2005 6/2/2005 06:30 - 08:30 2.00 CEMT P INT1 bbls min.800 psi, bump plug with 2500 psi, full retiJrns ,ttIru out . job, reciprocatiAg thrujob 08:30 - 09:00 0.50 CASE P INT1 Test csg to 2500 psi for 30 min. 09:00 - 10:00 1.00 CASE P INT1 PJSM, Lay down cement head and landing jl., flush stack 10:00 - 10:30 0.50 CASE P INT1 PJSM, install packoff and test to 5000 psi for 10 min. 10:30 - 12:00 1.50 CASE P INT1 PJSM, Change top rams to 2 7/8 x 5" , inject 100 bbls mud down 9 5/8 annulus 3 bbls min. 1000 psi 12:00 - 13:00 1.00 CASE P INT1 PJSM, Test top rams 250-3500 psi for 5 min. per test, Test witness by WSL 13:00 - 14:00 1.00 CASE P INT1 PJSM, Install wear ring, install short bales on top drive 14:00 - 17:00 3.00 CASE P INT1 PJSM, Picking up BHA # 3, shallow test MWD 17:00 - 20:00 3.00 CASE P INT1 PJSM, Trip in hole to 6568' 20:00 - 21 :30 1.50 CASE P INT1 PJSM, Slip and cut drilling line, service top drive 21 :30 - 23:30 2.00 CEMT P INT1 PJSM, Drill shoe track, float and shoe, new hole to 6791' 23:30 - 00:00 0.50 CASE P INT1 PJSM, Displace well with new 9.0# LSD mud 6/3/2005 00:00 - 01 :00 1.00 CASE P INT1 PJSM, Displace well with new 9.0 # LSD mud 01 :00 - 02:00 1.00 CASE P INT1 PJSM, Fit test with 4463 TVD, 6791 MD, 700 psi, 9.0 Mwt=12.0 EMwt 02:00 - 02:30 0.50 CASE P INT1 PJSM, Pump EP mud lube pill around. 02:30 - 00:00 21.50 DRILL P PROD1 Drill 6791' to 8361' with 280 gpm, 2300 psi, 80 rpms, AST 3.57, ART 10.5 TQ 4k 6/4/2005 00:00 - 12:30 12.50 DRILL P PROD1 Drill 8361' to 9297' with 280 gpm, 2300 psi, 80 rpms ;' 12:30 - 13:30 1.00 CASE P PROD1 Circ, two bottoms up with 275 gpm, 2100 psi, 80 rpms 13:30 - 16:00 2.50 CASE P PROD1 PJSM, Pumping out to Csg shoe @ 6760 with full drilling rate 16:00 - 17:00 1.00 CASE P PROD1 PJSM, RIH, wash last stand to bottom 17:00 - 18:30 1.50 CASE P PROD1 PJSM, Circ, three bottoms with 275 gpm, 2100 psi, 80 rpms 18:30 - 21 :00 2.50 CASE P PROD1 PJSM, Pumping out to Csg shoe @ 6760 with full drilling rate 21 :00 - 22:00 1.00 CASE P PROD1 PJSM, Circ bottoms up from 6760' 22:00 - 00:00 2.00 CASE P PROD1 PJSM, Trip out to BHA 6/5/2005 00:00 - 02:00 2.00 CASE P PROD1 PJSM, Laying down BHA 02:00 - 03:00 1.00 CASE P PROD1 PJSM, Rig up to run 4.5 liner 03:00 - 06:00 3.00 CASE P PROD1 PJSM, Picking up 4.5 liner, total 64 jts, Baker HMC liner hanger, (Hanger Bad) 06:00 - 10:00 4.00 CASE N SFAL PROD1 PJSM, Lay down hanger, wait on new hanger 10:00 - 11 :00 1.00 CASE P PROD1 PJSM, Picking up new hanger and inspection 10:00 - 14:00 4.00 CASE P PROD1 PJSM, Tripping in with liner, to 6761' 14:00 - 15:00 1.00 CASE P PROD1 PJSM, Circ liner @ csg shoe 6761', pick up 15 ft. pup 15:00 - 16:00 1.00 CASE P PROD1 PJSM, Tl'ipping to bottom with liner @9297, Liner top @ 6594, shoe 9297, llo8t9253, laAding collar 9212' 16:00 - 17:00 1.00 CASE P PROD1 PJSM, Circ for Cement job, P/U 125k, S/O 85k, reciprocate liner 20 ft. 17:00 - 18:30 1.50 CEMT P PROD1 PJSM, Cement with Schlumberger, Pump 5 bbls water, Test lines 4500 psi, 15 bbls CW-100, 25 bbls Mud push mixed @ 10.5, batch mixed and pumped 65.7 bbls 315 sxs Class G Mixed @ 15.8 yield 1.17, washed lines, drop plug, Kicked out plug with 45 bbls 8.7 brine, displace with rig with 65 bbls mud, cement was pumped and displace with 6 bbls min, liner was reciprocate thru out job, full returns, bump plug with 4200 psi 18:30 - 19:00 0.50 CASE P PROD1 PJSM, Set ZXP packer, release from liner, pulled out of liner with 1000 psi on stinger, circ 40 bbls to raise cement up hole. lay down cement head. 19:00 - 20:00 1.00 CASE P PROD1 PJSM, Circ. and reciprocate 11 bbls min. 2100 psi to clear well of excess cement, 10 bbls of good cement to surface. Printed: 6/13/2005 11 :09:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 5/18/2005 6/8/2005 Spud Date: 5/27/2005 End: 6/8/2005 6/5/2005 20:00 - 21 :00 1.00 CASE P PROD1 PJSM, Circ and reciprocate, Displace well with 8.7 brine 11 bbls min 1600 psi 21 :00 - 23:00 2.00 CASE P PROD1 PJSM, Laying down excess drill pipe 23:00 - 23:30 0.50 CASE P PROD1 PJSM\, Tripping out standing pipe in derrick 23:30 - 00:00 0.50 CASE P PROD1 PJSM, Pick up jt with cementing head, Breaking down, laying down same 6/6/2005 00:00 - 01 :00 1.00 CASE P PROD1 PJSM, Tripping out with running tools 01 :00 - 07:00 6.00 EVAL P LOWER1 PJSM,AiQ up Schtumberger9M<f\II1t'Iif'ígGRlUsItlCCL logging tool ftorAtop of liner 6594' to top of cement 4400' 07:00 - 08:00 1.00 PERFOB P LOWER1 PJSM, Test csg to 2500 psi for 30 min. 08:00 - 10:00 2.00 PERFOB P LOWER1 PJSM, Picking up, 2 78 HSD 6 spf PJ2906 Guns 10:00 - 11 :00 1.00 PERFOB P LOWER1 PJSM, Picking up, 2 7/8 PAC Drill pipe 11:00 -12:00 1.00 PERFOB N RREP LOWER1 PJSM, Repair Power stack tongs 12:00 - 14:30 2.50 PERFOB P LOWER1 PJSM, Picking up, 27/8 PAC Drill pipe 14:30 - 16:00 1.50 PERFOB P LOWER1 PJSM, Picking up, 4.5 HSD 5 spf PJ4505 Guns 16:00 - 18:00 2.00 PERFOB P LOWER1 PJSM, Tripping in with 4" drill pipe to 9,168' 18:00 - 20:30 2.50 PERFOB P LOWER1 PJSM, Rig up Schlumberger and correlate depth with RA tag 20:30 - 21 :30 1.00 PERFOB P LOWER1 PJSM, Perform perforate procedure, Both guns fired, Preforate well 9168-8668 6 shots perft., 6437-6410, 6390-6375 5 shots per ft. 21 :30 - 22:00 0.50 PER FOB P LOWER1 Monitor well, no loss or gain 22:00 - 23:30 1.50 PERFOB P LOWER1 PJSM, Tripping out with guns, standing back 40 stands in derrick, laying down excess pipe 23:30 - 00:00 0.50 PER FOB P LOWER1 PJSM, Slip and cut drill line, service top drive 6/7/2005 00:00 - 00:30 0.50 PERFOB P LOWER1 PJSM, Finish cutting drill line 00:30 - 08:00 7.50 PERFOB P LOWER1 PJSM, Laying down excess 4" pipe, 4" perforation guns - 2 7/8 pac pipe - 2 7/8" perforating guns - All shots fired 08:00 - 09:00 1.00 PERFOB P LOWER1 PJSM - Clear floor - Pull wear ring 09:00 - 10:00 1.00 RUNCOMP RUNCMP PJSM - Rig up torque turn equipment - 3 1/2" tubing handling equipment - Moblize tail pipe assemby 10:00 - 11 :00 1.00 RUNCOMP RUNCMP PJSM - Make up tail pie assembly 11 :00 - 19:00 8.00 RUNCOMP RUNCMP Run 3 1/2" completion to 6574" 19:00 - 21:30 2.50 RUNCOMP RUNCMP Tag bottom seal bore extension @ 6635' - Space out - Sting into seal extension - Make up hanger - Land tubing @ 6633' PU weight 95K SO weight 80K Block Weight 50K 21 :30 - 22:00 0.50 RUNCOMP RUNCMP Drop ball - RU Hot oil truck - Test lines to 4500 psi 22:00 - 23:30 1.50 RUNCOMP RUNCMP Pressure up to set Baker Premier packer - to 4200 psi - Held for 10 mins lost 400 psi to 3800 psi - Bleed off pressure - Pressure ·tIP to 4200 psi· -Hold for 30 mins lost 1400 psi - Pencil size stream of water coming out annulus - Did not decrease - Bleed off pressure to 2000 psi 23:30 - 00:00 0.50 RUNCOMP RUNCMP RU mud pump to annulus - Test annulus to 3200 psi with 2400 psi on tubing for 30 mins 6/8/2005 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Test annulus - 3200 psi annulus - 2400 psi tubing held for 30 mins - Swapped 100 psi from 3100 annulus to 2500 psi tubing - Bleed off annulus - Bleed off tubing - Consult with town - Con't with plan forward 01 :00 - 02:00 1.00 RUNCOMP RUNCMP RD Hot oil truck - test lines - Lay down landing joint - Install TWC - Test to 1500 psi 02:00 - 02:30 0.50 RUNCOMP RUNCMP Purge pump lines with water - Blowdown same - RD tbg equip - Clear rig floor 02:30 - 04:00 1.50 RUNCOMP RUNCMP ND BOP's - Change out saver sub 04:00 - 05:30 1.50 RUNCOMP RUNCMP NU adapter flange - Tree - Test pack-off to 5000 psi for 10 Printed: 6/13/2005 11 :09:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-12 MPE-12 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 5/18/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 5/27/2005 End: 6/8/2005 6/8/2005 04:00 - 05:30 05:30 - 06:30 06:30 - 08:30 1.50 RUNCOtvP 1.00 RUNCOtvP 2.00 RUNCOtvP 08:30 - 10:00 1.50 RUNCOtvP RUNCMP mins - Shell test tree to 5000 psi RUNCMP RU lubricator - Pull TWC - RU circulating hoses RUNCMP RU Hot oil truck - Test lines to 4500 psi - Shear out DCK-valve - Pump 88 bbls diesel down annulus - U-tube for 1 hr RUNCMP RU Lubricator - Install BPV - RD Lubricator - Hot oil truck - Secure well - Release rig @ 10:00 hrs Printed: 6/13/2005 11 :09:06 AM Legal Name: MPE-12 Common Name: MPE-12 5/29/2005 6/3/2005 FIT FIT 3,275.0 (ft) 6,791.0 (ft) 2,657.0 (ft) 4,463.0 (ft) 9.10 (ppg) 9.00 (ppg) 195 (psi) 700 (psi) 1,451 (psi) 2,787 (psi) 10.51 (ppg) 12.02 (ppg) . . Printed: 6/13/2005 11 ;08;59 AM . Halliburton Global . 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 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2005 Well: MPE-12 Slot Name: Well Position: +N/-S 2429.56 ft Northing: +E/-W -67.13 ft Easting: Position Uncertainty: 0.00 ft 6016227.28 ft Latitude: 569350.97 ft./ Longitude: 70 27 16.877 N 149 26 2.626 W +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 33.95 ft Mean Sea Level 24.59 deg 80.90 deg Direction deg 78.21 Wellpath: MPE-12 500292326200 Current Datum: MPE-12: Magnetic Data: 5/23/2005 Field Strength: 57575 nT Vertical Section: Depth From (TVD) ft 33.95 Height 57.35 ft Survey Program for Definitive Wellpath Date: 1/3/2005 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 89.00 349.00 MPE-12 Gyro(sperry SRO) (89.00-349.00) CB-GYRO-SS Camera based gyro single shots 377.93 9227.03 MPE-12 IIFR+CAZ+SAG (377.93-9227.03) MWD+IFR+MS MWD + IFR + Multi Station --------~j Survey ft 33.95 0.00 0.00 33.95 -23.40 0.00 0.00 6016227.28 569350.97 TIE LINE 89.00 0.15 80.00 89.00 31.65 0.01 0.07 6016227.29 569351.04 CB-GYRO-SS 169.00 0.36 98.80 169.00 111.65 -0.01 0.42 6016227.28 569351.39 CB-GYRO-SS 263.00 0.64 57.30 263.00 205.65 0.23 1.16 6016227.52 569352.12 CB-GYRO-SS 349.00 1.37 29.48 348.98 291.63 1.39 2.07 6016228.68 569353.02 CB-GYRO-SS 377.93 1.66 22.10 377.90 320.55 2.07 2.39 6016229.38 569353.34 MWD+IFR+MS 469.64 3.05 13.69 469.53 412.18 5.68 3.47 6016232.99 569354.39 MWD+IFR+MS 560.02 5.15 18.28 559.68 502.33 11.86 5.31 6016239.19 569356.17 MWD+IFR+MS 651.53 7.38 24.51 650.64 593.29 21.11 9.04 6016248.47 569359.81 MWD+IFR+MS 748.29 9.96 27.29 746.28 688.93 34.21 15.46 6016261.63 569366.11 MWD+IFR+MS 844.84 12.40 29.74 840.99 783.64 50.63 24.43 6016278.13 569374.92 MWD+IFR+MS 940.49 13.61 32.87 934.19 876.84 69.00 35.63 6016296.60 569385.95 MWD+IFR+MS 1037.02 14.17 36.68 1027.90 970.55 88.02 48.85 6016315.74 569399.00 MWD+IFR+MS 1130.65 15.84 38.64 1118.33 1060.98 107.19 63.68 6016335.05 569413.64 MWD+IFR+MS 1226.61 20.23 38.51 1209.56 1152.21 130.41 82.20 6016358.44 569431.94 MWD+IFR+MS 1322.69 25.06 37.47 1298.20 1240.85 159.58 104.93 6016387.81 569454.40 MWD+IFR+MS 1418.45 29.32 37.66 1383.36 1326.01 194.25 131.61 6016422.73 569480.75 MWD+IFR+MS 1514.81 32.90 35.51 1465.85 1408.50 234.25 161.23 6016462.99 569510.00 MWD+IFR+MS 1610.66 35.82 36.11 1544.97 1487.62 278.10 192.89 6016507.14 569541.24 MWD+IFR+MS 1707.02 36.17 36.45 1622.93 1565.58 323.76 226.40 6016553.10 569574.33 MWD+IFR+MS 1803.20 35.68 36.50 1700.82 1643.47 369.13 259.95 6016598.78 569607.45 MWD+IFR+MS 1900.11 33.60 36.59 1780.54 1723.19 413.39 292.75 6016643.34 569639.83 MWD+IFR+MS 1995.58 34.05 36.82 1859.85 1802.50 455.99 324.51 6016686.23 569671.19 MWD+IFR+MS 2091.29 35.51 37.18 1938.46 1881.11 499.59 357.37 6016730.13 569703.64 MWD+IFR+MS 2187.23 38.13 36.86 2015.26 1957.91 545.50 391.98 6016776.35 569737.82 MWD+IFR+MS 2283.12 41.37 37.45 2088.97 2031.62 594.35 429.02 6016825.55 569774.39 MWD+IFR+MS 2379.61 44.06 36.71 2159.86 2102.51 646.57 468.47 6016878.13 569813.35 MWD+IFR+MS 2476.04 50.25 35.84 2225.40 2168.05 703.56 510.26 6016935.49 569854.61 MWD+IFR+MS 2572.11 55.61 36.43 2283.29 2225.94 765.44 555.45 6016997.78 569899.22 MWD+IFR+MS . Halliburton Global . Survey 2667.96 55.30 36.16 2337.65 2280.30 829.07 602.19 6017061.84 569945.36 MWD+IFR+MS 2763.98 55.74 36.55 2392.00 2334.65 892.81 649.11 6017126.01 569991.68 MWD+IFR+MS 2859.50 57.49 37.61 2444.56 2387.21 956.44 697.20 6017190.07 570039.17 MWD+IFR+MS 2956.17 58.20 38.24 2496.01 2438.66 1020.99 747.50 6017255.09 570088.87 MWD+IFR+MS 3052.42 57.40 38.32 2547.30 2489.95 1084.93 797.96 6017319.48 570138.72 MWD+IFR+MS 3149.02 57.09 39.07 2599.57 2542.22 1148.33 848.74 6017383.35 570188.91 MWD+IFR+MS 3247.10 56.59 37.74 2653.22 2595.87 1212.67 899.75 6017448.16 570239.31 MWD+IFR+MS 3305.82 55.90 38.78 2685.85 2628.50 1251.01 929.98 6017486.77 570269.18 MWD+IFR+MS 3402.38 55.91 39.10 2739.97 2682.62 1313.20 980.24 6017549.42 570318.85 MWD+IFR+MS 3497.60 54.50 38.35 2794.31 2736.96 1374.20 1029.16 6017610.87 570367.19 MWD+IFR+MS 3593.17 54.68 36.79 2849.69 2792.34 1435.94 1076.65 6017673.04 570414.10 MWD+IFR+MS 3689.47 54.78 36.13 2905.29 2847.94 1499.17 1123.37 6017736.70 570460.23 MWD+IFR+MS 3785.73 57.64 36.90 2958.82 2901.47 1563.45 1170.97 6017801.42 570507.23 MWD+IFR+MS 3881.80 59.36 36.46 3009.02 2951.67 1629.14 1219.90 6017867.55 570555.54 MWD+IFR+MS 3976.35 57.61 35.34 3058.44 3001.09 1694.43 1267.17 6017933.27 570602.19 MWD+IFR+MS 4073.22 55.85 36.13 3111.58 3054.23 1760.17 1314.46 6017999.44 570648.87 MWD+IFR+MS 4169.45 54.60 35.22 3166.47 3109.12 1824.38 1360.56 6018064.07 570694.36 MWD+IFR+MS 4265.56 54.49 37.15 3222.22 3164.87 1887.56 1406.78 6018127.67 570739.98 MWD+IFR+MS 4360.36 53.16 37.51 3278.17 3220.82 1948.41 1453.18 6018188.95 570785.81 MWD+IFR+MS 4457.16 53.40 42.58 3336.08 3278.73 2007.77 1503.08 6018248.76 570835.15 MWQ+IFR+MS 4553.42 53.68 46.93 3393.30 3335.95 2062.72 1557.57 6018304.22 570889.12 MWD+IFR+MS 4648.30 53.46 47.11 3449.64 3392.29 2114.77 1613.42 6018356.77 570944.48 MWD+IFR+MS 4744.62 53.11 52.01 3507.25 3449.90 2164.83 1672.14 6018407.37 571002.74 MWD+IFR+MS 4840.54 51.79 57.13 3565.73 3508.38 2208.91 1734.06 6018452.03 571064.23 MWD+IFR+MS 4936.48 53.51 59.34 3623.94 3566.59 2249.04 1798.90 6018492.76 571128.69 MWD+IFR+MS 5031 .45 54.60 63.26 3679.70 3622.35 2285.94 1866.32 6018530.27 571195.76 MWD+IFR+MS 5126.38 54.20 67.29 3734.97 3677.62 2318.22 1936.41 6018563.20 571265.53 MWD+IFR+MS 5220.99 55.26 72.26 3789.63 3732.28 2344.88 2008.86 6018590.54 571337.73 MWD+IFR+MS 5318.76 55.65 78.09 3845.10 3787.75 2365.47 2086.66 6018611.84 571415.32 MWD+IFR+MS 5414.09 56.60 84.49 3898.27 3840.92 2377.42 2164.83 6018624.52 571493.37 MWD+IFR+MS 5510.10 56.34 89.55 3951.33 3893.98 2381.58 2244.71 6018629.42 571573.20 MWD+IFR+MS 5607.00 57.11 94.40 4004.52 3947.17 2378.77 2325.64 6018627.37 571654.14 MWD+IFR+MS 5702.95 57.59 100.16 4056.31 3998.96 2368.53 2405.72 6018617.88 571734.31 MWD+IFR+MS 5799.40 59.62 103.21 4106.56 4049.21 2351.84 2486.32 6018601.94 571815.05 MWD+IFR+MS 5895.04 61.99 107.58 4153.23 4095.88 2329.65 2566.77 6018580.50 571895.70 MWD+IFR+MS 5990.41 61.98 112.01 4198.04 4140.69 2301.15 2645.96 6018552.74 571975.15 MWD+IFR+MS 6086.47 63.32 116.61 4242.19 4184.84 2266.02 2723.68 6018518.34 572053.18 MWD+IFR+MS 6182.52 65.19 121.92 4283.93 4226.58 2223.72 2799.09 6018476.75 572128.98 MWD+IFR+MS 6278.72 68.26 123.32 4321.94 4264.59 2176.08 2873.51 6018429.80 572203.83 MWD+IFR+MS 6375.15 68.08 123.31 4357.80 4300.45 2126.91 2948.31 6018381.34 572279.08 MWD+IFR+MS 6469.92 68.13 123.32 4393.14 4335.79 2078.62 3021.79 6018333.73 572353.00 MWD+IFR+MS 6564.14 74.87 124.89 4423.02 4365.67 2028.53 3095.72 6018284.34 572427.38 MWD+IFR+MS 6613.12 77.67 125.17 4434.65 4377.30 2001.22 3134.68 6018257.40 572466.59 MWD+IFR+MS 6659.58 79.83 124.81 4443.71 4386.36 1975.09 3172.01 6018231.62 572504.16 MWD+IFR+MS 6709.78 79.69 124.96 4452.64 4395.29 1946.84 3212.53 6018203.75 572544.94 MWD+IFR+MS 6781.63 80.80 124.34 4464.81 4407.46 1906.58 3270.78 6018164.04 572603.55 MWD+IFR+MS 6830.65 86.40 127.19 4470.27 4412.92 1878.11 3310.28 6018135.95 572643.32 MWD+IFR+MS 6877.64 88.86 126.22 4472.22 4414.87 1850.06 3347.92 6018108.24 572681.21 MWD+IFR+MS 6926.14 90.59 123.55 4472.45 4415.10 1822.32 3387.70 6018080.88 572721.24 MWD+IFR+MS 6972.89 90.20 121 .03 4472.13 4414.78 1797.35 3427.22 6018056.28 572760.99 MWD+IFR+MS 7021 .42 90.40 120.47 4471.87 4414.52 1772.54 3468.92 6018031.86 572802.92 MWD+IFR+MS 7070.22 88.96 120.11 4472.14 4414.79 1747.92 3511.06 6018007.64 572845.28 MWD+IFR+MS . Halliburton Global . Survey 7117.83 92.09 121.47 4471.71 4414.36 1723.56 3551.95 6017983.66 572886.39 MWD+IFR+MS 7164.91 88.04 121.22 4471.65 4414.30 1699.07 3592.15 6017959.55 572926.81 MWD+IFR+MS 7213.97 87.59 120.51 4473.53 4416.18 1673.92 3634.23 6017934.80 572969.12 MWD+IFR+MS 7260.92 88.17 121.40 4475.26 4417.91 1649.79 3674.47 6017911.04 573009.58 MWD+IFR+MS 7308.80 88.59 121.02 4476.62 4419.27 1624.99 3715.40 6017886.63 573050.73 MWD+IFR+MS 7357.01 89.35 120.70 4477.48 4420.13 1600.26 3756.78 6017862.29 573092.34 MWD+IFR+MS 7405.46 90.71 119.12 4477.46 4420.11 1576.11 3798.77 6017838.53 573134.55 MWD+IFR+MS 7451.79 90.89 118.54 4476.81 4419.46 1553.77 3839.36 6017816.57 573175.34 MWD+IFR+MS 7501.61 90.95 117.94 4476.01 4418.66 1530.20 3883.24 6017793.41 573219.43 MWD+IFR+MS 7547.88 90.89 117.90 4475.27 4417.92 1508.54 3924.12 6017772.13 573260.51 MWD+IFR+MS 7595.87 91.18 116.88 4474.40 4417.05 1486.46 3966.72 6017750.46 573303.31 MWD+IFR+MS 7643.82 91.19 117.04 4473.41 4416.06 1464.73 4009.45 6017729.12 573346.24 MWD+IFR+MS 7691.76 91.32 116.97 4472.36 4415.01 1442.96 4052.16 6017707.76 573389.14 MWD+IFR+MS 7740.89 91.50 116.26 4471.15 4413.80 1420.96 4096.07 6017686.17 573433.25 MWD+IFR+MS 7789.32 90.76 115.27 4470.19 4412.84 1399.91 4139.67 6017665.53 573477.04 MWD+IFR+MS 7836.79 90.02 113.06 4469.87 4412.52 1380.48 4182.98 6017646.51 573520.52 MWD+IFR+MS 7884.33 88.03 111.47 4470.68 4413.33 1362.48 4226.96 6017628.91 573564.67 MWD+IFR+MS 7933.52 89.17 111.47 4471.88 4414.53 1 344.48 4272.73 6017611.34 573610.59 MWD+IFR+MS 7981.49 89.35 111.09 4472.50 4415.15 1327.07 4317.42 6017594.35 573655.44 MWD+IFR+MS 8029.40 89.84 110.67 4472.84 4415.49 1309.99 4362.18 6017577.69 573700.36 MWD+IFR+MS 8077.11 89.35 :110.24 4473.18 4415.83 1293.32 4406.88 6017561.44 573745.21 MWD+IFR+MS 8125.72 88.43 109.79 4474.12 4416.77 1276.69 4452.55 6017545.23 573791.02 MWD+IFR+MS 8172.67 88.73 109.79 4475.28 4417.93 1260.80 4496.71 6017529.75 573835.33 MWD+IFR+MS 8221.66 88.92 108.24 4476.29 4418.94 1244.84 4543.02 6017514.23 573881.78 MWD+IFR+MS 8269.66 89.54 106.91 4476.93 4419.58 1230.35 4588.77 6017500.17 573927.66 MWD+IFR+MS 8317.98 90.09 104.45 4477.09 4419.74 1217.29 4635.29 6017487.54 573974.29 MWD+IFR+MS 8366.59 89.38 101.96 4477.31 4419.96 1206.18 4682.61 6017476.88 574021.71 MWD+IFR+MS 8414.45 89.64 99.47 4477.72 4420.37 1197.29 4729.63 6017468.42 574068.80 MWD+IFR+MS 8462.99 89.64 97.95 4478.03 4420.68 1189.94 4777.61 6017461.52 574116.84 MWD+IFR+MS 8510.54 89.75 96.94 4478.28 4420.93 1183.78 4824.76 6017455.80 574164.04 MWD+IFR+MS 8559.33 89.63 95.80 4478.55 4421.20 1178.36 4873.24 6017450.84 574212.57 MWD+IFR+MS 8606.73 90.77 95.36 4478.38 4421.03 1173.75 4920.42 6017446.67 574259.78 MWD+IFR+MS 8655.20 91.32 93.90 4477.50 4420.15 1169.84 4968.72 6017443.21 574308.12 MWD+IFR+MS 8702.40 92.09 92.02 4476.09 4418.74 1167.41 5015.83 6017441.21 574355.25 MWD+IFR+MS 8751.24 90.82 88.45 4474.85 4417.50 1167.21 5064.65 6017441.46 574404.06 MWD+IFR+MS 8798.41 90.83 88.34 4474.17 4416.82 1168.53 5111.79 6017443.22 574451.18 MWD+IFR+MS 8847.64 87.84 88.72 4474.74 4417.39 1169.79 5161.00 6017444.94 574500.37 MWD+IFR+MS 8895.03 87.55 89.82 4476.65 4419.30 1170.39 5208.35 6017445.99 574547.70 MWD+IFR+MS 8945.96 87.74 89.01 4478.74 4421.39 1170.91 5259.23 6017446.98 574598.58 MWD+IFR+MS 8991.65 91.37 90.61 4479.10 4421.75 1171.06 5304.91 6017447.56 574644.25 MWD+IFR+MS 9040.14 93.80 89.11 4476.91 4419.56 1171.18 5353.35 6017448.13 574692.68 MWD+IFR+MS 9087.56 94.79 89.90 4473.36 4416.01 1171.59 5400.63 6017448.97 574739.95 MWD+IFR+MS 9136.00 94.96 89.35 4469.24 4411.89 1171.91 5448.89 6017449.74 574788.20 MWD+IFR+MS 9181.21 94.84 89.39 4465.38 4408.03 1172.40 5493.93 6017450.65 574833.24 MWD+IFR+MS 9227.03 97.69 90.91 4460.38 4403.03 1172.28 5539.47 6017450.96 574878.77 MWD+IFR+MS 9297.00 97.69 90.91 4451.02 4393.67 1171.18 5608.81 6017450.50 _ 574948.10 PROJECTED to TD . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th A venue, Suite 100 Anchorage, Alaska 99501 June 29, 2005 RE: MWD Formation Evaluation Logs MPE-12, AK-MW-3719142 1 LIS formatted Disc with verification listing. API#: 50-029-23262-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services 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: )~~c Signed: 1D ûllJ / Ÿ f3 ì-' ~ ?-. 0 :;- - ~ ~ 7 l-. { <.. . . r7ù 1, \ . '\\. æJ p iÞ Lb (;::;."\ ¡ , , ~ ¡IH i!u I .~ FRANK H. MURKOWSKI, GOVERNOR AI,ASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPE-12i BP Exploration (Alaska) Inc Permit No: 205-067 Surface Location: 3688' NSL, 1794' WEL, SEC. 25, T13N, R10E, UM Bottomhole Location: 4843' NSL, 1330' WEL, SEe. 30, T13N, RIlE, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ø Smcere 'r v y uaniel T.SeamoUIlt, Jr. Commissioner DATED thi/t day of May, 2005 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. II Drill 0 Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3688' NSL, 1794' WEL, SEC. 25, T13N, R10E, UM ' ¡Top of Productive Horizon: í1 ...... 57SA~NSL,~WEL, SEC. 30;"T13N, R11E, UM 7>vL I . ¿,¡ 'cv:./ ' Total DePth: I' 4843' NSL, 1330' WEL, SEC. 30, T13N, R11E, UM a STATE OF ALASKA . r ALAS~ OIL ;~~~I~~~R~~~~NL æMMIS~~CEIVED/..rAl 20 MC 25.005 APR ?, 2 2005 1b. Current Well Class 0 Exploratory 0 Development Oil 0 Multipl~ Zone o Stratigraphic Test II Service Alas ~IffiY~mlirt6'A§. Ci_lISlOftJe 5. Bond: !HI Blanket 0 Single Well 11. WEJl\-æRBn¡ftpd Number: Bond No. 2S100302630-277 MPE-12i 6. Proposed Depth: 12. Field I Pool(s): MD 9408 -' TVD 4488 / Milne Point Unit I Schrader Bluff 7. :roperty Designation: .ß 1>. .' 't 7';¡37J¥ ADL 028231 ç. z.. of> 8. Land Use Permit: 13. Approximate Spud Date: 05/18/05 9. Acres in Property: 2560 14. Distance to Nearest Property: 6615' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: X-569351, y-6016227 - Zone-ASP4 - (HeightaboveGL): 57.7' feet 500'awayfromMPE-30A./ 16. Deviated Wells: Kickoff Depth: '¡cd~ feet f))~_17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) ç V~."':Þ Maximum Hole Angle: 90.5 degrees 1 a: Casing Program: Size Casing 20" 1 0-3/4" 7-5/8" 4-1/2" Hole 42" Weight 92# 45.5# 29.7# 12.6# Specifications Grade Coupling H-40 Weld L-80 BTC-M L-80 BTC-M L-80 IBT-Mod Length 112' 3255' 6724' 2834' Downhole: 1924-' Setting Oepth Top ... .. .··Bottom MD TVD MD TVD Surface Surface 112' 112' Surface Surface 3255' 2658' Surface Surface 6724' / 4453' 6574' 4425' 9408' 4488' Surface: 1475./ QuantitYClf Cement (c.t. or s.acks) (including stage data) 260 sx Arctic Set (Approx.) 533 sx AS Lite, 473 sx Class 'G' 497 sx Class 'G' 497 sx Class 'G' 13-1/2" 9-718" 6-3/4" 19. PRE$ENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re--entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments !HI Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): !HI Drilling Program 0 Time vs Depth Plot o Seabed Report !HI Drilling Fluid Program o Shallow Hazard Analysis !HI 20 MC 25.050 Requirements Date: Contact David Johnson, 564-4171 Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Title Senior Drilling Engineer Phone , Prepared By Name/Number: Sondra Stewman, 564-4750 Permit To Drill API Number: . ., . Permit Approval I See cover letter for Number: '2...05 -Db 7 50- D 2-9·- 2-:3 z.Æ:, z. - æ.::> Date: -S=/Í t.Þ /or- other requirements Conditions of Approval: Samples Required 0 Yes KNo Mud Log Required 0 Yes [M"No Hydrogen Sulfide Measures 0 Yes "Øo Directional Survey Required .g'Yes 0 No Other: ~ooo\>e;, ~O\>-k?~~~~~~~a, '-I\~'~ (:~N\tt.,,\~~~\~~-¡ ~o~ r~V~~")'S.C~~S ~\\.)'), O~.-u."""'''-'.> .,~ o..--=~ "" (MD \. \) ~ · ~"'~~>ð J\"tt\ \ \ ". ut<'tt\ íN A L Original Signed By APPROVED BY _ /. / Approved By: DAN SEAMnUNT THE COMMISSION Date !ÿ/~/¿;J,,- Form 10,401 Revised 06/2004 Submit In Duplicate - bp · . I Well Name: I MPE-12 I Schrader NC/ND & OA Horizontal Injector Drilling and Completion Plan Summary r Type of Well: I Schrader Bluff NC/ND & OA Sand Horizontal Injector Distance to Property line Distance to nearest well 3,688' FSL and 1,794' FEL Section 25, T13N, R10E UM E = 569,351' N = 6,016,227' 564' FSL and 4,110' FEL Section 19, T13N, R11E UM E = 572,247' N = 6,018,410' Z = 4347' TVD 355' FSL and 3,803' FEL Section 19, T13N, R11 E UM E = 572,556' N = 6,018,204' Z = 4453' TVD 5,023' FSL and 2,871' FEL Section 30, T13N, R11 E UM E = 573,497' N = 6,017,602' Z = 4,483' TVD 4,852' FSL and 2,214' FEL Section 30, T13N, R11 E UM E = 574,156' N = 6,017,437 Z = 4,483 TVD 4',843 FSL and 1330' FEL Section 30, T13N, R11E UM E = 575,040' N = 6,017,437 Z = 4,488 TVD 6,61S SOO' from MPE-30A - OA Reservoir Surface Location: (As Proposed) T1 - Top NB T2 - Mid OA T3 -Mid OA T4-MidOA TS -Mid OA (TD) AFE Number: I Estimated Start Date: I 18-May-OS Rig: 1 Doyon 14 Rig days to complete: 1 13 MD: I 9,408' 1 TVD: 14,488' 1/ 1 Max Inc:190.So 1 I KOP: 1400' I 1 KBE:ls7.7' Well Design: Slimhole Objective: Schrader Bluff NC/ND & OA Horizontal Injector RECEIVED APR 22 2005 Alaska Oil & Gas Cons. Commission Anchorage Page 1 ORIGIf~AL Mud program:. 13-1/2" Surface Hole (0' - 3,255'): Density (ppg PV YP 8.6 - 9.8 10 - 30 30 - 50 . pH API Filtrate 8.5 - 9.5 NC-8 Spud Chlorides (mgfl) < 1000 9-7/8" Intermediate Hole (3,255' - 6,724'): Density (ppg PV YP pH 8.8 - 9.3 10 - 25 20 - 32 9.0 - 9.5 LSND API Filtrate Chlorides 6 - 8 < 1500 6-3/4" Production Hole (6,724' - 9,408'): Density (ppg PV YP pH 9.0-9.2 10-20 20-32 9.0-9.5 MOBM API Filtrate Chlorides 6 - 7 < 1500 MBT < 25 MBT < 25 / 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 1 R. Burst Collapse Length Top MDt TVDrkb l12-ft 0 CasinglTubing Program Hole Size WtlFt Grade Conn Csg Diam 42-in 20- in * 92 H-40 Weld 1530 520 13.5-in 1O.75-in 45.5 L-80 BTC-M 5210 2480 9.875-in 7.625-in 29.7 L-80 BTC-M 6890 4790 6.75-in 4.5 in 12.6 L-80 IBT- 8430 7500 Mod Cement Program: 3,255' 0 6,724' 0 2,834' 6,574' / 4,425 Bottom MDt TVDrkb 112-ft / l12-ft 3.255' / 2,658 6,724/ 4,,453 9,408' / 4,488 Casing Size 10-3/4",45.5#, L-80, BTC Surface Casing Tail cement = 1000' MD above shoe. 40% Excess over Gauge Hole Basis Lead to surface. 40% Excess over Gauge Hole to PF, 150% Excess over Gauge Hole from PF to Surface Total Cement 5 bbl water Volume: 463 bbl Wash 20 bbl CW 100 Spacer 50 bbl of MudPush Lead 363 bbl, 533 sx of ArcticSet Lite: 11 ppg and 3.83 fe/sx Tail 98 bbl, 473 sx "G" mixed at 15.8 Ib/gal & 1.17 fe/sx O retl . . " I RECE\VED APR 2 2 2005 . 'on 0·, & Gas Cons. CQmmlSSI A\asKa I Anchorage Page 2 L Casing Size Basis Total Cement Volume: 35 bbl Casing Size Basis Total Cement Volume: 35 bbl . . 7-5/8", 29.7#, L-80, BTC-M Intermediate Casing Tail cement = 500' MD above the TUZC. 40% Excess over Gauge Hole Wash Spacer Tail Temp 5-bbl water 10 bbl CW 100 20 bbl of MudPush 104 bbl, 497 sx "G" mixed at 15.8 Ib/gal & 1.17 ft;j/sx BHST ==80°F from SOR 4-1/2", 12.6#, L-80, IBT-M Liner Tail cement = 200' MD above the TUZC. 40% Excess over Gauge Hole Wash Spacer Tail Temp 5-bbl water 10 bbl CW 100 20 bbl of MudPush 104 bbl, 497 sx "G" mixed at 15.8 Ib/gal & 1.17 ft;j/sx BHST ==80°F from SOR Evaluation Program: 13-1/2" Section Open Hole: 9-7/8" Section Cased Hole: 6-3/4" Section Open Hole: Cased Hole: · Gyro · DIR/GR/RES · IFR/CASANDRA, · Sperry InSite / · DIR/GR/RES · IFR/CASANDRA, · Sperry InSite · GR/SCMT ./ · DIR/GR/RES · IFR/CASANDRA, · Sperry InSite ./ RECEIVED APR 2 2 Z005 Alaska Oil & Gas Cons. Commission Anchorage Page 3 Formation Marlrs: . Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) (Ib/gal) BPRF 2093 1938 816 8.35 Top Ugnu (TUZC) 5360 3868 1,654 8.35 Ugnu-MA 5771 4096 1,753 8.35 Ugnu-MB1 5790 4106 1,758 8.35 Ugnu-MB2 5929 4175 1,788 8.35 SBF2-NA 6212 4300 1,842 8.35 SBF1-NB 6292 4331 1,855 8.35 SBE4-NC 6344 4350 1,864 8.35 NO 6372 4360 1,868 8.35 SBE2-NE 6411 4374 1,874 8.35 SBE1-NF 6554 4420 1,894 8.35 TSBO- Top OA 6732 4454 1,909 8.35 / TO 9408 4488 1,924 8.35 Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 1 3-1/2" o - 3,255' 3255' Baker Hughes MX-1 2 9-7/8 3,255' - 6,724' 3469' Baker Hughes MX-1 3 6.75" 6,724' - 9408' 2684' Hycalog DSX-146 Well Control: Surface Hole: '£-\~ A diverter will be rigged up on ~ The header layout on E-Pad does not allow room to run the required 75' length diverter line as there is not sufficient clearance to run the diverter line thru the header. This will require a shorter diverter lenç¡th of 50' and the end of the diverter will be approximately 15' from the header. A variance is requested- for the shorter diverter line length. A notification procedure will be posted on the rig for an emergency shut down of E-pad in the event it is necessary to divert the well. See attached procedure. Intermediate/Production hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Integrity tests: Kick tolerance: · Integ rity tests: · Planned completion fluid: 1,924 psi at 4,488' TVD (TSBD-OA) / 1,475 psi at (Based on a full column of gas at 0.1 psi/ft) 3,000 psi FIT to 10.5 Ib/gal 20' below the 10-3/4" shoe. 50 Bbls with 9.4 Ib/gal mud at below the 10-3/4" shoe. FIT to 1 0.5 Ib/gal 20' below the 7-5/8" shoe. Kill Weight Brine with diesel cap. ./ Drilling Hazards & Contingencies: · Running Gravel/heavy clay problems have been encountered in somRliG(¡li\/i3]Iji}Vis Mud should be utilized. · Hydrates have been reported on E-Pad. Expected Depth for hydrates ~B' 2&tJ~0' SS. ./ Keep the Mud as Cool as possible. Alaska Oil & Gas Cons. Cum¡ms;;¡on Anchop;¡gì; L Page 4 Lost Circulation Lost Circulation is not reported as a major problem for E-Pad. Irregardless, of this good drilling practices need to be maintained. . . Expected Pressures · All Formation are expected to be normally pressured: 8.35 ppg or less. ./ Pad Data Sheet · Please Read the E-Pad Data Sheet thoroughly. Hydrocarbons · Hydrocarbons are possible in the Ugne & Schrader Bluff interval. Faults · Two (2) faults are mapped in the well. Fault #1 in the SV sands intermediate hole section at 3862' MD(2998' TVDss). Fault #2 is in the SV sands intermediate hole section at 4910' MD (3598' TVDss). Neither fault is expected to cause issues. Hydrogen Sulfide · MPE Pad is not designated as an H2S Pad, H2S detected from E-Pad wells on the pad: MPE-17 53ppm 2/2001 MPE-22 46 ppm 2/2001 MPE-04 5 ppm 2/2001 MPE-10 >2 ppm 2/2/01 Anti-collision Issues · MPE-12 passes the Major Risk Criteria on all wells. Distance to Nearest Property · MPE-12 is planned to be 6615 ft from the nearest Milne Point property line. ---- Distance to Nearest Well Within Pool · MPE-12 is 500 ft from the nearest sand penetration in the MPE-30A (OA reservoir). - RECEIVED APR 2 2 2005 Alaska Oil & Gas Cons. Commiuiol1 Anchorage Page 5 'DRILL & COM~TION PROCEDURE. Pre-Ria ODerations 1 . The 20" conductor will be installed pre-rig. Drillina: 1. MIRT and NU Diverter. 2. Function Test Diverter, PU 4" DP and BHA. 3. Drill 13-1/2" surface hole to the Schrader Bluff interval. / 4. Run and cement 1 0-3/4" surface casing. 5. ND diverter, install wellhead and NU/Test BOPE. 6. Drill 9-7/8" hole to intermediate casing point. 7. Run and cement 7-5/8" intermediate casing. 8. Drill 6-3/4" Horizontal Interval. 9. Run and cement 4-1/2" liner. 10. Run cement bond I?g on lower 7-5/8" intermediate casing. 11 . Perforate the OA sand in the 4 Y2" liner with TCP guns ad determined from logs. ~ 12. Perforate the NC/ND sands in the 7-5/8" casing as determined from logs. / 13. Run a 3 Y2" completion 14. ND BOP/NU Tree. 15. Freeze Protect With Diesel 16. RD & MO Doyon 14. RECEIVED APR 2 2 2005 Alaska Oil & Gas Cons. CommìssÌI:m Anchorage Page 6 . . Doyon 14 contingency plan in the event of using Divert line E-Pad · Doyon 14 rig will have a Mine Point radio and will have met with E- Pad operator(s) and informed them of the placement of their Divert Line, who in turn will inform ALL personnel who will be doing work on the pad. Nabors 4ES, contractors etc. · This Divert Line will have to be run near LIVE lines. Production, Test and Injection, due to space constraints on the pad. · In the event of using Divert Line, Doyon rig will call Milne Point control room board operator and request an ESD of E- Pad. · Doyon rig will then call Milne Point radio and inform them of action taken and why. Milne Point radio will make an announcement of restricted access to E-pad. · Control room board operator will notify E and S-Pad operators and then initiate ESD for the pad shutting down production from all wells and all injection as well. · The control room will then shut in XV -5873A the perimeter gas injection valve for E-Pad. · The control room board operator will shut in water injection for Sand E-Pads with the corresponding perimeter valve XV -5310. To make up for the loss of injection, board operator may have to divert water to B-50 injection well. · Doyon rig will then correspond with E-Pad operator about situation who will then account for all personnel under their authority and direct them to safe area. S-Pad operator will make required adjustments for loss of water injection. · E- Pad operator will then verify pad is in ESD mode and all wells and corresponding equipment did in fact shut in and ALL ESP's shut down. . In the event that Nabors 4ES is also on the pad they will have to be notified of any such action. . Once situation has been rectified Doyon rig will the notify the E-Pad operator, the control room board operator and Milne Point radio so provisions can be made to bring the pad back on line. RECEIVED APR 2 2 Z005 Alaska Oil & Gas Cons. Commission Anchorage . . RECEIVE[~~ o ';f- JPR 22 2005 ~ (.J IV) Alaska Oir~'G~iq;on 0 . p , z Anchorag~ CL ~ 7i'~ 2~p((, l~ E PAD -~~,~ ~ ~ hY.~ VICINITY MAP N.T.S. 0"') ~. Q\~"\ ," '? ~\\..,,"" ( ~ ~.- I + ----_. --- - _._- --. E-PAD ! 3 8 ¡ ¡ . · I :1 · 33 · 2 10 . · 4 22. .1 29i . 13. .5 26 . .30 9 . · 6 25 . .21 11 . · 7 18 . · 16 20 . .23 24. · 19 14. ~SLOT-A 15 . · 17 -,..- I LEGEND ~ RENAMED WELL CONDUCTOR . EXISTING WELL CONDUCTOR WELL SLOT-A REVISION NOTE THIS AS-BUILT DRAWING IS A REISSUE OF A PREVIOUS AS-BUILT DRAWING FOR CONDUCTOR SLOT-A. SLOT-A HAD BEEN PREVIOUSLY ç NAMED E-29. A NEW CONDUCTOR, E-29i, HAS t BEEN SET. o o o o o w N 1800.00 + -~_._._-~ ~--- _.'"'-- -..-. . u..+ NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 2. GEODETIC COORDINATES ARE NAD '27. 3. MEAN PAD SCALE FACTOR = 0.9999054. 4. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MONUMENTS CFP-3 AND E-1. 5. £LEVA TIONS ARE BASED ON BPX MILNE POINT DATUM (M.S.L.). 6. DATE OF SURVEY: JUNE 30, 1998. 7. REFERENCE FIELD BOOK: MP-98-06 PAGES 05-07. 8. THE WELL PREVIOUSLY NAMED "E - 29" LOCATED BETWEEN WELLS 17 & 19 HAS BEEN RENAMED "SLOT-A". SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 19, 2001. f; êc ., i ., ., LOCATED WITHIN PROTRACTED SEC. 25, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA ;' WELL ASP. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSmON(DMS) POSITJON(D.DD) BOX ELEV. OFFSETS Y= 6,016,227.28./ N. 1950.56 70·27'16.887" 70.4546879· 23.4' 3,688' FSL / SLOT-A X= 569,350.97/ E. 1450.11 149·26'02.626" 149.4340629· 1,794' FEL g , ~ i£ '" Jrn:~' DRAWN: JJC Obp CHECKED: RF¡t(, BP EXPLORATION O'ATE: 4/19/01 DRAw.mC: SHEET: MPE...5LOT-A MILNE POINT UNIT E-PAD l~o JOB NO; SCALE, AS-BUILT YÆ:LL CONDUCTOR 1Œ1 ~ filA IØIQIGM MIl tJIIG IuIt\It1OM YÆ:LL SLOT - A .. WES' ..... ~ 1·-200' .y (H( ~IIG[,""""'''''' :< "- / . ~ f ~ 0 4/1e/ø11S1U1D RIII_A_ ;;; 110. ~1[ IIE\o1SION Field: Milne Point Pad: E-Pad DIRILWD MWD OH I LOGS NONE NONE NONE Gyro DIR/GR/RES IFR/CASANDRA InSlte DIR/GR/RES NONE MRIUNeutron IFR/CASANDRA InSlte DIR/GR/RES NONE NeulDen IFR/CASANDRA InSlte 4/21/2005 FORM Permafrost Horlzonatl I DEPTH MD I TVD 112' Base Permafrost 2,093' 1,938' Top of Tall Cement 2,255' Top of Tall Cement 4,860' TUZC 5,360' 3,868' Top of NA 6,212· 4.300· Top of NB 6,292' 4,331' Top of NC. 6,344' 4,350' Top of ND 6,372' 4,360' 9,408' 4,488' BP EXPLORATION MPE-12 Producer HOLE SiZE ENG: D. Johnson RIG: Doyon 14 RKB: 58' CASiNG I Cemenl Slurry SPECS 20.000-ln 91.1-lb/ft H-40 Welded, Insul Surface CSQ 10-3/4" 45.5 Ib/ft L-80, BTC-M Int. Yield 5280 psi Collaspse 2480 psi Drift - 9.950" Inter. Casinq 7-5/8" 29.7Ibs/ft L-80, BTC-M Int. Yield 8890 psi Collaspse 4790 psi Drift - 8.875" Prod. liner 4-1/2" 12.6 Ibslft L-80,IBT-Mod Int. Yield 8430 psi Collaspse 7500 psi Drift - 3.833 363 Bbls, 533 SX 11.0 ppg 3.83 INFO Wellhead FMC Big Bore Tail Cement 98 bbls, 473 sX 15.8 ppg 40% Excess 1 .17 ft3/sx Cement Slurrv Tail 104 Bbls, 497 ax 15.8 ppg 1.17 it3/sx Cement Tail 104 Bbls, 497 SX 15.8 PP9 1.17 tt3/sx MP NC/ND, OA Single Completion :::: 23.4' :::: :::: 3.S·in, 9.3·lblfl. L·80. X Nipple ... ...... Bore ID "2,813-ln 2,500-ft MD .... - 3,5·in x 1.0·in wI dummy valve - 3,5·in,9,3.lblft, L-BO, TC·IITubing ID " 2,992-ln, Drift" 2.867-ln Burst" 10,160-lbf, Collapse" 10,530-lbf Capacity" 0.00870-bbllft 45,5-iblft, L·80, BTC 3,255·ft Me, 2,658·ft TVD GLM OA sands TBD MMG·W GLM wI dummy valve L.80, XN Nipple ID 2.750-ln Perforations: NC/ND sands TBD & ZXP Packer 80-40 PBR, x-o TOL at 6574.ft MD Set at +1- 75° 7.75" Shoesetat ± 830 6724·ft MD, 4453·ft TVD .. .. -... - - - - - - - - - --- - - - OA Sand: to DATE 03/2112005 04/18112005 Rev. BY M Green D Johnson E-12 lanned 1 0.25 Mile Suffer (Schrader Sluff Section) .E-30A ~,480.05 f+ ~E-06 ~E-04 Wen o 1000 2000 --- 1:12,000 4NAD .. Abandoned Gas Injector Injecting Operating Producing ·MllNEUOJP ~-~~~-MllNIU~AGRIVER MllNIUSCHRADER .. .... ... . ··MILNE_UGNU Redrnl *NB ··~E-08 Not Vet Reached. Pump COMPANY DETAILS REfElŒNCE INroRt...!ATJON BFAmoj,;o Tm¢ Nm1h CASING DETAILS FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 1937.70 2093.17 BPRF 2 3867.70 5360.36 TUZC 3 4095.70 5770.60 Ugnu-MA 4 4105.70 5789.97 Ugnu-MB! 5 4174.70 5928.58 Ugnu-MB2 6 4299.70 6211.74 SBF2-NA 7 4330.70 6291.99 SBFI-NB 8 4349.70 6344.11 SBE4-NC 9 4359.70 6372.01 ND 10 4373.70 641 SBE2-NE II 44J9.70 SBEI-NF 12 4453.70 TSBD-Top OA No. TVD MD Nmne Size 3254.99 6723.80 9408.00 103/4" 7 4 10.750 7.625 4.500 o 300' MD, 300TVD : SOO' MD. 499.91'TVD 900 Start Dir 3/100': 750· MD. 74X.6WTVD Start Dil'l .5/100': Ib16.67' MD, 1550.!šÓ'TVD End Dir : 1750' MD, 1660.07' TVD Start Dir4/100': 210X.37' MD. 1950TVD 1800 f '" '" "" "' i5. " ç¡ -¿;¡ 'Ë 2700 " > " 2 I- End Dir : 2607.37' MD, 2295.06' TVD Start Dir4/100': 4435.06' MD. 33 1 X.49TVD 3600 Vertical Section at 78.53" [900í1lin] [kpÚJ Fm Lkpth To Sur\"cy/Plau .3430 1.::00.00 See MD 34.30 300.00 500.00 750.00 1616.67 1750.00 2108.37 2607.37 4435.06 SURVEY PJWGRAJ'vl lne Azí TVD 0.00 0.00 34.30 0.00 36,00 300.00 3.00 36.00 499,91 8.00 36.00 748.68 34.00 36.00 1550,86 36.00 36.00 1660.07 36,00 36.00 1950.00 55.95 37.02 2295.06 55.95 37.02 3318.49 69.00 124.00 69,00 124.00 69.00 124.00 83,06 124.82 83.06 124.82 4455.12 88.79 124.01 4461.98 88,79 124.01 4478,35 89.00 115.00 4482,70 90.46 103.44 4484.07 90.46 103.44 89.50 95.00 89.69 90,21 89.69 90.21 Name MPE-12 Tl Top NB MPE-12 T2 Top OA MPE-12 T3 Mid OA MPE-12 T4 Mid OA MPE-12 T5 Mid OA End Dir : 6335.74' MD, 4346.7' TVD 1 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 21 22 7842,19 8133.12 1.49 8644.09 9408.44 Start Dir 5i I (){)' : 6442.29' MD, 4384J.;WTVD End Dir : 6723.87' MD, 4451.7' TVn Tou! - __n___m___m__n_________ _m___n______ ----- P!an: MPE-! 2 wp08 (Plan MPE-! 2/MPE- 12) Cn:¡¡t<:d By: Digita! Busìncss Client USI.,."Y Date: 3/29/2005 Chcckèd: Date: R.;viewed: Date: SECTION DETAILS +N/-S +E/-W DLeg TFace VSec Target 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 36.00 0.00 4.24 3.08 1.50 36.00 3.86 23.61 17.16 2.00 0.00 21.51 272.73 198.15 3.00 0.00 248.43 334.60 243.10 1.50 0.00 304.79 505.02 366.92 0.00 0.00 460.02 791.61 579.74 4.00 2.48 725.59 2000,60 1491.55 0.00 0.00 1859.62 2156.71 2916.70 4,00 106.1 I 3287.36 MPE-12 TI Top NB 2103.83 2995.10 0.00 0.00 3353.68 2101.09 2999.17 0,00 0.00 3357.12 1947.00 3224.00 5.00 3.37 3546.81 MPE-12 T2 Top OA 1935.66 3240.30 0,00 0.00 3560.53 1881.26 3319.70 6.00 -8.07 3627.53 1447.03 3963.18 0,00 0.00 4171.80 1336.20 4159.04 4.00 -88.77 4341.70 MPE-12 T3 Mid OA 1240.58 4433.28 4.00 -82.84 4591.44 1199.11 4606.76 0.00 0.00 4753,21 1165.05 4816.54 4.00 -96.49 4952,03 MPE- I 2 T4 Mid OA 1159,61 4936.25 4.00 -87.76 5068,26 1156.82 5700.58 0.00 0.00 5816.78 MPE-12 T5 Mid OA TVD 4346.70 4452.70 4482.70 4482.70 4487.70 TARGET DETAILS +N/-S +E/-W Northing Fasting Shape 2156.71 2916.70 6018410.84 572247.20 Point 1947.00 3224.00 60 18204.02 572556.40 Point 1336.20 4159,04 6017602.00 573497.00 Point 1165.05 4816.54 6017437.00 574156.00 Point 1156.82 5700.58 6017437.00 575040.00 Point WELL !)ETAILS Nmu..; N011híng E:1sting L;¡¡j¡mk LongÌlll<.k Sh¡¡ Plan MPE-12 2429.56 ·67_l3 60J6227,28 56935{.97 70"17'!6.i07N 149~26'02.626W N/A End Dir : 6g40.4' MD, 4461.%' TVD Start Dìr 6/100': 6743.Í'Ì7' MD, 4455. 1 2'TVD SlMl Dir4/100': 7616.g7' MD. 4478.35TVD EndDir :HI33.12·MD,44S4.0TTVD MPE-12 MPE-12 T5. MPE-12 wp08 41/2" 1 I I r ¡ 6300 SURVEY PROGRAM P1an: MPE·j2 wpOS (Plan MPE-12/MPE-J Depth Fm lkpll¡ To SurvcyiJ'hll1 Creak'\! By: DigitaJ Busine.'i5 Clîent User Date: 3i2{ ,., Checked: Date: ;y WELL DETAILS Nam N/·5 Northing I:';¡~ling L;iJiludc Longitu. 5!, PIa» 1\.11>);-12 1429.56 ~67. 13 6016217.28 569350.97 70"27'!6.8771'\ J49"2(j'02.626W NiA TARGET DETAILS Name TVD +N/-S iEI-W Northing Easting Shape MPE-12 Fault I 2070,64 1328.48 6018310,00 570660.00 Polyg( MPE-12 Fault 2 267658 1774.19 6018920.00 571100.00 Polyg< MPE-12 2156.71 2916.70 6018410,84 Point MPE-12 1947,00 3224.00 6018204.02 Point MPE-12 Poly 4452.70 2363.17 2887.42 6018617.00 572216.00 Polyg, MPE-12 Fault 4 4462.70 1929.65 2507,33 6018180,00 'olyg( MPE-12 Fault 3 4467.70 2864.71 1977.96 6019 II 0.00 'olyg( n. 4482.70 1336.20 4159,04 6017602,00 )oint 1165.05 4816,54 Joint MPE-12 1156.82 5700,58 )oint CASING DETAilS No. TVD MD Name Size 10 10.750 7 4487.70 4 INFORMATION NCE [ERJ HI 'AILS I COMPANY Targe 3.86 21.51 248.43 304.79 460.02 MPE-12 T MPE-12 T2. 3560.53 3627.53 4171.80 4341.70 MPE-12 n. MPE-12 T4. MPE-12 T5. VScc TFace 36,00 0.00 0.00 0.00 0,00 06.11 0.00 0.00 3.37 DLeg 0.00 0.00 UO 2.00 3.00 1.50 0.00 4.00 0.00 4.00 0.00 0,00 5.00 0.00 6.00 0,00 4.00 4.00 0,00 SECTION DETAILS +EI-W 0.00 0.00 3,08 17.16 198.15 243.10 366,92 579,74 1491.55 2916.70 2995.10 2999.17 3224.00 3240.30 3319,70 3963,18 4159,04 +NI-S 0.00 0.00 4.24 23.61 272.73 334.60 505.02 791.61 'VD 34.30 300.00 499.91 748,68 1550,86 1660.07 1950,00 2295.06 3318.49 4346.70 4383.00 4384,88 4452.70 4455.12 4461.98 4478,35 4482,70 4484,07 Azí 0.00 .16.00 36,00 .16.00 .16.00 36.00 .16.00 37.02 .17,02 24,00 24.82 24,01 Inc 0.00 0.00 3.00 8,00 34.00 36.00 36,00 55.95 89,00 90.46 90.46 89,50 89.69 89.69 MD .14..10 300.00 500.00 750.00 616,67 64.17,03 6442.29 6723.87 See I 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 21 22 0,00 0,00 8311.49 8524,21 8644.09 9408.44 FORMATION TOP DETAILS Nu. TVDPath MDPath Fonnatíon I 19.17.70 BPRF 2 3867.70 TUZC 3 Ugnu-MA 4 Ugnu-MB 5 Ugnu-MB: 6 SBF2-NA 7 SBFI-NB 8 4.149.70 SBE4-NC 9 4.159.70 ND 10 437.1.70 SBE2-NE II 4419.70 SBEl-NF 12 4453.70 TSBD-Top OA TVD West(-)/East(+) [800ibn] MPE- 90.2 800 .12( 240()- 600 E ~ ~ * o ~ "'" ;:; o VJ · Sperry-SUD . BP Planning Report RECEIVED Principal: Yes Date: 3/29/2005 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: Date Composed: Version: Tied-to: Time: 16:29:~PR2 2 ZOO~age: 1 Well: Plan MPE-12, True North Allab:QiÞ&7G'as Cons. Commission Well (0.OON,0').9~I8.53Azi) Minimum cu~rage Db: Oracle 1/25/2005 54 From: Definitive Path Company: Field: Site: Well: Wellpath: Plan: BP Amoco Milne Point MPtEPad Plan MPE-12 MPE-12 MPE-12 wp08 Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 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 6013798.68 ft 569440.72 ft Latitude: 70 26 Longitude: 149 26 North Reference: Grid Convergence: 52.982 N 0.655 W True 0.53 deg Well: Plan MPE-12 Slot Name: Well Position: +N/-S 2429.56 ft Northing: 6016227.28 ft Latitude: 70 27 16.877 N +E/-W -67.13 ft Easting : 569350.97 ft Longitude: 149 26 2.626 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 3254.99 2657.70 10.750 13.500 103/4" 6723.80 4452.69 7.625 9.875 7 5/8" 9408.00 4487.70 4.500 6.125 4 1/2" Formations MD TVD Formations Lithology Dip Angie Dip Direction ft ft deg deg 2093.17 1937.70 BPRF 0.00 0.00 5360.36 3867.70 TUZC 0.00 0.00 5770.60 4095.70 Ugnu-MA 0.00 0.00 5789.97 4105.70 Ugnu-MB 1 0.00 0.00 5928.58 4174.70 Ugnu-MB2 0.00 0.00 6211.74 4299.70 SBF2-NA 0.00 0.00 6291.99 4330.70 SBF1-NB 0.00 0.00 6344.11 4349.70 SBE4-NC 0.00 0.00 6372.01 4359.70 ND 0.00 0.00 6411.08 4373.70 SBE2-NE 0.00 0.00 6553.69 4419.70 SBE1-NF 0.00 0.00 6732.14 4453.70 TSBD-Top OA 0.00 0.00 0.00 TSBC-Base OA 0.00 0.00 0.00 OA OWC 0.00 0.00 Targets Map Map <-- Latitude --> <--. Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPE-12 Fault 1 2997.70 2070.64 1328.48 6018310.00 570660.00 70 27 37.240 N 149 25 23.592 W -Polygon 1 2997.70 2070.64 1328.48 6018310.00 570660.00 70 27 37.240 N 149 25 23.592 W -Polygon 2 2997.70 993.38 1018.42 6017230.00 570360.00 70 27 26.646 N 149 25 32.707 W MPE-12 Fault 2 3597.70 2676.58 1774.19 6018920.00 571100.00 70 27 43.198 N 149 25 10.492 W -Polygon 1 3597.70 2676.58 1774.19 6018920.00 571100.00 70 27 43.198 N 149 25 10.492 W -Polygon 2 3597.70 1587.27 1684.03 6017830.00 571020.00 70 27 32.485 N 1492513.148W MPE-12 n. 4346.70 2156.71 2916.70 6018410.84 572247.20 70 27 38.082 N 149 24 36.925 W MPE-12 T2. 4452.70 1947.00 3224.00 6018204.02 572556.40 70 27 36.018 N 149 24 27.899 W Company: Field: Site: Well: Wellpath: Targets Name MPE-12 Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 BP Amoco Milne Point MPtEPad Plan MPE-12 MPE-12 MPE-12 Fault 4 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 MPE-12 Fault 3 -Polygon 1 -Polygon 2 MPE-12 T3. MPE-12 T4. MPE-12 T5. Description Dip. Dir. Plan Section Information MD ft 34.30 300.00 500.00 750.00 1616.67 1750.00 2108.37 2607.37 4435.06 6335.74 6437.03 6442.29 6723.87 6743.87 6840.40 7616.87 7842.19 8133.12 8311.49 8524.21 8644.09 9408.44 Incl deg 0.00 0.00 3.00 8.00 34.00 36.00 36.00 55.95 55.95 69.00 69.00 69.00 83.06 83.06 88.79 88.79 89.00 90.46 90.46 89.50 89.69 89.69 Azim deg 0.00 36.00 36.00 36.00 36.00 36.00 36.00 37.02 37.02 124.00 124.00 124.00 124.82 124.82 124.01 124.01 115.00 103.44 103.44 95.00 90.21 90.21 . 4452.70 4452.70 4452.70 4452.70 4452.70 4452.70 4452.70 4452.70 4452.70 4462.70 4462.70 4462.70 4462.70 4462.70 4467.70 4467.70 4467.70 4482.70 4482.70 4487.70 TVD ft 34.30 300.00 499.91 748.68 1550.86 1660.07 1950.00 2295.06 3318.49 4346.70 4383.00 4384.88 4452.70 4455.12 4461.98 4478.35 4482.70 4484.07 4482.63 4482.70 4483.55 4487.70 Sperry-Sun . BP Planning Report TVD ft 2363.17 2363.17 2156.54 1249.89 1060.09 1050.16 1293.17 1302.95 1483.02 1929.65 1929.65 1389.04 802.80 1389.04 2864.71 2864.71 1915.08 1336.20 1165.05 1156.82 +N/-8 ft 0.00 0.00 4.24 23.61 272. 73 334.60 505.02 791.61 2000.60 2156.71 2103.83 2101.09 1947.00 1935.66 1881.26 1447.03 1336.20 1240.58 1199.11 1165.05 1159.61 1156.82 Date: 3/29/2005 Time: 16:29:11 Page: 2 Co-ordinate(NE) Reference: Well: Plan MPE-12, True North' t' Vertical (TVD) Reference: 23.4 + 34.3 57.7 Section (VS) Reference: Well (0.00N,0.00E,78.53Azi) Survey Calculation Method: Minimum Curvature ~ Db: Oracle +N/-S ft +E/-W ft 2887.42 2887.42 2737.48 4083.23 4810.56 5877.61 5879.88 4829.82 4180.41 2507.33 2507.33 3102.39 3226.95 3102.39 1977.96 1977.96 4072.41 4159.04 4816.54 5700.58 +E/-W ft 0.00 0.00 3.08 17.16 198.15 243.10 366.92 579.74 1491.55 2916.70 2995.10 2999.17 3224.00 3240.30 3319.70 3963.18 4159.04 4433.28 4606.76 4816.54 4936.25 5700.58 Map Northing ft Map Easting ft 6018617.00 572216.00 6018617.00 572216.00 6018409.00 572068.00 6017515.00 573422.00 6017332.00 574151.00 6017332.00 575218.00 6017575.00 575218.00 6017575.00 574168.00 6017749.00 573517.00 6018180.00 571840.00 6018180.00 571840.00 6017645.00 572440.00 6017060.00 572570.00 6017645.00 572440.00 6019110.00 571302.00 6019110.00 571302.00 6018180.00 573405.00 6017602.00 573497.00 6017437.00 574156.00 6017437.00 575040.00 <- Latitude --> <- Longitude -> Deg Min See Deg Min See 70 2740.112N 70 2740.112N 70 27 38.081 N 70 27 29.158 N 70 27 27.287 N 70 27 27.182 N 70 27 29.572 N 70 27 29.675 N 70 27 31.450 N 149 24 37.783 W 149 24 37.783 W 149 24 42.191 W 149 24 2.664 W 1492341.299W 149 23 9.951 W 149 23 9.879 W 149 23 40.728 W 149 23 59.805 W 70 27 35.850 N 70 27 35.850 N 70 27 30.531 N 70 27 24.765 N 70 27 30.531 N 149 24 48.956 W 149 24 48.956 W 149 24 31.479 W 149 24 27.827 W 149 24 31.479 W 149 25 4.502 W 149 25 4.502 W 149 24 2.971 W 70 27 45.048 N 70 27 45.048 N 70 27 35.700 N 70 27 30.006 N 149 24 0.435 W 70 27 28.319 N 70 27 28.232 N 149 2341.121 W 149 23 15.149 W 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.21 0.00 4.58 0.00 0.00 0.29 0.00 -0.84 0.00 -4.00 -3.97 0.00 -3.97 -4.00 0.00 TFO Target deg 0.00 36.00 36.00 0.00 0.00 0.00 0.00 2.48 0.00 106.11 MPE-12 T1. 0.00 0.00 3.37 MPE-12 T2. 0.00 -8.07 0.00 -88.77 MPE-12 T3. -82.84 0.00 -96.49 MPE-12 T 4. -87.76 0.00 MPE-12 T5. DLS Build Turn deg/10OO deg/100ft deg/100ft 0.00 0.00 1.50 2.00 3.00 1.50 0.00 4.00 0.00 4.00 0.00 0.00 5.00 0.00 6.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 0.00 0.00 1.50 2.00 3.00 1.50 0.00 4.00 0.00 0.69 0.00 0.00 4.99 0.00 5.94 0.00 0.09 0.50 0.00 -0.45 0.16 0.00 RECEIVED APR 2 2 2005 Alaska Oil S. Î1:J'i r.nn&. CommiuiQO Anchorage r"l Ji 1 ) ¡ ; :..,;," ¡ \ . Sperry-SuD . RECEIVED BP Planning Report APR 2 2 Z005 Company: BP Amoco Date: 3/29/2005 Ti'1{¡' k\î1"~~§.,J6.ssion3 Field: Milne Point Co-ordinate(NE) Reference: I . .,. ~ Site: MptEPad Vertical (TVD) Reference: 23.4 + 34.3 5Añchorille WeD: Plan MPE-12 Section (VS) Reference: Well (0.00N,0.00E,78.. Azi) WeDpath: MPE-12 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft deg/10Oft ft ft 34.30 0.00 0.00 34.30 -23.40 0.00 0.00 0.00 6016227.28 ' 569350.97 ' CB-GYRO-SS 100.00 0.00 36.00 100.00 42.30 0.00 0.00 0.00 6016227.28 569350.97 CB-GYRO-SS 200.00 0.00 36.00 200.00 142.30 0.00 0.00 0.00 6016227.28 569350.97 CB-GYRO-SS ,- 300.00 0.00 36.00 300.00 242.30 0.00 0.00 0.00 6016227.28 569350.97 Start Dir 1.5/1 400.00 1.50 36.00 399.99 342.29 1.06 0.77 1.50 6016228.35 569351.73 CB-GYRO-SS 500.00 3.00 36.00 499.91 442.21 4.24 3.08 1.50 6016231.54 569354.01 Start Dir 2/100 600.00 5.00 36.00 599.66 541.96 9.88 7.18 2.00 6016237.22 569358.05 CB-GYRO-SS 700.00 7.00 36.00 699.11 641.41 18.33 13.32 2.00 6016245.74 569364.12 CB-GYRO-SS 750.00 8.00 36.00 748.68 690.98 23.61 17.16 2.00 6016251.05 569367.90 Start Dir 3/100 800.00 9.50 36.00 798.10 740.40 29.77 21.63 3.00 6016257.24 569372.32 CB-GYRO-SS 900.00 12.50 36.00 896.25 838.55 45.20 32.84 3.00 6016272.78 569383.39 CB-GYRO-SS 1000.00 15.50 36.00 993.27 935.57 64.77 47.06 3.00 6016292.48 569397.42 CB-GYRO-SS 1100.00 18.50 36.00 1088.88 1031.18 88.42 64.24 3.00 6016316.29 569414.38 CB-GYRO-SS 1200.00 21.50 36.00 1182.84 1125.14 116.09 84.34 3.00 6016344.14 569434.22 MWD+IFR+MS 1300.00 24.50 36.00 1274.88 1217.18 147.70 107.31 3.00 6016375.96 569456.89 MWD+IFR+MS 1400.00 27.50 36.00 1364.75 1307.05 183.16 133.07 3.00 6016411.65 569482.32 MWD+IFR+MS 1500.00 30.50 36.00 1452.20 1394.50 222.38 161.57 3.00 6016451.13 569510.44 MWD+IFR+MS 1600.00 33.50 36.00 1537.00 1479.30 265.24 192.71 3.00 6016494.28 569541.18 MWD+IFR+MS 1616.67 34.00 36.00 1550.86 1493.16 272.73 198.15 3.00 6016501.82 569546.56 Start Dir 1.5/1 1700.00 35.25 36.00 1619.43 1561.73 311.04 225.98 1.50 6016540.38 569574.03 MWD+IFR+MS 1750.00 36.00 36.00 1660.07 1602.37 334.60 243.10 1.50 6016564.10 569590.92 End Dir : 1750 1800.00 36.00 36.00 1700.52 1642.82 358.38 260.38 0.00 6016588.03 569607.97 MWD+IFR+MS 1900.00 36.00 36.00 1781.42 1723.72 405.93 294.93 0.00 6016635.90 569642.08 MWD+IFR+MS 2000.00 36.00 36.00 1862.33 1804.63 453.48 329.47 0.00 6016683.77 569676.18 MWD+IFR+MS 2093.17 36.00 36.00 1937.70 1880.00 497.79 361.66 0.00 6016728.36 569707.95 BPRF 2100.00 36.00 36.00 1943.23 1885.53 501.04 364.02 0.00 6016731.63 569710.28 MWD+IFR+MS 2108.37 36.00 36.00 1950.00 1892.30 505.02 366.92 0.00 6016735.64 569713.13 Start Dir 4/100 2200.00 39.66 36.25 2022.36 1964.66 550.40 400.05 4.00 6016781.33 569745.84 MWD+IFR+MS 2300.00 43.66 36.48 2097.05 2039.35 603.91 439.45 4.00 6016835.20 569784.74 MWD+IFR+MS 2400.00 47.66 36.68 2166.93 2109.23 661.33 482.07 4.00 6016893.01 569826.82 MWD+IFR+MS 2500.00 51.65 36.85 2231.66 2173.96 722.37 527.68 4.00 6016954.46 569871.86 MWD+IFR+MS 2600.00 55.65 37.01 2290.91 2233.21 786.74 576.07 4.00 6017019.27 569919.64 MWD+IFR+MS 2607.37 55.95 37.02 2295.06 2237.36 791.61 579.74 4.00 6017024.17 569923.27 End Dir : 2607 2700.00 55.95 37.02 2346.93 2289.23 852.88 625.95 0.00 6017085.87 569968.90 MWD+IFR+MS 2800.00 55.95 37.02 2402.92 2345.22 919.03 675.84 0.00 6017152.47 570018.17 MWD+IFR+MS 2900.00 55.95 37.02 2458.92 2401.22 985.17 725.73 0.00 6017219.07 570067.43 MWD+IFR+MS 3000.00 55.95 37.02 2514.91 2457.21 1051.32 775.62 0.00 6017285.68 570116.70 MWD+IFR+MS 3100.00 55.95 37.02 2570.91 2513.21 1117.47 825.51 0.00 6017352.28 570165.96 MWD+IFR+MS 3200.00 55.95 37.02 2626.91 2569.21 1183.62 875.40 0.00 6017418.88 570215.23 MWD+IFR+MS 3254.99 55.95 37.02 2657.70 2600.00 1220.00 902.83 0.00 6017455.51 570242.32 10 3/4" 3300.00 55.95 37.02 2682.90 2625.20 1249.77 925.28 0.00 6017485.49 570264.49 MWD+IFR+MS 3400.00 55.95 37.02 2738.90 2681.20 1315.92 975.17 0.00 6017552.09 570313.76 MWD+IFR+MS 3500.00 55.95 37.02 2794.89 2737.19 1382.07 1025.06 0.00 6017618.70 570363.03 MWD+IFR+MS 3600.00 55.95 37.02 2850.89 2793.19 1448.21 1074.95 0.00 6017685.30 570412.29 MWD+IFR+MS 3700.00 55.95 37.02 2906.89 2849.19 1514.36 1124.84 0.00 6017751.90 570461.56 MWD+IFR+MS 3800.00 55.95 37.02 2962.88 2905.18 1580.51 1174.73 0.00 6017818.51 570510.82 MWD+IFR+MS 3862.18 55.95 37.02 2997.70 2940.00 1621.64 1205.75 0.00 6017859.92 570541.46 MPE-12 Fault 1 3900.00 55.95 37.02 3018.88 2961.18 1646.66 1224.61 0.00 6017885.11 570560.09 MWD+IFR+MS 4000.00 55.95 37.02 3074.87 3017.17 1712.81 1274.50 0.00 6017951.71 570609.35 MWD+IFR+MS 4100.00 55.95 37.02 3130.87 3073.17 1778.96 1324.39 0.00 6018018.32 570658.62 MWD+IFR+MS 4200.00 55.95 37.02 3186.87 3129.17 1845.10 1374.28 0.00 6018084.92 570707.89 MWD+IFR+MS 4300.00 55.95 37.02 3242.86 3185.16 1911.25 1424.17 0.00 6018151.52 570757.15 MWD+IFR+MS 4400.00 55.95 37.02 3298.86 3241.16 1977.40 1474.06 0.00 6018218.13 570806.42 MWD+IFR+MS . Sperry-SUD . RECEIVED BP Planning Report APR ? 2 Z005 Company: BP Amoco Date: 3/29/2005 Time: W:2~~ Pale: 4 Field: Milne Point Co-ordinate(NE) Reference:Alasi$ if> QQpf~ SIOI1 Site: MPtEPad Vertical (TVD) Reference: 23.4 + 34öMf.é Well: Plan MPE-12 Section (VS) Reference: Well (0.0 ,.. , .53Azi) Wellpath: MPE-12 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVD N/S E/W DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft deg/100ft ft ft 4435.06 55.95 37.02 3318.49 3260.79 2000.60 1491.55 0.00 6018241.48 570823.69 Start Dir 4/1 00 4500.00 55.26 40.06 3355.18 3297.48 2042.50 1524.92 4.00 6018283.69 570856.67 MWD+IFR+MS 4600.00 54.36 44.83 3412.83 3355.13 2102.79 1580.04 4.00 6018344.49 570911.22 MWD+IFR+MS 4700.00 53.65 49.69 3471.62 3413.92 2157.68 1639.42 4.00 6018399.93 570970.08 MWD+IFR+MS 4800.00 53.14 54.64 3531.27 3473.57 2206.91 1702.78 4.00 6018449.73 571032.98 MWD+IFR+MS 4900.00 52.84 59.63 3591.49 3533.79 2250.22 1769.82 4.00 6018493.66 571099.60 MWD+IFR+MS 4910.28 52.82 60.15 3597.70 3540.00 2254.33 1776.90 4.00 6018497.84 571106.64 MPE-12 Fault 2 5000.00 52.75 64.65 3651.98 3594.28 2287.42 1840.19 4.00 6018531.51 571169.62 MWD+IFR+MS 5100.00 52.87 69.67 3712.46 3654.76 2318.31 1913.57 4.00 6018563.08 571242.70 MWD+IFR+MS 5200.00 53.20 74.66 3772.62 3714.92 2342.76 1989.59 4.00 6018588.23 571318.48 MWD+IFR+MS 5300.00 53.74 79.60 3832.17 3774.47 2360.63 2067.88 4.00 6018606.84 571396.60 MWD+IFR+MS 5360.36 54.16 82.54 3867.70 3810.00 2368.21 2116.08 4.00 6018614.86 571444.72 TUZC 5400.00 54.47 84.45 3890.82 3833.12 2371.85 2148.07 4.00 6018618.80 571476.67 MWD+IFR+MS 5500.00 55.40 89.21 3948.29 3890.59 2376.36 2229.76 4.00 6018624.07 571558.30 MWD+IFR+MS 5600.00 56.51 93.85 4004.30 3946.60 2374.13 2312.55 4.00 6018622.61 571641.10 MWD+IFR+MS 5700.00 57.78 98.36 4058.57 4000.87 2365.18 2396.04 4.00 6018614.44 571724.66 MWD+IFR+MS 5770.60 58.78 101.47 4095.70 4038.00 2354.84 2455.18 4.00 6018604.65 571783.90 Ugnu-MA 5789.97 59.06 102.31 4105.70 4048.00 2351.42 2471.42 4.00 6018601.38 571800.16 Ugnu-MB 1 5800.00 59.21 102.74 4110.84 4053.14 2349.56 2479.82 4.00 6018599.59 571808.58 MWD+IFR+MS 5900.00 60.79 106.99 4160.86 4103.16 2327.32 2563.49 4.00 6018578.14 571892.44 MWD+IFR+MS 5928.58 61.26 108.18 4174.70 4117.00 2319.77 2587.32 4.00 6018570.81 571916.34 Ugnu-MB2 6000.00 62.49 111.10 4208.37 4150.67 2298.60 2646.63 4.00 6018550.19 571975.84 MWD+IFR+MS 6100.00 64.31 115.08 4253.16 4195.46 2263.52 2728.85 4.00 6018515.88 572058.37 MWD+IFR+MS 6200.00 66.24 118.94 4294.99 4237.29 2222.25 2809.74 4.00 6018475.38 572139.64 MWD+IFR+MS 6211.74 66.47 119.39 4299.70 4242.00 2217.01 2819.13 4.00 6018470.23 572149.07 SBF2-NA 6291.99 68.09 122.39 4330.70 4273.00 2179.00 2882.64 4.00 6018432.81 572212.93 SBF1-NB 6300.00 68.26 122.69 4333.68 4275.98 2175.01 2888.90 4.00 6018428.87 572219.23 MWD+IFR+MS 6335.74 69.00 124.00 4346.70 4289.00 2156.71 2916.70 4.00 6018410.84 572247.20 MPE-12T1. / 6344.11 69.00 124.00 4349.70 4292.00 2152.34 2923.18 0.00 6018406.53 572253.72 SBE4-NC 6372.01 69.00 124.00 4359.70 4302.00 2137.77 2944.78 0.00 6018392.17 572275.45 ND 6400.00 69.00 124.00 4369.73 4312.03 2123.16 2966.44 0.00 6018377.76 572297.24 MWD+IFR+MS 6411.08 69.00 124.00 4373.70 4316.00 2117.38 2975.02 0.00 6018372.06 572305.87 SBE2-NE 6437.03 69.00 124.00 4383.00 4325.30 2103.83 2995.10 0.00 6018358.70 572326.08 MWD+IFR+MS 6442.29 69.00 124.00 4384.88 4327.18 2101.09 2999.17 0.00 6018355.99 572330.17 Start Dir 5/100 6500.00 71.88 124.18 4404.20 4346.50 2070.61 3044.20 5.00 6018325.94 572375.48 MWD+IFR+MS 6553.69 74.56 124.34 4419.70 4362.00 2041.68 3086.68 5.00 6018297.41 572418.22 SBE1-NF 6600.00 76.87 124.47 4431.13 4373.43 2016.32 3123.71 5.00 6018272.39 572455.48 MWD+IFR+MS 6700.00 81.86 124.76 4449.57 4391.87 1960.50 3204.57 5.00 6018217.34 572536.85 MWD+IFR+MS 6723.80 83.05 124.82 4452.69 4394.99 1947.04 3223.94 5.00 6018204.06 572556.35 75/8" 6723.87 83.06 124.82 4452.70 4395.00 1947.00 3224.00 5.00 6018204.02 572556.40 MPE-12 T2. 6732.14 83.06 124.82 4453.70 4396.00 1942.31 3230.74 0.00 6018199.39 572563.19 TSBD-Top OA -- 6743.87 83.06 124.82 4455.12 4397.42 1935.66 3240.30 0.00 6018192.84 572572.80 Start Dir 6/100 6800.00 86.39 124.35 4460.28 4402.58 1903.94 3286.31 6.00 6018161.55 572619.10 MWD+IFR+MS 6840.40 88.79 124.01 4461.98 4404.28 1881.26 3319.70 6.00 6018139.18 572652.70 End Dir : 6840 6900.00 88.79 124.01 4463.23 4405.53 1847.93 3369.09 0.00 6018106.32 572702.39 MWD+IFR+MS 7000.00 88.79 124.01 4465.34 4407.64 1792.01 3451.96 0.00 6018051.17 572785.78 MWD+IFR+MS 7100.00 88.79 124.01 4467.45 4409.75 1736.09 3534.84 0.00 6017996.03 572869.16 MWD+IFR+MS 7200.00 88.79 124.01 4469.56 4411.86 1680.16 3617.71 0.00 6017940.88 572952.54 MWD+IFR+MS 7300.00 88.79 124.01 4471.67 4413.97 1624.24 3700.58 0.00 6017885.74 573035.92 MWD+IFR+MS 7400.00 88.79 124.01 4473.78 4416.08 1568.31 3783.46 0.00 6017830.59 573119.31 MWD+IFR+MS 7500.00 88.79 124.01 4475.88 4418.18 1512.39 3866.33 0.00 6017775.45 573202.69 MWD+IFR+MS 7600.00 88.79 124.01 4477.99 4420.29 1456.47 3949.20 0.00 6017720.30 573286.07 MWD+IFR+MS . Sperry-Sun . BP Planning Report Company: BP Amoco Date: 3/29/2005 Time: 16:29:11 Page: 5 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPE-12, True North Site: MPtEPad Vertical (TVD) Reference: 23.4 + 34.3 57.7 Well: Plan MPE-12 Section (VS) Reference: Well (0.00N,O.OOE,78.53Azi) Wellpath: MPE-12 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft deg/10Oft ft ft 7616.87 88.79 124.01 4478.35 4420.65 1447.03 3963.18 0.00 6017711.00 573300.14 Start Dir 4/100 7700.00 88.87 120.69 4480.05 4422.35 1402.57 4033.39 4.00 6017667.19 573370.75 MWD+IFR+MS 7800.00 88.96 116.69 4481.95 4424.25 1354.58 4121.08 4.00 6017620.03 573458.87 MWD+IFR+MS 7842.19 89.00 115.00 4482.70 4425.00 1336.20 4159.04 4.00 6017602.00 573497.00 MPE-12 T3. 7900.00 89.29 112.71 4483.56 4425.86 1312.82 4211.91 4.00 6017579.12 573550.08 MWD+IFR+MS 8000.00 89.79 108.74 4484.37 4426.67 1277.45 4305.42 4.00 6017544.62 573643.90 MWD+IFR+MS 8100.00 90.29 104.77 4484.29 4426.59 1248.63 4401.15 4.00 6017516.70 573739.89 MWD+IFR+MS 8133.12 90.46 103.44 4484.07 4426.37 1240.58 4433.28 4.03 6017508.95 573772.09 End Dir : 8133 8200.00 90.46 103.44 4483.53 4425.83 1225.03 4498.32 0.00 6017494.01 573837.27 MWD+IFR+MS 8300.00 90.46 103.44 4482.72 4425.02 1201.78 4595.58 0.00 6017471.67 573934.73 MWD+IFR+MS 8311.49 90.46 103.44 4482.63 4424.93 1199.11 4606.76 0.00 6017469.10 573945.93 Start Dir 4/1 00 8400.00 90.06 99.93 4482.23 4424.53 1181.19 4693.42 4.00 6017451.99 574032.74 MWD+IFR+MS 8500.00 89.61 95.95 4482.51 4424.81 1167.38 4792.44 4.00 6017439.11 574131.88 MWD+IFR+MS 8524.21 89.50 95.00 4482.70 4425.00 1165.05 4816.54 3.96 6017437.00 574156.00 MPE-12 T4. 8600.00 89.62 91.97 4483.28 4425.58 1160.45 4892.17 4.00 6017433.10 574231.67 MWD+IFR+MS 8644.09 89.69 90.21 4483.55 4425.85 1159.61 4936.25 4.00 6017432.67 574275.74 End Dir : 8644 8700.00 89.69 90.21 4483.85 4426.15 1159.40 4992.16 0.00 6017432.99 574331.65 MWD+IFR+MS 8800.00 89.69 90.21 4484.40 4426.70 1159.04 5092.16 0.00 6017433.56 574431.64 MWD+IFR+MS 8900.00 89.69 90.21 4484.94 4427.24 1158.68 5192.16 0.00 6017434.12 574531.63 MWD+IFR+MS 9000.00 89.69 90.21 4485.48 4427.78 1158.31 5292.15 0.00 6017434.69 574631.61 MWD+IFR+MS 9100.00 89.69 90.21 4486.02 4428.32 1157.95 5392.15 0.00 6017435.25 574731.60 MWD+IFR+MS 9200.00 89.69 90.21 4486.57 4428.87 1157.58 5492.15 0.00 6017435.82 574831.59 MWD+IFR+MS 9300.00 89.69 90.21 4487.11 4429.41 1157.22 5592.15 0.00 6017436.39 574931.58 MWD+IFR+MS 9400.00 89.69 90.21 4487.65 4429.95 1156.85 5692.15 0.00 6017436.95 575031.56 MWD+IFR+MS 9408.00 89.69 90.21 4487.70 4430.00 1156.83 5700.15 0.00 6017437.00 575039.56 41/2" , 9408.44 89.69 90.21 4487.70 / 4430.00 1156.82 5700.58 0.00 6017437.00 575040.00 MPE-12 T5. RECEIVED APR 2 2 2005 A\aska Oil & Gas Cons. Commission Anchorage L ¡ WELL DETAJLS ANTI-COLLISION SETTINGS COJ\!PANY DETAtLS Name Ei·W Northing Easùng Latitude Lmgitude S!m Pkm ¡\.WE,ll 2429.5Ú -67.l} (j0!6227.2X :;69.350,97 70Ql7'16.i07N J49"26'02.626W NiA BP Amm,;ü Interpolation Metbod:r.\1D Depth Range From: 3430 Maximum R,mge: ! 13 7 AI Interval: 25.00 To: 9408.44 Reterence: Plan: MPE·12 wp08 -80 -75 o ""'""'63 From 34 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 011000 11500 12000 12500 000 -38 -13 o ~13 -25 Sò: 3 4 5 " J X q 10 II 12 t3 14 15 16 17 IS 19 20 21 n Colour MD Ju<: SURVEY PROGRAM Depth Fm Depth Tü Survey/Plan ToMD 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 11000 11500 12000 12500 13000 13500 14000 14500 34.30 1l00,DO 1200.00 940K44 Azi Tool CB"GYRO-SS MWIYIFR-'-MS WELLPATH DETA!LS MPE I'~ Rig Rd:D1Ilum 34,,) 57_70n G.no 0.00 _3430 LEGEND SECTION DFTAJLS Tvn 'E!-\V DL~'g rf'¡¡œ VS<:(; Targd MPE-12TI I\-1PE-[21'2 !\tPE-12T3 MPE-!lT;: 1\.1PE-!2T5 Re: Permit Application for MPE-12 e e Subject: Re: Permit Application for MPE-12 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 12 May 2005 09:47:48 -0800 :'\ ,('\t To: "Johnson, David A. (Fairweather)" <john23@BP.com> C7'U J -"0 (g ì Dave, I got the information you sent regarding the changes on MPE-12. I will place them in the file. Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, We will send you all the necessary data. Apparently they tried a radical slim hole program referred to as RSD(?) where they they were starting out with 7-7/8" hole. The 13-3/8" conductors were set because the annular velocities inside the existing 20' conductors was to low for the small hole circulating rates. They cleaned out the 20" conductor to 40' below the conductor shoe and ran and cemented 13-3/8" casing. It is my understanding that the program was later abandoned and this was one of the "slimmed down" conductors left over. Dave From: Thomas Maunder (mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, May 10, 2005 3:11 PM To: Johnson, David A. (Fairweather) Subject: Re: Permit Application for MPE-12 Dave, I show in our record that the permit is likely ready to head out the door if it already hasn't. Why don't you send me a letter with the changed information attached. This would include the hole and casing size changes and what cement changes there will be as well. Changing the hole size and casings as you propose "shouldn't be a big thing". Glad you/they found this out now. Any information why the 13/3/8" is set inside the 20"?? There could be a nasty surprise waiting for you. Please let me know what you find out. Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, The permit application for MPE-12 was based on a 20" conductor and setting 10-3/4" surface casing in 13-1/2 hole, 7-5/8" intermediate casing in 9-7/8" hole and a 4-1/2" cemented liner in 6-3/4" hole.. Inspection of the landing ring and conductor by the field team revealed that this slot has a 13-3/8" conductor cemented inside the original 20" conductor. After reviewing the program we have elected to utilize the existing conductor and modify the wellbore design as follow for the same casing setting depths: 12-1/4" surface hole - 9-518" surface casing 8-1/2" intermediate hole - 7" intermediate casing 6-1/8" production hole - 4-1/2" liner. Would you like us to submit all the necessary modifications and design information as a change notice or re-submit the form 10-401. To my knowledge the original 1 0-401 has not been approved. Thank you. 10f2 5/12/2005 9:48 AM bp e e MPE 12 Tubular Program dOS--Qb ~ BP Exploration Alaska Inc. To: Tom Maunder- AOGCC Date: May 11th, 2005 From: David Johnson Milne Point ODE RECEI MAY J J 2005 Alaska Oil & Ar!í:twrage Subject: Well Bore Program Change Milne Point Well MPE-12 Inspection of the landing ring and conductor by the field team revealed that the slot for MPE-12 has a 13-3/8" conductor inside the original 20" conductor. This slot was originally prepared for a radical slim hole design. The 20" conductor was cleaned out 40' below the conductor shoe and a 13-3/8" conductor was run and cemented inside it. After reviewing the program for MPE-12, we have elected to utilize a slim hole program of 9-5/8" surface casing, 7" intermediate and 4-1/2" liner. Attached are the Hole size, casing size and cement volume changes. All other aspects of the MPE-12 program remain unchanged. l?::::?4~~ Milne Point ODE 564-4171 work e e MPE 12 Tubular Program EIVED MAY I 1 2005 Casingrrubing Program CommissirHi Hole Casing WtlFt Grade Conn Burst Collapse Top Top Botto.wL~18tICJom Length Size Size MD TVD TMD TVD 42 20 92 H-40 Weld 1530 520 0 0 112 112 112 18 13-3/8 72 K-55 BTC-M 3700 2230 0 0 162 162 162 12.25 9-5/8 40.0 L-80 BTC 5750 3090 0 0 3255 2658 3255 8.5 7.0 26 L-80 BTC-M 7240 6600 0 0 6724 4453 6724 6.125 4-1/2 12.6 L-80 IBT-M 8430 7500 6574 4425 9408 4488 2834 3-1/2 9.2 L-80 IBT-M 10160 10540 0 0 6574 4425 6574 Cement Program: 9-5/8",40#, L-80, BTC Surface Casing Tail cement = 1000' MD above shoe. 40% Excess over Gauge Hole Lead to surface. 40% Excess over Gauge Hole to PF, 150% Excess over Gauge Hole from PF to Surface 5 bbl water 20 bbl CW 100 50 bbl of MudPush 293 bbl, 370 sx of ArcticSet Lite: 10.7 ppg and 4.44 fe/sx 84.2 bbl, 404 sx lOG" mixed at 15.8 Iblgal & 1.17 fe/sx 7", 26#, L-80, BTC-M Intermediate Casing Tail cement = 500' MD above the TUZC. 40% Excess over Gauge Hole 5-bbl water 10 bbl CW 100 35 bbl of MudPush 62 bbl, 297.5 sx lOG" mixed at 15.81b/gal & 1.17 ft;j/sx BHST =80°F from SOA 4-1/2", 12.6#, L-80, IBT-M Liner Tail cement = 200' MD above the TUZC. 40% Excess over Gauge Hole 5-bbl water 15 bbl CW 100 35 bbl of MudPush 72 bbl, 343 sx lOG" mixed at 15.8 Ib/gal & 1.17 ft;j/sx BHST =80°F from SOA Casing Size Basis Total Cement Volume: 463 bbl Wash Spacer Lead Tail Casing Size Basis Total Cement Volume: 35 bbl Wash Spacer Tail Temp Casing Size Basis Total Cement Volume: 35 bbl Wash Spacer Tail Temp Field: Milne Point Pad: E-Ped DIFII lWD MWD NONE Gyro DIRlGRlRES IFRlCASANDRA InSite Il~~S I NONE NONE BP EXPLORATION MPE-12 Horizonatl Scrader Bluff NB Producer FORM DEPTH MI) TVD Permafrost 112' 162' Base Permafrost 2,093' 1,938' Top of Tail Cement 2,255' DIRlGRlRES MRIUNeulDen IFRlCASANDRA InSite NONE OIRlGRlRES NONE NeulOen IFRlCASANDRA InSite Top of Tail Cement 4,860' TUZC 5,360' 3,868' Top of NA 6,212' 4,300' Top of NB 6,292' 4,331' Top of NC. 6,344' 4,350' Top of NO 6,372' 4,360' 5/11/2005 9,408' 4,488' ENG: D. Johnson RIG: Doyon 14 RKEI: 58' HOLE CASING Cement Slurry SllE SPECS INFO 13-318 ' Conductor Wellhead Inside FMC Big Bore 20" Conductor Surface CSQ .Cement SluITV 9-5/8" Lead Cement 100% Excess in PF 40lb/tt 293 Bbls, 370 SX 40% Excess L-80, BTC 10.7 ppg Below PF Int. Yield 5750 psi 4.44 tt3/sx Collaspse 3090 psi Drift - 8.679" Tail Cement 84 bbls, 404 sx 15.8 ppg 40% Excess 1 .17 !t3/sx Inter. CasinQ 7" 26.0 Ibsllt L-80, BTC-M Int. Yield 7240 psi Collaspse 6600 psi Drift-6.151" Cement Slurrv Tail 62 Bbis. 298 sx 15.8 ppg 1.17 ft3Isx Prod. Liner 4-1/2" 12.61bsllt L-80, 1ST-Mod Int. Yield 8430 psi Collaspse 7500 psi Drift· 3.833 Cement SluITV Tail 72 Bbls, 343 sx 15.8 ppg 1.17 ft3Isx MPE-12 Ultra Slim Well Plan Schematic.xls MPU E-12 Proposed 1-Wi nj Schrader "NC/ND" & "OAn 2050610 SFD TERRIE L HUBBLE BP EXPLORATIONAK ·INC "Mastercard Check" PO BOX. 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 195 PAV.. TO. T.. H...E...........l.A-... -A-......... .. ..... ··.·tr. CÄ1£.. . ... .. · ..ðr.l. /I"6Cc. °õ;;;,"1&wøÁ~Jr[J . First National Bank Alaska Anchorage, AK 99501 MEMO ('(\PS.Qj DATE ()Lf-AAGS I $ IOéJ.ðD . DOLLARS ~Þ?~~ .: ~ 25 2000bO':1:11:1 ~"''''b 2 2 7"' ~ 5 Sbu· 0 ~I:1S . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER /J?PtL E-(2 CHECK WHAT APPLIES Rev: 04/01/05 C\jody\transm ittal_ checklist WELL NAME PTD# 205--0107 ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" (If API number last two (2) digits are between 60-69) The permit is for a new wellbore segment of existing well _, Permit No, API No. Production should continue to be reported as a function of the original API number stated above. PILOT (PH) HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce/iniect is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. . " Field & Pool. MILNE POINT, SCHRADER BLFF OIL - 525140 1ik:6 PTD#: 2050670 Company E:f.)~IO(ìOrt IILLlP"'S AU£K.A It4C; .R~ ~ J\ (J'1c (' ~ ~itlal ClasslType Administration Appr Date SFD 5/3/2005 Engineering Appr Date ]ì~5 Geology Appr Date SFD 5/2/2005 Geologic Commissioner: bN Well Name: MILNE PT UNIT SB E-12 SER I PEND GeoArea 890 Well bore seg 0 Annular Disposal 0 Program SER Unit 11328 On/Off Shore On 1 Permittee attached. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . 2 .LeasenIJmberappropriate .............. .. Yes. .... .Additipomadetp.40Z:.Su.rface.IOGinADL25.518,welJpassesthroyghADLA743.7,topp(odjnte.l"IiaJin 3 .U.niqlJe weltn.ame.and oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . ADL 47.438, .&.l:Q in ADL 26431.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WeUJocated ina define.dpool . . . . . . . . . . . . . . . . Yes ..... MiJnepoint $chra.der. Blyff Oil F'ool (5251040), governed by GO 4Z7. . . . . . . . . . . . 5 WeJlJocaled prpper .distance from driJling unitb.oundBry. ...................... Yes CO A7Z specities.gpvernmentaJ Qtr-Qtr:Qtr section; proposed weJLconforms .to lhis requiJemeJlt.. . 6 WellJocated pr.oper .distance. from other welJs. . . . . . .. ........ Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7S.ufficient açreage.ayailable in.drilliog unit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . WelJ bore will be moœJhan.500 feeUo th.e.exterior boundary oUhe CO A7Z area.. . . . . . . . . . . . . . . . 8 Jf.deviated, js weJlbore platincJu.ded . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . .. ...... . . . . .' ...... 90.)erator Only affected party. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . .. ....... . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .O.)e(ator has.appropriate.b.ond inJorçe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Permit can be issued without co.nserva.tion order. . . . . . Yes. . . . . . . . . . . . . . . . .. ................................. . . . . . . . . 12 Permilcan be issued without administratille.apprpvaJ. . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Can permit be approved before 15-day wait Yes 14 WellJocaled within area and.strata .authorized byJojectioo Ord.er # (pIJtlO# incomm.eots) (For. Yes. . . Area Injectio.n.Qrder No. 10-B . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 AJI welJs. within J 14. mile.area.of reyiew ideotlfied (Fpr servjc.ewell only). . . . . . . . . . . . . . . Yes. . . . . . . MPU E:3.2, 1;-321...1, 1;-30, .E.-3.0A, an.d.E-08.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 PJe-produ.ced injector; .duration.of pre-.)roduction less than 3. months (for.service well onJy) . . No.. ..... DavidJ.ohnspo,.BP, 5/2/2005; well will.notbe.)re-prod.uçed. . . . . . . . . . . . . . . 17 ACMP.Fïndjng.of Consistency.h.as bee.nJssIJed forthis p(oiect . . . . . . . . . . . . . .NA . . . . . . . WelJ driJled from exjsiiog pa.d, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18C.oodu.ct.or string. provided . . . . . . . . . . . . . .' ...... . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .S.urfacecasing.protectsaILknownUSDWs. .. . . .. . NA .. . . .Allaquifersexempted.A.O CFR1.47.102 (b)l3.).. . . .. . . . . . . . .. . . ... . . . . 20 .CMTvoladequateto circ.utateon.cçmd.uçtor.& su.rf.csg . . . . . . . . . Yes. . . . . .. ...... . . . . . . . 21 .CMT vol. adequ.ateto tie-in Jong string to.SIJrf csg. . . . . . . . . . . . No.. ..... All hyd(ocarbon.zpoes.will b.e.cpvered. . . . . . . . . . . . . . . . . . . . 22 .CMTwillcoyeraJlkoowJlpro.dlJctiYehorizon.s.............................. Yes . Lioerptaonediobe.œmeoted.. ...... .................... 23 .C.asing designs ad.eQyaie for C,T" B.&. permafr.ost . . . . . . . .. ........ Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 AdequateJankage.or re.serve pit. . . . . . . . . . . . . . . . . . . . . . .. Yes . . . Rig is.eqIJippe.dwith steeLpjts. No rese.l"Iie.pjt.)lanoed, All waste to.apprOlle.d.dispos.al wells.. . . . . . . 25 Jtare-drill" has a 10:40;3 for abandonment beeo approved ..................... NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Adequatewellb.oreseparatio.n.pro.)osed...................... .......... Ye'L..... . I:'rOJ5imityanBlysis pertorme.d, JrayelingcylioderplotiocJu.ded..Gyros.possible...................... 27 Jf.diverter req.uired, does itmeet reguJatioos. . . . . . . . . . . . . . . . . . . . . . . No. . VariBoœ.requested to .shorten Jine due to imp(oyements. on pad. . F'ad. SQ mitigation plan inclyd.ed . 28 .Drilling fluid. program sGhematic.& eq.uipJistadequate . . . . . . . . . . . . . . . . . . . . . . . . Yes . Maximum ex.)ected formaiion pressIJœ.8,3.EMW.. PtannedMW up to.9,4 io SB. . . . . . . . . . . 29 .BOPEs,do.they meelreguJatioo . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 .BOPE.press raiiog appropriate; .testto(pu.t psig incommeots) . . . . . . . . . . . . . . . Yes . . . MASF' calcuJaie.d.at 1475 psi, 30QO.p.sLBOi=> testplanoed, . . . . . . . . . . . . . . . . . . . . . . . . 31CMke.manifold compJies w/APtRi=>-5HMay 84) . . . . .. ...... ....... . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Work will oCC.ur withoytoperatjonshutdown. ...... ...... ...... ...... Y.es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 Js.presenceofH2Sgas.prob.able ........ ............ .. No.. .... . 1:i2Sba.s.nolb.eeo œportedjnSB produ.ction.onE pad.. RigJseq.uipped.with.sensors.andalarms,.. 34 Mecha.nicaLcoodJtlon p{ wells within AOR verified (For.s.ervjc.e welJ onJy). . . . . . . . . Yes . . . . . MPE-30 production casing andMF'E-08 surfaGe.casiog isolated SB.. MF'I;-32 oot d(illed.. . . 35 Permit can be issuedw/ohyd(ogen sulfide measures. . ...... . yes...... .WalterQ.uay, BP,4J26/Q5-no.H2SmeasuredJnSBalMF'U E-Pad.. SFD.... ....... 36 .D.ata.preseoted on pote.ntial olle.rpressIJœzoneJ>. . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes . NormaLpressyre gradieote~peçted.HYdr.ates possibleJ(om.2.000'-.4500' JYDss. .Mu.d.)rogram plan.ned according 37Seismicanalysjs. of J>haJlow gas.zpoes. . . . . . . . . .. ...... ...... ...... . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38 .Seabed .conditioo survey (if off-shore) . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39 . Contact namelphoneJorweekly prpgressreports [e~ploratoryonly]. . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ - - - - ~ . - - - - - -- - - - - - -- - - - - - - - Engineering Date:. Commissioner: Date ?; I fð,(.s ~ S+05 Public Commissioner Date . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ~.ðS--tJb7 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 29 08:38:52 2005 ,"- tt \ ") 7-1 , Reel Header Service name....... ......LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/29 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. . . . . . . . . . . . . . . . . . . . .05/06/29 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-12 500292326200 BP Exploration Sperry Drilling Services 29-JUN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003719142 R. FRENCH D. GREEN MWD RUN 2 MW0003719142 R. FRENCH D. GREEN MWD RUN 3 MW0003719142 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 13N 10E 3688 1794 57.35 23.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.750 6.125 CASING SIZE (IN) 13.375 9.625 7.000 DRILLERS DEPTH (FT) 162.0 3245.0 6761. 0 # 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 RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 2 & 3 INCLUDED COMPENSATED THERMAL NEUTRON (CTN) AND STABILIZED LITHO-DENSITY (SLD). RUN 2 ALSO INCLUDED MAGNETIC RESONANCE IMAGING LITHOLOGY (MRIL) AND ACOUSTIC CALIPER (ACAL). RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CONVERSATION BETWEEN DENNIS URBAN (BP GEOSCIENTIST) AND BUSTER BRYANT (SDS) ON 4/13/05. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-3 REPRESENT WELL MPE-12 WITH API#: 50-029-23262-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9297'MD/4451'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 (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (ACAL-DERIVED/FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: BIT RUN 2: ACAL-DERIVED, 8.75" RUN 3: FIXED HOLE SIZE, 6.125" BIT MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: CHLORIDES FLUID DENSITY: MATRIX DENSITY: 9.2-9.4 PPG 450-500 PPM CHLORIDES 12,000-21,000 PPM 1. 0 G/CC 2.65 G/CC . LITHOLOGY: $ . SANDSTONE File Header Service name... ........ ..STSLIB.001 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation.. .... .05/06/29 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 FET RPX RPS RPM RPD ROP NPHI FCNT NCNT PEF DRHO RHOB $ 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 104.0 135.0 135.0 135.0 135.0 135.0 144.5 3169.0 3169.0 3169.0 3245.5 3245.5 3245.5 STOP DEPTH 9240.0 9247.5 9247.5 9247.5 9247.5 9247.5 9297.0 9204.0 9204.0 9204.0 9219.0 9219.0 9219.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 104.0 3255.0 6771 . 0 MERGE BASE 3255.0 6771 . 0 9297.0 # 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...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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 104 9297 4700.5 18387 104 9297 ROP MWD FT/H 1. 33 3427.7 151.156 18306 144.5 9297 GR MWD API 9.61 135.02 67.4604 18273 104 9240 RPX MWD OHMM 0.28 2000 11. 9938 18226 135 9247.5 RPS MWD OHMM 0.06 1346.4 13.0114 18226 135 9247.5 RPM MWD OHMM 0.06 2000 21.0654 18226 135 9247.5 RPD MWD OHMM 0.08 2000 24.9195 18226 135 9247.5 FET MWD HOUR 0.12 237005 19.1742 18226 135 9247.5 NPHI MWD PU-S 9.42 93.96 37.2937 12071 3169 9204 FCNT MWD CNTS 129.16 2628.25 572.256 12071 3169 9204 NCNT MWD CNTS 14647.7 167896 79148.1 12071 3169 9204 RHOB MWD G/CM 1. 158 2.976 2.18278 11822 3245.5 9219 DRHO MWD G/CM -0.311 0.633 0.0573042 11822 3245.5 9219 PEF MWD BARN 0.03 6.8 1. 96814 11822 3245.5 9219 First Reading For Entire File..........104 Last Reading For Entire File.......... .9297 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number:. . . . . . . . . .1. 0 . 0 Date of Generation...... .05/06/29 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.......05/06/29 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 2 header data for each bit run in separate files. 1 .5000 START DEPTH 104.0 STOP DEPTH 3214.0 . . RPX 135.0 3206.5 RPS 135.0 3206.5 RPM 135.0 3206.5 RPD 135.0 3206.5 FET 135.0 3206.5 ROP 144.5 3255.0 $ # 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. RES IS. 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 28-MAY-05 Insite 66.37 Memory 3255.0 143.0 3255.0 .0 58.2 TOOL NUMBER 175785 63122 12.250 .0 SPUD 9.80 100.0 8.0 500 10.4 2.600 2.140 2.800 3.500 65.0 80.3 65.0 65.0 . . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 104 3255 1679.5 6303 104 3255 ROP MWD010 FT/H 16.19 3427.7 201.246 6222 144.5 3255 GR MWD010 API 20.71 135.02 65.367 6221 104 3214 RPX MWD010 OHMM 0.28 2000 17.3962 6144 135 3206.5 RPS MWD010 OHMM 0.06 803.11 19.3277 6144 135 3206.5 RPM MWD010 OHMM 0.06 2000 22.3077 6144 135 3206.5 RPD MWD010 OHMM 0.08 2000 25.6344 6144 135 3206.5 FET MWD010 HOUR 0.12 237005 54.3192 6144 135 3206.5 First Reading For Entire File.. ....... .104 Last Reading For Entire File.......... .3255 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation...... .05/06/29 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...... .05/06/29 Maximum Physical Record..65535 File Type................ LO Previous File Name... ....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT RPM RPD FET RPS RPX 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3169.0 3169.0 3169.0 3207.0 3207.0 3207.0 3207.0 3207.0 STOP DEPTH 6683.0 6683.0 6683.0 6728.0 6728.0 6728.0 6728.0 672 8.0 . GR PEF DRHO RHOB ROP $ 3214.5 3245.5 3245.5 3245.5 3255.5 6736.0 6697.0 6697.0 6697.0 6771 . 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 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # 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 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 . 01-JUN-05 Insite 66.37 Memory 6771.0 3255.0 6771.0 53.1 79.8 TOOL NUMBER 132477 66259 126970 201229 8.750 3245.0 LSND 9.10 60.0 8.0 500 8.0 3.200 2.230 3.500 3.400 68.0 100.4 68.0 68.0 . . 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 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3169 6771 4970 7205 3169 6771 ROP MWD020 FT/H 1. 66 842.93 123.51 7032 3255.5 6771 GR MWD020 API 9.61 129.93 69.6866 7044 3214.5 6736 RPX MWD020 OHMM 1.31 818.41 8.40466 7043 3207 6728 RPS MWD020 OHMM 0.4 818.69 8.52724 7043 3207 6728 RPM MWD020 OHMM 0.48 2000 12.9934 7043 3207 6728 RPD MWD020 OHMM 0.2 2000 23.9728 7043 3207 6728 FET MWD020 HOUR 0.25 41. 73 1. 19357 7043 3207 6728 NPHI MWD020 PU-S 9.42 93.96 38.1341 7029 3169 6683 FCNT MWD020 CNTS 423.29 2628.25 776.45 7029 3169 6683 NCNT MWD020 CNTS 99929.3 167896 120603 7029 3169 6683 RHOB MWD020 G/CM 1.158 2.961 2.1656 6904 3245.5 6697 DRHO MWD020 G/CM -0.311 0.601 0.0619784 6904 3245.5 6697 PEF MWD020 BARN 0.03 6.8 1.56655 6904 3245.5 6697 First Reading For Entire File......... .3169 Last Reading For Entire File.......... .6771 File Trailer Service name....... ..... .STSLIB.003 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation.......05/06/29 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...... .05/06/29 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. . BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI RPX RPS RPM RPD FET GR PEF RHOB DRHO ROP $ 3 .5000 START DEPTH 6680.0 6683.5 6683.5 6728.5 6728.5 6728.5 6728.5 6728.5 6736.5 6760.5 6760.5 6760.5 6771. 5 # 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: # STOP DEPTH 9204.0 9204.0 9204.0 9247.5 9247.5 9247.5 9247.5 9247.5 9240.0 9219.0 9219.0 9219.0 9297.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON 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: . 04-JUN-05 Insite 66.37 Memory 9297.0 6771 . 0 9297.0 80.8 97.7 TOOL NUMBER 156436 112439 110041 90518 6.125 6761. 0 LSND 9.00 67.0 8.0 200 7.0 4.400 3.220 5.000 3.000 70.0 98.1 70.0 70.0 . . $ # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..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 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6680 9297 7988.5 5235 6680 9297 ROP MWD030 FT/H 1. 33 321.31 127.945 5052 6771.5 9297 GR MWD030 API 29.64 114.23 66.9295 5008 6736.5 9240 RPX MWD030 OHMM 0.48 32.82 10.4231 5039 6728.5 9247.5 RPS MWD030 OHMM 2.51 1346.4 11. 5776 5039 6728.5 9247.5 RPM MWD030 OHMM 0.06 2000 30.8327 5039 6728.5 9247.5 RPD MWD030 OHMM 1. 92 2000 25.3709 5039 6728.5 9247.5 FET MWD030 HOUR 0.31 46.29 1. 45365 5039 6728.5 9247.5 NPHI MWD030 PU-S 12.73 47.09 36.1222 5042 6683.5 9204 FCNT MWD030 CNTS 129.16 1466.83 287.574 5043 6680 9204 NCNT MWD030 CNTS 14647.7 40486.9 21356.6 5042 6683.5 9204 RHOB MWD030 G/CM 1. 726 2.976 2.2069 4918 6760.5 9219 DRHO MWD030 G/CM -0.116 0.633 0.0507424 4918 6760.5 9219 PEF MWD030 BARN 1. 69 6.04 2.53191 4918 6760.5 9219 First Reading For Entire File......... .6680 Last Reading For Entire File.......... .9297 File Trailer Service name.. .......... .STSLIB.004 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation...... .05/06/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name...... .....STSLIB.005 Physical EOF Tape Trailer . . Service name........ .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/06/29 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. . . . . . . . . . . . . . . . . . . . .05/06/29 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