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Home My WebLink About204-020New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Run New Completion 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 8,421 feet N/A feet true vertical 4,184 feet 8,401 feet Effective Depth measured 8,421 feet 4,907 & 5,039 feet true vertical 4,184 feet 3,886 & 3,967 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.3 / L-80 / EUE 5,000' 3,943' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / TC-II 5,204' 4,065' D&L Ret. Hyd Iso Packers and SSSV (type, measured and true vertical depth)TNT Perm. 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 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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 and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: Oil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 279 Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Burst Collapse 8,430psi 7,500psi 324-101 Water-Bbl N/A OA Liner 3,191' 4-1/2" Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 297 Gas-Mcf MD 2,268 Size 112' 752 2,424226 296 261569 233 measured TVD 7-5/8" 4-1/2" Plugs Junk measured 4,226' 4,184' 5,560' 8,421' 112' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-020 50-029-23194-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025906 MILNE POINT UNIT / SCHRADER BLUFF OIL MILNE PT UNIT G-18 Length OB Liner 5,527' 3,013' Casing 3,191' Conductor Surface Production 20" 10-3/4" 78' 4,790psi 7,500psi N/A 5,210psi 6,890psi 8,430psi 3,226' 2,390' N/A 2,470psi 8,536' 4,176' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:19 am, May 07, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.05.07 09:34:26 - 08'00' Taylor Wellman (2143) RBDMS JSB 051524 WCB 2-12-2025 DSR-5/7/24 _____________________________________________________________________________________ Revised By: TDF 5/6/2024 SCHEMATIC Milne Point Unit Well: MPU G-18 Last Completed: 3/23/2024 PTD: 204-020 15 16 TD =8,421’ (MD) / TD = 4,184’(TVD) 20” Orig. KB Elev.: 63.7’/ Orig. GL Elev.: 29.5’ RKB – Hanger: 22.10’ (Doyon 16) 7-5/8” 8 10 11 10-3/4” 1213 14 “OA” Lateral PBTD =8,421’(MD) / TD = 4,184’(TVD) “OB” Lateral 5 2 6 3 7 9 1 4 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 3,226’ 7-5/8" Production 29.7 / L-80 / BTC-Mod 6.875 Surface 5,560' 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.958 5,273’ 8,536’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.958 5,338’ 8,421’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.992 Surface 5,000’ 4-1/2” Tubing 12.6 / L-80 / TC-II 3.958 5,000’ 5,204’ SLOTTED LINER DETAIL 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.958 5,380’ 8,490’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.958 5,531’ 8,377’ JEWELRY DETAIL No Depth Item 1 4,804’ 3-1/2” Viking Sliding Sleeve - Down to open : 2.813 Min ID 2 4,856’ Centralift Gauge Carrier - Zenith Gauge Installed 3 4,907’ 7-5/8” x 3-1/2” D&L RET. HYD. ISO Packer 4 4,966’ 3-1/2” X Nipple w/ RHC-M Installed: 2.813 Min ID 5 4,988’ 3-1/2” x 4-1/2” Non-Sealing Overshot:Bottom @ 5,000’ 6 5,039’ 7-5/8”” x 4-1/2” TNT Permanent Hydraulic Set Packer (3.856” ID) 7 5,079’ 4-1/2” X Profile (3.813” Packing Bore) 8 5,150’ 4-1/2” XN Profile (3.813” Packing Bore;3.725” No-Go Min ID) 9 5,203’ Wireline Entry Guide (Btm at 5,204’) 10 5,273’ Baker Hook Wall, Hanger above 7-5/8” Window 11 5,290’ Baker Hook Wall, Hanger below 7-5/8” Window 12 5,338’ Baker Tie Back Sleeve 13 5,345’ Baker ZXP Liner Top Packer 14 5,351’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 15 8,536’ Btm Baker 4-1/2” Guide Shoe (OA Lateral) 16 8,421’ Btm Baker 4-1/2” Guide Shoe (OB Lateral) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 460 sx PF ‘L’, 260 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 420 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 460’ MD Max Wellbore Angle = 63.0 deg @ 2,200’ MD WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23194-00-00 Drilled and Completed by Doyon 14 – 4/03/2004 ESP Repair by Nabors 3S – 5/19/2006 ESP Repair by Nabors 3S – 6/09/2008 ESP Repair by Nabors 4ES – 8/31/2008 Convert to Jet Pump by Doyon 16 – 3/16/2013 Recomplete with Sliding Sleeve by ASR – 3/23/2024 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,278’ MD; Bottom @ 5,290’ MD; Angle @ top of window is 54 deg Top of “OB” Window @ 5,418’MD; Bottom @ 5,430’ MD; Angle @ top of window is 62 deg Fish: Milled CIBP @ 8,401’ CTM 3/16/14 Well Name Rig API Number Well Permit Number Start Date End Date MP G-18 ASR#1 50-029-23194-00-00 204-020 3/18/2024 3/23/2024 BOPE testing complete. Pull CTS valve. Installed the T-bar and engage the poppit on the BPV observing gas only breaking out under the BPV. Allowed gas to bleed until dead. Attempt to fill the hole and after 15 BBLS, could not see fluid in the tubing. The IA began to blow again but died off quickly when the pump to the tubing was shut down. BPV was removed. Pull tubing haner to rig floor with 69K coming off seat, and a steady pull of 62K. Pump 25 BBLS down the IA, no returns. Breakout and lay down the hanger and pup. Secure the TEC Wire as per Centilift rep. POOH while maintaining 2x displacement. Cut Joint is clean. Recovered 119ea CC Clamps, 4ea Mid Joint. Empty Pipe Shed. Clean and clear Floor. RD Control Line equipment. Blow down all fluid lines and pump. Spot in Slickline unit. RD Birdbath, Riser, And Spool. No operations to report. 3/16/2024 - Saturday MIRU. Begin testing BOPE 250/2000psi. Rig accepted at 18:00. 3/19/2024 - Tuesday 3/17/2024 - Sunday No operations to report. 3/18/2024 - Monday 3/15/2024 - Friday No operations to report. 3/13/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/14/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP G-18 ASR#1 & SL 50-029-23194-00-00 204-020 3/18/2024 3/23/2024 3/22/2024 - Friday WELLHEAD: BOP stack removed, clean hgr void, new RX54, SBMS seal and run tech wire through adapter.Land tree/adapter and torque to spec.Test hgr void to 500/5000 (PASS), pull Bpv with T bar. All valves in closed position. WELL S/I ON ARRIVAL. RAN 3-1/2" 42BO. 3/20/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary SEND PCE UP BEAVER SLIDE, BEGIN R/U .125 CARBON, 5' X 2.625" RLR (3.50" wheels), QC, KJ, SSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 500H. RAN READ 40 ARM CALIPER, TAG STUMP @ 5025' SLM, LOG FROM 5020' SLM TO 0' SLM, (good data). Adjust Packer setting depth due to CSG damage caused by erosion through pervious SSD. PU Overshot, X-Nipple w/ RHC-M, 1 JT, D&L Retrievable Packer, 1 JT, Gauge Carrier, 1 Jt, SSD. RIH w/ 3-1/2",9.3#,L,EUE R2 completion while maintaining 2x displacement T/ 690' PUW = 8k, SOW = 7k. 3/21/2024 - Thursday Continue RIH w/ 3-1/2",9.3#,L,EUE R2 completion while maintaining 2x displacement F/690' T/ 5,000.09' MD. Space out. P/U M/U landing joint. Terminate TEC wire to hanger. Land hanger P/U 46K SOW 28K. Observed loss of 3K while swallowing stump. landed with 25K on hanger bowl. Pump 30bbls Corrosion Inhibited Source water down IA followed by 10bbls down TBG. Install landing joint and drop B&R (1-3/8" FN, 7' OAL). Freeze Protect TBG & IA. Set and test PKR. MIT-IA to 3000psi - Good. Install BPV. RDMO. No operations to report. Work continues from previous day. SHIFT SLD SLV OPEN @ 4807' MD. PULL BALL & ROD, RHC BODY FROM X -NIP @ 4966' MD. SET 2.81 X-LOCK, JET PUMP W/ SCREEN (11 C RATIO 87" lih) @4807' MD. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. MPU Well Support received well post-RWO and after Slickline Operations were completed. They tied well in and PT'd surface lines,then serviced wellhead. Handed well over to I&E Group for FCO. No issues. 3/23/2024 - Saturday No operations to report. 3/26/2024 - Tuesday 3/24/2024 - Sunday No operations to report. 3/25/2024 - Monday Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240412 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey MPU G-18 50029231940000 204020 3/21/2024 READ CaliperSurvey MPU L-07 50029220280000 190037 3/30/2024 READ CaliperSurvey PBU 01-19C 50029208000300 213171 2/22/2024 BAKER MRPM PBU 01-28B 50029215970200 223089 1/21/2024 BAKER MRPM PBU 11-42 50029237750000 223117 3/5/2024 HALLIBURTON RBT PBU N-11D 50029213750300 223083 2/14/2024 BAKER MRPM PBU N-21A 50029213420100 196196 3/28/2024 BAKER SPN PBU S-201A 50029229870100 219092 4/8/2024 READ LeakPointSurvey Please include current contact information if different from above T38705 T38706 T38707 T38708 T38709 T38710 T38711 T38712 T38713 MPU G-18 50029231940000 204020 3/21/2024 READ CaliperSurvey Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.16 11:46:27 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/4/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240404 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/23/2024 YELLOW JACKET GPT-PERF BRU 241-23 50283201910000 223061 11/25/2023 AK E-LINE Perf HV B-13 50231200320000 207151 3/11/2024 YELLOW JACKET GPT KALOTSA 6 50133206850000 219114 3/2/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 3/13/2024 YELLOW JACKET GPT-PERF KU 21-06RD 50133100900100 201097 3/19/2024 YELLOW JACKET GPT-PERF END MPI 2-62 50029216480000 186158 2/14/2024 YELLOW JACKET PERF MPU G-18 50029231940000 204020 3/21/2024 READ Caliper Survey MPU G-18 50029231940000 204020 3/9/2024 AK E-LINE HoistCutter MPU I-24 50029237780000 224001 3/11/2024 AK E-LINE CBL NCIU A-18 50883201890000 223033 12/20/2023 AK E-LINE Perf NCIU A-18 50883201890000 223033 12/18/2024 AK E-LINE GPT/Plug/Perf PAXTON 3 50133205880000 209168 3/6/2024 YELLOW JACKET GPT PAXTON 3 50133205880000 209168 3/8/2024 YELLOW JACKET PERF PAXTON 3 50133205880000 209168 3/12/2024 AK E-LINE PPROF PAXTON 7 50133206430000 214130 2/26/2024 YELLOW JACKET PERF PBU 09-52 50029236180000 218168 3/24/2024 HALLIBURTON PPROF SD-06 50133205820000 208160 2/20/2024 YELLOW JACKET PERF SRU 222-33 50133207150000 223100 12/19/2023 AK E-LINE Perf Please include current contact information if different from above T38683 T38684 T38685 T38686 T38689 T38687 T38690 T38691 T38691T38692 T38963 T38963 T38694 T38694 T38694 T38695 T38696 T38697 T38698 MPU G-18 50029231940000 204020 3/21/2024 READ Caliper Survey MPU G-18 50029231940000 204020 3/9/2024 AK E-LINE HoistCutter Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 13:48:29 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Michael Heinz-Brown - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:Hilcorp MPG-18 BOPE Test - Initial Date:Tuesday, March 19, 2024 6:48:04 PM Attachments:MPG-18 BOPE (initial) 3-18-24.xlsx MPG-18 BOPE (initial) 3-18-24.pdf Some people who received this message don't often get email from michael.heinzbrown@hilcorp.com. Learn why this is important Please see attached. Thank you, Mike Heinz-Brown | Milne Point | DSM | Hilcorp Alaska Rig Office: 907-685-1266 | Cell: 480-296-5214 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW* 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 3/18/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2040200 Sundry #324-101 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/2000 Annular:250/2000 Valves:250/2000 MASP:709 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11 P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5"P Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 1 2-1/16"P System Pressure (psi)3000 P Kill Line Valves 3 2-1/16"P Pressure After Closure (psi)1900 P Check Valve 0NA200 psi Attained (sec)17 P BOP Misc 0NAFull Pressure Attained (sec)53 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2275psi P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 16 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 2 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/16/2024 05:28 Waived By Test Start Date/Time:3/18/2024 22:30 (date) (time)Witness Test Finish Date/Time:3/19/2024 5:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Tested w/ 3-1/2", 4-1/2" Test Mandrels Bottle Pre-Charge = 1017psi C. Pace / M. Boord Hilcorp Alaska, LLC S. Heim / M. Heinz-Brown MPU G-18 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0318_BOP_Hilcorp_ASR1_MPU_G-18 9 9 9 9 9999 9 9 9 -5HJJ 99 %23(7HVW+LOFRUS$65 038*37' %23(7HVW+LOFRUS$65 038*37' %23(7HVW+LOFRUS$65 038*37' %23(7HVW+LOFRUS$65 038*37' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER Run New Completion Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-020 50-029-23194-00-00 CO 477.05 ADL 0025906 8421 Conductor Surface Intermediate Production Liner 4184 78 3191 5527 3083 8421 20" x 30" 10-3/4" 7-5/8" 4-1/2" 4184 34 - 112 35 - 3266 33 - 5560 5299 - 8421 709 34 - 112 35 - 2390 33 - 4227 4142 - 4184 8401 2480 4790 7500 None 5210 6890 8430 5531 - 8377 4-1/2" 12.6# L-80 32 - 52044222 - 4187 Structural 4-1/2" HES TNT , 5-1/2" Baker ZXP No SSSV Installed 5039 MD , 5345 TVD 3903 MD , 4083 TVD Date: Taylor Wellman Wells Manager Todd Sidoti Todd.Sidoti@hilcorp.com (907) 777-8443 MILNE POINT UNIT 3/15/2024 Current Pools: SCHRADER BLUFF OIL Proposed Pools: SAME Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov MILNE PT UNIT G-18 By Grace Christianson at 1:03 pm, Feb 20, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.20 11:55:51 - 09'00' Taylor Wellman (2143) 324-102 SFD 2/23/2024 BOPE test to 2000 psi. MGR23FEB24 10-404 324-101 SFD 709 DSR-2/21/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.02.26 11:37:07 -09'00'2/26/24 RBDMS JSB 022724 RWO – Tubing Swap Well: MPU G-18 Date: 15 Feb 2024 Well Name: MPU G-18 API Number: 50-029-23194-00-00 Current Status: SI Producer [Tbg Leaks] Pad: G-Pad Estimated Start Date: March 15, 2024 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-020 First Call Engineer: Brian Glasheen (907) 564-5277 (O)(907) 545-1144 (M) Second Call Engineer: Todd Sidoti (907) 777-8443 (O)(907) 632-4223 (M) Current Bottom Hole Pressure: 1100 psi @ 3910’ TVD Extrapolated from gauge data | 5.4 PPGE MPSP: 709 psi Gas Column Gradient (0.1 psi/ft) Max Inclination Horizontal Well Max Dogleg: 16.2°/100ft @ 5,435’ MD Brief Well Summary: MPU G-18 was drilled in February 2004 as a dual lateral Oa and Ob producer. TXIA communication was verified in February 2024. A caliper was ran to assess the tubing condition and it was found to be poor with severe pitting. Notes Regarding Wellbore Condition x Combo MIT-IA Passed to 2,850 psig on 2/7/2024. Objective: Pull 4-1/2” upper completion, install a 3-1/2” completion and return well to production. Pre-Rig Procedure (No sundry required): Eline & Fullbore 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU reverse out skid and 500 bbl returns tank. 4. MIRU eline and fullbore, pressure test PCE to 250 psi low / 2000 psi high. 5. RIH with mechanical tubing cutter. 6. Cut tubing in middle of first full joint above packer ~5,000’. POOH and RDMO eline. 7. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 8. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 9. RD fullbore pumpers and reverse out skid. 10. RU crane. Set BPV. ND tree and tubing head adapter. NU BOPE. 11. NU BOPE house. Spot mud boat. Brief RWO Procedure: RWO – Tubing Swap Well: MPU G-18 Date: 15 Feb 2024 12. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines. 13. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to setting CTS. 14. Test BOPE to 250 psi Low/ 2,000 psi High, annular to 250 psi Low/ 2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 16. MU landing joint or spear, PU and recover tubing hanger. a. Note that PU and SO weights were not recorded on the previous tally. 17. POOH and lay down the 4-1/2” tubing. 18. PU new 3-1/2” completion and run: A 3-1/2” x 4-1/2” Overshot with Dual Pins Pup Joint, 3-1/2" B Pup Joint, 3-1/2” 3-1/2” XN Nipple with RHC Installed Pup Joint, 3-1/2” C Pup Joint, 3-1/2" 7-5/8” x 3-1/2” Packer @ ~4,930’ Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" D Pup Joint, 3-1/2" Gauge Carrier, Baker, Zenith Gauge Installed Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" E Pup Joint, 3-1/2" Sliding Sleeve, 2.813" X profile, covered ports for I-wire bypass (closed) Pup Joint, 3-1/2" ~370 Joints Tubing, 3-1/2" 19. Shear out on 4.5” tubing stub at ~5,000’. Space out and land tubing hanger. Note pickup and slack- off weights on tally. 20. Pump 100 bbls inhibited source water followed by 80 bbls FP down 3-1/2” x 7-5/8” IA. 21. Pump 30 bbls FP down tubing. If any risk of trapped pressure below BPV, RU lubricator to pull valve. - mgr RWO – Tubing Swap Well: MPU G-18 Date: 15 Feb 2024 22. Drop ball & rod and pressure up on tubing to set packer as per manufacturer procedures. Perform MIT-IA to 3000 psi (charted). 23. Set BPV. Post-Rig Procedure: Slickline & Well Support 24. MIRU SL and PT lubricator to 250 psi low / 2000 psi high. 25. Pull Ball & Rod and RHC plug from XN @ ~4970’. RDMO SL. 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPE. 28. NU 3-1/8” 5M tree. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: NLW 03/17/2021 SCHEMATIC Milne Point Unit Well: MPU G-18 Last Completed: 3/16/2013 PTD: 204-020 15 16 TD =8,421’(MD) / TD = 4,184’(TVD) 20” Orig. KB Elev.: 63.7’/ Orig. GL Elev.: 29.5’ RKB – Hanger: 22.10’ (Doyon 16) 7-5/8” 10 11 10-3/4” 2 1213 14 “OA” Lateral PBTD =8,421’ (MD) / TD = 4,184’(TVD) “OB” Lateral 6 4 7 5 8 9 Min ID = 3.725” ID Min ID = 2.813” ID 3 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surf 112' 10-3/4” Surface 45.5 / L-80 / BTC 9.794 Surf 3,226’ 7-5/8" Production 29.7 / L-80 / BTC-Mod 6.750 Surface 5,560' 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.833 5,273’ 8,536’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.833 5,338’ 8,421’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TC-II 3.833 Surf 5,204’ LINER DETAIL 4-1/2” OA Solid Liner 12.6 / L-80 / IBT 3.833 5,299’ 5,380’ 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.833 5,380’ 8,490’ 4-1/2” OB Solid Liner 12.6 / L-80 / IBT 3.833 5,364’ 5,531’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.833 5,531’ 8,377’ JEWELRY DETAIL No Depth Item 1 22’ 4-1/2” Blast Rings below tubing hanger 2 2,510’ Sta #1: GLM – Camco KBG-2 4-1/2” x 1” –DCK-2 Shear set 3/16/2013 3 4,950’ 4-1/2” NDPG-C Multi-drop Discharge Gauge (3.864” ID) 44,962’4-1/2” XD Sliding Sleeve (3.813”)***Set 13C JP on 03/17/21*** 5 4,972’ 4-1/2” NDPG-C Single-drop Intake Gauge (3.864” ID) 6 5,039’ 7-5/8”” x 4-1/2” TNT Permanent Hydraulic Set Packer (3.856” ID) 7 5,079’ 4-1/2” X Profile (3.813” Packing Bore) 8 5,150’ 4-1/2” XN Profile (3.813” Packing Bore;3.725” No-Go Min ID) 9 5,203’ Wireline Entry Guide (Btm at 5,204’) 10 5,273’ Baker Hook Wall, Hanger above 7-5/8” Window 11 5,290’ Baker Hook Wall, Hanger below 7-5/8” Window 12 5,338’ Baker Tie Back Sleeve 13 5,345’ Baker ZXP Liner Top Packer 14 5,351’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 15 8,536’ Btm Baker 4-1/2” Guide Shoe (OA Lateral) 16 8,421’ Btm Baker 4-1/2” Guide Shoe (OB Lateral) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 460 sx PF ‘L’, 260 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 420 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 460’ MD Max Wellbore Angle = 63.0 deg @ 2,200’ MD WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23194-00-00 Drilled and Completed by Doyon 14 – 4/03/2004 ESP Repair by Nabors 3S – 5/19/2006 ESP Repair by Nabors 3S – 6/09/2008 ESP Repair by Nabors 4ES – 8/31/2008 Convert to Jet Pump by Doyon 16 – 3/16/2013 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,278’ MD; Bottom @ 5,290’ MD; Angle @ top of window is 54 deg Top of “OB” Window @ 5,418’MD; Bottom @ 5,430’ MD; Angle @ top of window is 62 deg Fish: Milled CIBP @ 8,401’ CTM 3/16/14 _____________________________________________________________________________________ Revised By: TCS 02/13/2024 PROPOSED SCHEMATIC Milne Point Unit Well: MPU G-18 Last Completed: 3/16/2013 PTD: 204-020 15 16 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20"Conductor 92 / H-40 / Welded N/A Surf 112' 10-3/4”Surface 45.5 / L-80 / BTC 9.794 Surf 3,226’ 7-5/8"Production 29.7 / L-80 / BTC-Mod 6.750 Surface 5,560' 4-1/2”Liner “A”12.6 / L-80 / IBT 3.833 5,273’8,536’ 4-1/2”Liner “B”12.6 / L-80 / IBT 3.833 5,338’8,421’ TUBING DETAIL 3-1/2”Tubing 9.3 / L-80 / EUE 2.992 Surf ~5,000’ LINER DETAIL 4-1/2”OA Solid Liner 12.6 / L-80 / IBT 3.833 5,299’5,380’ 4-1/2”OA Slotted Lnr 12.6 / L-80 / IBT 3.833 5,380’8,490’ 4-1/2”OB Solid Liner 12.6 / L-80 / IBT 3.833 5,364’5,531’ 4-1/2”OB Slotted Lnr 12.6 / L-80 / IBT 3.833 5,531’8,377’ JEWELRY DETAIL No Depth Item 1 ~4,860’3-1/2” Sliding Sleeve 2 ~4,900’3-1/2” Intake Gauge 3 ~4,930’7-5/8” x 3-1/2” Retrievable Packer 4 ~4,970’3-1/2” X Nipple 5 ~5,000’3-1/2” x 4-1/2” Non-Sealing Overshot 6 5,039’7-5/8”” x 4-1/2” TNT Permanent Hydraulic Set Packer (3.856” ID) 7 5,079’4-1/2” X Profile (3.813” Packing Bore) 8 5,150’4-1/2” XN Profile (3.813” Packing Bore; 3.725” No-Go Min ID) 9 5,203’Wireline Entry Guide (Btm at 5,204’) 10 5,273’Baker Hook Wall, Hanger above 7-5/8” Window 11 5,290’Baker Hook Wall, Hanger below 7-5/8” Window 12 5,338’Baker Tie Back Sleeve 13 5,345’Baker ZXP Liner Top Packer 14 5,351’Baker 7-5/8” x 5-1/2” HMC Liner Hanger 15 8,536’Btm Baker 4-1/2” Guide Shoe (OA Lateral) 16 8,421’Btm Baker 4-1/2” Guide Shoe (OB Lateral) OPEN HOLE / CEMENT DETAIL 20"Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4"Cmt w/ 460 sx PF ‘L’, 260 sx Class “G” in 13-1/2” Hole 7-5/8”Cmt w/ 420 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 460’ MD Max Wellbore Angle = 63.0 deg @ 2,200’ MD WELLHEAD Wellhead FMC Tubing Hanger, 11” x 4-1/2” TC-II Top & Bottom GENERAL WELL INFO API: 50-029-23194-00-00 Drilled and Completed by Doyon 14 – 4/03/2004 ESP Repair by Nabors 3S – 5/19/2006 ESP Repair by Nabors 3S – 6/09/2008 ESP Repair by Nabors 4ES – 8/31/2008 Convert to Jet Pump by Doyon 16 – 3/16/2013 LATERAL WINDOW DETAIL Top of “OA” Window @ 5,278’ MD; Bottom @ 5,290’ MD; Angle @ top of window is 54 deg Top of “OB” Window @ 5,418’MD; Bottom @ 5,430’ MD; Angle @ top of window is 62 deg Fish: Milled CIBP @ 8,401’ CTM 3/16/14 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/16/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 1-27 50029216930000 187009 2/6/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 2/7/2024 YELLOW JACKET GPT MPU G-18 50029231940000 204020 2/8/2024 READ Caliper Survey MPU B-28 50029235660000 216027 1/15/2024 YELLOW JACKET PATCH PBU PAVE 1-1 50029237670000 223094 1/5/2024 YELLOW JACKET CBL SRU 241-33B 50133206960000 221053 2/8/2024 YELLOW JACKET GPT Please include current contact information if different from above. T38513 T38514 T38515 T38516 T38517 T38518 2/21/2024 MPU G-18 50029231940000 204020 2/8/2024 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.21 09:17:43 -09'00' STATE OF ALASKA AL •A OIL AND GAS CONSERVATION COMM! )N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other LJ Mill Plug 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 ❑ '. 204-020-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 . 50-029-23194-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 ' ' SBL MPG-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MILNE POINT UNIT/SCHRADER BLUFF 11.Present Well Condition Summary: Total Depth measured • 8421 feet Plugs measured None feet true vertical 4183.91 feet Junk measured 8401 feet Effective Depth measured . 8421 feet Packer measured See Attachment feet true vertical 4183.91 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20"x 30" 34-112 34-112 None None Surface 3191 10-3/4"45.5#L-80 35-3226 35-2389.73 5210 2480 Intermediate None None None None None None Production 5527 7-5/8"29.7#L-80 33-5560 33-4230.01 6890 4790 Liner 3083 4-1/2"12.6#L-80 32-5204 32-4065 None None Perforation depth Measured depth P P 5531-8377 feet � f ?ate cg *gyp S..aux�;;at'r8� � �''.W.x.iielF True Vertical depth 4222.31-4186.94 feet :> SUMP JUN 1 201 1 i 2: ;; Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-5204 - /t.'\ GCC 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: I', Intervals treated(measured): RBDMS*MAY 15 2014 1 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: 220 84 0 0 195 - Subsequent to operation: 164 77 93 0 194 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator,❑ Development D Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil . ❑� Gas LI WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 1 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: i N/A Contact Nita Summerhays Email Nita.SummerhaysL bp.com Printed Name Nit .....____.„ a summe ys '`""`-- Title Data Coordinator S 0atu s—/ ` Phone 564-4035 C ' / �`. .4 �-e-ei�a�/� Date 4/14/2014 ._ _. VL/= `/2 z /< 4-71 f/�// Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0025906 ACTIVITYDATE I SUMMARY ***WELL FLOWING ON ARRIVAL*** MADE TWO ATTEMPTS TO PULL JET PUMP FROM XD SSD @ 4943' SLM/4962' MD 7/30/2013 ***CONT'D ON 07-31-13*** CTU#3 - 1.5" Coil Job Objective: Mill CIBP MIRU CTU 7/31/2013 ...Continued on WSR 8-1-13... T/I/O=0/0/0 Assist S/L- Load Tubing and IA/ unable to MI I"IA due to excessive pressure differental between Tubing and IA. Rigged up to Pump-In-Sub and pumped 40 bbls criesel to load Tubing. Rigged up to IA and pumped 60 bbls crude to load IA. **S/L in 7/31/2013 control of well on departure** FWHP's= 0/220/45 ***CONT'D FROM 07-30-13*** PULLED 3" RC JET PUMP (6-C RATIO, SER#BP-1082) FROM XD SSD @ 4943' SLM/ 4962' MD. LRS FREEZE PROTECT TUBING AND I/A RAN 4 1/2" B' SHIFTING TOOL, CLOSED XD SSD @ 4944' SLM/4962' MD 7/31/2013 ***WELL S/I ON DEPARTURE*** CTU#3 - 1.5" Coil Job Objective: Mill CIBP Make up logging BHA with a 2.2"carrier and 3.70"drift. RIH and dry tag fill at the window, 5273'. Jet through fill to top of CIBP tag at 5398'. logged up from the plug depth to 4700', Painted a flag @ 5368'. POOH. P/U mill assy and RIH, rest the elec counter©the flag to 5373.4' resume RIH tagged the plug @ 5397' milled the plug and pushed it to 5539'. POOH, cut the CTC and 23 ft of coil, rehead and P/U a new motor& 3.7" paraboilic mill, RIH Dry tag © 5438'. Work down to 5548'. POOH to inspect BHA. 8/1/2013 Continued on 08/02/13 WSR. CTU #3 - 1.5" Coil***Continued from WSR 8-1-13*** Job Objective: Mill CIBP POOH w/ mill run #2. No problems noted w/ BHA. RIH with mill run#3 and tempress agitator. Make very little headway with hard stalls, plug pushed to 5550' CTM at begining of slotted liner, possibly caught in liner damage. Well freeze protected with 50/50 methanol. Rig down move to MPE-13 8/2/2013 ...Job Complete.... T/I/0=29/0/30 MIT-IA PASSED to 3360 Pumped 2.5 bbls diesel down IA to reach test pressure. Loss of 51 psi 1st 15 min. Loss of 25 psi 2nd 15 min. FWHP=35/0/30 9/8/2013 SV,WV,SSV shut MV,IA,OA Open ***WELL S/I ON ARRIVAL*** (wrp drift) RAN 3.69" CENT DOWN TO 5440' SLM.SAW NO RESTRICTIONS. 9/9/2013 ***WELL LEFT S/I ON DEPARTURE *** ***COST PLACEHOLUER FOR MACHINE SHOP CHARGES TO MAKE EVO-TRIEVE 9/12/2013 BTM SUB*** Daily Report of Well Operations ADL0025906 ***JOB CONTINUED FROM 9/13/13***(E-LINE DRIFT/EVO-TRIEVE) CURRENTLY RIH W/GR/CCL/HES DPU/EVO-TRIEVE PLUG W/GAUGES CCL STOP DEPTH=5377.62', CCL TO ME=12.38' EVO-TRIEVE PLUG W/GAUGES MID-ELEMENT SET AT 5390' GOOD INDICATION OF SET AT SURFACE, LOSS —220# TOP OF PLUG=5388', BTM OF PLUG=5394', BTM OF GAUGES=5400' WELL SHUT IN UPON DEPARTURE, DSO NOTIFIED FINAL T/I/O=0/50/50 PSI 9/14/2013 ***JOB COMPLETE*** ***WELL S/I ON ARRIVAL***(coil prep) PULLED 3" JET PUMP (ser#by-1082) FROM 4962' MD. HELD MAN DOWN &WELL CONTROL SAFETY DRILLS. 2/7/2014 ***CONTINUE ON 02-08-14 *** 171/0= 130/0/20 Assist Slickline. Freeze Protect. Pumped 75 bbls 180* Criesel down TBG for freeze protect, Pumped 65 bbls Crude down IA for freeze protect, Pumped 3 bbls crude down FL, 3 bbls crude down test line and 3 bbls crude down power fluid line for freeze protect. FWWHP= 130/0/55 IA, OA=OTG WV,AL=Closed SV,SSV,MV=Open SSL in control of 2/8/2014 well at departure ***CONTINUED FROM 02-07-14 *** (coil prep) PERFORMED WEEKLY WLV TEST. LRS FREEZE PROTECT IA W/65 BBLS CRUDE, TEST LINE, JET PUMP LINE, & FLOW LINE (3 BBLS DOWN EACH) . DISPLACED TBG W/75 BBLS CRISEL. RAN 4.5"42-BO SHIFTING TOOL, CLOSED SSD @ 4962' MD. RAN 2" GS,TAGGED BOTTOM @ 5292' SLM.UNABLE TO LATCH EVO TRIEVE. MADE TWO RUNS W/3.5" DRIVE DOWN BAILER.BAILED FROM 5292' SLM TO 5302' SLM.RECOVERED 3.5 GALLONS OF FORMATION SAND. 2/8/2014 ***CONTINUE ON 02-09-14 *** ?/1/0= 80/0-/20 Assist Slickline Pumped 14 bbls criesel to verify sleeve closed. 2/9/2014 FWHP=0/64/20 Slickline on well at LRS departure. ***CONTINUED FROM 02-08-14 *** (coil prep) MADE MULTIPLE RUNS W/VARIOUS BAILERS (see log).BAILED FROM 5303' SLM TO 5353' SLM.RECOVERED 10 GALLONS SAND TOTAL. ESD ALL SLB EQUIP & 3RD PARTY EQUIP.HELD MAN DOWN, CONTROL OF WORK, FIRE DRILLS. 2/9/2014 *** CONTINUE ON 02-10-14 *** *** CONTINUED FROM 02-09-14 *** (coil prep) RAN 2.64" CENT W BULL NOSE TO VERIFY GETTING THRU LINER.S/D @ 5322' SLM. SLIGHT BOBBLE @ 5308' SLM. 2/10/2014 ***WELL LEFT S/I ON DEPARTURE *** CTU#9 w/ 1.75" CT. Job Scope: FCO, Pull Plug, Push CIBP. MOB from Deadhorse to MPG-18, MIRU. MU Baker MHA CTC 1.90"x .39', DBPV 1.69"x .1.51', Disco 1.69"x 1.37', Circ sub 1.69" x .93', X-over 1.70"x .19' (OAL 4.39'). 3/14/2014 ***Job continued on WSR 3-15-2014*** Daily Report of Well Operations ADL0025906 CTU#9 w/ 1.75" CT. Job Scope: FCO, Pull Plug, Push CIBP. U Baker MHA CTC 1.90" x .39', DBPV 1.69" x .1.51', Disco 1.69" x 1.37', Circ sub 1.69" x .93', X-over 1.70" x .19', SLB Stinger 2"x 4', Stinger 2"x 4', DJSN 2.5" x .583', (OAL12.973 ). RIH. Tag CTM at 5369 elec. 5368' mech. Jet at 2.5 bbls/min hard tags, puh to T.T. RBIH jetting down to EVO-Trieve plug. Made 4 jett passes PUH to T.T. Freeze protect CT POOH. LD FCO BHA. MU BTT fishing BHA+ 2" G Spear(OAL = 15.67' MOD = 3.38"). RIH. Tag plug at 5372' CTM, set 2k down, did not latch. Set 4k down, EQ plug. PU and sheared plug. Wait to relax. POOH. LD EvoTreve + gauge carrier. MU BTT 2-7/8" motor and 3.70" 3-blade junk mill (OAL = 24.9' MOD = 3.70"). RIH. Set down several times at 5257' CTM (7-5/8"window). Rolled through. RIH. Set down at 5324' CTM (liner top). Roll through. RIH. Set down on plug at 5548' CTM. Swap coil to 1% Slick KCL. Pumped Diesel w/776 114 bbls for friction reducer. Tag CIBP 5546' start milling. Pushing CIBP to 8421' 3/15/2014 ***Job icontinued on WSR 03-16-2014*** CTU#9 w/ 1.75" CT. Job Scope: FCO, Pull Plug, Push CIBP. Continued from 3/15/14 BTT 2-7/8" motor and 3.70" 3-blade junk mill (OAL =24.9' MOD = 3.70"). Continue pushing CIBP to 8421'. Pushed CIBP down to 8202' PUH low on fluids, started pulling heavy 11 k over at 6290'. Wt's back to normal around 5400'. POOH check motor& mill. Mill looks good. RIH w/same BHA. Roll into TOL and tag fill/debris @ 5360' CTM. Clean out to 5700' and chase sweep to 961'. RIH. Tag plug at 8209'. Pushed plug down to Tag TD 8401' Elec. 8412' Mech CTM. 14.2k up WT. . POOH chase sweep. Freeze protect tubing 38 bbls 60/40. 3/16/2014 ***Job continued on WSR 03-16-2013*** CTU#9 w/ 1.75" CT. Job Scope: FCO, Pull Plug, Push CIBP. Continued from 3/16/14 Weekly BOP test, Change packoffs, Chain Inspection. RDMO. 3/17/2014 ***Job Complete*** FLUIDS PUMPED BBLS 80 DIESEL 172 CRUDE 1868 SLICK 1% KCL 14 CRIESEL 209 60/40 METH 114 DIESEL W/776 40 POWERVIS 35 50/50 METH 2532 TOTAL Packers and SSV's Attachment ADL0025906 SW Name Type MD TVD Depscription MPG-18 PACKER 5039 3903.14 4-1/2" HES TNT Perm Packer MPG-18 PACKER 5345 4082.58 5-1/2" BAKER ZXP PACKER Tree: 4 1/16"-5M CIW MPG-18 Or IF elev.= 34.00'(Doyon 14) Wellhead: 5M Gen 5O. ,L.elev.= 29.70'(Doyon 14) • 11"x 11"w/4 1/6"TC-IIT&b Hanger 4.5"CIW"H" BPV profile Ex 2'Blast Casing tested to 3250 psi from 5130'during 3/16/13 RWO. 4 20'178#/ft.875 thick Driven conductor 120' SLB 4 1/2"x 1"KGB-2 2510' Gas lift mandrel 10 3/4"45.5 ppf L-80 BTC 3,226' , , KOP @ 460' 43+degree from 1,500' Max hole angle=63 degree @ 2,200' 4.5",12.6#,L-80 TC-II Tbg. SLB NDPG-C Discharge Gauge 4950' (cap.=.0152 bpf,id=3.958) 3.958"ID TVD=3913' 7 5/8"29.7 ppf,L-80,BTC-M Casing HES 4 1/2"XD Duro Sleeve 4962 (drift ID=6.750",cap.=0.0459 bpf) 3.813 Packing Bore ID (cap w/4 1/2"Tbg inside=bbf) SLB NDPG-C Intake Gauge 4972' 3.958"ID TVD=3926' HES 7 5/8"x 4 1/2"TNT Packer 5039' LJ HES 4 1/2"X Nipple 5079' I I 3.813 Packing Bore ID HES 4 1/2"XN Nipple 5150' 3.813 Packing Bore ID/3.725"No-Go ID WLEG(bottom) 5204' Baker Hook Wall Hanger inside 7"Window 5,273' Baker Hook Wall Window in 7"Casing @ 5,278'-5,290' Hanger outside 7"Window 5,290' Well Angle @ window=54° 61/8"Hole td @ 8,563' 75 jts.-4 1/2"Slotted Liner Rat Hole OA Upper Lateral 27' Pulled EVO-Trieve Plug 12.6#L-80 IBT(5,380'-8,490') 3/15/2014 — Baker Tie Back Sleeve 5,338' Btm Baker 4 1/2"Guide Shoe 8,536' � Baker ZXP Liner Top Packer 5,345' . Baker 7-5/8"x 5-1/2"HMC Liner Hanger 5,351' \ HES EVO-Trieve plug w/gauge,Mid-element set at 5390'Top at 5388',OAL of plug w/gauges=12.67 set 9/14/13 7 5/8"Halliburton Float Collar 5,476` �= 6 1/8"Hole td @ 8,421' A,7 5/8"Halliburton Float Shoe 5,560' OB Lower Lateral69 its. 4 1/2",12.6#L-80,IBT •Fish-sets@-6659'Ramainder-of4:5 P Slotted Liner (5,531'-8,377' I((((iiii! GIB y Pushed CIBP top 8401"CTM 3/16/2014 maker 4 1/2"Float Shoe 8,421' DATE REV.BY COMMENTS M I LN E POINT UNIT 04/03/04 ' MDO Drilled&Completed Doyon 14 WELL MPG-18 05/19/06 MDO ESP RWO Tbg.change out N-3S 6-9-08 REH ESP RWO-Nabors 3S API NO: 50-029-23194-60 8-31-08 REH ESP RWO-Nabors 4ES 3/16/13 Hulme Covert to Jet Pump-Doyon 16 API NO: 50-029-23194-00 08/02/13 Bill K CTD Milled out CIBP 09/1403/16/14 , BIIB xby ,ElineCoil pulled Plug and push CIBP to bottom BP EXPLORATION (AK) RECEIVED STATE OF ALASKA • AASKA OIL AND GAS CONSERVATION COMMISSION APR 1 2 2013 REPORT OF SUNDRY WELL OPERATIONS CC 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Jet Pump Conversion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 204 - 020 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 " 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 - MPG - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): f Milne Point Unit / Schrader Bluff 11. Present well condition summary: Total depth: measured 8421' feet Plu s: measured 9 ( ) 5400' feet true vertical 4184' feet Junk: (measured) None feet Effective depth: measured 8421' feet Packer: (measured) 5039' feet true vertical 4184' feet Packer: (true vertical) 3967' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34' - 112' 34' - 112' Surface 3191' 10 -3/4" 35' - 3226' 35' - 2390' 5210 2480 Intermediate 5527' 7 -5/8" 33' - 5560' 33' - 4227' 6890 4790 Production Liner 3083' 4 - 1/2" 5338' - 8421' 4142' - 4184' 8430 7500 Perforation Depth: Measured Depth: Slotted 5531' - 8377' feet True Vertical Depth: Slotted 4222' - 4187' feet Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# L - 5204' 4065' Packers and SSSV (type, measured and true vertical depth): 7 - 5/8" x 4 - 1/2" HES TNT Packer 5039' 3967' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED APR 1 9 2013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 111 38 120 240 184 Subsequent to operation: 0 0 0 0 0 14. A ttac hm e n ts : ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic . ® Development ❑ Service ® Daily Report of Well Operations Well Schematic Diagram 16. Well Status after work: ^ ® Oil ❑ Gas ❑ WDSPL ❑ 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: Contact: Noel Nocas, 564-4667 Email: Noel.Nocas @bp.com N/A Printed N : Jo- I_ ALL: Title: Drilling Technologist 1 Signatur 1 \' Phone: 564 - 4091 Date: l � `7 Form 10-404 R ed 10/2012 - "1' 8 APR 1 5 2013 '�`Ir r '' G fr ,/ � Submit Original Only • • 4cirthAmerce - ALASKA -SP : Operation Summary Be rt Common Well Name: MPG -18 ' AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18 /2013 X4- 00XF5- E:DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad • Rig Name /No.: DOYON 16 Spud Date/Time: 2/15/2004 12:00:00AM 1 Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT NPT Depth I Phase I Description of Operations (hr) 1 (usft) 1 3/13/2013 18:00 - 20:00 2.00 MOB P 1 I PRE PJSM, PREP RIG FOR MOVE I 1- WARM UP RIG HYDRAULICS, MAKE SPCC I I CHECKS I - INSTALL REAR BOOSTER WHEELS M/U HYDRAULIC LINES AND FUNCTION TEST 20:00 - 00:00 4.00 MOB P PRE 1- MOVE RIG TO ENTRANCE ON MP F PAD ' - CHECK ALL MOVING SYSTEM HYDRAULIC LINES FOR INTEGRITY I • - MOVE FROM MP F PAD TO MPG PAD 3/14/2013 1 00:00 - 02:30 2.50 MOB P PRE PRE -TOUR MEETING AT RIG CAMP, SPCC CHECKS - RIG MOVING FROM MP F PAD TO MPG PAD - RIG STAGED AT A PAD ENTRANCE AT MIDNIGHT - CONTINUE ON TO MPG PAD 02:30 - 07:45 5.25 MOB P PRE ARRIVE MPG PAD - PJSM, BRIDLE DOWN AND SECURE DERRICK. - REMOVE BOOSTER WHEELS - LAY RIG MATS AROUND MP G -18 WELLHEAD - MOVE BOP FROM STAND INTO CELLAR - MOVE NEW 4-1/2" TREE INTO CELLAR. 07:45 - 09:40 1 1.92 RIGU P PRE MOVE RIG OVER WELL. 1 , SET RIG DOWN AND SHIM TO LEVEL. CHINK 1 UP AND BERM CELLAR. RIG UP TOP DRIVE. 1 AOGCC GIVEN AN UPDATE OF BOP TEST TIMING. 09:40 - 12:30 2.83 j RIGU P I PRE I START LOADING PITS WITH 8.4 PPG 120 DEG ! I1 %KCLWATER. 1 * ** RIG ACCEPTED 10:00*** :RIG UP CIRCULATION SKID IN CELLAR TO PREP FOR WELL KILL. ' PRESSURE TEST LINE TO FLOWBACK TANK AND CIRC SKID LINES TO 250 / 3500 PSI, I GOOD. 12:30 - 13:30 1.00 WHSUR P DECOMP I LOAD BPV LUBRICATOR TO RIG FLOOR. 13:30 - 14:00 0.50 WHSUR 1 P DECOMP RIG EVAC DRILL WITH DAY SHIFT. ALL PERSONNEL MUSTER AND ARE ACCOUNTED FOR. MR AFTERWARDS. 14:00 - 15:30 1 1.50 WHSUR P I DECOMP RIG UP AND PRESSURE TEST BPV LUBRICATOR. I PULL BPV, PUT LUBRICATOR IN PIPE SHED. Printed 4/1/2013 9:07:17AM • • A North Amet1 Ce ASKi • BP , , Ope ration Summary Report Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 !X4- 00XF5- E:DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 2/15 /2004 12:00:00AM l Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. 1 UWI: Active datum: Kelly Bushing / Rotary Table ©63.70usft (above Mean Sea Level) Date 1 From - To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (usft) 115:30 - 18:00 2.50 WHSUR P DECOMP PJSM THEN KILL WELL AS PER PROGRAM. BLEED OFF IA TO 0 PSI IN 10 MIN, NO FLUID 1 SEEN. . PUMP DOWN TUBING 8.4 PPG 120 DEG _WATER, TAKE RETURNS UP THE IA. AFTER V 30 BBLS, NO FLUID SEEN I AFTER 30 BBLS, CLOSE CHOKE AND BULLHEAD 30 BBLS AT 3 BPM. ' FINAL BULLHEAD PRESSURE IS 600 PSI TBG, 420 PSI IA. OPEN CHOKE, CIRC 290 BBLS AT 5 BPM. GET CRUDE RETURNS BACK AT 1050 STROKES, ' WATER BACK AFTER 3200 STKS. FLUID COMING BACK IS 8.4 PPG. SHUT DOWN AFTER 290 BBLS CIRC. TUBING AND IA BOTH ON VAC. MONITOR FOR 30 MIN. NOTE: HAD TO BLEED THE OA TWICE FROM 1000 PSI. 18:00 19:30 1.50 WHSUR P DECOMP RIG DOWN MANIFOLD - BLOW DOWN LINES - RIG DOWN CIRCULATING LINES & KILL MANIFOLD - R/U SECONDARY KILL LINE FILL TUBING AND ANNULUS WITH CHARGE PUMP, 10 BBLS _ 19:30 - 21:00 1.50 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC - M/U LUBRICATOR & TEST 250 PSI LOW AND � k 3500 PSI HIGH FOR 5 MINS EACH , CHARTED { 1- SET TWC ry U 21:00 - 23:00 2.00 WHSUR P WHDTRE _PRESSURE TEST TWC s - ATTEMPT ROLLING TEST BELOW TWC / 1. - PUMP DOWN IA WIUTH NO RESPONSE ;FROM GAUGES, SHUT DOWN , REPLACE 1 SENSORS (30 BBLS KWF PUMPED) 1 - PUMP DOWN IA © 2 BPM AND 560 PSI FOR 10 MINS, CHARTED (56 BBLS KWF PUMPED) - TEST TWC FROM ABOVE,: 250 PSI LOW & 3500 PSI HIGH FOR 5 MINS EACH , CHARTED 23:00 - 00:00 1.00 WHSUR 1 P WHDTRE PJSM TO DRAIN AND NIPPLE DOWN TREE & N/U BOPE �0 N � 1 i -DRAIN TREE - NIPPLE DOWN FMC ADAPTER FLANGE & 2 X 1 9 /1 " ,5MTREE I CONTINUOUS HOLE FILLAT 15 BPH WITH 8.4 PPG KWF I LOSSES TO WELL - DURING KILL = 340 BBLS _ - AFTER KILL = 111 BBLS 3/15/2013 00:00 - 01:00 1.00 WHSUR P WHDTRE PRE -TOUR MEETING, SPCC CHECKS 1- NIPPLE DOWN FMC 2 9/16" , 5 M TREE .- FMC REP CLEAN AND INSPECT EUE 8RD HANGER THREADS i - CONFIRM 9 TURNS BY HAND. O 01:00 - 03:00 2.00 P WHDTRE PJSM, NIPPLE UP BOPE - N/U 13 -5/8" BOPE STACK. (1,I) Printed 4/1/2013 9:07:17AM . • .„ t peration Summary Report Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 X4- 00XF5- E:DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15/2004 12:00:00AM I Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) ' (usft) 03:00 - 03:30 0.50 WHSUR P WHDTRE RIG EVACUATION DRILL WTH NIGHT SHIFT. - AAR - PRIMARY MUSTER AREA WAS ANNOUNCED AS 'COMPRIMISED' - ALL PERSONNEL MUSTER TO SECONDARY AND ARE ACCOUNTED FOR. - GOOD SWEEP THROUGH RIG BY DRILLER - SCBA'S & LEL MONITORWAS AVAILABLE AND INSPECTED IN SIGN N TRAILER 03:30 - 08:30 5.00 WHSUR P WHDTRE PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - PERFORM ACCUMULATOR DRAW DOWN TEST. NO FAILURES. WSL WITNESSED TEST. - TEST ANNULAR WITH 2 7/8" TEST JOINT TO K 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST WTH FRESH WATER - JOHN CRISP OF AOGCC WAIVED STATE J RIGHT OF WITNESS BOP TEST ' 08:30 - 09:30 1.00 WHSUR P WHDTRE BLOW DOWN LINES, VAC OUT STACK RIG DOWN TEST EQUIPMENT. 09:30 - 11:30 2.00 WHSUR P WHDTRE PICKUP LUBRICATOR, TEST TO 250 / 3500 PSI, GOOD. PULL TWO AND LAY DOWN. 11:30 - 14:20 2.83 PULL P DECOMP PICK UP LANDING JOINT. MAKE UP TO TOP DRIVE. BACK OUT LOC( DOWN SCREWS. PICK UP 85K TO UNSEAT HANGER. I UP WT IS 79K, PULL UP TO FIRST CLAMP AND CUT CABLE. RUN BACK INTO PLACE SLICK JOINT :ACROSS BOPS. CLOSE ANNULAR AND PUMP 30 BBLS, TAKE I RETURNS FROM IA. 14:20 - 16:30 2.17 PULL P DECOMP OPEN ANNULAR. LINE UP TO FILL WELL ACROSS TOP FROM TRIP TANK. WELL TAKING 10 -15 BBUS HR. RIG UP SPOOLING UNIT. RIG UP TRUNK I i 1 I THAT CABLE WILL PASS THROUGH. HANG ESP SHEAVE PREFORM TOP DRIVE AND DERRICK IINSPECTION 16:30 - 22:00 5.50 I PULL P DECOMP POOH W/ 2/ -7/8" EUE 8RD TUBING AND ESP ASSEMBLY - POOH 'OM 5,240' MD , REMOVING LASALLE CLAMPS EVERY OTHER JOINT - STAND BACK TUBING - NO CORROSION OR BAD THREADS ON TUBING 21:20 - 1 CUP GLYCOL RELEASED FROM CREW VAN, FAILURE TBD. NOTIFICATIONS MADE TO MP G PAD OPERATOR AND MP ENVIRONMENTAL Printed 4/1/2013 9:07:17AM III • .. py�y`v�" :y��y 5(q „,„„ .. ...:,., .:::;,„„.:,,,,,,, ,,:,„:,, .. ,tN tki 9' 4 j / iil' i. F :„ , „. : .,:,,,„.,„,,,,.,,,,,,...,..,..:: ,,,,,,„:.,,,,,::::,,„,,,,,,„,„:7.,„4,,,,,,!.,.":4'.''.0 Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 I End Date: 3/18/2013 X4- 00XF5- E:DRILL (1,785,000.00 ) Project: Milne Point I Site: M Pt G Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 2/15 /2004 12:00:00AM Rig Release: 3/18/2013 i Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date I From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 122:00 - 00:00 2.00 rt PULL P DECOMP PJSM TO LAY DOWN ESP ASSEMBLY - PULL ESP TO RIG FLOOR - REMOVE ANNODE AND CENTRALIZER - TRACE OF CORROSION AT STAINLEES AND CARBON STEEL INTERFACE RECOVERED 89 LASALLE CLAMPS, 5 PROTECTOLIZERS, 3 FLAT GAURDS j CONTINUAL HOLE FILL WITH 8.4 PPG 1% KCL ! AT 15 BPH 234 BBLS KWF LOST FOR THE DAY 3/16/2013 00:00 - 01:00 1.00 PULL P DECOMP SPCC & DERRICK CHECKS PJSM. RIG DOWN ESP TOOLS. - RIG DOWN ESP TOOLS. - RIG DOWN SHEAVE AND SPLASH GUARD FROM DERRICK. - CLEAR AND CLEAN RIG FLOOR 01:00 - 01:30 0.50 EVAL P DECOMP MAKE UP WEAR RING RUNNING TOOL - P/U RUNNING TOOLAND INSTALL WEAR i i_ RING, I.D.= 9" 01:30 - 04:30 3.00 EVAL I P DECOMP PJSM, PU / MU 7 5/8" HES CHAMP PACKER PER HES REP. I - WSL, TOOLPUSHER, HES REP. RIG CREW IN ATTENDANCE. '- OD. OF HES 7 5/8" CHAMP PACKER = 6.51" - RIH ON 2 -7/8" EUE 8RD TUBING FROM I DERRICK. I- RIH TO -5130' MD CENTER OF ELEMENT. I- 6 ,j 04:30 - 05:00 0.50 EVAL P DECOMP SET 7 -5/8" HES CHAMP PACKER "U q - OBTAIN PARAMETERS AT 5111' MD \ - PUW= 68 K , SOW= 62 K I - WORK PACKER AT SET DEPTH OF 5130' MD - SET DOWN 5' & ROTATE 3 TURNS, PACKFR SET AT 5130' MD, CENTER OF ELEMENT 05:00 - 06:00 1.00 EVAL P DECOMP PJSM, MIT -IA, 7 5/8" L -80 29.7 # CSG BY 2 -7/8" TUBING ANNULUS. - CONFIRM VALVE ALLIGNMENT PRIOR TO TEST ` '- PUMPED 34 STKS (3 BBLS) TO / 3,250 PSI \\ FOR 30 CHARTED MINUTES. - TESTING BEGAN AT 05:30 AM MIT -IA MEETS BP SIP_ C_ RT -AK -10-45 CRITERIA i I SEE ATTACHMENTS 1 06:00 14:30 8.50 EVAL ! P I DECOMP PULL 2 -7/8" 8RD EUE TUBING OUT IN SINGLES, LAY DOWN. - LAY DOWN HES PACKER. 14:30 - 15:00 0.50 EVAL P 1 DECOMP MAKE UP WEAR RING RUNNING TOOL - P/U RUNNING TOOLAND PULL WEAR RING 115:00 - 16:30 1.50 RUNCOM P I RUNCMP RIG UP TO RUN 4-1/2" COMPLETION. - CLEAN AND CLEAR RIG FLOOR, CHANGE BAILS ON TOP DRIVE 1 - VERIFY RUN TALLY WITH ODE. VERIFY PIPE 1 ; COUNT IN SHED. !- RIG UP TORQ -TURN. 16:30 - 18:30 2.00 I RUNCOM P I I RUNCMP RIG UP SCHLUMBERGER EQUIPMENT ! - PULL SLB I -WIRE SPOOL TO RIG FLOOR I I - RIG UP I -WIRE SPOOLER AND SHEAVES. Printed 4/1/2013 9:07:17AM • • .Mnerr Nofthica - ALASKA BP..„ .. 5.of Operation Summary Report Common Well Name: MPG -18 AFE No Event Type: WORKOVER OA/0) Start Date: 3/13/2013 End Date: 3/18/2013 X4- 00XF5 -E: DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15 /2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UVNI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 1 -- 18:30 - 19:00 0.50 RUNCOM P RUNCMP PJSM WITH RIG CREW, HALLIBURTON, ,SCHLUMBERGER, & WSLS I- DISCUSS SPECIFIC HAZARDS FOR THE I SCOPE OF WORK 1 - DISCUSS WORKING ON A CROWDED RIG FLOOR 19:00 - 20:00 1.00 RUNCOM P RUNCMP P/U 41/2'x12.6# L -80 TC- 11 JET PUMP COMP LETIO_ N BHA - M/U MULE SHOE JOINT, XN WITH RHC -M PLUG, X- NIPPLE - M/U HES 7 5/8" X 4 1/2" HES TNT PACKER - BAKER LOCK ALL CONNECTIONS BELOW PACKER - SLB INTAKE GAUGE, HES SLIDING SLEEVE, SLB DISCHARGE GAUGE 20:00 - 22:30 2.50 RUNCOM P RUNCMP SCHLUMBERGER INSTALL 1-WIRE - M/U AND TIE IN I -WIRE TO INTAKE AND DISCHARGE GAUGES - MAKE SERVICE SPLICES AND TEST TO 5000 PSI 22:30 - 00:00 1.50 RUNCOM P RUNCMP RIH WITH 4 1/2" 12.6# L -80 TC -II JET PUMP COMPLETION - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY OF I -WIRE - RIH FROM BHA TO -600' MD CONTINUAL HOLE FILL WITH 8.4 PPG KWF AT F 8 BPH 124 HR LOSSES = 173 BBLS 3/17/2013 00:00 - 02:00 2.00 RUNCOM ; P RUNCMP PRE -TOUR MEETING, SPCC CHECKS RIH WITH 4 1/2" 12.6# L-80 TC-II JET PUMP COMPLETION - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY OF I -WIRE EVERY 1000' - RIH FROM 600' TO 1200' 02:00 - 02:30 0.50 RUNCOM P RUNCMP KICK WHILE TRIPPING DRILL. - CREW KNEW RESPONSIBILITIES AND THEIR ASSIGNED STATIONS. - SIMULATE I -WIRE CUT - STAB SAFETY VALVE, SIMULATE CLOSING AND SECURING WELL. 02:30 - 06:00 3.50 RUNCOM P RUNCMP RIH WITH 4 1/2" 12.6# L -80 TC -II JET PUMP 1 COMPLETION 1 - INSTALL CANNON CLAMPS ON EVERY (COLLAR 1 - CHECK CONTINUITY OF I -WIRE EVERY 1000' RIH FROM 1200' TO 3200' 06:00 - 09:15 3.25 RUNCOM P RUNCMP CONTINUE RIH WITH COMPLETION. MAKE UP LAST JT OF TUBING. UP WT IS 93K, SLACKOFF IS 81K. (NOTE: INCLUDES BLOCK WEIGHT OF 40K) MAKEUP LANDING JOINT. INSTALLED 119 CANNON CLAMPS & 4, ONE -HALF CANNON CLAMPS Printed 4/1/2013 9:07:17AM . • • • • North Afriii . Operation Summary Repor" . Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 X4- 00XF5- E:DRILL (1,785,000.00 ) Project Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15/2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:15 - 12:20 3.08 1 WHSUR P RUNCMP TERMINATE I -WIRE IN HANGER AND TEST, GOOD. PRESSURE TEST I -WIRE THROUGH HANGER, GOOD. LAND HANGER AND INSTALL LOCK DOWN SCREWS. BACK OUT LANDING JOINT AND LAY DOWN. 12:20 - 13:00 0.67 WHSUR P RUNCMP LINE UP TO REVERSE INTO IA TAKING RETURNS FROM THE TUBING. PRESSURE TEST THE LINES THAT WERE RIGGED UP TO THE REVERSE OUT SKID IN THE CELLAR. 13:00 - 14:30 1.50 WHSUR P RUNCMP PJSM THEN PUMP 80 BBLS HOT WATER INTO ANNULUS, FOLLWED BY 140 BBLS INHIBITED WATER. TAKE RETURNS FROM TUBING. PUMP AT 5 BPM / 390 PSI. AFTER REVERSING, PUMP 3 BBLS DOWN THE TUBING TO CLEAR THE BALL SEAT. 14:30 - 16:10 1.67 WHSUR P RUNCMP OPEN BLINDS, INSTALL LANDING JOINT. DROP BALL AND ROD WITH ROLLERS INTO TUBING, LANDS IN XN. PRESSURE UP TO TEST TUBING, 1.7 BBLS TO 3200 PSI. INITIAL PRESSURE 3240 PSI, 15 MIN 3210 PSI, 130 MIN 3200 PSI, PASS. 1 BLEED OFF TUBING TO 1720 PSI. LINE UP TO PUMP DOWN IA TO TEST. INTITIAL PRESSURE 3250 PSI, 15 MIN 3220 PSI, 30 MIN 3210 PSI, PASS. _ 16:10 - 17:00 0.83 WHSUR P RUNCMP REVIEW TEST RESULTS WITH WTL, GET 1 APPROVAL TO PROCEED WITH WELL PLAN. BLEED OFF TUBING PRESSURE, SHEAR OUT DCK VALVE. PUMP THROUGH DCK VALVE BOTH WAYS TO CONFIRM SHEAR. PUMP AT 3 BPM AND 1200 PSI 17:00 - 18:00 1.00 WHSUR P r RUNCMP _ SET TWO W AY CHECK - FMC REP SET TWC -TEST TO 1000 PSI FROM BELOW - TEST FROM ABOVE 250 PSI LOW & 3500 PSI HIGH FOR 10 MINS CHARTED 18:00 - 19:00 1.00 BOPSUR P RUNCMP :RIG DOWN LINES VAC OUT STACK BLOW DOWN LINES & MANIFOLD - RIG DOWN LINES AND MANIFOL 19:00 - 20:00 1.00 BOPSUR P RUNCMP PJSM TO CHANGE OUT RAMS 1 - ISOLATE & BLEED OFF ACCUMULATER - CHANGE FROM M2 -7/8" x 5" TO 2 -3/8" 20:00 - 21:30 1.50 BOPSUR P RUNCMP PJSM NIPPLE DOWN BOP - N/D BOP - CLEAN OUT STACK AND BLOW DOWN LINES 21:30 - 00:00 2.50 WHSUR P RUNCMP PJSM NIPPLE UP ADAPTER AND TIE IN I -WIRE - CLEAN AND INSPECT ADAPTER AND HANGER SEALS - _ N /U ADAPTER SPOOL ,- PASS I -WIRE THROUGH ADAPTER SPOOL ; PORT AND TERMINATE 24 HR LOSSES = 49 BBLS Printed 4/1/2013 9:07:17AM • • - ; #operation Summary Report Common Well Name: MPG -18 1 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 X4- 00XF5- E:DRILL (1,785,000.00 ) I Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15 /2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. 1 UWI: Active datum: Kelly Bushing / Rotary Table ©63.70usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/18/2013 100:00 - 01:00 ■ 1.00 WHSUR P RUNCMP PRE -TOUR MEETING, SPCC CHECKS - NIPPLE UP ADAPTER AND TIE IN I -WIRE - SLB TEST I -WIRE CONDUCTIVITY AT 00:00, NOTIFY AOGCC OF UPCOMING BOP TEST ON MPG -02. SUBMIT ONLINE FORM FROM AOGCC WEBSITE. 01:00 - 02:00 1.00 WHSUR P RUNCMP PRESSURE TEST ADAPTER - HANGER SEALS & VOIDS - 250 PSI LOW FOR 5 MINS, 5000 PSI HIGH FOR 30 MINS CHARTED 02:00 - 04:00 2.00 WHSUR P RUNCMP PJSM , INSTALL TREE - N/U CAMERON 4-1/16" 5M TREE ;- TEST TREE 250 PSI LOWAND 5100 PSI HIGH FOR 5 CHARTED MINS EACH 04:00 - 05:30 1.50 WHSUR P RUNCMP IPJSM, RIG UPLUBRICATOR ;- STAB ON LUBRICATOR ON TREE I- PT 250 PSI LOWAND 3500 HIGH FOR 5 MINS lEACH i PULL TWO WAY CHECK - RIG DOWN LUBRICATOR 05:30 - 07:00 1.50 WHSUR P RUNCMP 1 PJSM WITH LITTLE RED SERVICES FOR ' FREEZE PROTECT OF WELL - RIG UP LRS PUMP TRUCK AND LINES. PRESSURE TEST LRS LINES, GOOD. 07:00 - 09:20 2.33 WHSUR P RUNCMP REVERSE IN 100 BBLS DIESEL INTO IA, TAKING RETURNS FROM TUBING. ' CIRC AT 2 BPM / 800 PSI INTIALLY, 2 BPM 1000 PSI FCP. SHUT DOWN AND ALLOW TO U -TUBE FOR 1 HR. 09:20 - 10:20 1.00 WHSUR r P RUNCMP INSTALL BPV LUBRICATOR AND PRESSURE TEST 250 / 3500 PSI, GOOD. SET BPV. ' 10:20 - 12:00 1.67 WHSUR P RUNCMP LRS PRESSURE TEST BPV FROM IA SIDE, PUT 1000 PSI UNDER BPV. GOOD TEST. INSTALL GAUGES ON TREE. CLEAN UP CELLAR AREA, PREP TO MOVE RIG. I I *** RELEASE RIG AT 12:00*** ALL FURTHER ENTRIES TODAY ON MPG -02 Printed 4/1/2013 9:07:17AM Tree: 4 1/16" - 5M ee: e F elev. = 34.00' (Doyon 14) Wellhead: 5M Gen 5 MPG- 8 /L OI L. elev.= 29.70' (Doyon 14) 11" x 11" w/ 4 1/6" TC-Il T &B Hanger 4.5" CIW "H" BPV profile 0 R _ Casing tested to 3250 psi from 5130' during 3/16/13 RWO. I 20' 178 #/ft .875 thick Driven conductor 1 120' i I SLB 4 1/2 "x1 "KGB -2 2510' I i Gas lift mandrel 1 10 3/4" 45.5 ppf L -80 BTC 1 3,226' IA ■ KOP @ 460' 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' 4.5 ", 12.6 #, L -80 TC -II Tbg. SLB NDPG -C Discharge Gauge 4950' I ( cap. = .0152 bpf, id = 3.958) 3.958" ID TVD = 3913' 7 5/8" 29.7 ppf, L -80, BTC -M Casing • • HES 4 1/2" XD Duro Sleeve 1 4962 (drift ID = 6.750 ", cap. = 0.0459 bpf) 3.813 Packing Bore ID (cap w/ 4 1/2" Tbg inside = bbf) I: SLB NDPG -C Intake Gauge 1 4972' 3.958" ID TVD= 3926' HES 7 5/8" x 4 1/2" TNT Packer 5039' I L__1 HES 4 1/2" X Nipple 5079 I Li 3.813 Packing Bore ID HES 4 1/2" XN Nipple 5150' 3.813 Packing Bore ID / 3.725" No -Go ID WLEG (bottom) 5204' I Baker Hook Wall Hanger inside 7" Window 5,273' Baker Holl Hanger outside ok Wa 7" Window 5,290' Window in 7" Casing @ 5,278' - 5,290' 6 1/8" Hole td @ 8,563' Well Angle @ window = 54° A— 75 jts. - 4 1/2" Slotted Liner Ra27 ole OA Upper Lateral 12.6# L -80 IBT (5,380' - 8,490') Btm Baker 4 1/2" Guide Shoe 8,536' Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7 -5/8" x 5 -1/2" HMC Liner Hanger 5,351' I lormin Baker 4 1/2" CIBP set @ 5400' 7 5/8" Halliburton Float Collar 5,476' 6 1/8" Hole td @ 8,421' 7 5/8" Halliburton Float Shoe 5,560' OB Lower Lateral 69 jts. - 4 1/2 ", 12.6# L -80, IBT \` Slotted Liner (5,531' - 8,377') All Btm Baker 4 1/2" Float Shoe 8,421' DATE REV. BY COMMENTS M I LN E POINT UNIT 04/03/04 MDO Drilled & Completed Doyon 14 WELL MPG -18 05/19/06 MDO ESP RWO Tbg. change out N -3S 6 -9 -08 REH ESP RWO - Nabors 3S API NO: 50 - 23194 - 8 -31 -08 REH ESP RWO - Nabors 4ES API NO: 50 - 029 - 23194 - 3/16/13 Hulme Covert to Jet Pump - Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission a04-0a°, 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -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) MPG -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 gal MPG-01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG-02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG-05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG-07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG-08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG-09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG-10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG-11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG-12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 , MPG-13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG-15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG-16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG-17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 ' MPG-18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG-19 2041920 50029232280000 1.6 NA 1.6 NA 13.6 8/15/2011 STATE OF ALASKA A~ OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS ~~~ 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ®Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESPi ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development~ ^ Exploratory 204-020 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23194-00-00 7. KB Elevation (tt): KBE = 63 70' ~ 9. Well Name and Number: . MPG-18 8. Property Designation: 10. Field /Pool(s): ADL 025906 ~ Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8421 - feet true vertical 4184 ~ feet Plugs (measured) 5400 Effective depth: measured 8421 - feet Junk (measured) N/A true vertical 4184 ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 3191' 10-3/4" 3226' 2390' 5210 2480 Intermediate Production 5527' 7-5/8" 5560 4227' 6890 4790 Liner 3083' 4-1/2" 5338' - 8421' 4142' - 4184' 8430 7500 Perforation Depth MD (tt): Slotted 5531' - 8377' Perforation Depth TVD (ft): Slotted 4222' - 4187' 2-7/8", 6.5# L-80 5245' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 8 138 1626 320 219 Subsequent to operation: 10 180 2423 280 228 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram , ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Nick Frazier, 554-5633 N/p Printed Name Sondra Stewman Title Drilling Technologist Prepared ey Name/Number S' nature _ Phone 564-4750 Date C~'-ZS~~ Sondra Stewman 564-4750 Form 10-dU4~Revised 04/2006.. ~~l~~j ~~ ~ ^~~ } n~, ~,~r~~~ ~„ Submit Original Only ~~1~ Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 11"x 11" w/ 2-7/8" 8rd T&B Hanger 2.5" CIW "H" BPV profile 20' 178 #/ft .875 thick Driven conductor 10 3/4" L-80 Float Shoe KOP @ 460' 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' 10 3/4" 45.5 ppf L-80 BTRC (Drift ID = 9.794, cap. _ .0961 bpf) 7 5/8" 29.7 ppf, L-80, BTRC-mod production casing ( drift ID = 6.750", cap. = 0.0459 bpf ) 4.5", 12.6#, L-80 IBT tbg. ( cap. _ .0152 bpf, id =3.958 ) 2-7/8" 6.5# L-80 EUE 8rd tubing (drift ID = 2.347", cap. = 0.0058 bpf ) Window in 7" Casing @ 5,278` - 5,290' Well Angle @ window = 54° Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5,351' 7 5/8" Halliburton Float Collar 5,476` 7 5/8" Halliburton Float Shoe 5,560' Q Ori F elev. = 34.00' (Doyon 14) MPG - ~ (~ Ot~. elev.= 29.70' (Doyon 14) Camco 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM Camco 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM 2-7/8" HES XN-Nipple 2.313" bore (2.250"no-go) Centrilift ESP 130-P21 /SXD Centrilift tandem gas sep. GRSFTXARH6 Centrilift tandem seal section GS63DBUT SB/SB PFSA GSB3DBLT SB/SB PFSA 13T 4,979' 5,131 ` 5,184` 5,203' 5,208` Centrilift KMH series 5,221' 190 hp. motor, 2415 v/48 amp Centrilift Pumpmate XTO Sensor 5,238` 6 Fin Motor centrilizer and sacfrificial 5,240' Anode. Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' 6 1/8" Hole td @ 8,563' ~~ Rat Hole OA Upper Lateral 75 jts. - 4 1/2" Slotted Liner z7' 12.6# L-80 IBT (5,380`- 8,490') Btm Baker 4 1/2" Guide Shoe 8,536' Baker 4 1/2" CIBP set @ 5400` ~'^'- ~~ ~C)`1~~-1 6 1/8" Hole td @ 8,421' '1`8 ~~c~b~~~ OB Lower Lateral 69 jts. - 4 1/2", 12.6# L-80, IBT ~~' Slotted Liner (5,531'- 8,377') ~~ lq Btm Baker 4 1/2° Float Shoe 8,421' ~ DATE REV. BY COMMENTS 04/03/04 MDO Drilled & Completed Doyon 14 05/19/06 MDO ESP RWO Tbg. change out N-3S 6-9-08 REH ESP RWO -Nabors 3S 8-31-08 REH ESP RWO -Nabors 4ES MILNE POINT UNIT WELL G-18 API NO: 50-029-23194-60 API NO: 50-029-23194-00 BP EXPLORATION (AK) Page l ,of 1 .Well: MPG-18 • • Well History Well Date Summary MPG-18 8/26/2008 ***WELL SI ON ARRIVAL*** (pre rwo) TRAVELED TO MILNE POINT FROM PRUDHOE ***CONT WST ON 8-27-08*** MPG-18 8/26/2008 T/I/0=200/280/40 Freeze ProtecUln'ectivity Test (Pre-RWO~ Pumped 35 bbls diesel down tubing for infectivity test ana reeze protect, caug t fluid ~ 24 bbls away and established infectivity rate ~ 1.7 bpm ~ 2000 psi. Pumped 2 bbls 60/40 methanol, 3 bbls Diesel, and 2 bbls 60/40 methanol down production and test flowlines. Closed lateral valves and bleed pressure down to 20 psi. FWHP=200/280/40 Swab,wing, ssv closed, Master,lA, and OA open. MPG-18 8/26/2008 ***WELL SI ON ARRIVAL*** (pre rwo) TRAVELED TO MILNE POINT FROM PRUDHOE ***CONT WST ON 8-27-08*** MPG-18 8/27/2008 The Well Support Techs rigged up and removed the wellhouse flowlines and foundation. They then set the BPV after the slicklie work was completed. NOTE: The BPV is IN and the well is ready for the rig!!!!!!!! MPG-18 8/27/2008 ***CONT WSR FROM 8-26-08*** (pre rwo) FISH TOOL STRING FROM 5148' SLM (SWIVELED OFF RIH1 RECOVERED ALL TS24LS PULL 1" BK-DMY GLV FROM 4981' MD, LEFT POCKET OPEN PULL 1" BK-DPSOV FROM 139' MD, SET 1" BK-DMY GLV ASSIST VALVE CREW W/BPV ***WELL S/I ON DEPARTURE, NOTIFY DSO*** MPG-18 8/30/2008 ***SURFACE WORK NABOBS 4ES*** PULLED 1" BK-DGLV, RESET 1" BK-DGLV IN SPM TO BE RUN ON BOTTOM (marked) SET 1 ° BEK-DPSOV IN SPM TO BE RUN ON TOP (marked and flagged) ***JOB COMPLETE, NOTIFIED COMPANY REP AND TOOLPUSHER OF MANDREL CONFIGURATION*** MPG-18 9/2/2008 T/I/0=0/25/0 Freeze Protect Post RWO) Pumped 25 bbls 60/40 methanol and 15 bbls Dead Crude down tubing. umpe 6 s ea efh'anol and 65 bbls Dead Crude down IA. FWHP=0/20/0 Master, Swab, SSV, and Wing Closed. IA and OA open. MPG-18 9/2/2008 The Well Support Techs rigged up and set the foundation, installed the flowlines and wellhouse. They then pulled the back pressrue valve and leak tested the flowlines to 1150 psi. NOTE: The BPV was left OUT and the Leak test was GOOD!!!! Print Date: 9/25/2008 Page 1 of 1 BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 8/27/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/31/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/28/2008 02:00 - 04:00 2.00 MOB P PRE PJSM. Scope and lay over derrick. Prepare to move off of MPU H-09. Clear location and prep rig for move. 04:00 - 06:00 2.00 MOB N WAIT PRE Wait on trucks. 06:00 - 10:30 4.50 MOB P PRE Move rig and components from MPF pad to MPG pad. 10:30 - 11:30 1.00 RIGU P PRE Spot sub over well. Spot pipe shed and pits. 11:30 - 15:00 3.50 RIGU P PRE PJSM on raising and scoping derrick. Raise and scope derrick. Rigging up circulating lines to tree and I/A and to blowdown tank. '"ACCEPT RIG ~ 15:00-HRS." 15:00 - 15:30 0.50 RIGU P PRE Pre-spud meeting to discuss plan forward and scope of workover. 15:30 - 16:30 1.00 WHSUR P DECOMP Make up~ubricator to swab valve P/T lubricator to 500-osi. MPU Well Su ort ull BPV. lay down lubricator. Take on fluid to pits. 16:30 - 17:00 0.50 KILL P DECOMP PJSM -Killing well at MPU. ~SITP = 450-psi, SICP = 500-psi, OAP = 500-psi. Notified pad operator and MPU Front Desk of gas venting. Bled tubing and IA off to blowdown tank. 17:00 - 19:30 2.50 KILL P DECOMP Bullhead 35-bbls 1%KCI down Tbg ~ 4.0-BPM ~ 110-psi.. Bullhead 300-Bbls. 1%KCI down IA ~ 4-BPM G~ 175-psi. Bullhead 35-Bbls. down Tbg t~ 3.6-BPM G~ 70-psi. Monitor well for 30-minutes. Tbg on vac. Bleed IA from 90-psi to 0-psi, OA at 0-psi. 20:00 - 21:00 1.00 WHSUR P DECOMP FMC wellhead tech T-bar in TWC. Test TWC above to 3500- si. Hold and chart test for 10-minutes. Good test. Attempt to test TWC below to 500-asi. Unable to get any pressure below TWC. Bullhead 40-bbls to formation pumping at 6-bpm with 144-psi. 21:00 - 23:00 2.00 WHSUR P DECOMP PJSM -Lower beaver slide and ND tree. Lower the beaver slide and ND production tree. FMC wellhead tech bleed pressure off of test ports. Move tree out of cellar. Inspect hanger threads. Fill well with 30-BPH while ND tree. 23:00 - 00:00 1.00 BOPSU P DECOMP PJSM - NU BOP stack. NU BOP stack, Choke & Kill lines, Riser. Fill well with 30-BPH while NU Stack. 8/29/2008 00:00 - 01:00 1.00 BOPSU P DECOMP Continue NU BOP stack, choke & kill lines, riser. 01:00 - 01:30 0.50 BOPSU P DECOMP RU to test BOPE. MU test jt. Fill BOP stack. Inspect Koomey and choke manifold. PJSM -Testing BOPE. 01:00 - 07:30 6.50 BOPSU P DECOMP Test BOPE per BP and AOGCC procedures. Tested all BOPE components to 250-psi for low pressure test and 3500-psi for high pressure test. Held and charted all tests for 5-minutes. Test 2-7/8" x 5" VBR's and Hydril GX annular preventer using 2-7/8" donut test jt. Witness of BOP test waived by AOGCC rep Chuck Scheve. All tests witnessed by BP WSL and Nabors TP. Troubleshoot pressure bleed off in high pressure tests. Tighten LDS. Rig down BOPE test equipment. 07:30 - 08:00 0.50 WHSUR P DECOMP PJSM -Pull TWC. Make up Lopso-Opso to tubing hanger. Make u lubricator to Lopso-Opso. PR lubricator/lopso-Opso to 50 - si P and Lopso-Opso. Tubing and IA on vacuum. 08:00 - 09:00 1.00 PULL P DECOMP PJSM -Unland tubing hanger. Make up 2-7/8" 8RD. landing joint w/closed TIW valve. Screw landing joint into tubing hanger. BOLDS. Unland and hoist hanger to floor. P/U wt. _ 50K. Centrilift disconnect ESP cable and FMC pull wellhead penetrator from hanger. Open TIW valve and confirm tubing dead. Break out and lay down hanger, landing joint and TIW Printed: 9/15/2008 3:34:02 PM BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 8/27/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/31/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/29/2008 08:00 - 09:00 1.00 PULL P DECOMP valve. 09:00 - 10:30 1.50 PULL P DECOMP Pull ESP cable over cable sheave and through containment hose to cable spooler. POH w/ESP completion standing 2-7/8" tubing in derrick and spooling ESP cable to empty reel in cable spooler. Filling hole at rate of 30-BPH with MPU produced water while POH. 10:30 - 11:00 0.50 PULL N WAIT DECOMP BP ESP cable spooler malfunctioning. Repaired same. 11:00 - 15:00 4.00 PULL P DECOMP POH w/ESP completion standing 2-7/8" tubino in derrick and spooling ESP cable to empty reel in cable spooler. Filling hole at rate of 30-BPH with MPU produced water while POH. 15:00 - 16:00 1.00 PULL P DECOMP Centrilitt disconnect motor lead flat cable from ESP motor, drain seal sections and stand ESP BHA back in derrick. Attached rope to and pulled ESP cable over cable sheave to cable spooler. 16:00 - 16:30 0.50 PULL P DECOMP Clear and clean rig floor and rig down ESP pulling equipment and tools. 16:30 - 17:30 1.00 BOPSU P DECOMP Nippled down flow nipple and air boots. 17:30 - 18:00 0.50 BOPSU P DECOMP Pre-tour safety meeting. Service rig, inspect derrick and check alarms. 18:00 - 19:00 1.00 BOPSU P DECOMP Nippled up shooting flange to top of annular preventer. 19:00 - 21:30 2.50 DHB P DECOMP Spot E-line unit. PJSM with Schlumberger crew and Baker hand regarding upcoming logging. PU & RU Schlumberger R/CCL logging tools gauge ring, junk basket, lubricator and G _ ackoff. Fill lubricator and pressure test to 500-psi. Good test. 21:30 - 00:00 2.50 DHB P DECOMP RIH with Schlumberger logging tools, gauge ring and junk basket. Zero tools at rig floor and log going in hole. Identify fluid level at 2050'. Ta OA lateral liner to at 5 255'. Continue in hole and sit down on OB lateral liner to at 5 317'. Unable to pass thru liner to .Discuss with rig leadership and Schlumberger, decide run CIBP with extra centralization and attempt to get thru OB lateral liner to with CIBP. POH, logging to surface for correlation. 8/30/2008 00:00 - 01:30 1.50 DHB P DECOMP Schlumberger a-line continue POH, logging to surface. Change out E-line tools. MU 4-1/2" CIBP and setting tool. MU Schlumberger lubricator. 01:30 - 03:30 2.00 DHB P DECOMP RIH with 4-1/2" CIBP on E-line. Identify OA lateral liner top at 5255' (match initial gauge ring log) and OB lateral liner top at 5317' (where gauge ring sat down on initial run). Work a-line tool string into 4-1/2" liner in OB lateral. Able to log down to 5442' (middle of 3rd full jt of blank pipe). PU and position setting tool to set CIBP at 5400' (middle of second blank joint from top of O ateral mer . Fire setting tool. Tool fired with 21-second delay. Good indication of set with line movement and line tension drop off. Log up to OA lateral liner top for correlation. 03:30 - 04:30 1.00 DHB P DECOMP Schlumberger a-line POH to surface. No plug at surface. 04:30 - 06:00 1.50 DHB P DECOMP RD Schlumberger a-line tools and lubricator. ND shooting flange and NU flow nipple. Pre-tour HSE meeting with day crew. 06:00 - 06:30 0.50 BUNCO RUNCMP Service rig, daily derrick inspection, check PVT's and environmental walkaround. 06:30 - 10:00 3.50 BUNCO RUNCMP Centrilift make up and service ESP BHA. Pull ESP cable over cable sheave. Connect cable to motor. Printed: 9/15/2008 334:02 PM BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 8/27/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/31/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/30/2008 10:00 - 16:00 6.00 BUNCO RUNCMP RIH w/ESP completion on 2-7/8" tubing from derrick per running order. Filling hole at 30-Bbls. per hour, checking ESP cable every 2000' and pumping through ESP. Install 89-LaSalle clamps, 5- Protectrolizers, 3- Armsterguards. PU wt = 43 K-Ibs, SO wt = 34 K-Ibs. 16:00 - 17:30 1.50 BUNCO RUNCMP MU tubing hanger and landing jt to tubing string w/closed TIW valve. MU final ESP cable splice. FMC tech install penetrator in tubing hanger. 17:30 - 18:00 0.50 BUNCO RUNCMP Pre-tour HES meeting with night crew. Service rig, perform derrick inspection, location walkaround and PVT checks. 18:00 - 19:00 1.00 BUNCO RUNCMP Centrilife complete final ESP cable splice, install in hanger and verify cable is functional. Land tubing hanger in tubing spool. FMC tech RILDS. 19:00 - 20:00 1.00 BUNCO RUNCMP FMC tech d rod in TWC. Test TWC from above to 3000- si f r 10- harted minutes. Test TWC from below by establishing stable injection rate. Pump at 3.5-BPM with 50-psi for 10 minutes. Chart test. Both tests o 20:00 - 20:30 0.50 BUNCO RUNCMP Safety standdown with Smith's crew, Nabors TP and BP WSL. Focus on BP's 8 golden rules, where they came from, and what they mean to daily operations. 20:30 - 22:00 1.50 BOPSU P RUNCMP Drain BOP stack and ND. Disconnect choke and kill lines. Stand BOP stack back and secure on traveling pedestal. 22:00 - 23:00 1.00 WHSUR P RUNCMP PJSM on PU and NU tree. NU production tree. MPU G-pad operator verify alignment of tree in relation to production lines. FMC wellhead tech test hanger void for 30-minutes to 5000-psi -Good test. Centrilift perform final check of ESP cable -Good test. Fill tree with diesel and test to 5000-psi -Good test. 23:00 - 00:00 1.00 WHSUR P RUNCMP FMC wellhead tech test hanger void for 30-minutes to 5000-psi - Good test. Centrilift perform final check of ESP cable -Good test. Fill tree with diesel and test to 5000-psi -Good test. 8/31/2008 00:00 - 02:00 2.00 WHSUR P RUNCMP PU MPU well su ort lubricator and ressure test to 500- si. Good test. Pull TWC with lubricator. No pressure under TWC. Lubricate in BPV and test below. Bullhead 37-Bbls of produced water to formation at 4-BPM seeing 50 to 75-psi for 10 minutes. Secure cellar and well. **Release Ri at 0200-hrs on 8/31/08.** Printed: 9/15/2008 3:34:02 PM STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: , ^ Abandon ®Repair Well ^ Plug Perforations ®Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-020 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23194-00-00 7. KB Elevation (ft): KBE = 63.70' 9• Well Name and Number: MPG-18 8. Property Designation: 10. Field /Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8421 • feet true vertical 4184 • feet Plugs (measured) N/A Effective depth: measured 8421 feet Junk (measured) N/A true vertical 4184 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 3191' 10-3/4" 3226' 2390' 5210 2480 Intermediate Production 5527' 7-5/8" 5560 4227' 6890 4790 Liner 3083' 4-1/2" 5338' - 8421' 4142' - 4184' 8430 7500 ~~ ~~~~ Perforation Depth MD (ft): Slotted 5531' - 8377' °'' ~ J~~, ~ ~ 2~~$ Perforation Depth TVD (ft): Slotted 4222' - 4187' 2-7/8", 6.5# L-80 5246' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Acid Treatment (05111/2008) Attached Well Service Report and Well History Report. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A •rf C.O. Exempt: Contact Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist 'n,~ ~ ~ Prepared By Nam mber l Sign ure - Phone 564-4750 Date ~~1"~"~Sondra Stewman, 564-4750 ~: zu ~ y 4 4 ^,.c 5hras~~ Form 10-404 Revised 04/2006 .t -. ,I~I~ `~ ~ ~QQB Submit Original Only z. a.~ ~..~~ ~ ~~ ~ ~ ~ V~ t~ ~ ~a e Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 11"x 11" w/ 2-7/8" 8rd T&B Hanger 2.5" CIW "H" BPV profile I ~~~ 20' 178 #/ft .875 thick Driven conductor 10 3/4" L-80 Float Shoe KOP @ 460' 43+ degree from 1,500' Max hose angle = 63 degree @ 2,200' MPG' 1 O\~1 OO~L eelev.= 29.070' (Doyon 14) Camco 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM Camco 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM 2-7/8" HES XN-Nipple 2.313" bore (2.250"no-go) 10 3/4" 45.5 ppf L-80 BTRC (Drift ID = 9.794, cap. _ .0961 bpf) 7 5/8" 29.7 ppf, L-80, BTRC-mod production casing ( drift ID = 6.750", cap. = 0.0459 bpf ) 4.5", 12.6#, L-80 IBT tbg. ( cap. _ .0152 bpf, id =3.958 ) Centrilift ESP 130-P21 /SXD Centrilift tandem gas sep. GRSFTXARH6 Centrilift tandem seal section GS63DBUT SB/SB PFSA GS63DBLT SB/SB PFSA 2-7/8" 6.5# L-80 EUE 8rd tubing (drift ID = 2.347", cap, = 0.0058 bpf ) Centrilift KMH series 190 hp. motor, 2415 v/48 amp Centrilift Pumpmate XTO Sensor 6 Fin Motor centrilizer Window in 7" Casing @ 5,278' - 5,290' Well Angle @ window = 54° Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5,351' Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' 6 1/8" Hole td @ 8,563' 139' 4,981' 5,132' 5,185' 5,204` 5,209` 5,223` 5,240` 5,241 ` 75 jts. - 4 1/2" Slotted Liner RaZ~ ole OA Upper Lateral 12,6# L-80 IBT (5,380`- 8,490') Btm Baker 41/2" Guide Shoe 8,536` 6 1/8" Hole td @ 8,421' 7 518" Halliburton Float Collar 5,476' ~ ~ 7 5/8" Halliburton Float Shoe 5,560' OB Lower Lateral 69 jts. - 4 1/2", 12.6# L-80, IBT Slotted Liner (5,531 `- 8,377') Btm Baker 4 1 /2" Float Shoe 8,421' DATE REV. BY COMMENTS UNIT MILNE POINT ` 04/03/04 MDO Drilled & Completed Doyon 14 WELL G-18`~--.~ API NO: 50-029-23194-60 05/19/06 MDO ESP RWO Tbg. change out N-3S API NO: 50-029-23194-00 6-9-08 REH ESP RWO -Nabors 3S BP EXPLORATION (AK) BP EXPLORATION Page 7 of 2 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 6/7/2008 End: 6/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code ~ NPT Phase ~ Description of Operations 6/6/2008 22:00 - 22:30 0.50 MOB P PRE Rig down floor and prep to lower mast. 22:30 - 00:00 1.50 MOB P PRE Scope down mast, lower mast onto carrier and secure. 6/7/2008 00:00 - 02:00 2.00 MOB P PRE Unhook lines between components. Remove berming from around rig and prepare to move rig. 02:00 - 03:00 1.00 MOB P PRE Move pipeshed off of mats and stage on location. Move pits away from carrier. Move carrier off of MPA-02. Pad Operator and WSL were present when moving off well. 03:00 - 04:00 1.00 MOB P PRE Move from MPA-Pad to Tract 14 road to MPG-Pad. 04:00 - 06:00 2.00 MOB P PRE Stage components on MPG-Pad and prep to lay mats and herculite. Spot BOPE Cradle behind the well. 06:00 - 07:30 1.50 RIGU P PRE Lay mats around well slot MPG-18 and herculite for the Carrier. 07:30 - 11:30 4.00 RIGU P PRE Back the Carrier over well slot MPG-18 with the Pad Operator, WSL and Toolpusher present. Repeat several times to allow proper spacing of Pipe Shed and Pits due to tight location and soft pad due to rain and meltwater. Jack and level the Carrier. Lay mats and Herculite and spot the Pipe Shed and Pits. 11:30 - 17:00 5.50 RIGU P PRE Connect the Pipe Shed and Pits to the Carrier. Spot, berm and RU the Tiger Tank with Prudhoe Well Support Techs. Raise and scope the Derrick at 14:00 hrs. RU circulating lines to the Tree. The Rig was accepted at 15:30 hrs on 6/7/2008. Continue rigging up to kill the well. 17:00 - 18:00 1.00 KILL P DECOMP Pressure test surface lines to 3,500 psi. Pressure test hardline to tiger tank to 500 psi. Good test. 18:00 - 19:30 1.50 KILL P DECOMP R/U lubricator and pressure test to 500 psi with diesel. Pull, CIW 2-1/2" T e H BPV. 260 psi on the tubing and 240 psi on the IA. 0 psi on the OA. UD lubricator. 19:30 - 20:30 1.00 KILL P DECOMP Bleed off gas, came off quickly. Pump 35 bbls of 140 degree, 8.45 ppg seawater down tubing lined up to take returns out the IA through the choke manifold to the tiger tank. Pump at 3 bpm with 80 psi, no returns. 20:30 - 23:00 2.50 KILL P DECOMP Bullhead 300 bbls of 140 degree, 8.45 ppg seawater down IA at 3 bpm with 70 psi pump pressure. 23:00 - 23:30 0.50 KILL P DECOMP Bullhead 35 bbls of 140 degree, 8.45 ppg seawater down tubing at 3 bpm with 110 psi. 23:30 - 00:00 0.50 KILL P DECOMP Monitor well, 0 psi on tubing, 0 psi on IA and 0 psi on OA. Both tubing and IA are on a vacuum. 6/8/2008 00:00 - 00:30 0.50 KILL P DECOMP Blow down and R/D circulating lines. 00:30 - 01:00 0.50 WHSUR P DECOMP FMC tech installed 2-1/2" CIW Type H TWC with T-ba[. Test TWC to 3,500 psi for 10 minutes on the chart. 01:00 - 02:00 1.00 WHSUR P DECOMP N/D Tree, clean and inspect wellhead. Inspect hanger threads and lock down screws. Gravity feed IA with 30 bph of seawater. 02:00 - 05:30 3.50 BOPSU P DECOMP N/U 13-5/8" 5M BOP Stack. Hook up choke line, kill line and koomey lines. Hook up turnbuckles and install riser. Gravity feed IA with 30 bph of seawater. 05:30 - 06:30 1.00 BOPSU P DECOMP Function test ROPE, fill stack and choke manifold. 06:30 - 11:00 4.50 BOPSU P DECOMP Pressure test BOPE to 250 / 3,500 psi per BP / AOGCC Regulations. The state's right to witness the test was waived by Chuck Scheve. All tests witnessed by WSL and Toolpusher. The VBR's and Annular were tested with 2-7/8" Test Joint. 11:00 - 12:30 1.50 WHSUR P DECOMP PUMU Opso Lopso with 2-7/8" EUE 8rd XO. PUMU Lubricator ~ and Polished Rod with WeII Support Techs. Pressure test to 500 psi with diesel -good. Pull 2" Type "H" TWC -the well is Printed: 7/1/2008 3:07:39 PM BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 6/7/2008 End: 6/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/8/2008 11:00 - 12:30 1.50 WHSUR P DECOMP on a vacuum. LD Lubricator and Polished Rod. LD Opso Lopso. 12:30 - 14:30 2.00 PULL P DECOMP PU Landing Joint with TIW Valve and screw into the Hanger with 10 turns. BOLDS with FMC rep. Check the IA and it is on a vacuum. Pull the Hanger off seat with 60K and pull to the floor with 55K. Pump 30 bbls (tubing volume) of seawater down the Tubing at a rate of 4 bpm / 150 psi. LD the Hanger and Landing Joint. 14:30 - 20:00 5.50 PULL P DECOMP Cut the ESP Cable at the Penetrator and tie onto rope. Pull the rope over the Sheave. POOH with existing 2-7/8", 6.5#, L-80, EUE 8rd Tubing ESP Completion standin back in the Derrick. Maintain 30 b h fill rate while POOH. Replaced five joints due to galled threads. No indication of scale on any of the Tubing. 20:00 - 22:30 2.50 PULL P DECOMP B/O and UD ESP assembly. There was moderate pitting on ESP body where cable was laying. Maintain 30 bph fill rate. Recovered 89 Lasalle clamps, 5 protectolizers and 3 flat guards. 22:30 - 00:00 1.50 PULL P DECOMP Clear and clean rig floor. R/D containment trunk. 6/9/2008 00:00 - 03:00 3.00 BUNCO RUNCMP P/U ESP assembl ,service and fill with oil. Attach power cable to ESP and check conductivity. Maintain 30 bph fill rate. 03:00 - 08:30 5.50 BUNCO RUNCMP RIH with ESP on 2-7/8" 6.5# L-80, EUE 8rd tubin .Use Best-O-Life 2000 pipe dope. Maintain 30 bph fill rate. Ran a total of 163 Joints of 2-7/8" Tubing, 90 LaSalle Clamps, 5 Protectolizers and 3 Flat Guards. 08:30 - 09:00 0.50 BUNCO RUNCMP Flush the ESP a final time at a rate of 0.75 bpm / 300 psi. 09:00 - 09:30 0.50 BUNCO RUNCMP PUMU Landing Joint and Tubing Hanger. Install Penetrator and orient per FMC rep. Cut the ESP Cable and tail over the Sheave. Obtain final PUW = 50K ,final SOW = 33K. 09:30 - 11:00 1.50 BUNCO RUNCMP Perform ESP Penetrator splice with Centrilift rep. 11:00 - 11:30 0.50 BUNCO RUNCMP Land Tubing Hanger and RILDS with FMC re . 11:30 - 12:30 1.00 WHSUR P RUNCMP PU T-bar and set 2" Type "H" TWC with FMC rep. Pressure test from above to 3,500 psi for 10 charted mins -good. Unable to test from below due to vac. 12:30 - 15:30 3.00 BOPSU P RUNCMP ND 13-5/8" BOPE and DSA. Set in Cradle and remove from Cellar. 15:30 - 18:00 2.50 WHSUR P RUNCMP N/U adaptor flange and 2-9/16" tree. Test hanger void to 5,000 psi for 30 minutes. Test tree to 5,000 psi with diesel. 18:00 - 20:00 2.00 WHSUR P RUNCMP R/U lubricator and test to 500 psi, pull 2-1/2" CIW Type H TWC and set CIW Type H BPV. Secure well and cellar. Ri released at 20:00 hours on 6/9/2008 Printed: 7/7/2008 3:07:39 PM digital Well File ~ Page 1 of 1 Well: MPG-18 Well History Well Date Summary MPG-18 4/26/2008 T/I/0=300/310/40. (MIT T to 2000 psi.). Load tbg w/ 15 bbls diesel. MIT T to 2000 psi. Passed. Lost 10 psi in first 15 minutes & 0 psi in second 15 minutes. Total loss of 10 psi. Bleed tbg pressure down to 300 FW H P=300/310/40. MPG-18 4/26/2008 *** WELL FLOWING ON ARRIVAL **** TUBING TEST PULL DPSOV @ 138' SET DUMMY VALVE @138 SLM RAN2.313 CAT STANDING VALVE C~ 5138' SLM PRESSURE UP TO 2000 PSI FOR 30 MIN GOOD TEST PULL CAT PULL DUMMY C~ 138' SLM SET DPSOV @ 138 ' ***JOB COMPLETED *** MPG-18 5/3/2008 ASRC Test Unit #5, Move unit to MPG-pad, S/B for bed truck, Start R/U, ***Job in progress*** MPG-18 5/4/2008 ASRC Unit #5, 6 hour test **job complete** MPG-18 5/6/2008 T/I/0= 220/200/180 (IA Flush) Pumped 90 bbls Dead Crude down IA while well was online. FWHP= 220/180/280 ** Annulus valves open to gauges ** MPG-18 5/8/2008 ASRC Unit #5, divert well, stabilize, start test **job in progress** MPG-18 5/9/2008 ASRC Unit #5, 6 hour test **job complete** MPG-18 5/11/2008 T/I/0=260/260/280 Acid Treatment Pumped 20 bbls Dead Crude down tubing for infectivity. Followed by 10 bbls 7.5% DAD Acid, 3 bbls 60/40 methanol and 18 bbls Dead Crude for displacement. FW H P=200/180/0 MPG-18 6/3/2008 T/I/0=240/240/240 (Freeze Protect) Pumped 15 bbls Diesel down tubing. Pumped 2 bbls 60/40 methanol, 3 bbls diesel C~ 90*F and 2 bbls 60/40 methanol down production and test flowlines. FH W P=240/220/180 MPG-18 6/5/2008 Well Support Techspulled wellhouse, production lines and foundation. Set the BPV with help of the SL unit boom. ******NOTE****** BPV is set. MPG-18 6/5/2008 *** WELL SI ON ARRIVAL *** (pre rwo) PULLED 1" BK-DGLV FROM 4981' MD, LEFT OPEN PULLED 1" BEK-DPSOV FROM 138' MD, SET 1" BK-DGLV WELL SUPPORT SET BPV *** TURN WELL OVER TO DSO *** MPG-18 6/8/2008 ***SURFACE WORK 3S*** VERIFIED 1" BK-DGLV IN SPM TO BE RUN ON BOTTOM SET 1" BEK-DPSOV IN SPM TO BE RUN ON TOP ***JOB COMPLETE*** MPG-18 6/10/2008 T/I/0=0/0/0 Freeze Protect (Post RWO) -Pumped tbg w/15 bbls 100*F crude. Pumped IA w/80 bbls 100*F crude. Verify casing valves open to gauges, tag well & notify operator. Final WHP's=0/0/0 MPG-18 6/17/2008 G-18 Pressure tested. Test and Prod flow -lines to 1150 PSI for 10.min with diesel. Print Date: 7/1/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 7/1/2008 WELL SERVICE REPORT ~ • WELL JOB SCOPE UNIT ~PiG~18 ACID LRS 64 DATE DAILY WORK DAY SUPV 5/11/2008 ACID TREATMENT IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSGPDWLI8-C LRS-ROBUSTELLINI PERL MIN ID DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY T/I/0=260/260/280 Acid Treatment Pumped 20 bbls Dead Crude down tubing for infectivity. Followed by 10 bbls 7.5% DAD Acid, 3 bbls 60/40 methanol and 18 bbls Dead Crude for displacement. FWHP=200/180/0 LOG ENTRIES Init-> 260 260 280 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 17:00 Start ticket, PU procedure from co rep, road to location 17:30 Arrive & inspect location, spot in support e ui ment, PJSM, UWP, RU to tree ca 18:00 O erator SI well 18:10 C/O Fowler for Robustellini 18:27 PT to 3500 si. 18:45 .75 start crude 80" 450 280 180 Start um in down tubin . 18:47 1 2 450 280 180 increase rate. 18:51 1.30 6 500 280 180 18:59 1.3 16 550 260 140 19:02 1.3 20 650 260 140 Swa to acid. 19:04 1 start acid 20"F 650 260 140 Start acid. 19:06 1.1 2 500 260 140 19:08 1.7 5 900 260 140 19:11 1.7 10 1700 260 140 Shut down. Swa to methanol. 19:13 1. start 60/40 20"F 400 260 140 start 60/40 19:17 1 3 400 260 140 Shut down. Swa to crude. 19:19 1 start crude 80"F 500 260 140 Start crude. 19:21 1.2 3 900 260 100 19:32 1.2 18 1000 260 100 Shut Down. RDMO. 20:59 End Ticket. Final-> 200 180 0 SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL LITTLE RED $1,370 $1,370 LITTLE RED PLUS 20 PERCENT $274 $274 SCHLUMBERGER $2,156 $2,156 WAREHOUSE $119 $119 TOTAL FIELD ESTIMATE: $3,919 $3,919 FLUID SUMMARY 38 bbls crude 3 bbls 60/40 methanol 10 bbl acid Page 1 of 1 http://apps2-alaska.bpweb.bp.com/sst_drilling_wells/well_events_query/wellevent_awgs.asp?ID=64025E20... 7/1/2008 STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 6/8/2008 Rig Rep.: J.Greco/J.Fritts Rig Phone: 659-4487 Rig Fax: 659- 4486 Operator: BP Op. Phone: 659- 4485 Op. Fax: 659-4628 Rep.: W.Hoffman/B.Burson ~' Field/Unit 8~ Well No.: MP G-18 PTD tt 204020Q Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Ar~ar: 250!3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Wei Sim P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 135/8 5000 P Pipe Rams 1 2 7/8" x 5" P Lower Pipe Rams Blind Rams 1 Bfmd P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: V'~sual Test Alarm Tes# Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Quantify Test Result Upper Kelly Lower Kelly BaN Type 1 P Iruide BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes i P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1750 P 200 psi Rttained 27.sec P FuN Pressure Attained 1 min 32.sec P Blind Switch Covers: AN stations P Nitgn_ Bottles (avg): 4(c~1900 Test Results Number of Failures: 0 Test Time: 4_5 Hours Repair or replacement of equipment w~ be made within Inspector 659-3607, follow with written conf~mation to S~enriser at: Remarks: Tested with 2 7/8 test it /tested a~ components 24 HOUR NOTICE GIVEN YES X NO Date 06/07/08 Time 0500 hrs Test start 6:30 Fir>!sh BOP Test (for rigs) ~~~ ~uj~ ~ ~ ~~~~ BFL 11/14/07 Components tested ALL days. Notify the North Slope By .Chuck Sheve Witness J. Greco/ W.Hoffman Nabors 3S BOP Test MPG-18 6-8-08.x1s • • °.~.-~. . MICROFILMED 03101 /2008 DO NOT PLACE >..ti.: . ~.-~` ~~; 7 n '!M. ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc f>/.. RECE\Vt:U STATE OF ALASKA Q 10 ALA. OIL AND GAS CONSERVATION COM SION JUL 1 4 2006 REPORT OF SUNDRY WELL OPERATIONS . &6 C S Commission Alaska 011 as on. 1. Operations Performed: o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 204-020 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23194-00-00 7. KB Elevation (ft): KBE = 63.70' 9. Well Name and Number: MPG-18 8. Property Designation: 10. Field 1 Pool(s): ADL 025906 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 8421 feet true vertical 4184 feet Plugs (measured) NIA Effective depth: measured 8421 feet Junk (measured) NIA true vertical 4184 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 3191' 10-3/4" 3226' 2390' 5210 2480 Intermediate Production 5527' 7-5/8" 5560 4227' 6890 4790 Liner 3083' 4-1/2" 5338' - 8421' 4142' - 4184' 8430 7500 - '''~ .A;.·"i~¡';"r 'i;,.;' Ù"\;.I :.~. ""' Perforation Depth MD (ft): Slotted 5531' - 8377' Perforation Depth TVD (ft): Slotted 4222' - 4187' 2-718",6.5# L-80 5247' Tubing Size (size, grade, and measured depth): 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. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 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: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant - -->. -~ Prepared By Neme/Number: SiQ15'ature )~')'v'J·ç.À .k'~::: --1 I'')'X ~ Phone 564-4750 DatE() . -( YC p Sandra Stewman, 564-4750 .~--,..- ~~~. -- "'''... . . Form 1 0-404 Revised 04/2006 ORIGINAL ?~., R8DMS 8FL JUL 1 4 1006 Submit Onglnal Only Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 A 11"x 11" wI 2-7/8" 8rd T&~ Hanger 2.5" CIW "H" BPV profile 20' 178 #/ft .875 thick Driven conductor 120' 103/4" L-80 Float Shoe I 3,226'1 KOP @ 460' 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' 103/4" 45.5 ppf L-80 BTRG (Drift ID = 9.794, cap. = .0961 bpI) 75/8" 29.7 ppf, L-80, BTRG-mod production casing (drift ID = 6.750", cap. = 0.0459 bpf) 4.5", 12.6#, L-80 IBT tbg. (cap. = .0152 bpi, id =3.958) 2-718" 6.5# L-80 EUE 8rd tubing (drift ID = 2.347", cap. = 0.0058 bpf ) Window jn 7" Casing @ 5,278' - 5,290' Well Angle @ window = 540 Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7-5/8" x 5-112" HMC Liner Hanger 5,351' 75/8" Halliburton Float Collar 5,476' 7 S/8" Halliburton Float Shoe S,S60' DATE REV. BY 04/03/04 05/19/06 MOO MOO Drilled & Completed Doyon 14 ESP RWO Tbg. change out N-3S MPG-18\L\ _ OF elev. = 34.00' (Doyon 14) _ GL. elev.= 29.70' (Doyon 14) Gamco 2-7/8" x 1" wI BK latch sidepocket KBMM-2 GLM Cameo 2-7/8" x 1" wi BK latch sidepocket KBMM-2 GLM 2-7/8" HES XN-Nipple 2.313" bore (2.250"no-go) Centrilift GC2200 ESP GPMTAR 1:1 122 stages Centrilift tandem gas sep. GRSFTXAR Centri/ift tandem seal section GSB3DBUT AB/HSN PFSA GSB3DBL T AB/HSN FSA GL-5 Centrilift KMH 562 series 152 hp. motor, 2325 v/40 amp Centrilift Pump mate sensor 6 Fin Motor centrilizer Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' 6 1/8" Hole td @ 8,563' 75 jts. - 4 1/2" Slotted Uner 12.6# L-80 IBT (5,380'- 8,490') OA Upper Lateral 1 138' I 4,981'1 I 5,132' 1 15,185'1 15,205' I 15,210' 1 15,224'1 15,238'1 15,243'1 Rat Hole 27' Btm Baker 4 112" Guide Shoe 8,536' 61/8" Hole td @ 8,421' OB Lower Lateral 69 jts. - 41/2", 12.6# L-80, IBT Slotted Liner (S,531 '- 8,377') COMMENTS Btm Baker 4112" Float Shoe 8,421' MILNE POINT UNIT WELL G-18 API NO: 50-029-23194-60 API NO: 50-029-23194-00 BP EXPLORATION (AK) e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/15/2006 Rig Release: Rig Number: N3S Spud Date: 2/15/2004 End: 5/17/2006 00:00 - 07:00 7.00 RIGU P DECOMP R/U on MPG-18. 07:00 - 10:00 3.00 RIGU P DECOMP Accept rig. Rig spotted and rigged up. Stabbing board MU in Derrick. RU Flowback tank and hardline. Hang ESP Shieve in the Derrick Fill pits with 140 deg F Seawater. 10:00 - 14:00 4.00 KILL P DEGOMP Pull BPV. WHP's T / IA I OA of 425 / 560 1140 psi. Remove Stack from Tioga Hot Air Heater from Pipe Shed. Wind blew it from its moorings. Pump 40 Bbls 140 deg F Seawater taking returns to Tiger Tank. Shut in choke and Bullhead 60 Bbls down Tubing. Open choke and pump 260 Bbls of 140 deg F Seawater down Tubing taking returns from the Annulus to Tiger Tank. 360 Bbls total pumped, 160 Bbls returns. Well on Vacuum @ 3/4 Bbllmin. Bleed OA from 800 psi to 100 psi: 14:00 - 23:00 9.00 BOPSU P DECOMP Set TWC and test to 500 psi and 3500 psi from above. Nipple down Tree. Clean seal bore, screw 2 7/8" pup joint into landing nipple threads to confirm integrity, OK. NU BOPE. 23:00 - 00:00 1.00 BOPSU DECOMP Test BOPE to 250 psi Low I 3500 psi High 5/18/2006 00:00 - 05:00 5.00 BOPSU DECOMP Test BOPE to 250 psi Low 13500 psi High 05:00 - 07:30 2.50 PULL DECOMP PUMU lubricator. Pull TWC. SITP = 0 psi. SICP=O psi. UD lubricator. PUMU landing jt. Screw into tubing hanger. Unseat hanger with 35K and pull to floor. Load hole with 290 Bbls of 140 deg F Seawater wi no returns. RU elephant trunk and spooler 07:30 - 12:00 4.50 PULL P DECOMP POH laying down 2 7/8", 6.5 #/ft, L-80 Tbg wI Centrilift ESP. Filling hole with Seawater @ double pipe displacement, no returns. 12:00 - 13:00 1.00 PULL P DEGOMP Confirm wI BP Stores, 2 7/8" 13 CR tubing for new completion just leaving Fairbanks. 75 joints OOH, shut down and send Derrickman into Derrick to clear ice (ice falling down from above onto rig floor) 13:00 - 16:00 3.00 PULL P DECOMP Continue POH laying down 2 7/8" completion. 90 Jts OOH @ 14:30. Joints 105 - 115 (3300' - 3600') were pitted where ESP cable was against tubing. Appears to be electrolysis. Joints 106, 110. and 115 set aside for sending to Tuboscope and examination from production chemist. 16:00 - 21:00 5.00 PULL P DECOMP Continue POH laying down 2 7/8" completion. 21 :00 - 00:00 3.00 CASE P DECOMP R/U Shooting Flange, Riser, SL BOPs, and Lubricator for Junk Basket/Gauge Ring and Caliper Run to 5200' MD. 5/19/2006 00:00 - 05:00 5.00 CASE P DECOMP R/U Shooting Flange, Riser, SL BOPs, and Lubricator for Junk Basket/Gauge Ring and Caliper Run to 5200' MD. PT to 1200 psi. 05:00 - 07:00 2.00 CASE P DECOMP Run SL 6.25" Gauge Ring Drift wI Junk Basket to 5200' MD. 07:00 - 10:00 3.00 CASE P DECOMP MU PDS 40 arm memory caliper on Slickline and RIH to 5200' MD. Caliper to open at 08:00, POH @ 50 fpm logging to surface. Load new completion in pipe shed and strap I rabbit. 10:00 - 13:00 3.00 CASE P DECOMP Look at field data from PDS caliper, and casing looks to be in excellent condition. Send data to PDS Houston for computer analysis. Rig down SLB slickline, clear floor. ND shooting flange, and nipple up riser and pitcher nipple. 13:00 - 16:00 RUNCMP Nabors Crew change. Assess Caliper Log, and no significant corrosion or wall loss in 7 5/8" casing from 5200' to surface. Rig up all equipment to run new completion. 16:00 - 22:00 RUNCMP Pump 150 Bbls of 120 deg F Seawater into well @ 4 BPM 0 psi. PUMU Centrilift ESP BHA. Printed: 5/22/2006 11 :56:03 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/15/2006 Rig Release: Rig Number: N3S Spud Date: 2/15/2004 End: 09:00 - 12:00 3.00 WHSUR P LaSalle Clamps will not fit on 2-7/8" V AM TOP tubing. Consult with town on plan forward. Decision made to run 2-7/8" EUE 8rd tubing throughout the entire completion. Order 2-7/8" EUE 8rd tubing. RUNCMP Remove VAM TOP tubing from Pipe Shed. Gather jewelry for EUE 8rd completion. Clear rig floor. Strap new 2-7/8" EUE 8rd tubing and load into pipe shed. Steam each joint prior to drifting due to ice inside of Tubing. Pumped 147 Bbls downhole. Pump S Bbl seawater in hole every 30 minutes as work on tubulars. RIH wI new Centrilift ESP completion. MU ESP RIH. XN-Nipple threads galled. Call stores for new XN nipple wI 2 ea 10' 2 7/8" L-80 pup joints. MU new XN nipple and pup joints. RIH wI new completion wI torque of 2300 ft-Ib. Checking conductivity of electric cable every 2000' and pumping 10 Bbls thru tubing. P/U and M/U Landing Joint to Tubing Hanger. Install Penetrator and dummy plugs. Space out ESP Cable to Hanger and make electrical connection to the Penetrator. Land Tubing Hanger (S/O = SOk P/U = 32k), RILDS, and install I test TWC to 2,500 psi. N/D BOPE. N/U lockdown flange, tubing head adapter and tree. PIT tubing head adapter and tree to 5000 psi. Centrilift run final checks. 2.8 Balanced, 1 Gig phase to ground, temp 71 deg F, BHP 1588 psi. RUNCMP Secure tree and cellar. Wait on Wells Support for pulling BPV. Rig down stabbing board from Derrick. Freeze protection of well to be done by Wells Group. Set BPV RUNCMP Release Rig @ 12:00. RDMO to MPH-09. 5/20/2006 00:00 - 10:00 10:00 - 12:00 RUNCMP 12:00 - 21 :30 RUNCMP 21 :30 - 22:30 1.00 RUNCMP 22:30 - 00:00 1.50 RUNCMP 5/21/2006 00:00 - 01 :00 1.00 RUNCMP 01 :00 - 05:30 4.50 BOPSU P RUNCMP 05:30 - 09:00 3.S0 WHSUR P RUNCMP 12:00 - 00:00 12.00 WHSUR P Printed: 5/22/2006 11 :56:03 AM / }lp ~~ " ( DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2040200 Well Name/No. MILNE PT UNIT SB G-18 Operator BP EXPLORATION (ALASKA) INC .SÌ1....cL Is- 1~~).6 ~'f API No. 50-029-23194-00-00 MD 8421/ Completion Date 3/1/2004 / Completion Status 1-01L UIC N TVD 4184"- Current Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, IFRlCASANDRA, GYRO Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number }:- .' D Lis - 12551 )žD D "Pt1f ft.s 1..(. Rpt !Æ'D D...Pdt (\J l..lt í i Rpt Directional Survey ~ '. (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval Start Stop 70 8360 5405 8421 5405 8421 5405 8421 5405 8421 o 5578 o 5578 o 5578 Name Induction/Resistivity Directional Survey Directional Survey Directional Survey Directional Survey D Edf ~l\--iL\ I Directional Survey Directional Survey Directional Survey Directional Survey LIS Verification 12552 I nd uction/Resistivity LIS Verification D -f2Ej.f ~ \<..d Rpt I~ 1:98/ D. Lis ~ o o 5418 o Well Cores/Samples Information: OH/ CH Received Open 4/16/2004 3/18/2004 3/18/2004 3/18/2004 3/18/2004 3/18/2004 3/18/2004 3/18/2004 5578 o 5527 o Comments EWR4 GR ABI ROP MWD MWD PB1 PB1 PB 1 MWD 3/18/2004 PB1 MWD 4/16/2004 DSN 12551 Open 4/16/2004 PB1 EWR4 GR ROP 4/16/2004 DSN12552 Name Interval Start Stop Received Sample Set Number Comments Sent ADDITIONAL INFORMATION yGJ Daily History Received? ê0N 'GIN Well Cored? Chips Received? ~ Formation Tops Analysis Received? ~ . I . Permit to Drill 2040200 MD 8421 TVD 4184 Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT, 3/2/2006 Well Name/No. MILNE PT UNIT SB G-18 Operator BP EXPLORATION (ALASKA) INC Completion Date 3/1/2004 Completion Status 1-01L Current Status 1-01L . ·rb API No. 50-029-23194-00-00 UIC N Date: ~ ~~'f) & . . . . WELL LOG TRANSMITTAL d D4- - 0 f(1 D To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 9950 I February 16, 2006 351LÞ RE: MWD Formation Evaluation Logs MPG-18 PB1, 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 MPG-18 PB1: LAS Data & Digital Log Images: 50-029-23194-70 1 CD Rom r ~LQ .:) /99'/ Oft¡ e e 2c) c¡ -(,ì 2. U ) ; ~1- , WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom, Attn,: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 08, 2004 RE: MWD Formation Evaluation Logs MPG-18, AK-MW-2917922 1 LIS fonnatted Disc with verification listing. ~I#: 50-029-23194-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMlITAL LEITER TO THE ATTENTION OF: Speny-Sun 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: 13J~~ ~'1 1Lio~ Signed: e e -> r) L/ _,_ ",,",,- t".' I -,-) L...:;; 1 À \ ~- }- WELL LOG TRANSMIITAL To: State of Alaska Alaska Oil and Gas Conservation Comm., Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 08, 2004 RE: MWD Fonnation Evaluation Logs MPG-18 PB1, AK-MW-2917922 1 LIS fonnatted Disc with verification listing. API#: 50-029-23194-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun 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: } .> J ù.~ ~'1 Signed: ! ,- .- . STATE OF ALASKA I ALASKA"'e'íL AND GAS CONSERVATION COMM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 04/05/04, Start Production 1a. Well Status: Da Oil DGas D Plugged D Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic Test D Service 2. Operator Name: 5, Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/1/2004 204-020 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/15/2004 50- 029-23194-00-00 4a, Location of Well (Governmental Section): 7, Date T.D. Reached 14. Well Name and Number: Surface: 2/23/2004 MPG-18 2134' NSL, 3462' WEL, SEC, 27, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2257' NSL, 2359' WEL, SEC. 27, T13N, R10E, (OB) KBE = 63,70' Milne Point Unit I Schrader Bluff Total Depth: 9, Plug Back Depth (MD+ TVD) 2979' NSL, 5167' WEL, SEC. 27, T13N, R10E, (OB) 8421 + 4184 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 557139 y- 6014569 Zone- ASP4 8421 + 4184 Ft ADL 025906 TPI: x- 558242 y- 6014701 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 555426 y- 6015401 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes Da No N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , GYRO 22, CASING, liNER AND CEMENTING RECORD CASiNG WT.P¡:R··.t'T. . GftA,[)¡: SETTING DEPTHMQ §E11"ING~PTH TVD ...i~~€ i~"", .....,' ..,- SIZE TOP BOTTOM 101" ¡BOTTOM i 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx,) 10-3/4" 45.5# L-80 35' ,3226' 35' 2390' 13-1/2" 460 sx PF 'L', 260 sx Class 'G' 7-5/8" 29.7# L-80 33' 5560 33' 4227' 9-7/8" 420 sx Class 'G' 4-1/2" 12.6# L-80 5338' 8421' 4142' 4184' 6-1/8" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 124. ·"'0'''''''''' Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-12" Slotted Liner 2-7/8",6,5# x 12,6#, L-80 5246' None MD TVD MD TVD 5531' -8377' 4222' - 4187' 25. p.,C¡O,FRÄ¢TURE, QEM¡:NT ·E19· ........... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Dead Crude 26, PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc,): March 18, 2004 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR Oil -BSl GAs-McF W A TER-Bsl CHOKE SIZE GAS-Oil RATIO 3/22/2004 6 TEST PERIOD ... 381 69 164 182 Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF WATER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 1526 277 659 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 eRlGINAL RECEIVED ~~1 ØlsQft APR - 6 2004 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE Alaska Oil & Gas Cons. Commission G ( Anr.þnrar It # -' 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MBZ MB2 MC NA NB NC NE NF OA TSBC OB 4490' 4790' 4807' 4851' 5090' 5123' 5162' 5208' 5242' 5323' 5375' 5440' 5513' 3572' 3808' 3820' 3850' 3997' 4017' 4040' 4067' 4087' 4134' 4162' 4193' 4218' None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr Title Technical Assistant Date 04 - C6-o1 MPG- Well Number 204-020 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Matt Green, 564-5581 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion, ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 . . A STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a, Well Status: IBI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 o Development o Exploratory OGINJ OWINJ o WDSPL No, of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband, 12. Permit to Drill Number BP Exploration (Alaska) Inc, 3/1/2004 I 204-020 3. Address: 6, Date Spudded ,/ 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/15/2004 50- 029-23194-00-00 4a. Location of Well (Governmental Section): 7. Date TD. Reached / 14. Well Name and Number: Surface: 2/23/2004 MPG-18 2134' NSL, 3462' WEL, SEC. 27, T13N, R10E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2257' NSL, 2359' WEL, SEC, 27, T13N, R10E, (OB) KBE = 63.70' Milne Point Unit / Schrader Bluff Total Depth: 9, Plug Back Depth (MD+ TVD) 2979' NSL, 5167' WEL, SEC, 27, T13N, R10E, (OB) 8421 + 4184 Ft 4b. Location of Well (State Base Plane Co¡>rdinates): 10. Total Depth (MD+ TVD) 16. Property Designation: ,/ 8421 + 4184 ./ Ft ADL 025906 Surface: x- 557139 ¡ y- 6014569 Zone- ASP4 TPI: x- 558242 y- 6014701 Zone- ASP4 11, Depth where SSSV set 17, Land Use Permit: Total Depth: x- 555426 ~( y- 6015401./ Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IBI Yes ONo N/A MSL " 1800' (Approx.) 21, Logs Run: P~~wt ~(borL- ~"/ß Ot.S "-"'.... ' -y:~~lú"'"ÂJ 5"t../ I$'/ 1'1"71> ......' ,: MWD , GR , RES, IFRlCASANDRA , GYRO ¡,~ -/BfßI ~ 'II ß 'f /TVÞ 22. -'ASING, liNER AND (;EMENTING RECORD AD V-6"'D~ CA$If'jG ,Un (~?Z~.; ») ; ),;) SIZE .' VV1'.~ER FT.. ~j;)Anc: . lOP IjOTTOM ..... .);, 'i·IO~'·' ""'1;:;'''11;:;111'".,_ 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45,5# L-80 35' 3226' 35' 2390' 13-1/2" 460 sx PF 'L', 260 sx Class 'G' 7-5/8" 29.7# L-80 33' 5560 33' 4227' 9-7/8" 420 sx Class 'G' 4-1/2" 12,6# L-80 5338' 8421' 4142' 4184' 6-1/8" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. i) )... (. i Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) ¡ 4-12" Slotted Liner 2-7/8",6.5# x 12.6#, L-80 5246' None MD TVD MD TVD 5531' -8377' 4222' - 4187' ?§. " p$MEN1". ( DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Dead Crude 26, PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED .. OIL-BSL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r";:-;'-'--;-'::;;';';~'''' . "ÍJP,P,::; ilL'\¡ î , D.:\n:~ None I ~;:/_~:O . OR\GiNAl l-2iHn ! ; . =-/i_~'-_ ¡ ,i ....-"."¥-__"'''''!O-..,.,.,.,'''''~_.,_,.,.::, ~ -," . Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE SBfL APR 6 ~. G RfI)M r~ ¡. 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MBZ MB2 MC NA NB NC NE NF OA TSBC 08 4490' 4790' 4807' 4851' 5090' 5123' 5162' 5208' 5242' 5323' 5375' 5440' 5513' 3572' 3808' 3820' 3850' 3997'" 4017' 4040' 4067' 4087' 4134' 4162' 4193' 4218' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and a Leak-Off Test Summary Report 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant DateCß-~S- MPG-18 Well Number 204-020 Permit No, / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Matt Green, 564-5581 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 Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 _ 11"x 11" wI 2-7/8" 8rd T&B- Hanger 2.5" CIW "H" BPV profile 20' 178 #/ft .875 thick Driven conductor [igQJ 103/4" L-80 Float Shoe 13,226'1 KOP @ 460' 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' 103/4" 45.5 ppl L-80 BTRC (Drift ID = 9,794, cap. = ,0961 bpI) 7518" 29.7 ppl, L-80, BTRC-mod production casing (drift 10 = 6.750", cap. = 0.0459 bpI) 4.5",12,6#, L-80 IBTtbg. ( cap. = .0152 bpI, id =3.958 ) 2-7/8" 6.5# L-80 EUE 8rd tubing (drift ID '" 2.34T, cap. '" 0.0058 bpf ) Window in 7" Casing @ 5,278' - 5,290' Well Angle @ window = 540 Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5,351' 7 5/8" Halliburton Float Collar 5,476' 7 5/8" Halliburton Float Shoe 5,560' DATE REV, BY 04/03/04 MDO Drilled & Completed Doyon 14 COMMENTS MPG-1 &Ill ca:'iF sis\! <.iL. 34.00' (Doyon 14) 29.70' (Doyon 14) Cameo 2-7/8" x 1" w/ BK latch side pocket KBMM-2 GLM Cameo 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM 2-7/8" HES XN-Nipple 2.313" bore (2.250"no-go) Centrìlìft ESP GPMTAR 1:1 122 Centrí!ift seal section GSB3DBUTIILH6PFS AFLAS/HSN Cenlrilìft KMH 5(}2 serìes 152 2325 v/40 amp Centrilift Pump mate sensor 6 Fin Motor centrilìzer Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' 61/8" Hole td @ 8,563' OA Upper Lateral 75 jts, - 4 1/2" Slotted Liner 12,6# L-80 IBT (5,380'- 8,490') I 117' 1 I 5044'1 15,134" 15,187' I 15,208'1 15,213'1 1 5,227' I 15,241'1 15,246'1 Rat Hole 27' Btm Baker 41/2" Guide Shoe 8,536' 61/8" Hole td @ 8,421' OB Lower Lateral 69 jts. - 41/2",12,6# L-80, IBT Slotted Liner (5.531'- 8,377') Btm Baker 4 1/2" Float Shoe 8,421 ' MILNE POINT UNIT WELL G-1S\l\ API NO: 50~029-23194-60 API NO: 50-029-23194-00 BP EXPLORATION (AK) e BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: DRILL+COMPLETE Start: 2/7/2004 End: 3/1/2004 Contractor Name: DOYON DRILLING INC. Rig Release: 3/1/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To ¡Hours Task Code NPT I Phase Description of Operations 2/14/2004 20:30 - 00:00 3.50 MOB P PRE Move off of MPG-17 and Move to MPG-18 2/15/2004 00:00 - 01 :00 1,00 MOB P PRE Rig up MP-G18 Rig accept @ 1 :00 2/15/2005 01 :00 - 03:30 2.50 RIGU P PRE Nipple up Diverter 03:30 - 07:30 4.00 RIGU P PRE Picking up 4" drill pipe 07:30 - 09:30 2.00 RIGU N RREP PRE Repair pump on pipe skate 09:30 - 11 :30 2.00 RIGU P PRE Picking up pipe, mix spud mud 11 :30 - 13:30 2.00 RIGU P PRE Picking up HWP and DC and stand in derrick 13:30 - 15:30 2.00 DRILL P SURF Picking up motor and MWD, Orientate same 15:30 - 17:00 1,50 RIGU P PRE Diverter test, the right to witness test was waiver by Chuck Scheve AOGCC 17:00 - 18:00 1.00 DRILL P SURF Spud meeting with crews, fill Diverter and check for leaks, wash to bottom 18:00 - 00:00 6.00 DRILL P SURF Directional Drill 112' to 515' with 70 rpms, 425 gals min.,1 080 psi, AST 1,75, ART 1.25, running GYRO every stand, started Gyro @ 196' 2/16/2004 00:00 - 00:00 24.00 DRILL P SURF Directional Drill 515' to 3000' with 80 rpms, 485 gals min,,2300 psi running GYRO to 723', AST 12.5, ART 4.42, Saw hydrates @ flow line @ 2480' 2/17/2004 00:00 - 02:00 2.00 DRILL P SURF Directional Drill 3000' to 3235' with 80 rpms, 500 gals min.,2300 psi 02:00 - 04:00 2.00 CASE P SURF Circ Three bottoms up with 100 rpms, 500 gals min. 2050 psi 04:00 - 06:00 2.00 CASE P SURF Pumping out to HWDP with full drilling rate 06:00 - 07:00 1.00 CASE P SURF Flow Check - RIH from 725' to 3235' 07:00 - 09:00 2.00 CASE P SURF CBU 3 X - RPM 80 - TQ 8K 500 gpm - PP 2100 - PU 105K- SO 85K - ROT 95K 09:00 - 10:30 1.50 CASE P SURF Pump out from 3235' to 725' - 5" HWT - Pump at drilling rate 500 gpm 10:30 - 12:00 1,50 CASE P SURF Stand back 5" HWT - Lay down BHA 12:00 - 12:30 0.50 CASE P SURF Clear rig floor - Lay down vendors tools 12:30 - 14:00 1.50 CASE P SURF Rig up 103/4" casing tools - PJSM on running casing 14:00 - 14:30 0.50 CASE P SURF Pick up I make up float equipment - Circ through same 14:30 - 18:30 4,00 CASE P SURF Run 76 Joints of 103/4" 45.5# L-80 BTC casing to 3149' - Wash last joint down from 3149' to 3190' - Make up Hanger / landing joint and land at 3225' - (Tight spot at 2032' circulate - wash down from 2073' to 2156') 18:30 - 19:00 0.50 CASE P SURF Rig down Franks fill up tool - Make up Schlumberger cementing head - cementing lines 19:00 - 21 :00 2.00 CASE P SURF Break circulation - stage up pump from 2 bpm to 9 bpm - Circulate 2 casing volumes - PJSM (cementing casing) 21 :00 - 23:30 2.50 CEMT P SURF Pump 25 bbls water 5 bpm 150 psi - Test lines to 3500 psi - test good - Pump 25 bbls CW 100 @ 5 bpm 220 psi - Pump 75 bbls Mud Push @ 5.6 bpm 250 psi - (1 gallon dye in first 5 bbls pumped) - Drop bottom plug last 5 bbls spacer pumped on fly - Mix and pump 351 bbls 460 sxs Type 'ASL' Yield 4.28 cf/sx mixed at 10.7 ppg - Mix and pump Tail cement 260 sxs Class G with .9% S-001 + .4% 0-167 + m.3% 0-065 + .2% 0-046- Yield 1.17 cf/sx 54 bbls slurry mixed at 15.8 ppg - Kick out top plug with 30 bbls water with Dowell Schlumberger - Turn to Rig for 268 bbls displacement with mud @ 8 bpm 500 psi - Bump plug with 1000 psi over final pressure 1500 psi - CIP 23:30 Hrs - Bleed off pressure - Check floats - Floats holding - (185 bbs 0/ Printed: 3/8/2004 8:35:58 AM BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: DRILL+COMPLETE Start: 2/7/2004 End: 3/1/2004 Contractor Name: DOYON DRILLING INC. Rig Release: 3/1/2004 Rig Name: DOYON 14 Rig Number: 14 I Date From - To Hours Task iCode NPT i Phase I Description of Operations ! 2/17/2004 21 :00 . 23:30 2.50 CEMT P SURF cement to surface) 23:30 - 00:00 0.50 CASE P SURF Rig down Dowell Schlumberger Cementing head - Cementing lines 2/18/2004 00:00 - 02:00 2,00 CASE P SURF Flush Divertor - Lay down landing joint - Flush flow line - Lay down casing tools - Lay down Dowell Schlumberger cementing head 02:00 - 03:30 1.50 CASE P SURF Nipple down Divertor System 03:30 - 04:30 1,00 CASE P SURF Nipple up casing head - Tubing spool - Test casing head to 1000 psi for 10 mins - test good 04:30 - 06:30 2.00 CASE P SURF Nipple up BOP's 06:30 - 07:30 1.00 CASE P SURF Rig up to test BOP's - Install test plug - Open annulus valves - 07:30 - 10:30 3.00 CASE P SURF Test Annular 250 low 2500 high each test 5 mins - Pipe rams - Blind rams - HCR Choke - HCR kill - Manual Choke - Manual kill - Choke manifold - Upper / Lower IBOP - Floor safety valves - Perform Accumulator test - All test good - Chuck Scheve with AOGCC wavied witness of BOP test 10:30 - 11: 00 0.50 CASE P SURF Rig down testing equipment - pull test plug - Install Wear ring - Close Annulus valves 11:00-13:00 2.00 CASE P SURF Make up - Orient 9 7/8" BHA - Surface test MWD 13:00 - 14:30 1.50 CASE P SURF Change out elevators and slips from 5" to 4" - RIH to 3050' - Wash to Float collar @ 3142' 14:30 - 15:00 0.50 CASE P SURF CBU 1 X - GPM 375 - PP 800 psi - RPM 50 15:00 - 16:00 1.00 CASE P SURF Cut drlg line - Con't circ @ 2.5 bpm while cutting drilling line 16:00 - 17:00 1.00 CASE P SURF Blow down top drive - Rig up to test 10 3/4" casing - Test casing to 2500 psi for 30 mins on chart 17:00 - 18:30 1.50 CASE P SURF Drill out Float equipment to 3235' 18:30 - 19:00 0.50 CASE P SURF Drill 20' new hole from 3235' to 3250' 19:00 - 19:30 0.50 CASE N FLUD SURF Mud aired up - Pump not primed - Prime pump - Con't drill to 3255' 19:30 - 20:30 1.00 CASE P SURF PJSM - Displace well with 8.9 ppg LSND mud 20:30 - 21 :30 1.00 CASE P SURF Blow down top drive - Rig up test equipment - FIT - Mud weight 8.9 - MD 3235' TVD 2388' Surface pressure 390 psi - EMW 12,04 ppg 21 :30 . 00:00 2.50 DRILL P INT1 Directional Drill 9 7/8" hole from 3255' to 3599' - WOB 25K - RPM 100 - TO on 5K - off 5K - GPM 450 - PP on 1500 - off 1400 - PU 125K - SO 90K - ROT 95K 2/19/2004 00:00 - 00:00 24,00 DRILL P INT1 Directional Drill from 3599' to TO 97/8" Hole @ 5578' - WOB 25K - RPM 100 - TO on 10K - off 9K - GPM 500 - PP on 2760- off 2540 - PU 180K - SO 95K - ROT 120K Top of NB sand 5175' Top of OA sand 5377' Top of OB sand 5512' 2/20/2004 00:00 - 01 :30 1,50 CASE P COMP CBU 3 X - GPM 500 - PP 2800 - RPM 120 - TO 10K 01 :30 - 05:30 4.00 CASE P COMP Pump out - Pulling @ 400 fph for Mad pass log as per Geologist - from 5573 to 4500' - Pump at drlg rate 05:30 - 07:00 1.50 CASE P COMP Pump out to shoe at Drlg rate from 4500' to 3220' 07:00 - 08:30 1.50 CASE P COMP CBU - (Clay balls) - Flow check - well stable - Pump dry job 08:30 - 10:00 1.50 CASE P COMP POH to BHA 10:00 - 11 :00 1.00 CASE P COMP Lay down BHA 11 :00 - 11 :30 0,50 CASE P COMP Make up Hole opener BHA 11 :30 - 14:30 3.00 CASE P COMP RIH to 5578' - Hole in good shape 14:30 - 17:00 2.50 CASE P COMP CBU 3 X· GPM 525 - PP 2250 - RPM 120 - TO 10K 17:00 - 19:00 2,00 CASE P COMP Pump out to shoe from 5578' to 3220' - Pump at drlg rate ,/ Printed: 3/8/2004 8:35:58 AM Page 3 of 6 BP EXPLORATION Operations Summary Report CBU at shoe - GPM 525 - PP 1460 - RPM 120 - TO 5K - Flow check - Well stable - Pump dry job POH from 3220' to BHA 625' Lay down BHA Change Top rams to 7 5/8" - Pull wear ring - Install test plug -Test door seals to 1500 psi - Pull test plug - Rig up casing tools PJSM (Running casing) - Pick up / make up float equipment - Check floats - Pick up and run 80 joints of 7 5/8" casing to 3203' Circulate 1 casing volume - 1500 stks @ 60 spm - PP 450 Con't Run 7 5/8" 29.7# L-80 BTC-M casing from 3203' to 5538' - Make up landing joint / hanger - RIH from 5538' to 5570' land casing - Lay down Franks fill up tool - Make up Schlumberger cementing head - cementing lines COMP Break circulation staging up pump to 60 spm @ 420 psi - Circulate 2 casing volumes - 5700 strokes - condition mud for cement job COMP Held PJSM with rig crew and service hands. Pumped 5 bbls of CW-100 chemical wash - test lines to 4000 psi - 5 bbls of CW-100 - 15 bbls of 11.1 ppg Mud Push - 420 sxs (86 bbls) Class G cement + .3% 0065 Dispersant + .4% D167 Fluid Loss + .5% S001 Accelerator + ,2% 0046 Antifoam mixed in a 15.8 ppg slurry with a yield of 1.16 cftlsx. Washed cementing lines and kicked out top plug with 5 bbls of water. COMP Displaced cement with rig pumps at 6.0 bpm, Had full returns and good pressure increase as cement was pumped up annulus. Final pumping pressure 780 psi. Bumped plug at 0915 hrs 2-21-2004 with 3500 psi. Pressure tested annulus to 3500 psi for 30 minutes. Recorded on chart. Bled off pressure and float held. Rigged down cementing head and landing joint. Flushed wellhead with water. Install 7-5/8" casing mandrel packoff and tested to 5000 psi for 10 minutes. Remove 7-5/8" rams and installed 2 7/8" X 5" VBR rams - Full body test on BOP's to 2500 psi - Test Rams to 3500 psi Pull test plug close annulus valves - Install wear ring - Change casg bails to drlg bails on top drive Pick up 43/4" DC's and 3 1/2" HWT up from pipe shed - Run in hole - Circulate pipe volume POH Make up Baker Whipstock - MWD - Orient same - BHA - Surface test MWD @ 52 spm @ 600 psi RIH to 2800' - Fill pipe every 25 stds Rig service - Top drive service RIH to 5408' - Fill pipe every 25 stds Orient whipstock to 4R high side - Tag float collar @ 5474' slack off on whipstock 25K - Anchor set @ 10K - PU 10K over to confirm anchor set - Slack off 35K to shear brass bolt - Work down number of times to shear off bolt HMAN PROD1 Milling window @ 5418' to 5427' - WOM 5 - RPM 90 - TO on 5K - off 8K - GPM - 284 - PP 1330 - PU 160 - SO 88 - ROT 105 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 , NPT I Date [ From - To ' Hours Task Code Phase _._.___..:.__L_ --...... ......... ..-- m _........_...___.._ 2/20/2004 19:00 - 19:30 0,50 CASE P COMP 19:30 - 20:00 0.50 CASE P COMP 20:00 - 21 :30 1,50 CASE P COMP 21 :30 - 00:00 2,50 CASE P COMP 2/21/2004 00:00 - 02:30 2.50 CASE P COMP 02:30 - 03:00 0.50 CASE P COMP 03:00 - 05:00 2.00 CASE P COMP 05:00 - 07:30 2.50 CASE P 07:30 - 08:30 1.00 CEMT P 08:30 - 09:30 1.00 CEMT P 09:30 - 10:00 0,50 CEMT P COMP 10:00 - 10:30 0,50 CEMT P COMP 10:30 - 11 :00 0,50 CASE P COMP 11 :00 - 13:00 2,00 CASE P COMP 13:00 - 13:30 0,50 CASE P COMP 13:30 - 15:00 1.50 CASE P COMP 15:00 - 15:30 0.50 CASE P COMP 15:30 - 17:30 2.00 STWHIP N HMAN PROD1 17:30 - 19:30 2.00 STWHIP N HMAN PROD1 19:30 - 20:00 0,50 STWHIP N HMAN PROD1 20:00 - 21 :00 1.00 STWHIP N HMAN PROD1 21 :00 - 21 :30 0.50 STWHIP N HMAN PROD1 21 :30 - 00:00 2.50 STWHIP N Start: Rig Release: Rig Number: Spud Date: 2/15/2004 End: 3/1/2004 2/7/2004 3/1/2004 14 Description of Operations . .- --...-.--..---.----. ....--------------- Printed: 3/812004 8:35:58 AM Page 4 of 6 BP EXPLORATION Operations Summary Report legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Date From - To Hours: Task ; Code NPT Phase 2/21/2004 21 :30 - 00:00 2,50 STWHIP N HMAN PROD1 2/22/2004 00:00 - 02:30 2.50 STWHIP N HMAN PROD1 02:30 - 04:30 2.00 STWHIP N HMAN PROD1 04:30 - 06:00 1.50 STWHIP N HMAN PROD1 06:00 - 07:00 1.00 STWHIP N HMAN PROD1 07:00 - 07:30 0.50 STWHIP N HMAN PROD1 07:30 - 09:30 2.00 CASE P COMP 09:30 - 11 :30 2,00 CASE P COMP 11 :30 - 12:00 0.50 CASE P COMP 12:00 - 13:00 1,00 CASE P COMP 13:00 - 14:00 1.00 CASE N DFAL COMP 14:00 - 14:30 0.50 CASE N DFAL COMP 14:30 - 16:30 2,00 CASE N DFAL COMP 16:30 - 19:00 2,50 CASE N DFAL COMP 19:00 - 20:30 1,50 CASE N DFAL COMP 20:30 - 21 :30 1,00 CASE P COMP 21 :30 - 00:00 2.50 DRILL P PROD1 2/23/2004 00:00 - 23:30 23.50 DRILL P PROD1 23:30 - 00:00 0,50 CASE P COMP 2/24/2004 00:00 - 02:00 2,00 CASE P COMP 02:00 - 04:00 2.00 CASE P COMP 04:00 - 05:00 1.00 CASE P COMP 05:00 - 06:30 1.50 CASE P COMP 06:30 - 07:00 0,50 CASE P COMP 07:00 - 07:30 0.50 CASE P COMP 07:30 - 10:00 2,50 CASE P COMP 10:00 - 12:00 2,00 I CASE P COMP 12:00 - 13:00 1,00 CASE P COMP Start: 2/7/2004 Rig Release: 3/1/2004 Rig Number: 14 Spud Date: 2/15/2004 End: 3/1/2004 Description of Operations .. .._ ____.____._nn ____.. ___ ...__m_. Mill window from 5427' to 5442' - (TOW 5418' - BOW 5430') - WOM 5 - RPM 100 - GPM 285 - PP 1400 Pump Hi Vis sweep surface to surface - saw some increase of metal- (Displace LSND with 10.9 Flo Pro) - Pump Hi Vis spacer - Followed by 10,9 Flo Pro mud - Monitor well - Well Stable - Pump dry job POH with Baker Milling assembly to BHA Stand back HWT - DC's - Lay down Baker Mills and tools - Down load MWD Make up stack washer - Flush BOP's - Pick up bha to rig floor Make up - BHA - Orient Up Load MWD - Make up flex DC's - Shallow pulse test MWD RIH to 5401' Orient BHA - Slide out window - Drill from 5442' to 5452' Pull into casg - Perform FIT - MD 5418' TVD 4183 - Mud Wt 10.8 - Surface pressure 370 psi = EMW 12.5 MWD failure - GAB motor not working - Attempt to diagnose Problem - No success Pump EP mud lube pill - Mix dry job Flow check - Pump dry job - POOH to BHA Handle BHA - Down Load MWD - Change out OM - Up load MWD - Make up BHA - Surface test MWD 5.7 bpm - @ 1300 psi RIH to 5390' Slip cut drlg line - Rig service - Top drive service Orient - Slide through window - Directional Drill from 5452' to 5620' - WOB 10K - RPM 80 - TQ on 8K 8K - off 5K - GPM 250 - PP on 1800 - off 1650 - PU 135 - SO 85 - ROT 105 Directional Drill from 5620' to 'J:P 6 3/4" OB Lateral Hole @ ¡/ 8421' - WOB 5 to 10 - RPM 90 - TQ on 7.5K - off 8K - GPM 254 - PP on 2900 - off 2630 - PU 135K - SO 78K - ROT 100K - ECD 12,5 CBU 3 X - GPM 270 - PP 2500 CBU 3 X - GPM 270 - PP 2500 - ECD 12.3 Pump out from 8421' to 5450' - Pump at drlg rate - Pull through window from 5450' to 5400' with out pumping - 1 OK to 15K over pull @ 5426' to 5423' CBU 1 X - Monitor well - well stable - Pump dry job POH to BHA from 5305' to BHA at 215'. Laid down BHA Clear floor. Rig up to run 4,5" slotted liner. Service top drive and PJSM on running slotted liner. Picked up float joint, 69 jts of 4-1/2' slotted liner, 4 jts of 4-1/2" solid joints and Baker 7-518' X 5-1/2" HMC hanger with ZXP packer. Run in hole with liner on 4' drill pipe to TO at 8421 '. PU weight 140K SO weight 90K. PU and pulled the liner in tension. Broke circulation at 2,5 bpm at 400 psi. Dropped 29/32" ball down drill pipe. Pumped down drill pipe 1/2 drill pipe capacity at 5 bpm slowed down pumps to 2 bpm. Ball on seat. Pressure up to 3500 psi and set hanger and ZXP packer. Held pressure for 5 minutes, Bled pressure off of drill pipe, Pressure tested Printed: 3/8/2004 8:35:58 AM BP EXPLORATION Operations Summary Report Page 5 of 6 legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: DRlll+COMPlETE Start: 2n /2004 End: 3/1/2004 Contractor Name: DOYON DRilLING INC. Rig Release: 3/1/2004 Rig Name: DOYON 14 Rig Number: 14 Date ! From - To Hours ~:~~ _.I_~_~~~ NPT Phase Description of Operations .._..__.... .___ ..._._..___...___ .___.. ___...__..___n__.__" ._____ _n_____._.____ 2/24/2004 12:00 - 13:00 1.00 CASE P COMP annulus to 1500 psi. Bled off annulus and rotated out of liner hanger. Pulled out seal assembly and stood back 2 stands. Blow down top drive and installed Floor valve in string. Monitor well on trip tank. 13:00 - 16:00 3,00 CASE N RREP COMP Change out oil pump and high speed drive chain on draworks 16:00 - 16:30 0.50 CASE P COMP Service Top drive 16:30 - 18:30 2.00 CASE P COMP Pump Dry job - POH - Lay down Baker Liner running tools 18:30 - 19:30 1.00 CASE P COMP Pull wear ring - Install test plug - Open annulus valves - Rig up tst equipment 19:30 - 22:00 2,50 CASE P COMP Test Annular to 250 low - 2500 high - 5 mins each test - Top / Btm Rams - Blind Rams - Choke Manifold - HeR Choke / Kill valves - Manual Choke / Kill valves - Upper / Lower IBOP- Floor safety valves - 250 low - 3500 high - 5 mins each test - Accumulator test - All test good - John Crisp with AOGCC waived witness of BOP test 22:00 - 22:30 0.50 CASE P COMP Rig down test equipment - Pull test plug - Install wear ring - Close annulus valves 22:30 - 00:00 1.50 STWHIP P PROD2 PJSM - Pick up Baker Whipstock - Make up Whipstock assembly - Orient MWD with whipstock 2/25/2004 00:00 - 01 :00 1,00 STWHIP P PROD2 Con't make up Whipstock assembly - Shallow test MWD 01 :00 - 03:00 2,00 STWHIP P PROD2 RIH with Baker whipstock from 910' to 5225 - Orient Whipstock 1 R High side - RIH to 5347' - tag up - Set whipstock - Shear off with 32K down weight 03:00 - 06:00 3.00 STWHIP P PROD2 Mill OA window - TOW 5278' to BOW 5290' - Con't drill formation to 5302' 06:00 - 07:30 1.50 STWHIP P PROD2 Clean up window - CBU Hi Vis sweep surface to surface - Flow check - Pump dry job 07:30 - 09:00 1.50 STWHIP P PROD2 POH from 5302' to BHA 909' 09:00 - 10:00 1.00 STWHIP N RREP PROD2 Change out hydralic hose on skate 10:00 - 10:30 0,50 STWHIP P PROD2 Lay down BHA 10:30 - 11 :00 0.50 STWHIP P PROD2 Flush BOP's with stack washer 11 :00 - 11 :30 0.50 STWHIP P PROD2 Make up 6 3/4" Drlg Assembly - Orient - Shallow pulse test 11 :30 - 13:30 2.00 STWHIP P PROD2 RIH from 217' to 5200' 13:30 - 00:00 10.50 DRILL P PROD2 Orient motor to 0 deg - turn off pump - Slide through window - Directional Drill from 5302' to 5779' - WOB 12K to 15K - RPM 80 - TO on 8K - off 6K - GPM 254 - PP on 1800 - off 1600 - PU 140 - SO 95 - ROT 110 2/26/2004 00:00 - 00:00 24,00 DRILL P PROD2 Directional Drill From 5779' to 7565' - WOB 2k TO 10k - RPM 90 - TO on 7k - off 6.5k - PP on 2250 - off 2100 PU 140 - SO 80 - ROT 102 2/27/2004 00:00 - 16:00 16.00 DRILL P PROD2 Directional Drill from 7565' to 8563' TO OA Lateral - WOB 10K - RPM 80 - TO on 7K - off 5K - GPM 254 - PP on 2440 - off 2220 - PU 125 - SO 82 - ROT 102 16:00 - 18:00 2,00 CASE P COMP CBU 3 X - RPM 100 - TO 5K - GPM 280 - PP 2750 18:00 - 21 :00 3,00 CASE P COMP Pump out @ Drlg rate GPM 254 - From 8563' to 5320' - Pull through window with out pump from 5380' to 5250' 21 :00 - 22:00 1,00 CASE P COMP CBU 1 X - GPM 280 - PP 2200 - RPM 100 - TO 3K - Flow Check - Pump Dry job 22:00 - 00:00 2,00 CASE P COMP POH from 5200 to 217' @ BHA 2/28/2004 00:00 - 00:30 0.50 CASE P COMP Lay down BHA 00:30 - 01 :30 1.00 CASE P COMP Pick up Baker Whipstock Retrieving assembly - MWD - Orient 01 :30 - 02:30 1.00 CASE P COMP Down load - Up Load MWD - Surface test MWD 02:30 - 03:30 I 1,00 CASE P COMP RIH to with 4.75" spiral DC's - 3 1/2" HWDP - Shallow test I Printed: 3/8/2004 8:35:58 AM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: DRILL+COMPLETE Start: 2/7/2004 End: 3/1/2004 Contractor Name: DOYON DRILLING INC. Rig Release: 3/1/2004 Rig Name: DOYON 14 Rig Number: 14 Date I From - To f Hours i Task :Code NPT Phase Description of Operations i 2/28/2004 02:30 - 03:30 1,00 CASE P COMP MWD - Good test 03:30 - 05:00 1.50 CASE P COMP RIH from 867' to 5183' - Fill DP @ 3267' 05:00 - 06:00 1.00 CASE P COMP Cut Drlg Line - Top Drive Service 06:00 - 06:30 0,50 CASE P COMP RIH to 5280' - Orient high side - Engage hook slide - Pull 80K over pick up weight - Slide free - Pick up weight gained 5K - Observe well - Well static - Pump dry job 06:30 - 09:00 2.50 CASE P COMP POH from 5280' to 867' - @ controlled speed 09:00 - 11 :00 2.00 CASE P COMP Lay down 3.5" HWT - 4.75" Dc's - MWD - Baker Whipstock slide assy - Tail pipe assy 11 :00 - 12:00 1.00 CASE P COMP Clear rig floor - Lay down Baker tools - MWD tools 12:00 - 15:00 3,00 CASE P COMP PJSM - Pick up 78 joints 41/2" L-80 12,6# IBT Slotted liner- Make up Baker hanger - Baker Hook wall assy 15:00 - 18:00 3.00 CASE P COMP RIH with 4 1/2" slotted liner to 8260' - Two attempts to exit liner 0/ in OA Lateral 18:00 - 19:30 1,50 CASE P COMP Hook liner to bottom of window @ 5290' on fourth attempt- Slack off 40K to confirm hook was set - Drop ball and pump down to liner running tool - 40 spm @ 700 psi - Ball on seat - Pressure up to 3000 psi to release running tool - Pick up 30' - Lost 20K weight - pressure up to 4600 psi shear out ball / seat out of running tool 19:30 - 22:00 2,50 CASE P COMP Flow check - Pump dry job - POOH from 5290' to 3150' - Lay down remaining 4" drill pipe 22:00 - 00:00 2,00 RUNCO COMP Make up mule shoe - RIH to 5225' 2/29/2004 00:00 - 01 :00 1,00 RUNCO COMP PJSM - Flush surface lines with fresh water 01 :00 - 02:00 1,00 RUNCO COMP Displace 10,8 Flo Pro mud with 10.9 Brine - Pump viscosified 10.9 brine sweep - followed by 10,9 brine - GPM 500 - PP 2000 - RPM 120 02:00 - 06:00 4.00 RUNCO COMP PJSM - Lay down all 4" DP from 5225' 06:00 - 06:30 0.50 RUNCO COMP Pull wear ring - Clean and clear rig floor 06:30 - 07:00 0.50 RUNCO COMP PJSM with - Centrilift Tech, Crew, Co Man, - Rig up to run 2 7/8" tubing 07:00 - 10:30 3.50 RUNCO COMP Make up pump and motor - Fill motor with oil - Connect ESP cable - Clamps - Check ESP continuity - Good 10:30 - 13:00 2.50 RUNCO COMP PJSM with Centrilift techs on running tubing and ESP - Run 2 .. 7/8" L-80 6.5# 8 rd tubing to 1727' 13:00 - 19:30 6,50 RUNCO RREP COMP Pipe Skate - Repair Hydraulic pump on skate 19:30 - 00:00 4.50 RUNCO COMP Con't Run 2 7/8" ESP completion to 5215' 3/1/2004 00:00 - 00:30 0.50 RUNCO COMP Fill tubing - Pump 10 bbls down tubing - @ 42 spm @ 1250 psi - Install TWC- Ran 88 LaSalle ESP cable clamps - PU 85K - SO 75K 00:30 - 02:30 2.00 RUNCO COMP Install Hanger Penetrators - splice ESP cable - Connect ESP cable to penetrators - Test ESP continuity - Good test 02:30 - 03:00 0.50 RUNCO COMP RIH from 5215' to 5246' landing tubing on hanger - RILDS 03:00 - 03:30 0,50 RIGD P COMP Test TWC to 1000 psi from above - Test good 03:30 - 04:30 1.00 RIGD P COMP Nipple down BOP's - Stand back on stump - Secure same 04:30 - 06:00 1.50 RIGD P COMP Nipple up FMC 11" X 2 9/16" tubing head adapter - Test ESP cable continuity - Good - Test tubing packoff to 5000 psi for 10 mins - good test 06:00 - 07:00 1,00 RIGD P COMP Nipple up CIW 2 9/16" 5K Tree - Test to 5000 psi for 10 mins good test 07:00 - 07:30 0,50 RIGD Ip COMP Pull TWC with dry rod - Install BPV with Dry rod 07:30 - 08:00 0,50 RIGD Ip COMP Remove 1502 pump-in sub flange - Install wing valve flange- I Secure well - Release Rig @ 08:00 hrs Printed: 3/8/2004 8:35:58 AM .WEL~ SERVICE REPORT e e WELL JOB SCOPE UNIT MPG-18 NEW WELL POST UNKNOWN DATE DAILY WORK DAY SUPV 3/1/2004 FREEZE PROT O'MALLEY AFE KEY PERSON NIGHT SUPV MSD337374 UNKNOWN UNKNOWN MINID I DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY Freeze Protect TBG and fA Init-> 0 325 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 12:37 Travel / Standbv for Ria Move 13:45 Load Dead Crude 14:14 Load Diesel 14:36 PT TBG to 3800 psi 14:39 1 sta rt crude 450 Down TBG 14:50 .9 10 1700 14:56 .9 15 1700 Shut Down Switch to IA 15:04 1.5 start 800 Down IA 15:13 1.5 15 850 15:23 1.45 30 900 15:38 1.48 50 975 15:49 1.48 65 1025 Shut Down 16:11 RDMO / Travel Fi nal-> 575 575 I FLUID SUMMARY 80 bbls Dead Crude SERVICE COMPANY - SERVICE DAILY COST CUMULTOTAL BP $0 $0 FESCO $1 170 $1,170 TOTAL FIELD ESTIMATE: $1,170 $1,170 Legal Name: MPG-18 Common Name: MPG-18 ----------- Test Date 2/18/2004 2/22/2004 FIT FIT Test Type Test Depth (TMD) __.._._...._.__.____...__. "_U____... "......__. ._______" 3,225.0 (ft) 5,559,0 (It) BPEXPLORATION Leak-Off Test Summary Test Depth (TV D) -.. ... -. .----- 2,388.0 (ft) 4,183,0 (ft) AMW 8,90 (ppg) 10.80 (ppg) Surface Pressure ....--..-. 390 (psi) 370 (psi) Leak Off Pressure (BHP) 1,494 (psi) 2,717 (psi) Page 1 of 1 EMW 12.04 (ppg) 12,50 (ppg) Printed: 3/8/2004 8:35:36 AM . . fjo'i -()!:)O 16-Mar-04 AOGCC Howafd Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data fOf Well MPG-18 Dear Dear Sir/Madam: Enclosed afe two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,405.65' MD 5,418.00' MD 8,421.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARLULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signe0~\~~'-º ~~~ Please call me at 273-3545 if you have any questions Of concerns. Regards, William T. Allen Survey Managef RECEI\/ED Attachment(s) ~"~ . r , > ~I c: 2004 l-';;'~f ..~~ 1'\ , _~" _ " ·.;t~'¡f1., \.;omn¡¡~a¡j RBDMS RD MAR 3 0 ,1JIJ4 DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-18 e Job No. AKZZ292319400, Surveyed: 23 February, 2004 Survey Report 15 March, 2004 Your Ref: API 500292319400 Surface Coordinates: 6014569.32 N, 557139.33 E (70027'01.5895" N, 149032'01.7335" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014569.32 N, 57139.33 E (Grid) Surface Coordinates relative to Structure Reference: 2836.97 N, 763.91 E (True) Kelly Bushing Elevation: 63.70ft above Mean Sea Level Kelly Bushing Elevation: 63.70ft above Project V Reference Kelly Bushing Elevation: 63.70ft above Structure Reference SpBI""'I""'Y-SUI'1 DRtLLtNGSERVtCES A Halliburton Company Survey Ref: svy1346 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18 Your Ref: AP/500292319400 Job No. AKZZ292319400, Surveyed: 23 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5405.65 61.560 279.050 4113.99 4177.69 106.87 N 1200.99 E 6014685.40 N 558339.47 E -1031,18 Tie On Point ...' 5418,00 62.260 278,920 4119,81 4183.51 .... 108.57 N 1190,23 E 6014687.02 N 558328.69 E 5,744 -1020,77 Window Point ,/' 5448,02 65,350 279.440 4133.06 4196,76 112.87 N 1163.64 E 6014691.11 N 558302.07 E 10.410 -995,01 5543.49 80,700 281.130 4160.85 4224.55 129,18N 1074.08 E 6014706,73 N 558212.39 E 16.167 -907.42 5592.89 86,600 282.000 4166.31 4230.01 139,02 N 1026,00 E 6014716,20 N 558164.24 E 12.071 -859,92 e 5639.42 91.730 277,090 4166,99 4230,69 146.73 N 980.15 E 6014723,56 N 558118.33 E 15,258 -815.36 5689,11 92.470 278.600 4165.17 4228,87 153.51 N 930.96 E 6014729,96 N 558069,09 E 3,382 -768.21 5735.54 92,100 279.100 4163.31 4227.01 160,64 N 885.12 E 6014736.75 N 558023.19 E 1,339 -723.91 5783.86 92.160 280.080 4161,52 4225.22 168,69 N 837.51 E 6014744.43 N 557975.52 E 2.031 -677,62 5830.58 91,610 281.370 4159.98 4223.68 177.38 N 791,63 E 6014752.76 N 557929.58 E 3.000 -632.61 5880,14 90,740 281,380 4158.97 4222.67 187.15 N 743,06 E 6014762.16 N 557880,93 E 1.756 -584,69 5926.53 90.310 280.190 4158.54 4222.24 195.83 N 697.49 E 6014770.49 N 557835.30 E 2.727 -539,96 5976.50 90.250 280.700 4158,30 4222,00 204.89 N 648.35 E 6014779.18 N 557786,09 E 1.028 -491.85 6022.10 90.990 281.700 4157,80 4221,50 213.75 N 603.62 E 6014787,69 N 557741.29 E 2,728 -447.79 6072.92 91.170 284,320 4156,84 4220.54 225.18 N 554.12 E 6014798.75 N 557691.70 E 5.167 -398.31 6118.67 91,850 282,820 4155.64 4219.34 235.91 N 509,66 E 6014809.14 N 557647,17 E 3.599 -353.67 6168.43 91.730 282.410 4154.08 4217,78 246.78 N 461,13 E 6014819.63 N 557598,55 E 0.858 -305,31 6215.60 91.850 282,820 4152.61 4216,31 257,07 N 415.12 E 6014829.57 N 557552.46 E 0,905 -259,47 6267.96 91.850 285.370 4150,92 4214,62 269.82 N 364,36 E 6014841,92 N 557501,62 E 4,868 -208.30 6311.79 91.670 282.460 4149.57 4213.27 280.35 N 321.85 E 6014852.13 N 557459,02 E 6,649 -165.48 6362.69 91.230 282,200 4148,29 4211.99 291.22 N 272.14 E 6014862.62 N 557409,22 E 1,004 -116.07 6407,99 90.740 283,350 4147,51 4211.21 301.23 N 227,96 E 6014872.29 N 557364.98 E 2.759 -72,00 e 6458,63 90.560 284.060 4146,93 4210,63 313.23 N 178.77 E 6014883.91 N 557315.69 E 1 .446 -22,55 6503.75 90.250 282.460 4146.61 4210.31 323.58 N 134.86 E 6014893.92 N 557271.70 E 3,612 21.43 6554.91 90.120 282,040 4146.45 4210.15 334.43 N 84,86 E 6014904.39 N 557221.62 E 0,859 71,10 6600,05 90.250 282.580 4146,30 4210.00 344,06 N 40,76 E 6014913,68 N 557177.45 E 1.230 114.93 6654.58 90,370 282.580 4146.01 4209.71 355,93 N 12.46 W 6014925.15 N 557124.14 E 0.220 167,94 6696.43 90.620 284.350 4145.65 4209.35 365.68 N 53,16 W 6014934.58 N 557083,37 E 4.271 208.77 6747.10 90,310 283.730 4145.23 4208.93 377.97 N 102,31 W 6014946.49 N 557034,12 E 1.368 258.32 6792.67 90.120 284.000 4145,06 4208.76 388.89 N 146.55 W 6014957.07 N 556989.80 E 0,724 302.85 6842.77 90,000 283.160 4145.01 4208.71 400.65 N 195,25 W 6014968.46 N 556941.01 E 1.694 351.75 6888.04 90.000 282.020 4145.01 4208.71 410.52 N 239.43 W 6014977.99 N 556896,76 E 2.518 395.76 6938.84 91.170 282.100 4144.49 4208.19 421 ,13 N 289,11 W 6014988.22 N 556847,00 E 2.309 445.03 6983,84 91,300 281.830 4143.52 4207,22 430,46 N 333,12 W 6014997.21 N 556802.92 E 0.666 488.65 7033.92 91.110 281.430 4142.47 4206,17 440,55 N 382.16 W 6015006.93 N 556753.80 E 0,884 537.13 15 March, 2004 - 9:10 Page 20f4 DrillQuest 3.03.06.002 · . Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18 Your Ref: API 500292319400 Job No. AKZZ292319400, Surveyed: 23 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7079.07 91.300 284.400 4141.52 4205.22 450.64 N 426.16 W 6015016.68 N 556709.73 E 6,590 581.07 7128.74 91.360 284.410 4140,37 4204.07 463.00 N 474,25 W 6015028.67 N 556661.54 E 0.122 629,69 7175.45 91.110 284.320 4139.36 4203.06 474,58 N 519.49 W 6015039.90 N 556616.22 E 0.569 675.41 7222.77 91.670 283.990 4138.21 4201,91 486.15 N 565.36 W 6015051.12 N 556570.26 E 1.374 721,68 7271.71 91.480 285.620 4136,87 4200.57 498,65 N 612.66 W 6015063,26 N 556522,87 E 3,352 769,65 e 7319,87 91.110 287.210 4135.78 4199.48 512,26 N 658.84 W 6015076,51 N 556476,58 E 3.389 817,11 7368,00 91,730 285,690 4134.59 4198.29 525.88 N 704,98 W 6015089.78 N 556430.34 E 3.410 864.53 7415.53 91,360 285.390 4133.30 4197.00 538.61 N 750.76 W 6015102.16 N 556384,46 E 1.002 911,24 7463.71 90.860 285.790 4132.37 4196.07 551.56 N 797,16 W 6015114.75 N 556337,97 E 1,329 958.60 7511.79 90,430 284.520 4131.83 4195.53 564.12 N 843.56 W 6015126.96 N 556291.47 E 2,789 1005,79 7560.18 90,120 283.510 4131,60 4195,30 575.84 N 890.51 W 6015138.32 N 556244.43 E 2.183 1053,10 7608.21 89.940 284.240 4131,57 4195,27 587.36 N 937.14 W 6015149.48 N 556197.72 E 1,565 1100,04 7656.30 89,750 285.420 4131.70 4195.40 599.67 N 983.62 W 6015161.43 N 556151.14 E 2.485 1147.20 7704.69 90.120 286.500 4131,76 4195.46 612.97 N 1030.15W 6015174.38 N 556104.51 E 2,359 1194.82 7752.11 89,810 286.040 4131.79 4195.49 626.26 N 1075.67 W 6015187.31 N 556058.89 E 1,170 1241.54 7802.63 89.940 287.220 4131.90 4195,60 640,72 N 1124.08 W 6015201.40 N 556010,38 E 2.350 1291.37 7848.49 89.690 287.800 4132.04 4195,74 654.52 N 1167.81 W 6015214,86 N 555966.54 E 1.377 1336.71 7896.95 89.440 286.380 4132.41 4196,11 668.76 N 1214.13 W 6015228.75 N 555920.11 E 2.975 1384,57 7945,02 89.440 286,720 4132,88 4196.58 682.45 N 1260.20 W 6015242.09 N 555873.93 E 0.707 1431.96 7992.49 90.060 289.050 4133.09 4196.79 697.03 N 1305.38 W 6015256.32 N 555828,65 E 5.079 1478,94 8040,35 89,750 288,170 4133.17 4196.87 712,30 N 1350.73 W 6015271.24 N 555783.18 E 1.949 1526.39 8088.46 90.370 288,390 4133.12 4196.82 727.39 N 1396.41 W 6015285.98 N 555737.38 E 1,367 1574.05 e 8137.13 90.120 290.330 4132.91 4196.61 743.52 N 1442,33 W 6015301.76 N 555691.34 E 4.019 1622.37 8185.41 91.230 291,120 4132.34 4196,04 760.61 N 1487.48 W 6015318,50 N 555646,06 E 2.822 1670.43 8233.35 92.160 291,260 4130.92 4194.62 777.93 N 1532.16 W 6015335.48 N 555601,25 E 1,962 1718.17 8282.53 93,150 290,750 4128.65 4192.35 795.54 N 1578,02 W 6015352.73 N 555555.25 E 2,264 1767,10 8329.35 93.020 290,590 4126.13 4189.83 812.04 N 1621.76 W 6015368.90 N 555511,39 E 0.440 1813,64 8378.26 93.950 291,140 4123,15 4186.85 829.43 N 1667.38 W 6015385,94 N 555465,64 E 2,208 1862,26 '" 8421.00 93.950 291.140 4120,21 4183.91 ... 844,80 N 1707.15 W 6015401.01 N 555425.75 E '- 0,000 1904,73 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 296.130° (True). 15 March, 2004 - 9:10 Page 3 of 4 Dril/Quest 3.03.06.002 ~ Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18 Your Ref: API 500292319400 Job No. AKZZ292319400, Surveyed: 23 February, 2004 BPXA Milne Point Unit Based upon Minimum Curvature type calculations, at a Measured Depth of 8421.00ft" The Bottom Hole Displacement is 1904,75ft., in the Direction of 296.329° (True), Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment e 5405.65 5418.00 8421,00 4177.69 4183.51 4183.91 106.87 N 108,57 N 844.80 N 1200.99 E 1190.23 E 1707.15 W Tie On Point Window Point Projected Survey Survey toollJroøram for MPG-18 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 642,00 0.00 640.36 642.00 8421.00 640,36 Tolerable Gyro (MPG-18PB1) 4183.91 AK-6 BP JFR-AK (MPG-18PB1) e 15 March, 2004 - 9:10 Page 4 of4 DrillQuest 3.03.06.002 . . ð 0 1-/ -OdÔ 16-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPG-18 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,405.65' MD 5,418.00' MD 8,421.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Sign;~\~u..~~\.o!Î""J< ~~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) F{ECEIVED I, ,'''\ .,~ () f'.(\;'\ ,1 ", '< i U ¡~~':.}v ¿~ RBDMS RO MAR :3 0 2004 ~ , Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-18 MWD e Job No. AKMW2917922, Surveyed: 23 February, 2004 Survey Report 15 March, 2004 Your Ref: API 500292319400 Surface Coordinates: 6014569.32 N, 557139.33 E (70027'01.5895" N, 149032'01.7335" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014569.32 N, 57139.33 E (Grid) Surface Coordinates relative to Structure Reference: 2836.97 N, 763.91 E (True) Kelly Bushing Elevation: 63.70ft above Mean Sea Level Kelly Bushing Elevation: 63.70ft above Project V Reference Kelly Bushing Elevation: 63.70ft above Structure Reference sper"'r"'Y-su,! DRILLING s·eRVICes A Halliburton Company Survey Ref: svy1355 .. . Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18 MWD Your Ref: API 500292319400 Job No. AKMW2917922, Surveyed: 23 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5405.65 61.560 279,610 4114.00 4177.70 118.83 N 1203,00 E 6014697.37 N 558341.39 E -1027,72 Tie On Point 5418.00 62.260 278.920 4119.82 4183.52 120.58 N 1192,25 E 6014699.04 N 558330.62 E 7.511 -1017,29 Window Point 5448.02 65.350 279.440 4133.07 4196.77 124,88 N 1165.66 E 6014703,13 N 558304,00 E 10.410 -991,53 5543.49 80.700 286.920 4160,89 4224.59 145.86 N 1077.15 E 6014723.43 N 558215,33 E 17.727 -902.83 5592.89 86.600 279.900 4166.36 4230,06 157.22 N 1029.44 E 6014734.43 N 558167.53 E 18.491 -854,99 e 5639.42 91,730 276,600 4167.04 4230.74 163.89 N 983.42 E 6014740.74 N 558121.46 E 13,108 -810.73 5689,11 92.470 277.690 4165,22 4228.92 170.06 N 934.15 E 6014746.54 N 558072.15 E 2.650 -763,78 5735.54 92.100 278.560 4163,37 4227.07 176.62 N 888,22 E 6014752,75 N 558026,17 E 2.035 -719,66 5783.86 92.160 278,080 4161.57 4225.27 183.61 N 840.44 E 6014759.37 N 557978.34 E 1,000 -673.68 5830,58 91.610 281.400 4160,04 4223.74 191.51 N 794.43 E 6014766.91 N 557932,27 E 7.199 -628,89 5880.14 90.740 282.890 4159.02 4222,72 201,93 N 745.99 E 6014776.97 N 557883,75 E 3.481 -580,81 5926.53 90.310 280,190 4158.59 4222.29 211,21 N 700.54 E 6014785,90 N 557838.23 E 5,893 -535,93 5976,50 90.250 276,890 4158.35 4222,05 218.63 N 651.14 E 6014792,94 N 557788.77 E 6.605 -488.30 6022.10 90.990 278.720 4157,86 4221.56 224.82 N 605,96 E 6014798,78 N 557743.55 E 4.329 -445,02 6072.92 91.170 285,530 4156.90 4220,60 235.49 N 556,31 E 6014809.07 N 557693,82 E 13.403 -395,75 6118.67 91,850 279.390 4155.69 4219.39 245.35 N 511.68 E 6014818.59 N 557649.11 E 13.498 -351.33 6168.43 91.730 282.950 4154,14 4217.84 254.98 N 462.89 E 6014827.85 N 557600.25 E 7.155 -303,29 6215,60 91,850 281,860 4152.66 4216.36 265,11 N 416.85 E 6014837.62 N 557554.13 E 2.324 -257.49 6267.96 91.850 283,820 4150.97 4214.67 276.74 N 365,83 E 6014848,86 N 557503.02 E 3.741 -206.56 6311.79 91.670 279,640 4149.62 4213,32 285.65 N 322,94 E 6014857.43 N 557460.07 E 9.541 -164.13 6362.69 91.230 279.970 4148.34 4212.04 294,31 N 272.80 E 6014865,71 N 557409.87 E 1.080 -115.30 6407,99 90.740 282.900 4147.56 4211.26 303.29 N 228.41 E 6014874.35 N 557365.41 E 6,557 -71.50 e 6458.63 90.560 283.690 4146.98 4210,68 314,94 N 179.13 E 6014885.62 N 557316,04 E 1,600 -22.12 6503.75 90.250 310.080 4146,66 4210.36 335,16 N 139,25 E 6014905,54 N 557276.00 E 58.491 22.59 6554.91 90.120 280.790 4146.49 4210.19 356.89 N 93.55 E 6014926,92 N 557230.14 E 57,252 73.19 6600.05 90,250 283.880 4146.34 4210.04 366.53 N 49.45 E 6014936,22 N 557185.97 E 6.851 117.03 6654,58 90.370 280.970 4146.05 4209.75 378.27 N 3.79W 6014947.55 N 557132.64 E 5.341 170,00 6696.43 90.620 280,780 4145.69 4209.39 386,16 N 44,89 W 6014955,13 N 557091.48 E 0,750 210.37 6747.10 90,310 276,600 4145.28 4208.98 393.81 N 94.97 W 6014962,39 N 557041.35 E 8.272 258.70 6792.67 90.120 279,960 4145.10 4208.80 400.38 N 140,05 W 6014968.61 N 556996,21 E 7.385 302,07 6842.77 90.000 276.600 4145.05 4208.75 407.59 N 189,62 W 6014975.44 N 556946,59 E 6.711 349.75 6888.04 90.000 275,380 4145.05 4208.75 412,31 N 234.65 W 6014979.82 N 556901.53 E 2.695 392.25 6938.84 91.170 282.350 4144,53 4208,23 420,14 N 284,80 W 6014987.26 N 556851.31 E 13.911 440,73 6983.84 91.300 281.330 4143.56 4207.26 429.37 N 328.84 W 6014996,15 N 556807.21 E 2.284 484.33 7033.92 91.110 279,210 4142.51 4206,21 438.29 N 378.10 W 6015004.70 N 556757,88 E 4.249 532.49 15 March, 2004 - 8:52 Page 2 of 4 DrillQuest 3.03.06.002 .- . Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18 MWD Your Ref: API 500292319400 Job No. AKMW2917922, Surveyed: 23 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7079.07 91,300 283.920 4141.56 4205.26 447.34 N 422,31 W 6015013.41 N 556713.60 E 10.438 576.16 7128.74 91.360 281.290 4140.41 4204.11 458.18 N 470.77 W 6015023.87 N 556665,06 E 5,295 624.44 7175.45 91.110 283.940 4139.40 4203.10 468.37 N 516.33 W 6015033.72 N 556619.42 E 5.697 669.84 7222.77 91.670 281.160 4138,25 4201.95 478.65 N 562.51 W 6015043,65 N 556573.17 E 5.991 715.82 7271.71 91.480 282,540 4136.91 4200,61 488.70 N 610.38 W 6015053,32 N 556525.22 E 2,845 763,23 e 7319.87 91.110 285,560 4135.82 4199,52 500.39 N 657,09 W 6015064,65 N 556478.43 E 6.316 810,30 7368.00 91.730 278,710 4134.62 4198.32 510.50 N 704.10 W 6015074.40 N 556431.34 E 14.286 856.96 7415,53 91.360 282,340 4133.34 4197,04 519,17 N 750,80 W 6015082,72 N 556384.57 E 7.674 902,72 7463,71 90.860 285,500 4132.41 4196.11 530.76 N 797,55 W 6015093,95 N 556337,73 E 6.639 949,79 7511,79 90.430 282.41 0 4131.87 4195.57 542.35 N 844,20 W 6015105.18 N 556290.99 E 6.488 996.78 7560.18 90,120 282.090 4131.63 4195,33 552.62 N 891.49 W 6015115,09 N 556243.63 E 0.921 1043,76 7608,21 89,940 283.660 4131,61 4195.31 563,32 N 938,31 W 6015125.43 N 556196,72 E 3,290 1090,51 7656,30 89,750 288,740 4131.74 4195,44 576.73 N 984.48 W 6015138.49 N 556150.46 E 10.571 1137,86 7704.69 90,120 295.010 4131,79 4195.49 594.75 N 1029.36 W 6015156,16 N 556105.44 E 12,980 1186.09 7752.11 89.810 285.750 4131.82 4195.52 611.25 N 1073.77 W 6015172,32 N 556060.91 E 19.539 1233,22 7802.63 89,940 286.990 4131.93 4195.63 625.49 N 1122.24 W 6015186.18 N 556012.33 E 2.468 1283.01 7848.49 89.690 295.010 4132.08 4195.78 641,91 N 1165.01 W 6015202.28 N 555969.43 E 17.496 1328.65 7896.95 89.440 287.260 4132.45 4196,15 659.37 N 1210.18 W 6015219,39 N 555924.13 E 16.000 1376.89 7945.02 89.440 286,250 4132.92 4196,62 673,23 N 1256.21 W 6015232.89 N 555878.00 E 2.101 1424.31 7992.49 90.060 295.010 4133.13 4196,83 689,93 N 1300.59 W 6015249.26 N 555833.49 E 18.500 1471.52 8040,35 89,750 295.010 4133.21 4196.91 710,17 N 1343.96 W 6015269.16 N 555789.96 E 0,648 1519,37 8088.46 90.370 288.840 4133.16 4196.86 728,12 N 1388.57 W 6015286.77 N 555745,22 E 12.889 1567,33 e 8137,13 90,120 289,770 4132.95 4196.65 744,21 N 1434,50 W 6015302.51 N 555699.16 E 1.979 1615,65 8185.41 91.230 286.280 4132.38 4196.08 759.15 N 1480.40 W 6015317,10 N 555653,15 E 7.585 1663.44 8233,35 92.160 286.940 4130,96 4194,66 772,85 N 1526,32 W 6015330.44 N 555607,13 E 2,378 1710,69 8282,53 93.150 287.730 4128.68 4192.38 787.48 N 1573.21 W 6015344,72 N 555560.12 E 2.574 1759.24 8329,35 93.020 283.210 4126.16 4189.86 799.95 N 1618,26 W 6015356,84 N 555514,98 E 9.644 1805,18 8378,26 93,950 302,950 4123.16 4186.86 818,99 N 1662.95 W 6015375.54 N 555470,15 E 40.329 1853,68 8421,00 93,950 302.950 4120,22 4183.92 842.18 N 1698,73 W 6015398.45 N 555434.19 E 0.000 1896.02 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4, The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth òf 296.130· (True). 15 March, 2004 - 8:52 Page 3 of 4 DrillQuest 3.03.06.002 Milne Point Unit nalllDurton Sperry-Sun Survey Report for Milne Point MPG - MPG-18 MWD Your Ref: API 500292319400 Job No. AKMW2917922, Surveyed: 23 February, 2004 BPXA Based upon Minimum Curvature type calculations, at a Measured Depth of 8421.00ft., The Bottom Hole Displacement is 1896.04ft., in the Direction of 296,3710 (True). Comments Measured Depth (ft) 5405,65 5418,00 8421.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment e 4177.70 4183.52 4183,92 118.83 N 120,58 N 842.18 N 1203.00 E 1192,25 E 1698.73 W Tie On Point Window Point Projected Survey Survey tool proøram for MPG-18 MWD From Measured Vertical Depth Depth (ft) (ft) 0,00 642,00 0,00 640,36 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 642,00 8421.00 640.36 Tolerable Gyro (MPG-18PB1 MWD) 4183.92 MWD Magnetic (MPG-18PB1 MWD) e 15 March, 2004 - 8:52 DrillQuest 3.03.06.002 Page 4 of4 . . ~ðt-{-Œ[) 16-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPG-18PB1 Dear Dear Sir/Ma~am: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 5,578.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 signe~ \';t ^I'~,.sL§'~.}... --'C'-/\f"\... Date Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED AUachment(s) . . . -1 0 ";'\U~ ,\ t. -, ,~ !", : I II.~ :" " i 'J :-¡.J .,.. ReDMS p~ MAR~o- Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-18PB1 Job No. AKZZ2917922, Surveyed: 19 February, 2004 Survey Report 15 March, 2004 Your Ref: API 500292319470 Surface Coordinates: 6014569.32 N, 557139.33 E (70027'01.5895" N, 149032'01.7335" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1014569.32 N, 57139.33 E (Grid) Surface Coordinates relative to Structure Reference: 2836.97 N, 763.91 E (True) Kelly Bushing Elevation: 63. 70ft above Mean Sea Level Kelly Bushing Elevation: 63.70ft above Project V Reference Kelly Bushing Elevation: 63. 70ft above Structure Reference SpE!r'r'Y-SUI'1 DRILLING SERVIc::eS A Halliburton Company D EFIN ITIVE e e Survey Ref: svy1343 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 Your Ref: API 500292319470 Job No. AKZZ2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0,00 0,000 0.000 -63.70 0.00 0,00 N 0.00 E 6014569.32 N 557139.33 E 0.00 Tolerable Gyro 186,00 0,500 126,000 122.30 186.00 0.48 S 0,66 E 6014568.85 N 557139.99 E 0.269 -0.80 276.00 1.150 110,000 212.29 275.99 1,02 S 1.82 E 6014568.32 N 557141.16 E 0,759 -2.08 367.00 2.750 110.000 303,23 366,93 2.08 S 4.73 E 6014567.28 N 557144.08 E 1.758 -5.16 460.00 4.250 104.000 396,06 459.76 3.67 S 10,17 E 6014565.73 N 557149.53 E 1,658 -10.75 e 552,00 6,200 100,000 487.67 551.37 5,36 S 18.37 E 6014564.10 N 557157.74 E 2,155 -18,86 642.00 10,750 99.000 576.66 640.36 7.52 S 31.46 E 6014562.04 N 557170.84 E 5.058 -31.55 AK-6 BP JFR-AK 761.64 17,620 109,690 692.61 756.31 15,38 S 59,57 E 6014554.40 N 557199.01 E 6,122 -60,25 857,75 20,070 104,140 783,56 847.26 24.31 S 89,26 E 6014545,70 N 557228.77 E 3,156 -90,84 953.74 21,030 99.030 873.45 937,15 31.03 S 122,24 E 6014539.22 N 557261,81 E 2.119 -123.42 1049,62 25,650 97,100 961.46 1025.16 36.30 S 159,85 E 6014534,24 N 557299.45 E 4.883 -159,50 1145.05 31.330 93,790 1045.31 1109,01 40,50 S 205.14 E 6014530,39 N 557344.77 E 6.176 -202,01 1243.25 34,560 94,370 1127.71 1191.41 44.31 S 258.40 E 6014526.99 N 557398,06 E 3.305 -251.51 1334.93 36,790 94.960 1202,18 1265.88 48.67 S 311,69E 6014523.05 N 557451,38 E 2.461 -301.26 1431,60 39.330 94.050 1278,29 1341.99 53.33 S 371.09 E 6014518,83 N 557510,82 E 2.691 -356.65 1528.04 42,870 94.580 1350.95 1414.65 58.11 S 434.30 E 6014514,54 N 557574.06 E 3,688 -415.50 1624.54 46,040 92.460 1419.83 1483,53 62,23 S 501.74 E 6014510.94 N 557641.53 E 3.627 -477.87 1722.21 44,950 92,080 1488.29 1551.99 64,99 S 571.34 E 6014508.72 N 557711,15E 1,150 -541.57 1818.12 46.790 92.450 1555,07 1618,77 67.71 S 640,12 E 6014506.52 N 557779.96 E 1,938 -604.52 1912.53 48.250 93,130 1618.82 1682.52 71.10 S 709.67 E 6014503,66 N 557849,52 E 1.635 -668.45 2009.19 55,540 93.390 1678.43 1742.13 75.44 S 785.55 E 6014499.91 N 557925.44 E 7.545 -738.49 2105,90 62.440 93.030 1728,23 1791.93 80.06 S 868.26 E 6014495.91 N 558008,18 E 7.142 -814,78 e 2201,62 63.440 92.850 1771.77 1835.47 84.44 S 953,39 E 6014492.20 N 558093.34 E 1.058 -893.14 2297.89 62,970 93.290 1815.17 1878.87 89,04 S 1039,20 E 6014488.25 N 558179.18 E 0.636 -972.20 2394.28 63.160 93,820 1858.83 1922.53 94.37 S 1124,97E 6014483.58 N 558264.99 E 0.528 -1051.55 2490.21 62,580 94.350 1902.58 1966.28 100.45 S 1210,12 E 6014478.15 N 558350.19 E 0.779 -1130.68 2586.20 62.830 94.250 1946,60 2010.30 106,84 S 1295.19 E 6014472.41 N 558435,30 E 0.276 -1209.87 2682.77 63.200 94,680 1990.42 2054,12 113.54 S 1380,98 E 6014466,37 N 558521.14 E 0,552 -1289.85 2779.06 59.810 93.590 2036,35 2100.05 119.66S 1465.37 E 6014460,90 N 558605.57 E 3,658 -1368,30 2874.89 55,500 94,530 2087.61 2151,31 125.37 S 1546,11 E 6014455.81 N 558686,35 E 4.573 -1443.31 2971.16 51.480 93.810 2144,87 2208.57 131.01 S 1623,26 E 6014450,76 N 558763.55 E 4.219 -1515.06 3064.76 46.280 91.830 2206.41 2270.11 134.53 S 1693.66 E 6014447.78 N 558833.97 E 5,779 -1579.81 3161.32 41,310 90,920 2276,09 2339.79 136.15 S 1760.44 E 6014446.67 N 558900,76 E 5,188 -1640.48 3248.56 36,290 90.010 2344.06 2407,76 136.62 S 1815,09 E 6014446.62 N 558955.41 E 5,791 -1689,75 3297.26 34.310 89.190 2383.80 2447.50 136.43 S 1843,23 E 6014447.03 N 558983.55 E 4,180 -1714,93 15 March, 2004 - 8:52 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 Your Ref: AP/500292319470 Job No. AKZZ2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3344.53 31.320 89,140 2423.52 2487,22 136,06 S 1868.84 E 6014447.60 N 559009.16 E 6,326 -1737,76 3393,77 27,500 89,370 2466.41 2530.11 135.74 S 1893.01 E 6014448.10 N 559033.33 E 7.761 -1759.32 3441.24 23,370 88,940 2509.27 2572.97 135.44 S 1913.39 E 6014448.55 N 559053.70 E 8,709 -1777.49 3492.13 20,880 85.550 2556.41 2620.11 134,55 S 1932.53 E 6014449,59 N 559072,83 E 5.497 -1794,28 3537.75 18,710 82.080 2599,33 2663.03 132,91 S 1947.88 E 6014451,35 N 559088.17 E 5.407 -1807.34 e 3587,20 16.870 80.410 2646.42 2710.12 130.63 S 1962,81 E 6014453.75 N 559103,09 E 3,861 -1819.74 3632.47 14,670 77.190 2689,98 2753.68 128.26 S 1974,88 E 6014456.21 N 559115,14 E 5,228 -1829,53 3683,77 12.480 76.060 2739.85 2803.55 125.48 S 1986.60 E 6014459.07 N 559126.83 E 4.300 -1838,83 3729.01 9.970 75.300 2784.22 2847,92 123,31 S 1995.13 E 6014461.31 N 559135.35 E 5,558 -1845.53 3778.97 8.090 63.400 2833.56 2897.26 120.64 S 2002.46 E 6014464.04 N 559142,66 E 5,286 -1850.93 3825.48 7.850 48,370 2879.62 2943.32 117,06S 2007.76 E 6014467.65 N 559147.93 E 4.497 -1854,12 3876.46 7.960 29.430 2930.13 2993.83 111,68 S 2012,10 E 6014473.07 N 559152.23 E 5,091 -1855.64 3921.57 7.610 15.260 2974,83 3038.53 106.07 S 2014.42 E 6014478.69 N 559154,50 E 4.314 -1855,26 3972.58 7,110 352.11 0 3025.43 3089.13 99.69 S 2014.87 E 6014485,09 N 559154,91 E 5.854 -1852.85 4017.91 8.220 329.670 3070.36 3134,06 94.11 S 2012,85 E 6014490,65 N 559152.85 E 6,987 -1848,58 4068.92 9.940 312.930 3120.74 3184.44 87.96 S 2007.79 E 6014496.76 N 559147.73 E 6,146 -1841.32 4114.80 11 .770 299,690 3165.80 3229.50 82.95 S 2000.82 E 6014501.72 N 559140.73 E 6.717 -1832.86 4164.02 15.040 290,140 3213.68 3277,38 78.26 S 1990.46 E 6014506,33 N 559130.33 E 8.002 -1821,50 4209.92 18,870 287,140 3257.58 3321,28 74.02 S 1977,77 E 6014510.47 N 559117,61 E 8.556 -1808.24 4256.08 20.940 287,530 3300,98 3364.68 69,33 S 1962,77 E 6014515.04 N 559102.57 E 4.494 -1792.71 4302.37 23.680 289.140 3343.80 3407.50 63.79 S 1946,10 E 6014520.45 N 559085.86 E 6,064 -1775.30 4351,82 26.560 288.960 3388.57 3452.27 56.94 S 1926.26 E 6014527.15 N 559065,97 E 5,826 -1754.47 e 4398.80 28.690 287.760 3430.19 3493.89 50,09 S 1905.58 E 6014533.84 N 559045,24 E 4.686 -1732.89 4449,81 31.020 286.800 3474.43 3538,13 42,56 S 1881.33E 6014541.19 N 559020.94 E 4.663 -1707.80 4495.06 32.960 286.480 3512.81 3576.51 35,69 S 1858,37 E 6014547,88 N 558997,92 E 4,304 -1684.16 4545.05 34,380 286,790 3554.41 3618,11 27,76 S 1831,81 E 6014555.61 N 558971.30 E 2.861 -1656,82 4591.85 35,920 285,990 3592,67 3656,37 20.16 S 1805,96 E 6014563.01 N 558945.40 E 3.435 -1630.27 4640.70 37.440 285.210 3631,85 3695.55 12.32 S 1777.86 E 6014570.64 N 558917.23 E 3,254 -1601.58 4687.75 39.460 283,590 3668,70 3732.40 5.05 S 1749.52 E 6014577.68 N 558888.84 E 4,797 -1572.94 4735.79 41 .920 282.390 3705,12 3768.82 1.98 N 1719.01 E 6014584.48 N 558858.27 E 5.373 -1542.45 4782.90 44.820 281,640 3739.36 3803.06 8.71 N 1687,37 E 6014590.97 N 558826.58 E 6.252 -1511.08 4831.47 47.360 280.770 3773.04 3836,74 15.50 N 1653.04 E 6014597.50 N 558792.21 E 5,386 -1477,27 4880.17 49,240 280.450 3805.44 3869.14 22.20 N 1617,31 E 6014603.92 N 558756.42 E 3.891 -1442.24 4927.25 52.120 281.300 3835.27 3898.97 29.07 N 1581.54E 6014610.52 N 558720.60 E 6,275 -1407,10 4974,55 52.590 281,530 3864.16 3927.86 36.48 N 1544.83 E 6014617.65 N 558683.84 E 1.066 -1370.88 15 March, 2004 - 8:52 Page 3 of 5 DrillQuest 3.03.06.002 - . Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 Your Ref: API 500292319470 Job No. AKZZ2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5023.58 52.880 281,740 3893,85 3957.55 44.35 N 1506,61 E 6014625.22 N 558645.56 E 0.683 -1333.10 5070.72 53.190 282.110 3922,19 3985,89 52,14 N 1469,76 E 6014632.72 N 558608.65 E 0.909 -1296,59 5119,10 53.420 281.740 3951.10 4014.80 60.15 N 1431,81 E 6014640.45 N 558570.63 E 0,776 -1258.98 5165,24 53.730 282.090 3978.50 4042.20 67.82 N 1395.48 E 6014647.84 N 558534.25 E 0.908 -1222,99 5214.19 54.350 282.280 4007.24 4070.94 76.18 N 1356.75 E 6014655.90 N 558495.46 E 1.305 -1184,54 e 5260,08 54.630 282.420 4033.90 4097.60 84.17 N 1320.26 E 6014663.61 N 558458,91 E 0.659 -1148,26 5311.44 54,700 281.680 4063.60 4127.30 92.92 N 1279.29 E 6014672.04 N 558417,87 E 1.183 -1107.62 5356,58 57,020 279,950 4088.94 4152.64 99,92 N 1242.59 E 6014678.76 N 558381.12 E 6.039 -1071.59 5405.65 61.560 279.050 4113.99 4177.69 106,87 N 1200.99 E 6014685.40 N 558339.47 E 9.385 -1031,18 5453,65 64,270 278.540 4135,84 4199.54 113.40 N 1158.76E 6014691.61 N 558297.19 E 5.725 -990,39 5504.48 67,090 277.800 4156,77 4220.47 119.98N 1112,92 E 6014697.83 N 558251.30 E 5.704 -946,33 5578.00 67,090 277.800 4185,39 4249.09 129,17 N 1045,82 E 6014706.51 N 558184.13 E 0.000 -882,05 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 296,130° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5578.00ft" The Bottom Hole Displacement is 1053,77ft., in the Direction of 82.959° (True). e 15 March, 2004 - 8:52 Page 4 of5 DrillQuest 3.03.06.002 : ø' Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 Your Ref: API 500292319470 Job No. AKZZ2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) Comment 5578.00 4249.09 129,17 N 1045,82 E Projected Survey e Survey tool proaram for MPG-18PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 642.00 0.00 640.36 642.00 5578.00 640.36 Tolerable Gyro 4249,09 AK-6 BP _IFR-AK e 15 March, 2004 - 8:52 Page 5 of 5 DrillQuest 3.03.06.002 . . t) õtf -OCJÒ 16-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPG-18PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 5,578.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Sign~\~ ~'-9 ~~, Date Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED AUachment(s) '"< '1 8 (,DG¿¡ RBDM$ Pf\ MAr ::\ 0 1(11Tft .. Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-18PB1 MWD e Job No. AKMW2917922, Surveyed: 19 February, 2004 Survey Report 15 March, 2004 Your Ref: API 500292319470 Surface Coordinates: 6014569.32 N, 557139.33 E (70027'01.5895" N, 149032'01.7335" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014569.32 N, 57139.33 E (Grid) Surface Coordinates relative to Structure Reference: 2836.97 N, 763.91 E (True) Kelly Bushing Elevation: 63.70ft above Mean Sea Level Kelly Bushing Elevation: 63.70ft above Project V Reference Kelly Bushing Elevation: 63.70ft above Structure Reference sper""r""y-su:1! DRILLING .mSERVIc:eS A Halliburton Company Survey Ref: svy1352 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 MWD Your Ref: AP/500292319470 Job No. AKMW2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0,000 0.000 -63.70 0.00 0.00 N 0.00 E 6014569.32 N 557139.33 E 0.00 Tolerable Gyro 186.00 0.500 126.000 122,30 186.00 0.48 S 0.66 E 6014568.85 N 557139.99 E 0.269 -0.80 276.00 1,150 110.000 212.29 275.99 1,02 S 1.82 E 6014568,32 N 557141.16 E 0.759 -2.08 367.00 2.750 110.000 303.23 366,93 2.08 S 4.73 E 6014567.28 N 557144,08 E 1.758 -5.16 460.00 4,250 104.000 396.06 459.76 3,67 S 10,17 E 6014565.73 N 557149.53 E 1.658 -10.75 e 552.00 6.200 100.000 487.67 551.37 5,36 S 18.37 E 6014564.10 N 557157,74 E 2.155 -18.86 642.00 10.750 99,000 576.66 640.36 7.52 S 31.46 E 6014562.04 N 557170.84 E 5,058 -31.55 MWD Magnetic 761.64 17.620 109,790 692,61 756,31 15.41 S 59,55 E 6014554.37 N 557199,00 E 6.129 -60.25 857.75 20.070 104.150 783,56 847.26 24,36 S 89,24 E 6014545.64 N 557228,75 E 3.174 -90.85 953,74 21.030 98.840 873.45 937,15 31.04 S 122,23 E 6014539.22 N 557261.80 E 2.183 -123.41 1049,62 25.650 96,980 961.46 1025.16 36,21 S 159,85 E 6014534.34 N 557299.45 E 4,879 -159.46 1145.05 31.330 93,350 1045,31 1109,01 40.17 S 205.16 E 6014530,72 N 557344.79 E 6,220 -201.88 1243.25 34,560 93.720 1127,71 1191.41 43.47 S 258.46 E 6014527,83 N 557398.11 E 3.296 -251.18 1334.93 36,790 94.500 1202,18 1265,88 47.31 S 311,78 E 6014524.40 N 557451.46 E 2.482 -300.75 1431.60 39.330 93.920 1278.29 1341,99 51.68 S 371.21 E 6014520.49 N 557510.92 E 2.653 -356,03 1528.04 42,870 94.410 1350.95 1414.65 56.29 S 434.43 E 6014516.36 N 557574,18 E 3.686 -414,82 1624,54 46.040 91.590 1419.83 1483.53 59.78 S 501.90 E 6014513,39 N 557641.67 E 3,870 -476.93 1722,21 44.950 91,530 1488.29 1551.99 61.68 S 571,53 E 6014512.03 N 557711,32 E 1,117 -540,28 1818.12 46.790 92.420 1555,07 1618,77 64,06 S 640.32 E 6014510,17 N 557780,13 E 2,031 -603.09 1912.53 48.250 92.850 1618.83 1682,53 67.26 S 709.88 E 6014507.50 N 557849.70 E 1.583 -666.95 2009.19 55,540 93.820 1678.44 1742,14 71.71 S 785.75 E 6014503.63 N 557925.61 E 7.583 -737.03 2105.90 62.440 93,800 1728.23 1791,93 77.22 S 868.41 E 6014498.76 N 558008.31 E 7.135 -813.66 e 2201,62 63.440 93,000 1771,78 1835.48 82.27 S 953.50 E 6014494.36 N 558093.43 E 1.283 -892.28 2297.89 62,970 93.030 1815.18 1878.88 86.79 S 1039.31 E 6014490.50 N 558179.28 E 0.489 -971.31 2394.28 63,160 93.470 1858.84 1922.54 91.66 S 1125.11 E 6014486,29 N 558265.11 E 0.452 -1050.49 2490.21 62.580 94.720 1902,58 1966.28 97.76 S 1210.26E 6014480,85 N 558350,31 E 1,308 -1129.62 2586.20 62,830 93.650 1946,60 2010.30 103.98 S 1295.34 E 6014475.27 N 558435.42 E 1.024 -1208.74 2682.77 63.200 95.270 1990.43 2054,13 110.67 S 1381.13 E 6014469.24 N 558521,26 E 1.543 -1288,71 2779.06 59.810 92.750 2036.36 2100.06 116,62 S 1465,52 E 6014463.94 N 558605.70 E 4,205 -1367.1 0 2874,89 55.500 92.630 2087.62 2151,32 120.42 S 1546,37 E 6014460,76 N 558686.58 E 4.499 -1441.36 2971.16 51.480 92.970 2144.89 2208.59 124,19 S 1623.64 E 6014457.58 N 558763.88 E 4,185 -1512.40 3064.76 46.280 92.480 2206.42 2270,12 127.56 S 1694.05 E 6014454.75 N 558834.31 E 5,570 -1577,09 3161.32 41,310 91,640 2276,10 2339.80 129.98 S 1760.81 E 6014452,84 N 558901.09 E 5.182 -1638,10 3248.56 36,290 90.020 2344,07 2407.77 130.81 S 1815.45 E 6014452.43 N 558955.73 E 5.870 -1687.52 3297,26 34,310 89,310 2383.81 2447,51 130.65 S 1843.59 E 6014452.80 N 558983,86 E 4.152 -1712.71 15 March, 2004 - 8:52 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 MWD Your Ref: API 500292319470 Job No. AKMW2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3344.53 31.320 89,120 2423,53 2487,23 130.31 S 1869,20 E 6014453.35 N 559009.47 E 6,329 -1735.55 3393,77 27.500 89.490 2466.42 2530,12 130.01 S 1893,37 E 6014453,83 N 559033.64 E 7.767 -1757.12 3441,24 23,370 88.720 2509.28 2572.98 129.70 S 1913.75E 6014454,30 N 559054,02 E 8,728 -1775,28 3492.13 20.880 85.410 2556.42 2620.12 128.75 S 1932.89 E 6014455.40 N 559073.15 E 5.470 -1792.04 3537,75 18,710 82.300 2599.34 2663,04 127,12 S 1948,24 E 6014457.14 N 559088.49 E 5.286 -1805.11 e 3587.20 16.870 80.830 2646.43 2710,13 124.91 S 1963.19 E 6014459.47 N 559103.42 E 3.830 -1817,56 3632.47 14.670 77.410 2689.99 2753.69 122,61 S 1975,27 E 6014461.85 N 559115.48 E 5,274 -1827.39 3683,77 12.480 76.270 2739.86 2803,56 119,88 S 1986,99 E 6014464.68 N 559127.19 E 4,301 -1836.72 3729.01 9,970 75.450 2784.23 2847.93 117.74S 1995.54 E 6014466,89 N 559135,71 E 5.559 -1843.44 3778,97 8.090 63.640 2833,57 2897.27 115,09 S 2002.87 E 6014469.59 N 559143.03 E 5,266 -1848,86 3825.48 7.850 48.480 2879.64 2943.34 111.53 S 2008.18 E 6014473.19 N 559148.31 E 4.535 -1852.06 3876.46 7,960 29,700 2930,14 2993,84 106.16S 2012.54 E 6014478.60 N 559152,62 E 5.049 -1853,60 3921,57 7,610 15.470 2974.84 3038,54 100.56 S 2014.88 E 6014484.21 N 559154.93 E 4.331 -1853.25 3972,58 7,110 352.420 3025.44 3089.14 94.18 S 2015.37 E 6014490.60 N 559155.36 E 5.830 -1850,87 4017.91 8.220 330.020 3070,37 3134.07 88.59 S 2013,38 E 6014496.17 N 559153.33 E 6.977 -1846.62 4068.92 9.940 313,220 3120.75 3184.45 82.41 S 2008,35 E 6014502,31 N 559148,25 E 6.161 -1839,38 4114,80 11,770 299,890 3165,82 3229,52 77.37 S 2001.40 E 6014507,30 N 559141.27 E 6.746 -1830.93 4164,02 15.040 290,370 3213.69 3277,39 72.64 S 1991.06 E 6014511,95 N 559130.89 E 7,994 -1819.56 4209.92 18.870 287,800 3257.59 3321.29 68.30 S 1978.40 E 6014516.19 N 559118.20 E 8,501 -1806,29 4256,08 20.940 287.690 3300.99 3364.69 63,51 S 1963.44 E 6014520.87 N 559103,20 E 4.485 -1790,74 4302,37 23.680 289,200 3343,81 3407.51 57,94 S 1946,77 E 6014526,31 N 559086.49 E 6.047 -1773,33 4351.82 26.560 288.790 3388.58 3452.28 51.11 S 1926.93 E 6014532.99 N 559066,59 E 5,835 -1752,50 - 4398,80 28.690 287.660 3430.20 3493,90 44.30 S 1906.24 E 6014539,63 N 559045.85 E 4.669 -1730.92 4449.81 31.020 287.060 3474.44 3538.14 36.73 S 1882.00 E 6014547.02 N 559021,56 E 4.605 -1705.83 4495.06 32,960 286.370 3512.82 3576.52 29.84 S 1859.04 E 6014553.73 N 558998.54 E 4,363 -1682.18 4545,05 34.380 286.760 3554.42 3618.12 21.94 S 1832.48 E 6014561.43 N 558971.92 E 2.873 -1654.85 4591.85 35,920 286,870 3592.68 3656,38 14,15S 1806.69 E 6014569,03 N 558946,07 E 3.293 -1628.27 4640.70 37.440 285.390 3631.86 3695.56 6.05S 1778,66 E 6014576.91 N 558917.98 E 3.599 -1599,53 4687.75 39.460 284.030 3668.71 3732.41 1.38 N 1750.36 E 6014584.12 N 558889.63 E 4.654 -1570.86 4735.79 41 .920 283,010 3705,13 3768,83 8.69 N 1719.91 E 6014591.20 N 558859,12 E 5,304 -1540.30 4782,90 44,820 281.980 3739,37 3803,07 15.68 N 1688.33 E 6014597,95 N 558827.49 E 6,336 -1508,87 4831.47 47.360 282.020 3773,06 3836.76 22.96 N 1654.10 E 6014604.96 N 558793.21 E 5,230 -1474.94 4880,17 49.240 281.410 3805.45 3869.15 30.34 N 1618.50 E 6014612.06 N 558757.55 E 3,972 -1439.72 4927,25 52,120 282,600 3835.28 3898.98 37.92 N 1582,88 E 6014619.37 N 558721.87 E 6.422 -1404.41 4974.55 52,590 281.930 3864.17 3927.87 45.87 N 1546,28 E 6014627,05 N 558685,22 E 1 .498 -1368,05 15 March, 2004 - 8:52 Page 3 of 5 DrillQuest 3.03.06.002 · Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 MWD Your Ref: API 500292319470 Job No. AKMW2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5023.58 52,880 282,520 3893,86 3957,56 54,14 N 1508.15 E 6014635.02 N 558647,02 E 1,126 -1330.17 5070.72 53.190 282.470 3922.20 3985.90 62.28 N 1471,37 E 6014642.88 N 558610.18 E 0,663 -1293.57 5119.10 53.420 282,530 3951.11 4014.81 70.68 N 1433.50 E 6014650,99 N 558572,25 E 0.486 -1255,87 5165.24 53,730 281,870 3978,51 4042,21 78,53 N 1397.21 E 6014658.56 N 558535,90 E 1,333 -1219.83 5214.19 54,350 283.340 4007.26 4070.96 87.17 N 1358,55 E 6014666.91 N 558497.17 E 2.741 -1181,31 e 5260.08 54.630 283,310 4033.91 4097,61 95.78 N 1322,20 E 6014675.24 N 558460.76 E 0.612 -1144,88 5311.44 54.700 281.520 4063.62 4127,32 104.79 N 1281,29 E 6014683.93 N 558419,77 E 2,846 -1104,18 5356,58 57,020 279.840 4088.95 4152.65 111,71 N 1244.57 E 6014690.57 N 558383,01 E 5,992 -1068.18 5405.65 61,560 279.610 4114,00 4177,70 118.83 N 1203.00 E 6014697.37 N 558341.39 E 9.261 -1027.72 5453.65 64.270 279.850 4135.86 4199,56 126.05 N 1160.89 E 6014704.27 N 558299.22 E 5,663 -986,73 5504.48 67,090 278.720 4156.79 4220.49 133.52 N 1115,18 E 6014711.39N 558253,45 E 5,906 -942.40 5578.00 67.090 278,720 4185.41 4249,11 143.79 N 1048.24 E 6014721,14 N 558186.44 E 0,000 -877.78 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 296.130° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5578.00ft., The Bottom Hole Displacement is 1058.06ft., in the Direction of 82.190° (True). e 15 March, 2004 - 8:52 Page 4 of 5 DrillQuest 3.03.06.002 ,I; .. Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18PB1 MWD Your Ref: AP/500292319470 Job No. AKMW2917922, Surveyed: 19 February, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5578,00 4249.11 143.79 N 1048,24 E Projected Survey e Survey too/proaram for MPG-18PB1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 642.00 0.00 640,36 642.00 5578.00 640.36 Tolerable Gyro 4249.11 MWD Magnetic e 15 March, 2004 - 8:52 Page 5 of 5 Dri/lQuest 3.03.06.002 . . FRANK H. MURKOWSKI, GOVERNOR AIIASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Mile Point Unit MPG-18 BP Exploration (Alaska), Inc. Permit No: 204-020 Surface Location: 2134' NSL, 3462' WEL, Sec. 27, T13N, RlOE, UM Bortomhole Location: 3051' NSL, 50' WEL, Sec. 28, T13N, RIOE, OB Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska), Inc. assumes the liability of any protest to the spacing exception that may occur. 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 witness any required test. Contact the Commission's North Slope petroleum field inspector 3607 (pager). BY ORDER.Q~ THE COMMISSION DATED thi~ day of January, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. iNGA ~12.¿I2-ðt7L( STATE OF ALASKA .. ALASKA_AND GAS CONSERVATION COrvllrSSION PERMIT TO DRILL 20 MC 25.005 1a. Type of work II Drill [J Redrill 11b. Current Well Class [J Exploratory [J Re-Entry I [J Stratigraphic Test [J Service 2, Operator Name: 5. Bond: IHI Blanket 0 Single Well BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 3. Address: 6. Proposed Depth: " P.O, Box 196612, Anchorage, Alaska 99519-6612 MD 8525' # TVD 4193' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 025906 ,- ~~~:fN~~d~:~~: ~~r~~~C' 27, T13N, R10E, UM' /bpi-IS. Land Use Permit: 13. Approximate Spud Date: 2264' NSL, 2429' WEL, SEC. 27, T13N, R10E, (OB) vr^ 02/05/04 Total Depth: ~"v 9, Acres in Property: 14. Distance to Nearest Property: 3051' NSL, 50' WEL, SEC. 28, T13N, R10E, (OB) om 2560 8020' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: X-557139 y-6014569 Zone;6.SP4 (Height above GL): P~~;~,KBE feet 160' from Schrader Penetration Sand in MPG·12 16, Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Kickoff Depth 275 ft Maximum Hole Angle 94.600 Downhole: 2146 - psig Surface: 1750'" psig 18.Casin~i::ögram Specifications> To;ett¡l'ig[)èþt~ottom QlI(~~f~lt¿ro:a~~~ent Hole Casino Weioht Grade Couplino Lenoth MD TVD MD TVD (includino staoe datal 42" 20" 92# H-40 Welded 112' Surface Surface 112' 112' 60 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC-M 3215' Surface Surface 3215' 2424' 76 sx PF 'L', 261 sx Class 'G' ,,- 9-7/8" 7-5/8" 29.7# L-80 BTC-M 5508' Surface Surface 5508' 4234' 06 sx Class 'G' /' 6-1/8" 4-1/2" 12,6# L-80 BTC 3167' 5358' 4184' 8525' 4193' Uncemented Slotted Liner /' II Development Oil [J Multiple Zone [J Development Gas [J Single Zone 11, Well Name and Number: MPG-18 12. Field / Pool(s): Milne Point Unit / Schrader Bluff 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): . . ~ize . . . MD· I VU . !=;trllr.h m::¡1 Cnnd' '''tnr !=;lIrf::lr.A Intør Prnrtllr.tinn I inør 20. Attachments IHI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): IHI Drilling Program 0 Time vs Depth Plot o Seabed Report IHI Drilling Fluid Program o Shallow Hazard Analysis 1H120 MC 25,050 Requirements 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 Name Pat Archey Title Senior Drilling Engineer (J , Prepared By Name/Number: .. SfJ ,..P., ..4 Phone 564-5803 Date JIZ()/fl'l Sondra Stewman, 564-4750 Commission Use Only . Date: Contact Matt Green, 564-5581 Sianature Permit To Drill ¡ / IAPI Numb~ ·0 { / 0 Number: 20,-0 -;2..0 50- Ó '2-7 - 2. 3 I / ( ,- 0 Conditions of APProval.~samp equired D Yes ~o . ~ Hy ~ Sulfide Measures DYes ßNO Othe' 0P; ~~ f<' " Mo=ed:~ Form 10-401 Revised ~03 "---- I Permit Approval / Isee cover letter for Date: //..5t:9/¿:; t/ other requirements Mud Log Require£.) t: r'E·· HJlfS' gNo Directional Surv~ "~Wt ~E (¡j No "../' JAN 2 I 2004 Alaska Oil & Gas Cons, cornrr~liíÌss' n i<;~ BY ORDER OF Anchorage ~/ ...... - I _ I ... , A THE COMMISSION Date rJ. . ~ 'ð U K IlJ , I\J A L Syf>mit lïÞuPli¢,ate e Milne POeMPG-18 Well Permit IWell Name: IMPG-18 Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Multi Lateral Producer "OA" & "OB" Surface Location: 3146' FNL, (2134' FSL), 3462' FEL, (1817' FWL), SEC. 27, T13N, R10E E=557139.24 N=6014569.14 - Target Location: 2971' FNL, (2308' FSL), 2650' FEL, (2630' FWL), SEC. 27, T13N, R10E TOP "OA" E=557950 N=6014750 Z=4125'TVO Target Location: 2228' FNL, (3051' FSL), 50' FEL, (5229' FWL), SEC. 28, T13N, R10E BHL "OA" Well TO E=555263 N=6015472 Z=4065' TVO Target Location: 3016' FNL, (2264' FSL), 2429' FEL, (2850' FWL), SEC. 27, T13N, R10E TOP "OB" E=558171 N=6014707 Z=4170'TVD Target Location: 2228' FNL, (3051' FSL), 50' FEL, (5229' FWL), SEC. 28, T13N, R10E BHL "OB" Well TD E=555263 N=6015472 Z=4130'TVD ~~.. I AFE Number: I TBD 1 Estimated Start Date: 15-Feb-2004 ~ 8,525 I" 1 TVD: 14,1931" 1 Rig: 1 Doyon 14 / 1 Operating days to complete: 113.6 I 1 Max Inc: ~ I KOP: [TI[] ~ 1 KBE: 163.81 1 ' I 1 Well Design (conventional, slimhole, etc.): I Conventional Grass Roots ML Producer 1 Objective: 1 Schrader Bluff OA & OB Sand Mud Proxram: 13.S-in Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density ., Funnel Vis YP HTHP pH API Filtrate LG Solids 8.6- 9.2 75 - 150 25 - 60 N/A 9.0-9.5 <12 < 6.5 9.87S-in Intermediate Hole Mud Properties: LSND Freshwater Mud Density -, PV YP HTHP pH API Filtrate LG Solids 8.8 - 11.0 10 - 20 25 - 30 10-11 9.0-9.5 <6 <15 6.12S-in Production Hole Mud Properties: KCI-CaC03 FloPro Density I~~~\ PV YP HTHP pH API Filtrate MBT 10.8 - vr.QI 10 - 20 25 - 30 10-11 9.0-9.5 <6 <7 LCM Rdtl1etions: No Or anic LCM roducts in the Schrader Bluff formation ,l g p 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 lR. 1 e Milne PO&PG-18 Well Permit Cement Pro ram: Casing 10.75-in 45.5-lb/ft L-80 BTC-M surface casing Size Basis 100% over gauge hole. Top of tail cement 500-ft MD above casing shoe. Total Cement Wash 20-bbl Water Spacer Vol: 406-bbl Tail S acer Lead Temp Casing 7.625-in 29.7-lb/ft L-80 BTC-M intermediate casing Size Basis Top of lead cement 500-ft above top of Ugnu-sand. 0% excess over gauge. To of tail cement 500-ft MD above top of N-sand. 40% excess over QauQe. Total Cement Wash 5-bbl Water Vol: 88-bbl Spacer 30-bbl 10.3-lb/gal un-viscosified Alpha Spacer Tail 88-bbl, 406-sx 15.6-lb/gal Premium G - 1.15 ft"'/sx (top of tail at 3,932-ft MD) ~'''''''''''''''' ·^·-"0'~';l'Jc"';W"W""·-·"'·"·";':;;i'V1"; Temp BHST::= 80°F from SOR, BHCT 70°F estimated by Schlumberger Evaluation Program: 13.S-in Hole Section: Open Hole: MWD/GR, IFRlCASANDRA Cased Hole: N/A 9.87S-in Hole Section: Open Hole: MWD/GRlRES,IFRlCASANDRA . Cased Hole: N/A 6.12S-in Hole section: Open Hole: MWD/GRlRES, ABIIIFRlCASANDRA " Cased Hole: N/A 2 e Milne PO&PG-18 Well Permit Formation Markers Formation Tops M Orkb TVOrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 2292 1864 TUZC 4432 3579 1526 8.35 NA 5046 4024 2146 10.42 NB 5098 4054 2162 10.42 NC 5142 4079 2175 10.42 NE 5169 4094 2184 10.42 NF 5257 4139 2208 10.42 Top OA 5323 4169 2224 10.42 Base OA 5427 4209 2246 10.42 Top OB 5508 4234 2259 10.42 Base OB 5646 4259 2273 10.42 ö. ~ 1 / * Based on SS depths c IT b" p aSln~ u In g rogram Hole Size Csg/ WtlFt Gr~e ConY" Length Top Bottom Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Welded 80- ft O-ft 112-ft / 112-ft 13.5-in 10.75-in 45.5# L-80 BTC-M 3,215-ft O-ft 3,215-ft / 2,424-ft 9.875-in 7.625-in 29.7# L-80 BTC-M 5,508-ft O-ft 5,508-ft / 4,234-ft 6.125-in 4.5-in 12.6# L-80 BTC 3,167-ft 5,358-ft / 8,525-ft / OB Slotted 4,184-ft 4,193-ft 6.125-in 4.5-in 12.6# L-80 BTC 3,198-ft 5,318-ft / 8,516-ft / OA Slotted 4,166-ft 4,129-ft * The 20-in conductors are insulated. R d d B"t P ecommen e I rogram BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13.5-in O-ft - 3,215-ft Hughes 3-15 & 1-1 0 MX-C1 2 9.875-in 3,215-ft - 5,508-ft Smith 3-15 & 1-1 0 FGXiCPS 3 6.125-in 5,508-ft - TO Secu rity 3-12 FM2643 4 6.125-in 5,318-ft - TO Secu rity 3-12 FM2643 3 e Milne PO&'PG-18 Well Permit Well Control: Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: " · Planned BOP test pressure: · Integrity test: 2,146-psi @ 3,960-ft TVOrkb - Top of "NA" 1 ,750-psi @ surface I"'" (Based on BHP and a full column of gas from TO @ 0.1-psi/ft) 3,500-psi. ~ An FIT to 12.0-lb/gal will be made on the 10.75-in casing shoe. 14-bbl with 10.9-lb/gal mud. 9.7-lb/gal brine / 7.0-lb/gal Diesel (1 ,800-ft MO). · Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: Hydrates -/ · Light to moderate hydrates were encountered on several of the previous G-Pad wells. No drilling problems related to the hydrates were reported. · Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow.gas and/or hydrates. Use recommended practices for drilling hydrates. Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. · Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · Maximum reservoir pressure is expected to be (10.42 Ib/gal EMW). In this well, the Schrader ... Bluff formation will be drilled with 10.9-lb/gal mud. Pad Data Sheet · Please Read the G-Pad Data Sheet thoroughly. 4 e Milne PO&PG.18 Well Permit Breathing . N/A Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · A 20-ft OTE fault is expected at 4,700-ft MO in the Ugnu. · A 15-ft OTE fault is expected at 5,900-ft MO in the Schrader. Hydrogen Sulfide · MPG Pad is not designated as an H2S Pad. All G-Pad wells had <2-ppm H2S on the 2001 report. Anti-collision Issues · The abandoned wellbore MPG-06 is risk based at 1/200 to pass anti-collision scan. Distance to Nearest Property . MPG-18 is 8,020-ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPG-18 is 160-ft from the Schrader-sand penetration in MPG-12. / 5 e Milne P6PG-18 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. The 20-in insulated conductor is installed 2. NU diverter Procedure 1. MI/RU Doyon 14 J 2. Function test diverter, PU 4.0-in drill pipe 3. Drill 13.5-in surface hole 4. Run and cement 10.75-in casing / 5. ND diverter, install wellhead, NU BOPE and test / 6. Drill 9.875-in intermediate hole 7. Run and cement 7.625-in casing / 8. Drill 6.125-in OB horizontal production hole 9. Run 4.5-in slotted liner 10. Run whipstock and mill window for OA lateral / 11. Drill 6.125-in OA horizontal production hole 12. Retrieve whipstock 13. Run 4.5-in slotted liner and hang off in 7.625-in casing 14. Displace drilling mud to brine 15. Run 4.5-in jet pump completion 16. ND BOPE / NU tree 17. Freeze protect well 18. RD/MO 6 TREE: Cameron 2-9/16" 5M KB. ELEV =63.8-ft WELLHEAD: FMC Gen 5 11",5M Cellar Box ELEV = 29.7-ft Tubing Head: FMC 11-ln x 2.875-ín I 114' I 20" 92 Iblft, H-40 Welded 42" Hole Insulated 2,875-in X 1.0-in Gas Lift Mandrel @ 116-ft TVD 10-314" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing ID: 9.950 f-- Coupling OD: 11.75" .... Burst: 5,210 psi 10-3/4"@ 3,215' MD, 2,424' TVDrkb Collapse: 2,480 psi 2,875-in x 1.0-in GLM I I 2.875-in 6.5-lblft, L-80, 8rd, EUE Tubing ID: 2.441-in Tubing Capacity: O,00579-bbl/ft 2-7/8" XN nipple I I Tensile (100%): 145-k.lbf (ID 2.205") Burst: 10,570-psi Collapse: 13,870-psi Pump, 122 stg. GC2200 I I Tandem Gas Separator I I 7-5/8" 29.7#, L-80, BTC-M Tandem Seal Section I I Casing Drift: 6.75 GSB3 DB UT/L T IL H6 PFS Aflas/HSN Casing ID: 6.875 Coupling OD: 11.75" Motor, 171 HP KMH I I Burst: 6,890 psi 2390 volt, 44 amp Collapse: 4,790 psi PumpMate Sensor I I w/6 fin Centralizer \~ 6,125-in OA Lateral a,517-ft MD Window in 7-518" casing @ 5,318-ft MD Well Inclination @ Window = 64 Degrees ....... """'"- - - - - - - - r- _ - - - - - - - - I 4.5-in Slotted Liner w/Hookwall hanger 9.875-in Hole 4.5-in liner top @ 5,358-ft MD (150-ft lap) 7.625" Casing Shoe @ 5,508-ft MD, 4,234-ft TVD a,525-ft MD I / Well Inclination @ Shoe = 81 Degrees 6,12S-in OB Lateral ....... \ - - - - - - - - ...... ~-- - - - - - - - 4.5-in Slotted Liner & Hanger - DATE REV. BY COMMENTS 19 Jan 2004 Mi5G Level 3 Multi-Lateral, 2.875-in ESP Completion WELL DETAll.S N... +NI.s +pj·W Northing -og Latitude Longitude Slot Plan Moe G-18 2837.13 763.59 6014569.13 55713922 70027'01.58SN 149°32'01.737W NlA TARGET DETAILS """" TVD +N/-5 +E/-W Northing fasting Shape Moe T3 REV I 4192.80 917.32 -1869.42 6015472.00 555263.00 Point Moe T2 Rev I 4201.80 557.57 -864.45 6015120.00 556270.60 Point MoeFault 1 4218.80 ·325.96 1146.43 6014252.00 558288.00 Polygon MoeTI Rev 1 4233.80 129.97 1032.91 6014707.0() 558171.00 Point Moo Poly 4233.80 412.35 .708.15 6014976.00 556428.00 Polygon SECTION DETAILS Sec MD Inc Azi TVD +N/-S +EI·W DLeg TFace VSec Target I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 3 395.00 3.00 95.00 394.95 -0.27 3.13 2.50 95.00 -2.93 4 2005.42 59.36 94.60 1717.81 -64.74 801.13 3.50 -0.42 -747.73 5 2696.47 59.36 94.60 2069,95 -112.39 1393.81 0.00 0.00 -1300.79 6 4974.51 54.81 281.00 3982.36 40.85 1491.39 5.00 -174.28 -1320.90 7 5124.51 54.81 281.00 4068.80 64.24 1371.06 0.00 0.00 -1202.56 8 5508.25 74.00 281.00 4233.80 129.97 1032.91 5.00 0.00 -870.03 Moe II Rev 1 9 5533.25 74.00 281.00 4240.69 134.55 1009,32 0.00 0.00 -846.83 10 5682.76 91.85 282.79 4259.03 165.05 864.73 12.00 5.81 -703.60 11 7435.52 91.85 282.79 4202.33 552.84 -843.65 0.00 0.00 1000.92 12 7456.86 91.00 282.79 4201.80 557.57 -864.45 4,00 179.94 1021.68 Moe T2 Rev 1 13 7646.87 90.43 290.37 4199.42 611.74 -1046.41 4.00 94.23 1208.89 14 8524.80 90.43 290.37 4192.80 917.32 -1869.42 0.00 0.00 2082,36 Moe T3 REV 1 ~...., IU"L~::::",,~,:,:vl"'.. COMPANY DETAILS BP Amoco Calculation Method: Minimum Curvatuœ =~~ ~;;V~~nœrNortb Em>r Surface: Elliptical -t Casing Wamin Method Rules Based cy~~~ ~ ~=:~ ~~I~ ~4~~P~~5~L ~¿~~OTrœ North Section (VS) Reference: Slot. (O.OON,O.OOE) Measured Deøtb Reference: 0-14 (~4.3 + 29.5 GL) 63.80 Calculation Method: Minimum Curvatuæ REFERENCE INFORMA nON SURVEY PROGRAM Deptb Fm Depth To Survey/P1an 34.30 700.00 Planned: MPG-18 wp06 VIS 700.00 8524.80 Planned: MPG-t8 wp06 V15 Tool CB-OYRO·SS MWD+JFR+MS Obp 80 D Start Dir 2.5/100': 275' MD, 275'TVD Start Dir 3.5/100': 395' MD, 394.95TVD 160 c ~ o ~ .c Õ. 240 ~ ~ ',:: .;: ~ 320 ~ ,I I ;/ ;/ ;/ 1/;' I~ ,I . ; / , , # / :< # .. 400 # , #' / " ~#~~ 480 -1600 -800 o 800 Vertical Section at 296.14° [800ft/in] 1600 2400 Plan: MPG-18 wp06 (plan Moe G-18/Plan Moe) Created By: Ken Allen Checked: Date: 1211212003 Date Reviewed: Date" CASING DETAILS No. TVD MD Name Size 2423.80 3214.77 103/4" 10.750 4233.80 5508.25 7 5/8" 7.625 4192.80 8524.79 4112" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1863.80 2291.91 BPRF 2 3578.80 4431.94 TUZC 3 3813.80 4719.69 Ugnu·MA 4 3823.80 4733.25 Ugnu-MBI 5 3873,80 4803.45 Ugnu-MB2 6 4003.80 5011.71 Ugnu-MC 7 4023.80 5046.42 SBF2-NA 8 4053.80 5098.48 SBFI-NB 9 4078.80 5142.05 SBE4-NC 10 4093.80 5169.14 SBE2-NE 11 4138.80 5257.15 SBE1-NF 12 4168.80 5323.48 TSBD-Top OA 13 4208.80 5427.43 TSBC-Base OA 14 4233.80 5508.25 TSBB-Top OB 15 4258.80 5645.80 SBA5-Base OB COMPANY DETAß..S :~~ BPAmoco Calcu\al.ion Method: Minimum Curvature = ~et~~ ~;v~~~nœr North ErrorSurrace: Ellipt\caI-rCasing Wamin Method: Rules Based REFERENCE INFORMATION SURVEY PROGRAM Depth Pm Depth To SurveylPlan 3430 700.00 Planned: MPG-III wp06 V15 700.00 8524.80 Planned: 1vfPG.18 wp06 VI5 Tool CB-GYRO-SS MWD+IFR+MS Plan: MPG-18 Wp06 (plan Moe G·I8JPlan Mae) Created By: Ken Allen Date: 12/12/2003 bp ~i:ecm~ ~~=~ ~~I~ ~~~~Pi~5~L ~6~~OTrue North Section (VS) ~rerence: Slot· (O.OON,O.OOE) MellSU~~rar~~~:~ ~~~£~~:~GL) 63.80 Checked: Date:_ Reviewed: Date:_ WFLL DETAILS N~ +NI-S +EI-W Northing Ea8ting Latitude Longiwde Slot Plan MoeG-18 2837.13 763.39 6014569.13 55713922 70027'OI.588N 149"32'U1.737W WA TARGET DETAILS N~ TVD +w.s +EI-W Northing Easting Shape Mae T3 REV I 4192.80 91732 ,1869.42 6015472.00 55526J.OO Point MoeT2Revl 4201.80 557.57 -864.45 6015120.00 556270.60 Point Mae Fauh 1 4218.80 ·325.96 1146.43 6014252.00 558288.00 Polygon Mae Tl Rev I 4233.80 129.97 1032.91 6014707.00 558171.00 Point Mae Poly 4233.80 41235 -708.15 6014976.00 556428.00 Polygon .,'...., ..........~ SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 275,00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 3 395.00 3,00 95,00 394.95 -0.27 3.13 2.50 95,00 -2.93 4 2005.42 59.36 94,60 1717.81 -64.74 801.13 3.50 -0.42 -747.73 5 2696.47 59,36 94.60 2069.95 -112.39 1393,81 0.00 0.00 -1300.79 6 4974.5 I 54.81 281.00 3982.36 40.85 1491.39 5.00 -174.28 -1320.90 7 5124.51 54.81 281.00 4068.80 64.24 1371.06 0.00 0.00 -1202.56 8 5508.25 74.00 281.00 4233.80 129.97 1032.91 5.00 0.00 -870.03 Moe T1 Rev 1 9 5533.25 74.00 281.00 4240.69 134.55 1009.32 0.00 0.00 -846.83 10 5682.76 91.85 282.79 4259.03 165.05 864.73 12.00 5.81 -703.60 11 7435.52 91.85 282,79 4202.33 552.84 -843.65 0.00 0.00 1000.92 12 7456.86 91.00 282.79 4201.80 557.57 -864.45 4.00 179.94 1021.68 Moe T2 Rev 1 13 7646.87 90.43 290.37 4199.42 611.74 -1046.41 4.00 94.23 1208.89 14 8524.80 90.43 290.37 4192.80 917.32 -1869.42 0.00 0.00 2082.36 Moe T3 REV I CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Formation 1 2423.80 3214.77 103/4" 10.750 I 1863.80 2291.91 BPRF 2 4233.80 5508.25 75/8" 7.625 2 3578.80 4431.94 ruzc 3 4192.80 8524.79 41/2" 4.500 3 3813.80 4719.69 Ugnu-MA 4 3823.80 4733.25 Ugnu-MBl 5 3873.80 4803.45 Ugnu-MB2 6 4003.80 5011.71 Ugnu-MC 7 4023.80 5046.42 SBF2-NA 8 4053.80 5098.48 SBF1-NB 9 4078.80 5142.05 SBE4-NC 10 4093.80 5169.14 SBE2-NE 11 4138.80 5257.15 SBE1-NF 12 4168.80 5323.48 TSBD-Top OA ; 7646.87' MD, 4199.42' TVD 13 4208.80 5427.43 TSBC-Base OA Sill:". Dir 4/1!0(1' ; 7435.52' MD, 4202.33'TVD 14 4233.80 5508.25 TSBB-Top OB f 15 4258.80 5645.80 SBA5-Base OB -# ## ... #' ~~ tOO '.,.... " â o o ~ +' :E: 15 ~ :E: :; o VJ ~~~, 50 ", " ", ..............", ....;.. ---..,...:.. '''---.. ...'........ ....'....... '-'':h,·l ~ R~\ F:aIDI: : :,(,k:! "':6' ~1D. ·:2;C) ~}:;' 1\'1) ---"..~--~....--._ ~" I..... . . ')lilT! I>ir 11 100': 5:'.'3 ~5' ~1). -=2':0 6~n \'1) ....,.., --------____~ ...., ..~/ . ....~.: f: . _ F:!(! Dir 5:'/)~~2:" \1~).<.:.2.',]:~· ~~~'? _ II _ . '-"__ '! ..../. , SI,'1'; IJ" . IOU "...., '. MD,4068.8'TVD . . ''''''. -"_._ -'-___1.7 5. W' :,¿ .. . - . ¡ I:nd nil' ·;'17".'" MD. 3982.36' TVD . .:-. =:·:-::::':i_,~~~t---:;::::¿"""L. '" ;,>'-;;;;;-~ S:""DII..5lO();..,~,n,,...,I\D! ....'..'......_._..! ! . _()(¡O _.._......_·~--'--:;¡í:)() s,,,,, 1)".\ > lO()': ~I):i' :'>1[). 394.95T\·[) "'-"'-'" .......... _".. i 25(\') . -1-...... Elld DII . 1()O>,42' ~1D. I? I ~ S I' 1'\1) .... ". - '''~,.......,~ '...... '"'''''' .............. " ...".... , " -50 ·2500 -2000 -1500 -1000 ·500 o West(-)Æast(+) [500ftlin] 500 1000 1500 2000 spe........y-sun DRIL.L.ING seRVIc:es "K.\1UI:It1Jt1'OH(:.oMf'~ 'perry-Sun - Draft Copye KW A Planning ....:,....,.\,.......5:..;,........f....,.....~.:...:.....l:.m.I,'I..~.II...P..¡......a·.a..·t·.n...·.hy.·...;......J~~:~~' .' >' . .:{"i~ !;~ïån Mò~:¡i¡::!}:i:":::~:::·!:·:::':<f:· ;~> ". Principat: Yes Plan: MPG-18 wp06 bp l)ate:~12t12t~Ò03 ·'.'·':'.:Ti·Mf: 11:06:@':,;,., ". Page: Co-'ordiriàte(l'IE) Refereneè:":'>':'W~II: Plári,.Moè·G-18, True North Yertieal(TVD) Reference:' .... . 'þ-14 (~.3+2~J:5GL >,,63,8 Secti(!ß (YS) Reference: :'··'Well(O:OONiO:QOE,296.14Azi) , S~_ry~ ~~Je~latión.Method:M¡ïïjr¡ipÏid:;uiVát!:lte·" '~b:__ ':rac1e Date Composed: Version: Tied-to: 12/9/2003 15 From Well Ref, Point Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M pt G Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Eastlng: Position Uncertainty: 0.00 ft Ground Levet: 0,00 ft Well: Plan Moe G-18 Planned Well Surface from Joe C. Well Position: +N/-S 2837.13 ft Northing: +E/-W 763,59 ft Easting: Position Uncertainty: 0,00 ft Wellpath: Plan Moe Current Datum: Magnetic Data: Field Strength: Vertieat Section: Casing Points ::-,.¡;J;~~:,:..;, 3214.77 5508,25 8524.79 Formations '::.·:'-MD· '. '. .,.... ft .-" 2291,91 4431.94 4719.69 4733.25 4803.45 5011,71 5046.42 5098.48 5142.05 5169.14 5257.15 5323.48 5427.43 5508.25 5645,80 TVD' ,.ft " 2423.80 4233,80 4192.80 .:.:dyn'".: . :,:;···.ft . 1863.80 3578,80 3813.80 3823.80 3873,80 4003,80 4023,80 4053,80 4078,80 4093.80 4138,80 4168.80 4208.80 4233.80 4258,80 0-14 ( 34,3 + 29.5 GL ) 6/23/2003 57512 nT Depth From (TVD) ft 34,30 .' Diameter " in: 10,750 7,625 4,500 HOlj~~.~ ' 13.500 9,875 6,125 . Formations BPRF TUZC Ugnu-MA Ugnu-MB1 Ugnu-MB2 Ugnu-MC SBF2-NA SBF1-NB SBE4-NC SBE2-NE SBE1-NF TSBD-Top OA TSBC-Base OA TSBB-Top OB SBA5-Base OB Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 6011726.58 ft 556397,19 ft Latitude: 70 26 Longitude: 149 32 North Reference: Grid Convergence: 33,685 N 24.162 W True 0.43 deg Stot Name: 6014569.13 ft 557139,22 ft Latitude: 70 27 Longitude: 149 32 1.588 N 1.737 W Height 63.80 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angte: +E/-W ft 0.00 Well Ref, Point 34,30 ft Mean Sea Level 25.44 deg 80,83 deg Direction deg 296,14 +N/-S ft 0.00 103/4" 7 5/8" 4 1/2" Lithology Dip Angle deg 0.00 0,00 0.00 0.00 0,00 0,00 0,00 0,00 0.00 0.00 0,00 0,00 0,00 0.00 0.00 .,::- Dip Dke¢tion ' deg ~,______. 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0,00 0,00 0,00 0.00 0.00 0,00 spel"""l"""y-sun DRaL-LING SERVIc:es "tt.U.UIill,III;TOf\I('(fo.W"""· 'perry-Sun - Draft Copye KW A Planning bp ;èo'ìnpany: BP Amoco "Field:'· . Milne Point ·~·~r~;~;~·:.;.,;,;;~:;~..~~ag-1.8. Targets .. .... .. .. . .. .. ..... . . . . .. . , ~:~din~~~~~·~~fere~~~;~ime~~~1r~~o~9~~LI~;E~~F..· : ;.~. .. __ ._____1:~~2&~I!~~:~~~:~~;;;;i:: .·~~ï'~~~0~~~~~~,r;1~ffl~t;;~6~CI~·· . .j .:., . .. Map . .. .... .n <- Lorig!tilde --> ~Iap..i. '" '<---'Latitilde,:-~:.:::.t,· .. . .. Name Description tNl~ +EI-W Northing Easting DClfMiniSëê > .. Deg MI~.~'Sec Dip. mr. ·"·ft· ft ft ft ::').'.<',' ------~- ..-..-...-- Moe T3 REV 1 917.32 -1869.42 6015472,00 555263,00 70 27 10,607 N 149 32 56,645 W Moe T2 Rev 1 4201,80 557.57 -864.45 6015120,00 556270,60 70 27 7.071 N 149 32 27.126 W Moe Fault 1 4218.80 -325.96 1146.43 6014252,00 558288,00 70 26 58.381 N 149 31 28,070 W -Polygon 1 4218,80 -325.96 1146.43 6014252,00 558288,00 70 26 58.381 N 149 31 28,070 W -Polygon 2 4218,80 117.80 -1162.46 6014678,00 555976,00 70 27 2,745 N 149 32 35.877 W -Polygon 3 4218.80 775.47 -2413,58 6015326,00 554720.00 70 27 9,210 N 149 33 12.627 W -Polygon 4 4218,80 117.80 -1162.46 6014678.00 555976.00 70 27 2.745 N 149 32 35.877 W Moe T1 Rev 1 4233,80 129.97 1032.91 6014707.00 558171.00 70 27 2.865 N 149 31 31.402 W Moe Poly 4233.80 412,35 -708.15 6014976,00 556428.00 70 27 5,643 N 149 32 22,535 W -Polygon 1 4233.80 412,35 -708.15 6014976,00 556428.00 70 27 5.643 N 149 32 22,535 W -Polygon 2 4233.80 -17.47 1347,82 6014562,00 558487.00 70 27 1.415 N 1493122,154W -Polygon 3 4233.80 191,32 1379,42 6014771,00 558517,00 70 27 3.468 N 149 31 21.224 W -Polygon 4 4233.80 616,12 -674,58 6015180,00 556460.00 70 27 7,647 N 149 32 21.550 W -Polygon 5 4233.80 1129,89 -2070,82 6015683.00 555060.00 70 27 12,697 N 149 33 2.562 W -Polygon 6 4233.80 894,29 -2127,63 6015447.00 555005,00 70 27 10.380 N 149 33 4.229 W Plan Section Information F\¡;2:C~' Incl Azim ·····,+E/'-W .' . .... .,. DUS'.,·'Build· ..... Turn . ;.. T<fe~ ·)\,~.::t~~~." .. deg deg >!'ft deg!100ffdegI10()ft deg/1 000 .'. .. . 34.30 0.00 0.00 34.30 0,00 0,00 0,00 0.00 0.00 0.00 275,00 0.00 0.00 275,00 0,00 0,00 0,00 0,00 0.00 0.00 395,00 3.00 95.00 394,95 -0,27 3.13 2.50 2,50 0,00 95,00 2005,42 59.36 94.60 1717,81 -64.74 801.13 3.50 3.50 -0,03 -0.42 2696.47 59,36 94,60 2069,95 -112.39 1393.81 0.00 0,00 0,00 0.00 4974.51 54,81 281.00 3982,36 40.85 1491.39 5.00 -0.20 -7.62 -174.28 5124.51 54,81 281,00 4068,80 64,24 1371,06 0.00 0,00 0.00 0,00 5508,25 74.00 281.00 4233,80 129.97 1032.91 5.00 5,00 0.00 0,00 Moe T1 Rev 1 5533.25 74.00 281.00 4240,69 134,55 1009,32 0,00 0.00 0,00 0,00 5682,76 91.85 282.79 4259.03 165,05 864.73 12.00 11.94 1,20 5,81 7435,52 91.85 282.79 4202,33 552.84 -843.65 0.00 0,00 0.00 0,00 7456,86 91,00 282,79 4201,80 557.57 -864.45 4,00 -4.00 0.00 179.94 Moe T2 Rev 1 7646,87 90.43 290,37 4199.42 611,74 -1046.41 4,00 -0.30 3.99 94,23 8524,80 90.43 290,37 4192,80 917,32 -1869.42 0.00 0.00 0,00 0.00 Moe T3 REV 1 ... --,._-,~..~ .~-' ..--. ". ----------.-....- -----......._~.......__...~ Incl' ··.Azim. .TVD Sys TVD MapN MapE VS DLS TFO deg '.. .. deg.;. ft .' ·ft ft ft ft deg/100ft '" . deg ----- 0.00 0,00 34.30 -29.50 6014569,13 557139.22 0.00 0,00 0,00 CB-GYRO-SS 0,00 0.00 100,00 36.20 6014569.13 557139,22 0.00 0,00 0,00 CB-GYRO-SS 0,00 0.00 200,00 136.20 6014569.13 557139,22 0,00 0,00 0,00 CB-GYRO-SS 0.00 0,00 275.00 211.20 6014569,13 557139,22 0.00 0.00 0,00 CB-GYRO-SS 0.63 95,00 300.00 236.20 6014569.12 557139,36 -0.13 2,50 0.00 CB-GYRO-SS 395.00 3.00 95,00 394,95 331,15 6014568,88 557142.35 -2,93 2.50 0.00 CB-GYRO-SS 400.00 3,17 94,98 399,94 336.14 6014568,86 557142.62 -3.18 3,50 359.58 CB-GYRO-SS 500,00 6.67 94.77 499,55 435.75 6014568.20 557151,18 -11,18 3,50 359.61 CB-GYRO-SS 600,00 10.17 94,70 598.46 534.66 6014567.10 557165,78 -24,82 3,50 359.81 CB-GYRO-SS 700.00 13.67 94,67 696,29 632.49 6014565.58 557186,38 -44.05 3.50 359.88 MWD+IFR+MS 800.00 17,17 94,65 792.67 728,87 6014563.62 557212,90 -68,79 3.50 359.91 MWD+IFR+MS 900,00 20,67 94.64 887,25 823,45 6014561.24 557245,24 -98.97 3.50 359,93 MWD+IFR+MS 1000.00 24,17 94,63 979.67 915.87 6014558.45 557283.28 -134.45 3.50 359.94 MWD+IFR+MS 1100,00 27,67 94.62 1069,59 1005,79 6014555,26 557326,87 -175,12 3.50 359.95 MWD+IFR+MS 1200.00 31,17 94.62 1156.68 1092,88 6014551.67 557375.85 -220,82 3,50 359,95 MWD+IFR+MS 1300.00 34.67 94.61 1240.61 1176.81 6014547.71 557430.05 -271.38 3.50 359.96 MWD+IFR+MS spel""'l""''Y-sun DRIL.L.ING seRVIces " K.\U.1Øl.IltTONCæ.W.vt\" 'perry-Sun - Draft Copye KW A Planning bp [ ë~,;";~~,;·):;· BP Amoco ! Field' Milne Point I Site:' M Pt G Pad ! Well: Plan Moe G-18 L_~~'~~I..p'nlh: Plan Moe Survey -- .---... ------- - - ..,...--.- "..-- Dale: 12/12/2003 Time: 11 :06:04 ¡'age: 3 CO-OI"dimlle(:'iE) I~efen'nee: Well: Plan Moe G-18, True North , Vertical (TVI» Reference: 0-14 ( 34.3 + 29.5 GL) 63,8 i Seelion (\'S) I~eferenee: Well (0.00N,0.00E,296.14Azi) i Survey Calculation Method: Minimum Curvature Ub: Oracle I no ..__ ____.. , _......._. _,J .. Sys 1'VI>' .' .. .. , ·d', .. ·;.·MD Ine! Azim TVD MapN . MapE VS '. DLS TI?O ''', ..·,...,';.;,.c;.;,.;,Y.·" :.:.\..ft . deg deg ft ft . .::!.!:; :.:~ . n" . ··ft ft ft" .. degf100ft deg ::~', ~ ;.;;.',;.,' 1400,00 38.17 94.61 1321.06 1257.26 6014543.40 557489.25 -326.60 3,50 359.96 MWD+IFR+MS 1500,00 41.67 94.61 1397.73 1333.93 6014538.73 557553.25 -386,30 3.50 359.96 MWD+IFR+MS 1600,00 45.17 94.60 1470.35 1406,55 6014533.74 557621.79 -450,23 3,50 359.97 MWD+IFR+MS 1700.00 48.67 94.60 1538.64 1474,84 6014528.43 557694,62 -518,17 3,50 359,97 MWD+IFR+MS 1800,00 52,17 94.60 1602,33 1538.53 6014522,84 557771.48 -589,85 3.50 359.97 MWD+IFR+MS 1900,00 55.67 94.60 1661,21 1597.41 6014516,98 557852.07 -665,02 3,50 359.97 MWD+IFR+MS 2005.42 59.36 94.60 1717,81 1654,01 6014510,54 557940.74 -747,73 3,50 359,97 MWD+IFR+MS 2100,00 59.36 94,60 1766,01 1702,21 6014504,64 558021.90 -823.42 0.00 0.00 MWD+IFR+MS 2200,00 59.36 94.60 1816,96 1753.16 6014498.40 558107.71 -903.45 0.00 0.00 MWD+IFR+MS 2291.91 59,36 94.60 1863.80 1800.00 6014492,67 558186,58 -977,02 0.00 0.00 BPRF 2300.00 59,36 94,60 1867.92 1804,12 6014492,17 558193.52 -983.49 0.00 0.00 MWD+IFR+MS 2400.00 59.36 94.60 1918.88 1855.08 6014485,93 558279.32 -1063,52 0.00 0,00 MWD+IFR+MS 2500,00 59.36 94.60 1969.83 1906.03 6014479.70 558365,13 -1143.55 0.00 0.00 MWD+IFR+MS 2600.00 59.36 94.60 2020.79 1956.99 6014473.46 558450,94 -1223,59 0,00 0.00 MWD+IFR+MS 2696.47 59.36 94.60 2069.95 2006.15 6014467.44 558533.72 -1300.79 0.00 0.00 MWD+IFR+MS 2700,00 59.19 94.58 2071.75 2007.95 6014467.22 558536.75 -1303,62 5,00 185.72 MWD+IFR+MS 2800,00 54.22 93.96 2126,64 2062.84 6014461,63 558620.11 -1381.17 5,00 185.73 MWD+IFR+MS 2900,00 49.25 93.26 2188,55 2124.75 6014457.27 558698.46 -1453,67 5.00 186,07 MWD+IFR+MS 3000.00 44,28 92.45 2257.03 2193,23 6014454,18 558771,22 -1520.58 5.00 186,50 MWD+IFR+MS 3100,00 39,32 91.48 2331.56 2267.76 6014452.37 558837,82 -1581.38 5,00 187,06 MWD+IFR+MS 3200,00 34,37 90,29 2411.56 2347.76 6014451.87 558897,76 -1635.61 5,00 187,78 MWD+IFR+MS 3214,77 33,64 90.08 2423.80 2360,00 6014451.91 558906,02 -1643.04 5,00 188,74 103/4" 3300.00 29.44 88.74 2496.42 2432,62 6014452.67 558950,58 -1682.87 5.00 188.91 MWD+IFR+MS 3400.00 24.53 86.64 2585.51 2521,71 6014454.78 558995,89 -1722,78 5.00 190,05 MWD+IFR+MS 3500,00 19,66 83,58 2678,14 2614,34 6014458,17 559033.33 -1755,05 5.00 191,93 MWD+IFR+MS 3600,00 14.88 78.61 2773,61 2709,81 6014462,81 559062,62 -1779.44 5.00 194,77 MWD+IFR+MS 3700,00 10.30 69.24 2871.18 2807,38 6014468,68 559083.53 -1795.74 5.00 199,51 MWD+IFR+MS 3800.00 6.38 47.14 2970,13 2906.33 6014475,73 559095,92 -1803.85 5,00 208.67 MWD+IFR+MS 3900.00 5.01 356.72 3069.69 3005,89 6014483.90 559099,68 -1803.69 5.00 230.56 MWD+IFR+MS 4000.00 7.71 317,04 3169.12 3105,32 6014493,13 559094.79 -1795.28 5.00 280.76 MWD+IFR+MS 4100.00 11.98 301.46 3267,64 3203,84 6014503,36 559081.28 -1778,67 5.00 320.22 MWD+IFR+MS 4200.00 16.66 294.24 3364,51 3300,71 6014514,50 559059,26 -1753,99 5.00 335.59 MWD+IFR+MS 4300,00 21.48 290,16 3459.00 3395,20 6014526.47 559028,89 -1721.43 5,00 342,59 MWD+IFR+MS 4400,00 26,37 287.52 3550,38 3486,58 6014539,18 558990.40 -1681,24 5.00 346.45 MWD+IFR+MS 4431.94 27,94 286,86 3578,80 3515,00 6014543.38 558976.44 -1666.84 5.00 348,86 TUZC 4500.00 31,29 285.67 3637.96 3574,16 6014552,53 558944.09 -1633,72 5.00 349.45 MWD+IFR+MS 4600.00 36.23 284.27 3721.08 3657.28 6014566.42 558890.31 -1579,23 5.00 350.49 MWD+IFR+MS 4700.00 41,18 283.17 3799,09 3735.29 6014580.74 558829.48 -1518.19 5.00 351,65 MWD+IFR+MS 4719.69 42.16 282,98 3813.80 3750,00 6014583.61 558816.70 -1505.44 5,00 352.51 Ugnu-MA 4733.25 42.83 282,85 3823,80 3760,00 6014585.58 558807,76 -1496,52 5.00 352,66 Ugnu-MB1 4800,00 46.14 282.27 3871.41 3807.61 6014595,39 558762,04 -1451.06 5,00 352,75 MWD+IFR+MS 4803.45 46.31 282.24 3873,80 3810,00 6014595,90 558759,60 -1448.64 5,00 353,17 Ugnu-MB2 4900.00 51.11 281.50 3937.49 3873.69 6014610.26 558688,52 -1378.36 5.00 353.19 MWD+IFR+MS 4974.51 54.81 281,00 3982.36 3918,56 6014621.41 558630.11 -1320.90 5.00 353.67 MWD+IFR+MS 5000,00 54,81 281,00 3997,05 3933.25 6014625,22 558609.64 -1300,78 0.00 0,00 MWD+IFR+MS 5011.71 54.81 281.00 4003.80 3940,00 6014626,98 558600,23 -1291.55 0.00 0.00 Ugnu-MC 5046.42 54.81 281.00 4023,80 3960,00 6014632.18 558572.35 -1264.17 0.00 0.00 SBF2-NA 5098.48 54.81 281,00 4053.80 3990,00 6014639,97 558530.52 -1223.09 0.00 0.00 SBF1-NB 5100.00 54.81 281,00 4054,68 3990.88 6014640,20 558529.30 -1221.89 0,00 0.00 MWD+IFR+MS 5124.51 54.81 281,00 4068.80 4005,00 6014643,87 558509,61 -1202,56 0.00 0.00 MWD+IFR+MS 5142.05 55.69 281,00 4078,80 4015.00 6014646,51 558495.44 -1188.64 5.00 360.00 SBE4-NC 5169.14 57,04 281.00 4093.80 4030.00 6014650.65 558473,28 -1166.88 5,00 0.00 SBE2-NE 5200.00 58.59 281.00 4110.24 4046,44 6014655.43 558447.60 ' -1141.66 5.00 360.00 MWD+IFR+MS spe~~Y-5un DRILLING seRVices " N.\W¥lJliTON COMf'.vt'o' .sperry-Sun - Draft COP' KW A Planning ,"f:i~~~f1,¡,:;:~r~l~~~;,' ' 5~:::~:~~:: ':,~:~~::~å~, ~.:1:;8,_______" ... 5257.15 5300.00 5323.48 5400,00 5427.43 5457.71 5508,25 5533.25 5550.00 5575.00 5600.00 5625.00 5645.80 5650.00 5675.00 5682.76 5700,00 5800.00 5900.00 6000.00 6100.00 6200,00 6300.00 6400.00 6500,00 6600.00 6700,00 6800.00 6900.00 7000,00 7100.00 7200.00 7300.00 7400.00 7435,52 7456.86 7500,00 7600.00 7646,87 7700.00 7800,00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8524.79 ,'8524,80 ','Azim deg 281,00 63,59 281,00 64,76 281,00 68.59 281.00 69.96 281,00 71.47 281.00 74.00 281,00 74.00 281.00 76.00 281.21 78.98 281,52 81,97 281,82 84,96 282,11 87.44 282,36 87.94 282.41 90.93 282.70 91.85 282.79 91.85 282.79 91.85 282.79 91.85 282,79 91,85 282,79 91.85 282,79 91.85 282,79 91,85 282.79 91.85 282.79 91.85 282.79 91,85 282,79 91.85 282.79 91.85 282.79 91.85 282,79 91,85 282.79 91,85 282.79 91.85 282.79 91,85 282.79 91.85 282.79 91,85 282.79 91,00 282,79 90,87 284,51 90.57 288.50 90.43 290.37 90.43 290.37 90.43 290,37 90.43 290,37 90.43 290,37 90.43 290,37 90.43 290,37 ,90.43 290.37 90.43 290.37 90.43 290,37 90,43 290,37 90.43 290,37 .... ',' ....... o. . , .... .. .. . ..... ... ..... ,".:n:".:..:.::..:. :' .:" . . " .:: ,"" ~~ .. .. TV!:>:' >-SysTVD' ·ft ' , ,," '" ft 4138.80 4075,00 4158,57 4168,80 4199.09 4208,80 4218.80 4233,80 4240,69 4245.02 4250,44 4254,57 4257.42 4258,80 4258.97 4259,22 4259,03 4258.47 4255.24 4252.00 4248,77 4245.53 4242.30 4239,06 4235,83 4232.59 4229.36 4226,12 4222.89 4219.65 4216.42 4213,18 4209,95 4206.72 4203.48 4202,33 4201.80 4201,10 4199.83 4199.42 4199,02 4198.27 4197.51 4196.76 4196.00 4195.25 4194.50 4094,77 4105.00 4135,29 4145.00 4155.00 4170,00 4176,89 4181.22 4186.64 4190.77 4193,62 4195,00 4195.17 4195.42 4195,23 4194.67 4191.44 4188,20 4184.97 4181.73 4178.50 4175,26 4172,03 4168,79 4165.56 4162,32 4159.09 4155.85 4152,62 4149,38 4146.15 4142,92 4139.68 4138.53 4138.00 4137,30 4136.03 4135.62 4135,22 4134.47 4133,71 4132.96 4132,20 4131.45 4130.70 4193,74 4129,94 4192.99 4129,19 4192.80 4129.00 4192,80" 4129,00 .·"~tiif~C~~~~~¿J~~;~ :: :.>....... . MapN ft "'" 6014664,50 6014671.47 6014675.34 6014688.22 6014692,92 6014698,15 6014707.00 6014711.40 6014714.40 6014719.02 6014723.82 6014728,78 6014733,03 6014733,89 6014739.14 6014740.79 6014744.48 6014765.85 6014787.23 6014808.60 6014829.97 6014851.35 6014872.72 6014894.10 6014915.47 6014936.85 6014958,22 6014979.60 6015000.97 6015022.35 6015043.72 6015065.10 6015086,47 6015107.84 6015115.44 6015120.00 6015129.86 6015157,52 6015172.77 6015190.88 6015224,96 6015259.05 6015293,13 6015327,21 6015361.30 6015395.38 6015429.46 6015463,55 6015472,00 6015472,00 '::,:::'mrt~~, " 558398.94 558361.58 558340.81 558271,75 558246,54 558218.45 558171,00 558147.38 558131.49 558107.53 558083.35 558059.02 558038,70 558034.60 558010.16 558002.58 557985.75 557888.13 557790,50 557692,88 557595.25 557497.62 557400.00 557302.37 557204.75 557107,12 557009.50 556911.87 556814,25 556716.62 556618.99 556521,37 556423.74 556326,12 556291.44 556270,60 556228.62 556132,56 556088.25 556038.31 555944,31 555850,31 555756,31 555662,31 555568.31 555474.31 555380.31 555286,31 555263,01 555263.00 bp "::"VS' '., '''ft -1093.88 DLSTFÒ' deg/10Oft: 'deg 5.00 360.00 SBE1-NF -1057,19 -1036,79 -968.97 -944.21 -916.62 -870,03 -846,83 -831,21 -807.62 -783.75 -759.67 -739.52 -735.45 -711.15 -703.60 -686,84 -589.59 -492,34 -395,09 -297,85 -200.60 -103.35 -6,10 91,14 188,39 285,64 382.89 480.13 577.38 674,63 771,88 869,13 966.37 1000.92 1021.68 1063.78 1162.35 1208,89 1261,75 1361.24 1460.73 1560.23 1659.72 1759,21 1858.70 1958,19 2057,68 2082,34 2082.36 5,00 0,00 12.00 12,00 12.00 12,00 12.00 12.00 12.00 12,00 4.00 4,00 4,00 0.00 0,00 0,00 0,00 0,00 0.00 0,00 0,00 0.00 0.00 0.00 5,00 5.00 5,00 5,00 5.00 0.00 0.00 360.00 0.00 360.00 0,00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0,00 0.00 4.00 0,00 0.00 0.00 0.00 179.94 94.23 94.26 94,31 0.00 0.00 MWD+IFR+MS TSBD-Top OA MWD+IFR+MS TSBC-Base OA Moe Fault 1 0,00 0,00 5,81 5.76 5.69 Moe T1 Rev 1 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 5,64 5.61 5.59 5.59 5.59 MWD+IFR+MS SBA5-Base OB MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 0.00 0,00 0.00 0.00 0.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 0,00 0.00 0.00 0.00 0.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 0.00 0.00 0,00 0.00 0.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS Moe T2 Rev 1 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 0.00 0.00 0.00 0.00 0.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 0.00 MWD+IFR+MS 0,00 MWD+IFR+MS 0.00 4 1/2" 0.00 Mae T3 REV 1 4" DAlto 11/25/2003 055204 p055204 DESCRIPTION GROSS VENDOR DISCOUNT NET DATE INVOICE I CREDIT MEMO H 11/25/200 PR111803N PERMIT TO DRill EES e RECEIVE JAN 2 1 2004 Ala ka Oil & Gas Cons. Co Anchorage -(1'1 þ~)(~- l ~ ~ l?; L I TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHQRAG;. AK99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 CONSOLIDATED COMMERCIAL ACCOUNT Ho.P 055204 e r;'" "1'" .111111\ ,'llh\ .,11.11,,,1" t,"", PAY: AMOUNT *******$1 00.00******* TO THE ORDER OF: Oil & GAS 333 W 7TH AVENUE SUITE 100 ANCHORA<3E. AK 99501-3539 NQTV~~~~fi 1~.~b~YS.. ..'~. ..>.. ~:'7".'-'¿ \'\;1;i'·~'?'\'i:'W·~·..:~~~~i~i;'%:f~ , . . .' '"\ 8" .., .' , < . . :. ",' :' .. ," .. .. -'.' . : ". 4:- . .'._.....0 ". .,"'...~ ., .. ". .. -.. .. ,- ... . .. .~. . .:., :':.:::..:<.:::::":':':::~;.., ,:~:·::·:1é'·j\·ff~;~:~~~;t'f):·:""'·~~~J II' 0 5 5 2 0 ....11. I: 0.... . 2 0 3 8 g 5 I: O1. 2 7 8 g b liD e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME )1~ (J-$ ?-Oy -0 2/) PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well_, Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(t), all (PH) 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 The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon " issuance of a conservation order ~oving a ./ .f"/~ V/ spacing exception. rß, C-/ (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 07110/02 C\jody\templates Geology WEl:hf~'MITc"E¢.KLlST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB G-18 Program DEV Well bore seg 0 PTD#:2040200 Company BPEXPLORATION(ALASKA)INC InitialClasslType DEV/PEND GeoArea 890 Unit 11328 On/OffShore On Annular Disposal 0 Administration 1 Pßrmit fee attache.d Yes 2 .Leasßnumberappropriate. Yßs 3 .U.n[que weltn.amß.aod ol.!mb.er . .. . Yßs . .. 4 WellJQC<ltßd in.a defineJ:Lpool. Yßs 5 WeJIJQcated proper distance. from driJling unitb.oundary YßS SI?ACING EXCEPTION NEEDED: 6 WeU IQcatßd pr.oper .distance from otbeJ welJs No . WelJ is JOC<lted IßSs. than 20.0'. from. O-Sand perforatjo.ns In.MfJU G-.12 (ioactille.PJoducer), 7S.utfjcien!.acreageayailable In. dJilJiog unjt. No G~ 12 perfoJatioos iO OoSands. occur witbio same driJIing unit 8 Jfdßvi¡¡ted, js weJlb€)re pl¡¡tincJu.ded Yßs 9 .Operator onl}' affected party. Yes 10 .Operator bas. appropriate. bond lnJorce . . . Yßs. .. . .. . 11 pß(I1] it c.ao be lSSl.!ed wjtbQut conserva.tion order Y ßS Appr Date 12 Pßrmit~ao be lSSl.!ed wjtbQut ¡¡d.ministratille.approvaJ No SFD 1/22/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQcatßd within area and.str¡¡ta .authorlzed by.lojectioo Ordßr # (putlO# in.commßotsUFor. NA 15 AJI welJs.withln.1l4.mile are.a of reyiew jdßotlfied (Fors.ervjC.ß)llell onl}'L. .NA . 16 Pre-produJ::ed iojector; .duratio.nof pre-pro.ductioo tess. than.:3 montbs(For.service well onJy) .NA 17 ACMPF:indjng .of Con.sisteocy.h.as beenJs.sued.for.this project . . . NA WelJ drllled from exjsiiog pa.d, Engineering 18 .C.ooduct.or string.PfQvided Yßs 19Surf¡¡cß .cas.ing pJQtects. alLknown USDWs Yßs No USDW, 20 .CMTv.oladeQl.!ate.to Circ.utate on cond.uctor.& SUJfcsg YßS . 8deJ::uate excess, 21CMT v.ol adeQu.ate to tie-inJQng .striog to surf csg. N.o 22 .CMTwilJ coyera]l koow.npro.ductiye bQri;¡:on.s No Slotted, 23 .C.asiog desigos ad.eCua.te for C..T. B .&. permafrost Yßs 24 .A.dequate.tan.kage.oJ re.serye pit YßS Doyoo 14, 25 Jf.a.re-.drilt has.a 10-403 fQr abandon.ment beßO apPJoved NA New well, 26 A.dequateweHbore sepªratjo.n.propose.d. . . . .Yßs . . . . . . . . . 27 Jtdjverter Jeq.uired, does j!.meßt reguJations .YßS Appr Date 28 .DJilJiog flujd. program schem¡¡tic. & eq.uip Jistadequate. Y ßS M¡¡x MW. 1.1 ,0 .ppg.. WGA 1/22/2004 29 .B.OPEs,.dothey meetreguJation Yßs 30 .BOPEpress ra.tiog appropriate; .testto(put psig in .comments) Yßs Test to .3500. psi. MSfJ 17.5.0 psi.. 31 Choke. manifold cQmpJies. w/APt RfJ-53 (May 64) Yßs 32 Work willoccjJr withoutoperationshutdo.wn. YßS 33 Js preseoce. Qf H2S gas. prQbable. No. 34 MeJ::han[caLcoodJlloo of we.lIs within80R yerified (for.s.ervice welJ on.ly) .NA 35 Pßrmit cao be lssl.!ed wlo hydrogen. sulfide meaSjJres 36 .D.ata.PJeseoted on. pote.ntial oveJpressurß .zones. 37 .Sßismican¡¡lysjs. of shaJlow gas.z.ooes. 38 .Sßªbed .condjtjoo Sl.!rvey(if off-sh.ore} 39 . Conta.ct namelphoneJor.weelsly progress.reports [exploratory .0oIYJ. e e YßS Yßs Expected pressurßJs. 10A ppgEMW in.Schrade.rBluff; wiIJ be. driJled with.1P,.9.ppg mud. t-i}'drates.ltave be.eo ßo~ountered in .G-Pad. weJls.. Mitiga.tion disc.uss.ed io DrilUn-9.Ha;¡:ards seJ::tio.n, Appr SFD Date 1/22/2004 NA .NA NA Geologic Commissioner: bTJ' Date: ¡!2f,) 1- Engineering Commissioner: Date Public Commissioner Date SPACING EXCEPTION NEEDED: CO 477 allows spacing rule modifications by Administrative Approval. Well may be drilled, but not perforated or produced until such approval is granted. SFD e e 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. Sperry-Sun Drilling Services LIS Scan Utility '? ,,')' C(.... C' <- r.' <:.- '-.' -. ._/ c:::... ...... $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 07 10:32:26 2004 J ) J 7-1 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/04/07 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 MPG-18 500292319400 BP Exploration (Alaska) / Inc Sperry-Sun Drilling Services 07 -APR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002917922 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002917922 T. MCGUIRE E. VAUGHN MWD RUN 3 MW0002917922 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002917922 T. MCGUIRE E. VAUGHN MWD RUN 5 MW0002917922 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 27 13N 10E 2134 3462 MSL 0) 63.70 29.70 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE 13.500 9.875 6.750 (IN) SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 3225.0 5418.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVO). 3. THIS WELLBORE EXITS MPG-18 PBl AT 5418'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. MWD RUN 3 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND MILL WINDOW. THE TOP OF THE WHIPSTOCK WAS AT 5418'MD AND THE BOTTOM WAS AT 5430'MD. ONLY SROP DATA ARE PRESENTED. 7. MWD RUN 4 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ AND AN EXPERIMENTAL GAMMA AND AT-BIT-INCLINATION (GABI) TOOL, WHICH FAILED AT 5452'MD. ONLY SROP DATA WERE ACQUIRED AND ARE PRESENTED. 8. MWD RUN 5 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ AND AT-BIT-INCLINATION (ABI) . 9. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 3/4/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 10. MWD RUNS 1 - 5 REPRESENT WELL MPG-18 WITH API#: 50-029-23194-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8421'MD/4184'TVO. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 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 ROP FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 70.5 112.5 3200.0 3200.0 3200.0 3200.0 3200.0 STOP DEPTH 8360.0 8421. 5 8367.5 8367.5 8367.5 8367.5 8367.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 70.5 3235.0 5418.0 5442.5 5452.0 MERGE BASE 3235.0 5418.0 5442.0 5452.0 8421. 5 # Data Format Specification Record Data Record Type............ ... ...0 Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units.. ........ .Feet Data Reference Point............. . Undefined Frame Spacing... .......... ....... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H Min 70.5 0.84 Max 8421. 5 2132.39 Mean Nsam 4246 16703 229.764 16619 First Reading 70.5 112.5 Last Reading 8421.5 8421. 5 GR MWD API 9.05 124.39 67.375 16580 70.5 8360 RPX MWD OHMM 0.06 1808.31 7.72501 10336 3200 8367.5 RPS MWD OHMM 0.12 2000 12.3941 10336 3200 8367.5 RPM MWD OHMM 0.1 2000 11.4429 10336 3200 8367.5 RPD MWD OHMM 0.08 2000 16.7396 10336 3200 8367.5 FET MWD HOUR 0.1198 72.6213 0.922342 10336 3200 8367.5 First Reading For Entire File......... .70.5 Last Reading For Entire File... ....... .8421.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name...... ...... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 70.5 112.5 STOP DEPTH 3189.0 3235.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-FEB-04 Insite 66.37 Memory 3235.0 112.0 3235.0 .0 63.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 155790 # 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 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 13.500 .0 SPUD MUD 8.90 200.0 9.5 400 12.8 .000 .000 .000 .000 .0 75.2 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 70.5 3235 1652.75 6330 70.5 3235 ROP MWD010 FT/H 0.97 1302.06 231.05 6246 112.5 3235 GR MWD010 API 22.55 124.39 67.7197 6238 70.5 3189 First Reading For Entire File......... .70.5 Last Reading For Entire File.......... .3235 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 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 GR RPX FET RPD RPS RPM ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3189.5 3200.0 3200.0 3200.0 3200.0 3200.0 3235.5 STOP DEPTH 5418.0 5418.0 5418.0 5418.0 5418.0 5418.0 5417.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 20-FEB-04 Insite 66.37 Memory 5418.0 3235.0 5418.0 7.1 67.1 TOOL NUMBER 149205 136749 9.875 3225.0 LSND 10.80 55.0 8.5 1200 4.8 1. 900 1. 260 1. 700 2.400 68.0 105.8 68.0 68.0 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3189.5 5418 4303.75 4458 3189.5 5418 ROP MWD020 FT/H 1.16 2132.39 227.152 4365 3235.5 5417.5 GR MWD020 API 9.05 113.62 63.1871 4458 3189.5 5418 RPX MWD020 OHMM 0.06 75.68 8.20875 4437 3200 5418 RPS MWD020 OHMM 0.12 2000 10.7915 4437 3200 5418 RPM MWD020 OHMM 0.1 2000 12.5552 4437 3200 5418 RPD MWD020 OHMM 0.08 2000 24.3291 4437 3200 5418 FET MWD020 HOUR 0.12 43.79 1.18499 4437 3200 5418 First Reading For Entire File........ ..3189.5 Last Reading For Entire File.. ...... ...5418 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record..65535 File Type.. ............. .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5418.0 STOP DEPTH 5442.0 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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 22-FEB-04 Insite 66.37 Memory 5442.0 5418.0 5442.0 .0 .0 TOOL NUMBER 6.750 5418.0 LSND 10.70 62.0 8.0 1000 4.6 .000 .000 .000 .000 .0 87.8 .0 .0 Data Reference Point............. .Undefined Frame Spacing............ ........ .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD030 FT/H Min 5418 3.06 Max 5442 42.18 First Reading For Entire File........ ..5418 Last Reading For Entire File.......... .5442 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type.... ....... ... ..LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 5 Mean 5430 14.119 Nsam 49 49 First Reading 5418 5418 Last Reading 5442 5442 header data for each bit run in separate files. 4 .5000 START DEPTH 5442.5 STOP DEPTH 5452.0 # 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): 22-FEB-04 Insite 66.37 Memory 5452.0 5442.0 5452.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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... ..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 DEPT ROP MWD040 .0 .0 TOOL NUMBER 6.750 5418.0 FLO-PRO 10.80 49.0 10.3 170000 2.5 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD040 FT/H Min 5442.5 26.42 Max 5452 108.83 First Reading For Entire File......... .5442.5 Last Reading For Entire File.......... .5452 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Mean 5447.25 70.0185 Nsam 20 20 .0 78.1 .0 .0 First Reading 5442.5 5442.5 Last Reading 5452 5452 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..04/04/07 Maximum Physical Record. .65535 File Type. .............. .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 5418.5 5418.5 5418.5 5418.5 5418.5 5418.5 5452.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 8367.5 8367.5 8367.5 8367.5 8360.0 8367.5 8421.5 23-FEB-04 Insite 66.37 Memory 8421. 0 5452.0 8421. 0 80.7 94.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 160796 148574 # 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): 6.750 5418.0 FLO-PRO 10.80 49.0 10.0 170000 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .400 .290 .850 2.000 65.0 93.5 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units........ ...Feet Data Reference Point...... ....... . Undefined Frame Spacing.................. ...60 .1IN Max frames per record. ........... .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5418.5 8421. 5 6920 6007 5418.5 8421.5 ROP MWD050 FT/H 0.84 1260 232.648 5939 5452.5 8421. 5 GR MWD050 API 42.59 112.79 70.1827 5884 5418.5 8360 RPX MWD050 OHMM 0.73 1808.31 7.36115 5899 5418.5 8367.5 RPS MWD050 OHMM 3.04 2000 13 .5995 5899 5418.5 8367.5 RPM MWD050 OHMM 3.24 1808.93 10.6064 5899 5418.5 8367.5 RPD MWD050 OHMM 3.37 1809.34 11.0312 5899 5418.5 8367.5 FET MWD050 HOUR 0.2251 72.6213 0.724862 5899 5418.5 8367.5 First Reading For Entire File......... .5418.5 Last Reading For Entire File.......... .8421.5 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type.. ............. .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name..... .......... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments....... ......... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .04/04/07 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 ~,.... .. ",/_. c}"; (.) ,,~. (.) r v Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 07 08:36:53 2004 #- \ }>\)- Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name..... . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name......... . . . .LISTPE Date.................... .04/04/07 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 MPG-18PB1 500292319470 BP Exploration (Alaska) I Inc Sperry-Sun Drilling Services 07-APR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002917922 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002917922 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 27 13N 10E 2134 3462 MSL 0) 63.70 29.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13 .500 9.875 CASING SIZE (IN) 20.000 10.750 DRILLERS DEPTH (FT) 112.0 3225.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. THE MAIN WELLBORE EXITS THIS SECTION AT 5418'MD. THIS SECTION WAS PLUGGED-BACK FOR GEOLOGICAL REASONS. 6. A MAD PASS WAS PERFORMED AFTER REACHING TD OF RUN 2, FROM TD TO 4418' MD (BIT DEPTH) . 7. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 3/4/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1 & 2 REPRESENT WELL MPG-18 PB1 WITH API#: 50-029-23194-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5578'MD/4244'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT SMOOTHED TOOL SPEED WHEN NOT 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). SLIDE = NON-ROTATED INTERVALS. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 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 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH STOP DEPTH GR ROP FET RPX RPS RPM RPD $ 70.5 112.5 3200.0 3200.0 3200.0 3200.0 3200.0 5527.5 5578.0 5537.5 5537.5 5537.5 5537.5 5537.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 70.5 3235.0 MERGE BASE 3235.0 5578.0 # REMARKS: MERGED MAIN PASS. $ # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 70.5 5578 2824.25 11016 70.5 5578 ROP MWD FT/H 0.97 2132.39 227.475 10932 112.5 5578 GR MWD API 9.05 124.39 66.1117 10915 70.5 5527.5 RPX MWD OHMM 0.06 75.68 8.11009 4676 3200 5537.5 RPS MWD OHMM 0.12 2000 10.575 4676 3200 5537.5 RPM MWD OHMM 0.1 2000 12.2645 4676 3200 5537.5 RPD MWD OHMM 0.08 2000 23.4528 4676 3200 5537.5 FET MWD HOUR 0.12 43.79 1.15739 4676 3200 5537.5 First Reading For Entire File......... .70.5 Last Reading For Entire File......... ..5578 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............. . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX RAT $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 4369.0 4377.0 4377.0 4377.0 4377.0 4377.0 4412.0 STOP DEPTH 5526.0 5536.0 5536.0 5536.0 5536.0 5536.0 5572.5 # MERGED DATA SOURCE PBU TOOL CODE $ MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE # REMARKS: MERGED MAD PASS. $ # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4369 5572.5 4970.75 2408 4369 5572.5 RAT MAD FT/H 0.62 1424.53 335.234 2322 4412 5572.5 GR MAD API 22.23 111.08 64.4173 2315 4369 5526 RPX MAD OHMM 1. 33 48.33 6.35772 2319 4377 5536 RPS MAD OHMM 1.3 54.99 6.72918 2319 4377 5536 RPM MAD OHMM 1. 33 46.63 7.06851 2319 4377 5536 RPD MAD OHMM 1. 39 39.8 7.24146 2319 4377 5536 FET MAD HOUR 1.41 21. 57 12.5376 2319 4377 5536 First Reading For Entire File......... .4369 Last Reading For Entire File.......... .5572.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 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 GR ROP $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 70.5 112.5 STOP DEPTH 3189.0 3235.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-FEB-04 Insite 66.37 Memory 3235.0 112.0 3235.0 .0 63.4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER 155790 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value.... .............. ....-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 13.500 .0 SPUD MUD 8.90 200.0 9.5 400 12.8 .000 .000 .000 .000 .0 75.2 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 70.5 3235 1652.75 6330 70.5 3235 ROP MWD010 FT/H 0.97 1302.06 231.05 6246 112.5 3235 GR MWD010 API 22.55 124.39 67.7197 6238 70.5 3189 First Reading For Entire File......... .70.5 Last Reading For Entire File.......... .3235 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type......... . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 3189.5 3200.0 3200.0 3200.0 3200.0 3200.0 3235.5 STOP DEPTH 5527.5 5537.5 5537.5 5537.5 5537.5 5537.5 5578.0 # 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: 20-FEB-04 Insite 66.37 Memory 5578.0 3235.0 5578.0 7.1 67.1 TOOL NUMBER 149205 136749 9.875 3225.0 LSND 10.80 55.0 8.5 1200 4.8 1.900 1. 260 1.700 68.0 105.8 68.0 MUD CAKE AT MT: 2.400 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3189.5 5578 4383.75 4778 3189.5 5578 ROP MWD020 FT/H 1.16 2132.39 222.71 4686 3235.5 5578 GR MWD020 API 9.05 113.62 63.9671 4677 3189.5 5527.5 RPX MWD020 OHMM 0.06 75.68 8.11009 4676 3200 5537.5 RPS MWD020 OHMM 0.12 2000 10.575 4676 3200 5537.5 RPM MWD020 OHMM 0.1 2000 12.2645 4676 3200 5537.5 RPD MWD020 OHMM 0.08 2000 23.4528 4676 3200 5537.5 FET MWD020 HOUR 0.12 43.79 1.15739 4676 3200 5537.5 First Reading For Entire File......... .3189.5 Last Reading For Entire File.......... .5578 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............ . . . .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/04/07 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