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203-224
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:Russell Gallen - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:L-43 initial BOPE test report Date:Saturday, May 4, 2024 5:40:59 AM Attachments:L-43 BOPE test report (initial ) 2024.xlsx Some people who received this message don't often get email from russell.gallen@hilcorp.com. Learn why this is important Thanks Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 5/3/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2032240 Sundry #324-111 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:3728 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2-7/8" x 5" VBR P Flow Indicator P P #2 Rams 1 2-7/8" x 5" VBR P Meth Gas Detector P P #3 Rams 1 Blinds P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR 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)1750 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 0 NA Full Pressure Attained (sec)57 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 2412 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 13 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:8.5 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 4/30/24 18:30 Waived By Test Start Date/Time:5/2/2024 20:30 (date) (time)Witness Test Finish Date/Time:5/3/2024 5:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Tested with 2-7/8" test joint Precharge bottle psi = 1,005 psi C. Greub / M. Boord Hilcorp Alaska LLC S. Heim / R. Gallen MPU L-43 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0503_BOP_Hilcorp_ASR1_MPU_L-43 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,645'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: Tubing MD (ft): 6.5 / L-80 8,813' 3/11/2024 Viking Hyd set ESP & Baker 7” x 4-1/2” “ZXP’ LTP and N/A 2,128 MD / 1,935' TVD & 8,835 MD/ 6,691 TVD and N/A See Schematic See Schematic 2-7/8" 6,097' 8,953' Perforation Depth MD (ft): 4-1/2"817' Perforation Depth TVD (ft): Tubing Size: 9-5/8" 7" MD N/A 8,430psi 5,750psi 7,240psi 4,439' 6,803' 7,484' 6,097' 8,953' 9,645' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,484' 9,559' 7,398' 3,728 N/A 112' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 203-224 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23190-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL Same C.O. 432E MILNE PT UNIT L-43 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY ryan.lewis@hilcorp.com 303-906-5178 Ryan Lewis Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:01 pm, Feb 27, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.23 13:57:21 - 09'00' Taylor Wellman (2143) 324-111 DSR-2/28/24MGR07MAR2024 BOPE test to 4000 psi. Annular to 2500 psi. 10-404 SFD 2/29/2024 Obsolete form. SFD JLC 3/8/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.08 12:22:27 -09'00'03/08/24 RBDMS JSB 030824 Well: MPL-43 PTD: 203-224 API: 50-029-23190-00-00 Well Name:MPL-43 API Number:50-029-23190-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:3/11/2024 Estimated Duration:7 days Regulatory Contact:Tom Fouts Permit to Drill Number:203-224 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 4,443 psi @ 7,153’ TVD 2/14/2024 | 12.0 EMW 12.2 KWF Max Potential Surface Pressure: 3,728 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 54° Sail Angle from 4,710’ MD Brief Well Summary: MPU L-43 is a Kuparuk producer that had a TTC-ESP from 2016-22. The ESP plugged with 150’ of sand on the pump. June 2023 the well was converted to a conventional ESP. The cable was compromised on install and we lost the DH gauges after a month. The total runtime for this ESP was 7 months. Due to the excessive BHP Hilcorp has requested permission to flow this well back to reduce the BHP prior to the workover. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 1,800 psi on 6/26/2023 at 8,700’ MD. Pre-Rig Procedure (Non Sundried Work) Slickline After flowing back the well, revalidate the BHP. 1. RU slickline, pressure test PCE to 250psi low / 4,000psi high. 2. Drift and tag with sample bailer. 3. RIH for SBHPS with 10 min stops at 8,738’MD (6,600’ TVD) and 8,630’ MD (6,500’ TVD). 4. RDMO. 5. If BHP is confirmed lower: update BHP, MASP, BOPE configuration and KWF required and provide to AOGCC. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 4,000 psi. 5. Circulate at least one wellbore volume with 12.2# brine water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Well: MPL-43 PTD: 203-224 API: 50-029-23190-00-00 Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with 12.2# KWF prior to setting CTS. 3. Test BOPE to 250 psi low/ 4,000 psi high. Test annular to 250 psi low/ 3,000 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per 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 2-7/8” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 12.2# brine water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable and 3/8” packer vent line and 3/8” cap string. a. Use extreme care in spooling the vent line to promote reuse of the string. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC 11” x 2-7/8”, with 2-7/8” EUE thread. b. 2023 tubing PU weight on ASR #1 recorded as 65 kip. Slack off weight recorded as 36 kip. c. 2-7/8” L-80 EUE yield is 144 kip. d. The ESP packer is pinned to shear release at 22k overpull. Estimated PUW to release packer is ~87 Klbs. e. Work pipe up from 100 Klbs to 115 Klbs in 5 klbs increments. f. If pipe has not released at 115 klbs, contact engineer prior to working pipe any further. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Re-use all tubing based on Caliper data (2/14/24). b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 156 ii. SS Bands = 2 on the motor iii. Protectolizers: 5 + 2 additional doors. iv. Flatguards clamps = 2 - 3 doors welded on. 10. Lay Down ESP. 11. Pressure test both pulled 3/8” vent and capillary tubing to 3500 psi. If PT passes, plan to save for re-run. Well: MPL-43 PTD: 203-224 API: 50-029-23190-00-00 12. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 8,800’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint d. Photograph vent packer prior to running in hole. e. Run single 3/8” cap string the length of the completion and from vent packer back to surface, clamping with cable. 13. PU and MU Viking packer. Verify that there are four (4) setting shear pins and confirm with OE number of release shear pins. Target release pins to shear at 20,000 pounds overpull. Nom. (OD)Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 ~8,800’ MD 4.5 2 Intake Sensor 30 5.62 34 Motor 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 10 GINPSH 45 5.38 ~57 Pump 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” XN-nipple 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~6,430 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” X-nipple with RHC profile 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 30 Packer, Viking ESP Retr. Dual Vent ~2,000 MD 2-7/8" 30 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 Well: MPL-43 PTD: 203-224 API: 50-029-23190-00-00 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~1,720 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 14. Terminate the ESP cable and make up the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 15. Make up the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in the daily report). Bleed the pressure to 500 psi and maintain 500 psi while running in hole. a. Periodically confirm control line is maintaining 500 psi. 16. Continue running ESP completion per plan. 17. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator. MU the control line to the tubing hanger and dummy off any additional control line ports if present. 18. Land tubing hanger, avoiding any damage to ESP cable or control line. RILDS. Lay down landing joint. Note PU and SO weights on tally and in daily report. 19. Drop ball and rod. 20. Pressure up on tubing to 4,000 psi and hold for 15 minutes to set the ESP packer. 21. Bleed tubing to 0 psi. 22. Pressure up on tubing to 4,000 psi and hold for 5 more minutes and then bleed to 0 psi. 23. Bleed packer control line to 0 psi, closing packer vent valves. 24. Slowly pressure up IA at 50 psi/min to 1,500 psi and hold for 30 minutes. Chart test. 25. Lay down landing joint. 26. Set BPV. 27. RDMO ASR. Post-Rig Procedure: Well Support: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Well: MPL-43 PTD: 203-224 API: 50-029-23190-00-00 Slickline: 1. RU slickline, pressure test PCE to 250psi low / 4,000psi high. 2. Pull ball and rod. 3. Pull RHC profile. 4. Pull DGLV and set GLSOV in upper GLM at ~200’ MD. 5. RDMO. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Triple BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 8/7/2023 SCHEMATIC Milne Point Unit Well: MP L-43 Last Completed: 7/7/2023 PTD: 203-224 TD =9,645’ (MD) / TD = 7,484’(TVD) 20” OKB Elev.: 50.8’/ Orig. GL Elev.: 16.3’’ Doyon 16 RT to TTbg spool= 21.84’ 7” 10 11 & 12 13 & 14 15 9-5/8” Howco ES Cementer @ 1,930’ 9-5/8” 8& 9 16 PBTD =9,559’(MD) / PBTD = 7,398’(TVD) 1 2 3 17 & 18 19 4-1/2” 4 5 6 7 KUPARUK RIVER OIL CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,097’ 0.0758 7" Intermediate 26 / L-80 / BTC-M 6.276 Surface 8,953 0.0383 4-1/2" Production 12.6 / L-80 / IBT-M 3.958 8,828’ 9,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,813’ 0.0058 JEWELRY DETAIL No Top (MD) Item 1 162’GLM #4: 2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 2 2,069’GLM #3: 2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 3 2,128’ Packer: Viking Hyd Set ESP Packer W/Dual vent valve 4 2,184’GLM #2: 2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 5 2,243’ 2-7/8” X-Nipple (2.313 ID) - RHC installed 6 8,567’GLM #1:2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 7 8,689’ 2-7/8” XN-Nipple (2.205 No-go ID) 8 8,741.9’ Discharge Head: DSCHG B/O PMP 513 9 8,742’ Zenith Ported Sub: HEAD S/A B/O PRESS PORT 513/538P PMP 10 8,743’ Pump: 538PMSXD FLEX27 135 FER H6 11 8,771’ Gas Separator: 538GM2T HV E V X MT HS FER 12 8,776’ Intake: GPXARCINT FER H6 13 8,777’ Upper Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 14 8,784’ Lower Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 15 8,791’ Motor: 562XP 250 Hp/ 2505V / 61A 16 8,808’ Zenith Sensor & Centralizer:Bottom @ 8,813’ 17 8,828’ Baker Tie-Back Sleeve 18 8,835’ Baker 7” x 4-1/2” “ZXP’ Liner Top Packer 19 8,842’ Baker 7” x 4-1/2” Flex Lock Liner hanger PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C1/B6 9,312’ 9,332’ 7,153’ 7,172’ 20 8/12/2004 Open Kup. A1B 9,320’ 9,360’ 7,160’ 7,200’ 40 6/27/2023 Open Kup. A3 9,394’ 9,414’ 7,234’ 7,254’ 20 8/12/2004 Open Kup. A2 9,415’ 9,435’ 7,255’ 7,275’ 20 6/30/2004 Open Kup. A1 9,449’ 9,469’ 7,289’ 7,309’ 20 6/30/2004 Open Kup. B 9,480’ 9,500’ 7,320’ 7,339’ 20 6/27/2023 Open Ref Log: PDC GR/ CCL - 6/29/2004 OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I in 24” Hole 9-5/8”250 sx Lite-crete in 12-1/4” hole plus 225 sx Class “G” followed by 215 sx Lite-crete through ES cementer 7" 120 sx Class “G” in 8-3/4” hole, est. TOC= 8,453’ 4-1/2”” 120 sx Class “G” in 6-1/8” hole, est. TOC= 8,820’ WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 54 deg. @4,700’ Max Hole Angle through perforations = 6 deg. TREE & WELLHEAD Tree 5M CIW 4” Wellhead 11” 5M FMC Gen 5A, w/ 4-1/2” FMC Tbg. Hngr., 4-1/2” Hydril 521 Top & Btm. Hanger thread and 4” “H” BPV profile GENERAL WELL INFO API: 50-029-23190-00 Orig. Drilling by Doyon 14 – 6/26/2004 Orig. Completion by Nabors 4-ES – 8/14/2004 RWO w/ Nabors 4-ES, ESP c/o and FCO – 12/6/2007 RWO w/ Nabors 3S, ESP c/o 10/4/2008 & 6/2/2009 RWO w/Doyon 16, ESP c/o and FCO – 3/31/2011 & 12/26/2013 ESP Swap and Perf by ASR – 7/7/2023 _____________________________________________________________________________________ Revised By: DH 2/12/2024 PROPOSED Milne Point Unit Well: MP L-43 Last Completed: 7/7/2023 PTD: 203-224 TD =9,645’ (MD) / TD = 7,484’(TVD) 20” OKB Elev.: 50.8’/ Orig. GL Elev.: 16.3’’ Doyon 16 RT to TTbg spool= 21.84’ 7” 10, 11 12 16 14, 15 9-5/8” Howco ES Cementer @ 1,930’ 9-5/8” 9 PBTD =9,559’(MD) / PBTD = 7,398’(TVD) 1 3 4 2 13 4-1/2” 5 6 7 8 KUPARUK RIVER OIL CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,097’ 0.0758 7" Intermediate 26 / L-80 / BTC-M 6.276 Surface 8,953 0.0383 4-1/2" Production 12.6 / L-80 / IBT-M 3.958 8,828’ 9,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.4 / L-80 2.441 Surface ±8,800’ 0.0058 JEWELRY DETAIL No Top (MD) Item 1 ±205’ GLM #4: 2-7/8 X 1'' Side Pocket w/Dummy Valve 2 ±1,953’ GLM #3: 2-7/8 X 1'' Side Pocket w/ Dummy Valve 3 ±2,001’ Packer: Viking ESP Retr.Packer W/Dual vent valve 4 ±2,072’ GLM #2: 2-7/8 X 1'' Side Pocket w/ Dummy Valve 5 ±8,532’ GLM #1: 2-7/8 X 1'' Side Pocket w/ Dummy Valve 6 ±8,620’ 2-7/8” XN-Nipple with RHC profile 7 ±8,672’ Ported Discharge Head 8 ±8,673’ Pump 9 ±8,740’ Gas Separator 10 ±8,748’ Upper Tandem Seal 11 ±8,755’ Lower Tandem Seal 12 ±8,762’ Motor 13 ±8,796’ Intake Sensor & Centralizer: Bottom @ ±8,800’ 14 8,828’ Baker Tie-Back Sleeve 15 8,835’ Baker 7” x 4-1/2” “ZXP’ Liner Top Packer 16 8,842’ Baker 7” x 4-1/2” Flex Lock Liner hanger PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C1/B6 9,312’ 9,332’ 7,153’ 7,172’ 20 8/12/2004 Open Kup. A1B 9,320’ 9,360’ 7,160’ 7,200’ 40 6/27/2023 Open Kup. A3 9,394’ 9,414’ 7,234’ 7,254’ 20 8/12/2004 Open Kup. A2 9,415’ 9,435’ 7,255’ 7,275’ 20 6/30/2004 Open Kup. A1 9,449’ 9,469’ 7,289’ 7,309’ 20 6/30/2004 Open Kup. B 9,480’ 9,500’ 7,320’ 7,339’ 20 6/27/2023 Open Ref Log: PDC GR/ CCL - 6/29/2004 OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I in 24” Hole 9-5/8”250 sx Lite-crete in 12-1/4” hole plus 225 sx Class “G” followed by 215 sx Lite-crete through ES cementer 7" 120 sx Class “G” in 8-3/4” hole, est. TOC= 8,453’ 4-1/2”” 120 sx Class “G” in 6-1/8” hole, est. TOC= 8,820’ WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 54 deg. @4,700’ Max Hole Angle through perforations = 6 deg. TREE & WELLHEAD Tree 5M CIW 4” Wellhead 11” 5M FMC Gen 5A, w/ 4-1/2” FMC Tbg. Hngr., 4-1/2” Hydril 521 Top & Btm. Hanger thread and 4” “H” BPV profile GENERAL WELL INFO API: 50-029-23190-00 Orig. Drilling by Doyon 14 – 6/26/2004 Orig. Completion by Nabors 4-ES – 8/14/2004 RWO w/ Nabors 4-ES, ESP c/o and FCO – 12/6/2007 RWO w/ Nabors 3S, ESP c/o 10/4/2008 & 6/2/2009 RWO w/Doyon 16, ESP c/o and FCO – 3/31/2011 & 12/26/2013 ESP Swap and Perf by ASR – 7/7/2023 Updated 2/20/2024 11” BOPE INTEGRATED11'’-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 2-7/8" Pipe Ram Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 2/20/2024 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: 2/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp KBU 42-6 50133205460000 204209 2/23/2024 HALLIBURTON PPROF KU 31-07X 50133204950000 200148 2/2/2024 HALLIBURTON PressTemp MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Please include current contact information if different from above. T38535 T38536 T38537 T38538 T38539 T38540 T38541 T38542 T38543 2/29/2024 MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 09:17:32 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Ryan Lewis Cc:AOGCC Records (CED sponsored) Subject:PTD 203-224 Approved for 60 day flow back MPU L-43 Date:Tuesday, February 20, 2024 10:30:29 AM Attachments:image001.png Ryan, Hilcorp is approved for a 60 day flow back with a 24/7 man-watch as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907- 793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Lewis <Ryan.Lewis@hilcorp.com> Sent: Friday, February 16, 2024 10:55 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPL-43 Mel- MPU L-43 is a Kuparuk producer that had a TTC-ESP from 2016-22. The ESP plugged with 150’ of sand on the pump. June 2022 the well was converted to a conventional ESP. The cable was compromised on install and we lost the DH gauges after a month. 2/14/24 SBHPS showed a high BHP. The injectors (MPL-05,MPL-63, MPL-09) supporting this well have been shut in. Hilcorp is requesting permission to flowback MPL-43 through the open GLM at 8,567’ MD, up the tubing to the facilities or tanks. Objectives: Flowback MPL-43 to get the BHP down on this well to perform the RWO ESP swap. Notes Regarding Wellbore Condition: - 7” casing test to 1,800 psi on 6/26/2023 at 8,700’ MD. - There is an ESP packer isolating the IA at 2,128’ MD. Procedure (Non Sundried Work) 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: ESP Install Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,645 feet N/A feet true vertical 7,484 feet N/A feet Effective Depth measured 9,551 feet 2,128 & 8,835 feet true vertical 7,390 feet 1,935 & 6,691 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 8,813' 6,671' Viking Hyd Set ESP Packer Packers and SSSV (type, measured and true vertical depth)Baker 7” x 4-1/2” “ZXP’N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: Burst N/A Collapse N/A 3,090psi 7,500psi 5,750psi 7,240psi 8,430psi 8,953' 6,803' 5,410psi Conductor 7,484'9,645' 8,920' 6,097'Surface Production Liner 20" 9-5/8" 7" 78' 6,062' MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT L-43 Plugs Junk measured measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-224 50-029-23190-00-00 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: ADL0025509 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' Size 112' 4,439' Length 817' Casing N/A Taylor Wellman twellman@hilcorp.com 907-777-8449 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 172 0 1,521 42022 0 00 367 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-149 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG PL G 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 3:51 pm, Aug 07, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.08.07 14:22:41 - 08'00' Taylor Wellman (2143) DSR-8/7/23WCB 4-8-204 RBDMS JSB 080823 _____________________________________________________________________________________ Revised By: TDF 8/7/2023 SCHEMATIC Milne Point Unit Well: MP L-43 Last Completed: 7/7/2023 PTD: 203-224 TD =9,645’ (MD) / TD = 7,484’(TVD) 20” OKB Elev.: 50.8’/ Orig. GL Elev.: 16.3’’ Doyon 16 RT to TTbg spool= 21.84’ 7” 10 11 & 12 13 & 14 15 9-5/8” Howco ES Cementer @ 1,930’ 9-5/8” 8& 9 16 PBTD =9,559’(MD) / PBTD = 7,398’(TVD) 1 2 3 17 & 18 19 4-1/2” 4 5 6 7 KUPARUK RIVER OIL CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,097’ 0.0758 7" Intermediate 26 / L-80 / BTC-M 6.276 Surface 8,953 0.0383 4-1/2" Production 12.6 / L-80 / IBT-M 3.958 8,828’ 9,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,813’ 0.0058 JEWELRY DETAIL No Top (MD) Item 1 162’GLM #4: 2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 2 2,069’GLM #3: 2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 3 2,128’ Packer: Viking Hyd Set ESP Packer W/Dual vent valve 4 2,184’GLM #2: 2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 5 2,243’ 2-7/8” X-Nipple (2.313 ID) - RHC installed 6 8,567’GLM #1:2-7/8 X 1'' Side Pocket w/Dummy & BK Latch 7 8,689’ 2-7/8” XN-Nipple (2.205 No-go ID) 8 8,741.9’ Discharge Head: DSCHG B/O PMP 513 9 8,742’ Zenith Ported Sub: HEAD S/A B/O PRESS PORT 513/538P PMP 10 8,743’ Pump: 538PMSXD FLEX27 135 FER H6 11 8,771’ Gas Separator: 538GM2T HV E V X MT HS FER 12 8,776’ Intake: GPXARCINT FER H6 13 8,777’ Upper Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 14 8,784’ Lower Tandem Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 15 8,791’ Motor: 562XP 250 Hp/ 2505V / 61A 16 8,808’ Zenith Sensor & Centralizer:Bottom @ 8,813’ 17 8,828’ Baker Tie-Back Sleeve 18 8,835’ Baker 7” x 4-1/2” “ZXP’ Liner Top Packer 19 8,842’ Baker 7” x 4-1/2” Flex Lock Liner hanger PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C1/B6 9,312’ 9,332’ 7,153’ 7,172’ 20 8/12/2004 Open Kup. A1B 9,320’ 9,360’ 7,160’ 7,200’ 40 6/27/2023 Open Kup. A3 9,394’ 9,414’ 7,234’ 7,254’ 20 8/12/2004 Open Kup. A2 9,415’ 9,435’ 7,255’ 7,275’ 20 6/30/2004 Open Kup. A1 9,449’ 9,469’ 7,289’ 7,309’ 20 6/30/2004 Open Kup. B 9,480’ 9,500’ 7,320’ 7,339’ 20 6/27/2023 Open Ref Log: PDC GR/ CCL - 6/29/2004 OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I in 24” Hole 9-5/8”250 sx Lite-crete in 12-1/4” hole plus 225 sx Class “G” followed by 215 sx Lite-crete through ES cementer 7" 120 sx Class “G” in 8-3/4” hole, est. TOC= 8,453’ 4-1/2”” 120 sx Class “G” in 6-1/8” hole, est. TOC= 8,820’ WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 54 deg. @4,700’ Max Hole Angle through perforations = 6 deg. TREE & WELLHEAD Tree 5M CIW 4” Wellhead 11” 5M FMC Gen 5A, w/ 4-1/2” FMC Tbg. Hngr., 4-1/2” Hydril 521 Top & Btm. Hanger thread and 4” “H” BPV profile GENERAL WELL INFO API: 50-029-23190-00 Orig. Drilling by Doyon 14 – 6/26/2004 Orig. Completion by Nabors 4-ES – 8/14/2004 RWO w/ Nabors 4-ES, ESP c/o and FCO – 12/6/2007 RWO w/ Nabors 3S, ESP c/o 10/4/2008 & 6/2/2009 RWO w/Doyon 16, ESP c/o and FCO – 3/31/2011 & 12/26/2013 ESP Swap and Perf by ASR – 7/7/2023 Well Name Rig API Number Well Permit Number Start Date End Date MP L-43 LRS & ASR#1 50-029-23190-00-00 203-224 6/21/2023 7/7/2023 6/23/2023 - Friday Continue POOH w/ 4-1/2" 12.6# L-80 Hyd 521 TTC ESP completion. F/ 7,150' T/ 5,100' counting all clamps. pumping double pipe displacement. Rig Service, check equip. fluid levels. Continue POOH w/ 4-1/2" 12.6# L-80 Hyd 521 TTC ESP completion. F/ 5,100' T/ 1,676' counting all clamps. Pumping double pipe displacement. Continue POOH w/ 4-1/2" 12.6# L-80 Hyd 521 TTC ESP completion. F/ 1,676' T/ 41' counting all clamps. Pumping double pipe displacement. L/D TTC ESP completion. All components intact. All clamps accounted for. 220 - canon clamps, 3 - protectolizers, 1- Cross splice canon clamps, 2 Flat guards recovered. L/D ESP tools & equip. f/ rig floor. Load 25 JTS of 2-7/8" PH6 & 4-1/4" DC for clean out run in pipe shed. Service rig, check equip. fluid levels. C/O handling equipment t/ 2-7/8", Simops. strap & tally clean out BHA. P/U Liner clean out BHA, 3-3/4" roller cone bit, BS. RIH W/ Liner clean out BHA, P/U 25 JTS of 2-7/8" 7.9# PH6. P/U & M/U. XO, P x P, 7" casing scraper, BS, LBS, JAR, 6 x 4-1/4" DC. T/ 989'. 6/21/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary LRS Well kill- Pumped 20 bbls of 100* diesel and 195 bbls 40* 10.5 ppg brine down TBG up IA to return tank. TBG went on vac. Bull headed 15 bbls 10.5 ppg brine down IA. IA & TBG pressured up. Cont. circ down TBG up IA to return tank with 135 BBL IA and tubing on vac. Install BPV. Blow down lines and disconnect hoses and hard line. Spot mud boat. Finish engine/ transmission swap. Clear rig floor, change house and spooler. Set pits on L-43. Prep for tree removal. Serviced valves on BOPE. Remove tree. Verify hanger threads. Obtain XO. Install BOPE torque all flange connections. Spot cellar. Fly rig floor. R/U stairs to modules. Laid out accumulator lines. Spot in Cat walk. M/U KILL/Choke lines. Perform final checks on Rig engine. Replaced coolant line. Timed drive line. Road rig to L-43. Connect koomey lines to BOPE. Spot rig & level rig. Raise derrick. Engage derrick lock pins. Tighten guy lines. Break in engine, remain in high idle for 3 HRS. Install driller side stairs. Install rack pins. Unlock sheave arm. Perform derrick inspection. 6/22/2023 - Thursday Spot in pipe sheds. Spot in office trailers and change room. Hook up koomey lines and electrical. preform function test of BOPE Top off nitrogen back up for accumulator. Rig accepted @13:00 6/22/2023. Pick up Test mandrel. Line up to test. Fill stack. Lock in Pipe rams. Preform shell test. Good test. Pressure test BOPE T/ 250psi low & 3000psi high F/ 5/5 charted mins as per approved sundry. AOGCC Rep Bob Noble witness test. L/D test JT, B/D test lines. Remove test water f. pits & fill w/ 10.5 PPG NA/BR brine. Simop. hang ESP cable sheave & containment hose. P/U tee bar. W/ IA open, Remove CTS valve. tubing on a vac. Remove BPV. M/U landing JT. BOLDS. P/U hanger off seat at 103k. Pulled hanger to floor 120k P/U wt= 120k dragging up t/ 127k. F/ 7k over. Fill well w/ 21bbls of 10.5ppg brine. Indicating fluid level = ~1,130. Cut ESP cable. Secure hanger & L/D w/ landing joint. Rig Service, check equip. fluid levels. POOH w/ 4-12" 12.6# L-80 Hyd 521 TTC ESP completion. F/ 8,770' T/ 7,150' Securing all clamps & tallying. Well Name Rig API Number Well Permit Number Start Date End Date MP L-43 LRS & ASR#1 50-029-23190-00-00 203-224 6/21/2023 7/7/2023 Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ 3-1/2" workstring and cleanout BHA from F/ 988' T/ 6,350'. Well taking 15 BPH. Rig service. Check fluids and equipment. RIH w/ 3-1/2" workstring & cleanout BHA F/ 6,350' T /TOL @ 8,835' Well taking 15 BPH. P/U wt = 82K S/O wt = 42K. RIH w/ 3-1/2 workstring and cleanout BHA F/ 8,835' T/ 9,368' tag fill w/ 6K down. Pick up, swivel up and line up to pump. P/U wt = 89K S/O wt = 46K. Swivel pipe packing leaking. Attempt to tighten. Leak persists. C/O packing. Pump dw string at 4 BPM w/ 1,000 PSI. 18 bbls to fill, fluid level = 682'. Rotate at 30 rpm w/ 2.8k tq. Wash & ream dw past obstruction no set dw. Cont. Wash & ream at 9,437'. P/U 90k S/O 43K. Losses at 30 BPH. At 9,437' after connection. Tag up. Set dw 20k. P/U T/ 100K for 10k over. Attempt to pump. String plugged off. Work pipe up T/ 130K for 40k over. Allow Jars to Hit. Unable to recock jars. P/U 10' PUP. Cock Jars & Cont. to work stuck pipe. Ensure backside clear. Pump down backside @ 1 BPM w/ 550 PSI, Losing fluid to perfs. Line back up down WS & cont. to pressure up to 1000 PSI, Hold pressure & work JARS for 27 hits. Pipe free, Con't to wash & ream dw T/ 9,445' 30 RPM w/ 2.4k TQ Pump a high vis sweep at 5 BPM w/ 1200 psi. Pump a total of 315 bbls for a surf. to surf. Sweep back with minimal sand. P/U JT # 212 Con't to wash & ream dw T/ 9,485' 30 RPM w/ 2.4k TQ Pump a high vis sweep at 5 BPM w/ 1,200 psi. Pump a total of 189 bbls. Sweep at ~ 5000' in IA. P/U JT # 213 Cont. to wash & ream dw T/ 9,525' 30 RPM w/ 2.4k TQ Pumping at 5 BPM w/ 1230 psi. Sweep back with substantial sand. Cont. pumping for BTU. Bottoms up returning sand, cont. pumping until shaker cleans up. Losses reduced to 12 BPH. 6/24/2023 - Saturday Continue RIH w/ 7" test PKR on 3-1/2" 9.5# WS. F/ 4,019' T/ 8,700' Monitor well via displacement to tank. Set test packer @ 8,733' placing center of elements @ 8,729', Fill hole shut annular and test 7" casing to 1,750 psi. Had drop in pressure. Bled off and released packer. Circulate down tubing taking returns up IA. Set packer Again in same spot. pressure up to 1,800 psi and test 7" casing for 30 min. good test. bled off pressure. Release packer. pump 5 BBLs down tubing. Monitor well. Rig service. Check fluids and equipment. Break out of swivel. Lay down kelly hose and start POOH W/ 3-1/2 workstring and test packer F/ 8,733' to 15'. L/D 7" test PKR. PKR intact & functional. Clear rig floor of third party tools. P/U landing JT, M/U to testing hanger. Fill well w/ 4 bbls. Land hanger w/ TWC installed & RILDS. Monitor well via IA. Rig service, check rig equip. fluids. R/D flow & riser spools. Install shooting flange & torque. M/U E-line BOPE & PCE equipment. Remove bails for E-line sheave, hang sheave. Test E-line PCE against TWC. Test t/ 250 psi low & 3000 psi high. Good test. Remove TWC via tee bar. Close IA fill well. Begin P/U of 3-1/8" HC guns E-line guns. 6/25/2023 - Sunday P/U JT # 214 Cont. to wash & ream dw T/ 9,551' 30 RPM w/ 2.4k TQ Pumping at 5 BPM w/ 1230 psi. Sweep back with minimal sand. Cont. pumping for BTU. Bottoms up minimal sand, Losses reduced to 8 BPH. Shut pumps down. Monitor well. Well still on losses POOH with 3-1/2" workstring F/ 9,551' to TOL @ 8,835'. Rig down kelly hose, Rig service. Check all fluids and equipment. service swivel packing. POOH with 3-1/2 workstring and cleanout BHA F/ 8,835 T/ 988' pumping double pipe displacement. L/D 6 x DC, JARS, LBS, Casing scraper, 25 JTS of 2-7/8" PH6, & Bit. All BHA components intact. Bit roller cone bearings ineffective,. Service Rig, check rig equip. fluid. C/O handling equip. M/U test PKR, XO to WS. RIH w/ 5 JTS of 3-1/2" 9.5 # workstring. Proof test 7" test PKR. Fill hole w/ 8 bbls. Well fluid level = 303'. Set PKR pressure up close annular. Pressure up IA to 1500psi. Pressure holding. Bleed off. Open annular. release PKR. RIH w/ 7" test PKR on 3-1/2" 9.5# WS. F/ 216' T/ 4,019' Monitor well via displacement to tank. 6/26/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP L-43 LRS & ASR#1 50-029-23190-00-00 203-224 6/21/2023 7/7/2023 Hilcorp Alaska, LLC Weekly Operations Summary RIH W/ yellowjacket E-line with first perf gun to 9,550' WLM. Correlate gun on depth. CCL to top shot 9.0'. CCL stop 9,471. shoot perfs from 9,480'-9,500'. Well losing fluid after shot. loss rate 6 BPH. POOH W/ E-line. Gun on surface. monitor well swap gun Start RIH W/ E-line. RIH W/ E-line using continuous hole fill. from surface to 9,450. correlate up. Move into position CCL to top shot 9.0'. CCL stop depth 9,331. shoot perfs from 9,340' - 9,360'. POOH W/E-line using continuous hole fill. losing 8 BPH. Swap guns. RIH to 9,400'. correlate up. move into position. Fire gun. CCL to top shot 9.0' CCL stop 9,311' shot perfs from 9,320'-9,340'. POOH W/ E-line From 9,340 to surface. lay down last gun. Rig down E-line, Pull E-line out of the way. N/D shooting flange. N/U spacer/flow spools. Pull hanger.. Prep to run ESP completion. Rack & tally completion. Stage ESP accessory equip. Run cables through sheave & rehang sheave. M/U ESP motor (service motor), Tandem seal, Intake, gas sep., pump, Zenith ported sub & DS head w/ Pup. Test ESP motor & gauge. Good test. RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 71' T/ 1,014' as per tally. 2 BPH losses w/ CHF 6/27/2023 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP L-43 LRS & ASR#1 50-029-23190-00-00 203-224 6/21/2023 7/7/2023 6/30/2023 - Friday M/U ESP motor & tandem seals. (service motor & new tandem seals). Replace chemical injection check valve on centralizer. P/U & M/U. Intake, gas sep., pump. Attempt to RIH. Set dw in wellhead profile. P/U, observed 3/8" stainless line for gauge pressure line binding against 5.62" OD motor, switch out to 1/4" line & band to motor. Cont. to P/U & M/U, Zenith ported sub & DS head w/ Pup. Test ESP motor & gauge. Good test. RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 71' T/ 3,634' as per tally. Testing ESP cable every 1000'. Rig service, check equip. fluid levels. RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 3,634' T/ 6,119' as per tally. Testing ESP cable every 1000'. 6/28/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 71' T/ 3,407' as per tally. 2 BPH losses w/ CHF. Testing ESP cable every 1000'. Perform rig service. Adjust rig PTO. Tally pipe while mechanic services. RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 3,407' T/ 6,703' as per tally. 2 BPH losses w/ CHF. Testing ESP cable every 1000'. M/U ESP PKR, perform splice. After cutting cable, ESP rep. determined cable to be grounded. Phases were balanced on cable. Reattached to POOH to find possible cable damage. Tandem seals, current TVD ~4893', L/D PKR. POOH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 6,703' T/ 5,872'. Found damage to cable at canon clamp. Clamp appears to have slid up. Used clamp possibly stretched. Tandem seals, current TVD ~4212',. Cut ESP cable & test under damaged line. Cable intact under armor, cable remains grounded. Rep. redressed stripped ESP cable. Cont. to POOH for inspection. POOH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 5,872' T/ 3,896' Inspecting cable while POOH. Fill hole every 15 JTS. 6/29/2023 - Thursday POOH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 3,896' T/ 71' Inspecting cable while POOH. Fill hole every 15 JTS. L/D ESP assy. DS head w/ Pup, Zenith ported sub, pump, gas sep.,tandem seals, motor. MLE found wore down to exposed copper. Cap line rotated behind MLE at top of pump. Motor meg. tested good. L/D all ESP handling Equip. Prep for BOPE test. P/U jt & M/U test plug. Set test plug. Flush & fill stack w/ fresh water. P/U & set 2-7/8" donut test joint in stack. Lock in rams. Shell test BOPE. Ensure proper line up & air purged. Test BOPE as per approve sundry. AOGCC waived witness. Test BOPE to 250 psi low & 3,000 psi high f/ 5/5 charted mins. Preform accumulator drawdown. Monitor well via IA during all testing. L/D testing equip. Remove fresh water water. P/U landing jt, pull test plug. Close IA. Monitor well via hole fill. 10 bbls to fill. Static fluid level = 261'. P/U & M/U ESP assy. as follows. motor (servicing motor). Well Name Rig API Number Well Permit Number Start Date End Date MP L-43 LRS & ASR#1 50-029-23190-00-00 203-224 6/21/2023 7/7/2023 Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 6,119' T/ 6,589' as per tally. Testing ESP cable every 1000'. Limiting run speed to 60 ft/min. M/U ESP PKR, perform cable splice through packer. Test ESP cable (good test) Pass 3/8" chemical injection line & attach vent valve's 3/8" control line, Test control line to 5,000 PSI. Good test. PKR vents starts opening at 2,400 psi. Full open at 3000 psi. Bleed to 500 psi for RIH. RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 6,589' T/ 8,786' as per tally. Testing ESP cable every 1,000'. Limiting run speed to 60 ft/min. P/U & M/U TBG hanger. Test ESP cable prior to splice good test. Bleed down cap lines & terminate ESP cable & cap lines to hanger. Perform final ESP electrical test prior to land good test. Attach umbilical cable to penetrator to monitor ESP while landing,. Test cap line to PKR to 5,000 psi (good test). Attach line to surface to monitor pressure while landing. Test chem. injection line. & cap off at hanger. Land hanger P/U wt= 65K S/O wt = 36K. ESP cable & gauge tests are good. RILDS. Drop 1.31" OD ball & rod. Prep to set PKR & IA MIT. Attach pump lines. Fill tubing & IA. Pressure up tubing To 4,000 psi & hold for 30 mins. Bleed to 0. Pressure TBG back up to 4000 psi f/ 5 mins. as per procedure. Line up on IA & pressure up at 50 psi a min to 1,500 psi & hold f/ 30 charted mins. failed test. Bleed off & re-appl y pressure at 50 psi/min, hold for 30 min. 7/1/2023 - Saturday 7/2/2023 - Sunday Cont. to test IA, to 1,500 psi & hold f/ 30 charted mins. failed test x3 . Pressure up cap line to 3500 psi on vent valves to a llow wellbore fluid to pass through. (Perfs taking fluid) Lock in 500 psi on cap line. Cont. to test IA, to 1,500 psi & hold f/ 30 charted mins. failed test. Bleed cap line to zero. To ensure no bypass by vents. Pressure up tubing to 2000 psi hold & Re-test IA to 1500 psi. failed test on IA. No TBG communication. Pressure up cap line to 3,500 psi on vent valves to open. Pump 5 bbls through ESP PKR vents. Close vent valves. Pressure TBG to 4,000 psi, Hold for good test, Bleed TBG dw to 500 psi & hold while testing IA to 1600 psi. Failed test on IA. R/D testing lines. Remove ESP spooling unit. Prep area for slickline. Back in slickl ine unit. Run out line & hold PJSM w/ crew & third party. Slickline RIH to retrieve ball & rod at 2,210'. Tool on floor. Ball & rod retrieved. R/D. Rig Service, Check equip. fluid levels. Change rig oil. Spot in ESP spooler & rerun cables over windwalls through sheave. BOLDS. Unseat hanger w/ 55k. Pull up to 85k to shear release ESP PKR. Pull hanger to floor. Remove ESP cable, & two capillary lines from hanger. Run over sheave. L/D hanger. Pull 5 jts & GLM #4. End of ESP cable at spooling unit for cable splice. ALS rep. performed cable splice. Simops. crew replaced service loop wrap. Disposed of oil waste & clean work areas. POOH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 8,601' T/ 7,316'. Pump double displacement every 15 JTS. Cont. POOH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 7,316' T/ 6,642'. Pump double displacement every 15 JTS. Inspect PKR, No significate damage over the typical pull release stresses. "backer on element pulled off" capture images for O drive. Test ESP cable (good) L/D PKR. Depth = 6,701'. Cont. Jt 208, GLM, Jt 207, x nip., & Jt 206. F/ 6,701' T/ 6,558'. Pump double displacement every 15 JTS. Jts 205 in slips. Will remove one joint prior to PKR & jewelry to prevent splice below PKR. ALS dressing new PKR w/ penetrator at shop & install vent valves. Simops. cleaning rig & prep to RIH. Well Name Rig API Number Well Permit Number Start Date End Date MP L-43 LRS & ASR#1 50-029-23190-00-00 203-224 6/21/2023 7/7/2023 Hilcorp Alaska, LLC Weekly Operations Summary Perform ESP electrical test prior to land (good test). Land hanger P/U wt= 65K S/O wt = 36K. ESP cable & gauge tests are good after landing. RILDS. Drop 1.31" OD ball & rod. Hook up test lines. Fill tubing & IA. Pressure up tubing To 4,000 psi & hold fo r 20 mins. Bleed to 0. Pressure TBG back up to 4000 psi f/ 5 mins. as per procedure. Line up on IA & pressure up to 1,500 psi, holding f/ 30 charted. (good test). B/D testing lines & R/D. P/U tee bar & set BPV. Remove all well equipment from floor. R/D ESP sheaves. Remove catwalk, pipe shed, & tongs. Release rig. Pulled PKR vent valves failed pressure testing on wellbore side of valve. Install new vent valves & test on surface. (Good) Simops. cleaning rig & prep to RIH. Test ESP cable. Prior to M/U (good test) M/U x nipple, JT GLM, JT & PKR. Depth = 6,669'. Top off hole. Loss rate = 1.5 BPH. BH ALS rep. Splice in ESP cable & chem line through PKR. Install cap line to vent valves on PKR. Test vent line to 5000 psi. hold for 5 min. (Good test) Lock in 500 psi on both cap lines. Await splice completion. RIH w/ 2- 7/8" 6.5# L-80 EUE & ESP completion F/ 6,669' T/ 8,193' as per tally. Testing ESP cable every 1,000'. Limiting run speed to 60 ft/min. Service rig, Check equip. fluid levels. RIH w/ 2-7/8" 6.5# L-80 EUE & ESP completion F/ 8,193' T/ 8,786' as per tally. Testing ESP cable every 1,000'. Limiting run speed to 60 ft/min. P/U & M/U TBG hanger. Test ESP cable prior to splice good test. Bleed down cap lines & terminate ESP cable & cap lines to hanger. Perform final ESP electrical test prior to land good test. Attach umbilical cable to penetrator to monitor ESP while landing. 7/4/2023 - Tuesday 7/3/2023 - Monday Fill tubing & IA. Pressure up tubing To 4,000 psi & hold for 20 mins. Bleed to 0. Pressure TBG back up to 4000 psi f/ 5 mins. as per procedure. Line up on IA & pressure up to 1,500 psi, holding f/ 30 charted. (good test) Well Name Rig API Number Well Permit Number Start Date End Date MP L-43 LRS & ASR#1 50-029-23190-00-00 203-224 6/21/2023 7/7/2023 7/7/2023 - Friday RIG UP COMPLETE, PT W/ TRI-PLEX, 300 LOW, 2500 HIGH GOOD TEST. PULL BK-DGLV FROM STA.# 4 @ 161' MD. SET BK (ported latch) DPSOV IN STA. # 4 @ 161' MD. 7/5/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD; M/U hanger to string terminated 2ea 3/8 cap lines one for vent valve one for chem inj into hanger. Landed hanger to RKB of 16.81 RILDS, set BPV S/B RDMO. N/U tree/adapter test void 500 low 5000 high 5/10 min test good. Pulled BPV secured well. BEGIN R/U .125 CARBON, 1-1/2'' RS, QC, 8' X 1-1/2'' STEM, QC, KJ, 10' X 1-1/2'' STEM, QC, OJ, QC, KJ, LSS, CHECK ALL CONN. w/ WRENCHES, PT= 250L / 3500H. PULL BALL & ROD @ 2227' SLM. PULL RHC @ 2230' SLM / 2243' MD. Well Support Techs installed new sub timers, set foundation, installed prodcution piping, pressure tested piping to1150 psi, and 7/6/2023 - Thursday No operations to report. No operations to report. 7/8/2023 - Saturday PULL BALL & ROD @ 2227' SLM. PULL RHC @ 2230' SLM / 2243' MD. Landed hanger to RKB of 16.81 RILDS, set BPV S/B RDMO If we flowback to facilities: Total fluid flow rate during the flowback is estimated to be 2050 BFPD based on previous well test fluid rates not exceeding 2026 BFPD with an ESP running at 54 Hz. The last L-43 SITP read 1,540 psi 2/14/2024. This well is on L-Pad and does not fall under 20 ACC 25.265.d.2. and does not require an SSSV. From previous requests that were approved, we will ensure that either a 24/7 man watch or shutdowns for the tubing and IA are in place. Temporary piping from neighboring injector L-21 will be hooked up to enable water delivery at pressure 30% greater than SITP (L-pad injection header is 2500 psi), at a rate 30% greater than maximum open choke production rate of 2050 BFPD. If we flowback to tanks: 1. Clear and level pad area in front of well. Spot containment. 2. MIRU lines from the well to a choke manifold and 4 - 500 barrel return tanks. 3. Pressure test lines to 4,500 psi. 4. Bring on the well. 24-hour man watch will be required. Attachments: 1. Current Wellbore Schematic 2. Surface piping from L-16 injector Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity 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 ortelephone 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 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: 07/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230711 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 22-06 50133205500000 205054 7/6/2023 YELLOW JACKET CBL KBU 22-06 50133205500000 205054 7/2/2023 YELLOW JACKET CBL/PERF KBU 33-06X 50133205290000 203183 6/14/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/29/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/13/2023 YELLOW JACKET PERF KU 12-17 50133205770000 208089 6/14/2023 YELLOW JACKET PERF MP F-89 50029232680000 205090 7/6/2023 READ Caliper Survey MP K-05 50029226700000 196068 5/30/2023 READ Caliper Survey MPU E-23 50029225700000 195094 6/23/2023 YELLOW JACKET CUT MPU L-43 50029231900000 203224 6/27/2023 YELLOW JACKET PERF PAXTON 12 50133207100000 223014 6/28/2023 YELLOW JACKET PERF Please include current contact information if different from above. T37830 T37830 T37831 T37831 T37831 T37832 T37833 T37834 T37835 T37836 T37837 YELLOWMPU L-43 50029231900000 203224 6/27/2023 PERFJACKET Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.11 14:54:56 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT L-43 JBR 07/31/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 K3 and C5 valves failed, they were changed out and passsed R/T. Test Results TEST DATA Rig Rep:GreubOperator:Hilcorp Alaska, LLC Operator Rep:Haberthur Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:2032240 DATE:6/22/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopRCN230629133307 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 2887 Sundry No: 323-149 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 11"P #1 Rams 1 2 7/8" x 5"P #2 Rams 1 Blinds P #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 3 2 1/16"FP Check Valve 0 none NA BOP Misc 0 none NA System Pressure P3100 Pressure After Closure P1925 200 PSI Attained P15 Full Pressure Attained P57 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2350 ACC Misc NA NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P18 #1 Rams P6 #2 Rams P5 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 9 9 9 9 9 9 9999 9 9 9 K3 and C5 valves failed, FP FP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Install 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,645'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: Tubing MD (ft): 12.6 / L-80 / Hydril 521 8,761' 4/1/2023 Baker 7” x 4-1/2” “ZXP’ LTP and N/A 8,835 MD/ 6,691 TVD and N/A See Schematic See Schematic 4-1/2" 6,062' 8,920' Perforation Depth MD (ft): 4-1/2"817' Perforation Depth TVD (ft): Tubing Size: 9-5/8" 7" MD N/A 8,430psi 5,750psi 7,240psi 4,439' 6,803' 7,484' 6,097' 8,953' 9,645' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,484' 9,559' 7,398' 2,887 N/A 78' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 203-224 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23190-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT L-43 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY twellman@hilcorp.com 777-8449 Taylor Wellman Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 1:46 pm, Mar 10, 2023 323-149 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.03.10 12:59:42 -09'00' David Haakinson (3533) 2,887 MGR17MAR23 BOPE test to 3000 psi. 10-404 GCW 03/20/23JLC 3/20/2023 3/20/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.03.20 10:29:36 -08'00' RBDMS JSB 032123 Well: MPU L-43 Scope: TTC to Conventional ESP Swap Date: 03/09/2023 Well Name:MPU L-43 API Number:50-029-23190-00-00 Current Status:Producer [Shut in ESP]Pad:L-Pad Estimated Start Date:April 1, 2023 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:203-224 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Brian Glasheen (907) 564-5277 (O) (907)545-1144 (M) AFE Number:Job Type:TTC-ESP Pump Swap Current Bottom Hole Pressure: 3,553 psi @ 6,659’ TVD Downhole Gauge |10.3 PPGE Maximum Expected BHP:3,553 psi @ 6,659’ TVD Downhole Gauge |10.3 PPGE MPSP:2,887 psi (0.1psi/ft gas gradient) Max Deviation:51° @ 3,111’ MD Max Dogleg:5.3°/100ft @ 6,208’ MD Min ID:3.958” ID @ 0’ MD Tubing Hanger BPV Profile:4” Type “H” Brief Well Summary: W MPU L-43 is a Kuparuk producer that has a TTC-ESP (Thru Tubing Conveyed ESP) installed. These specific pumps have been in the well since 2016 and have exceeded normal run life. Over the past months performance has been degrading as pump wear has been observed. The well shut down and it was hard to restart. CT was used and have diagnosed that the spline off the motor has sheared rendering the TTC-ESP inoperable. Objective: Pull the existing TTC-ESP Completion / Run Conventional 2-7/8” ESP Completion Notes Regarding the Well & Design 7” casing was last pressure tested down to 8,800’ md to 4,500 psi for 5 mins on 12/21/2013. Offset Injector Support o L-05: SI on 11/29/2022 o L-24: Online – supports L-04, L-14, L-41. Injecting 830 bwpd Pre-Rig Procedure Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 10.5ppg brine down tubing, taking returns up IA to 500 bbl returns tank. 6. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. Set CTS Plug. NU BOPE. 2,887 psi Well: MPU L-43 Scope: TTC to Conventional ESP Swap Date: 03/09/2023 Brief RWO Procedure 1. MIRU ASR, ancillary equipment and lines. 2. Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. a. Notify the AOGCC 24 hours in advance of BOP test. b. Test upper 2-7/8” x 5” rams with the 2-7/8” and 4-1/2” test joints. c. Confirm test pressures with Approved Sundry. d. Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug. e. Once BOPE test is complete, send a copy of the test report (10-424 form) to AOGCC and town engineer. 3. Pull CTS Plug. Check for pressure below the BPV. a. If indications show pressure underneath BPV, lubricate out BPV and re-kill as needed. 4. MU landing joint, BOLDS, PU on the tubing hanger. a. The current completion was landed w/ PUW = 109k, SOW = 111k lbs. 5. Confirm hanger free, lay down tubing hanger. 6. POOH and lay down the 4-1/2” tubing and permanent ESP completion components. a. Tubulars to be cleaned and inspected for re-use based on caliper results. Contact OE for results if not already provided. b. Clamps to be recovered, washed and saved for re-use if possible. 220 Cross Collar Cannon Clamps 3 Protectolizer Clamps 1 Cross Splice Cannon Clamps 2 Flat Guards 7. PU 2-7/8” workstring and clean out BHA for the 4-1/2” liner. TIH and clean out down to a target depth of 9,550’ MD. TOOH. 8. Contingency: Based on amount of sand/fill recovered MU 7” casing scraper and TIH to 8,800’ MD. Reciprocate from 8,650’ – 8,750’ MD. 9. PU 7” test packer and TIH to ±8,700’ MD and test casing to 1,750psi. 10. MIRU e-line unit and pressure test lubricator to 250 psi low / 3,000 psi high. 11. RIH with 3-1/8” HC gun assembly and perforate the following intervals: a. Kuparuk A1B from ±9,320’ – ±9,360’ MD b. Kuparuk B Silts from ±9,480’ – ±9,500’ MD c. Correlate to log provided by town engineer or geologist. Contact Geologist for correlation confirmation: John Salsbury jsalsbury@hilcorp.com, 907-350-1088. 12. POOH and RDMO e-line. 13. RU to run ESP completion. 14. PU and MU new ESP assembly. Set base of ESP assembly at ±8,800’ MD. Check electrical integrity test every 2,000’. Note clamp locations on each joint used in the tally. a. Base of ESP at ± 8,800’ MD. a. ESP: centralizer (with foot valve for chemical injection in the centralizer), motor, seals, gas separator, pump sections. b. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing If indications show pressure underneath BPV, lubricate out BPV and re-kill as needed. Well: MPU L-43 Scope: TTC to Conventional ESP Swap Date: 03/09/2023 c. Nipple, HES 2.313” XN-Nipple (2.205” no-go) d. 3-4 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. GLM, 2-7/8” x 1”, DV installed f. Multiple joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. Nipple, HES X-Nipple (2.313”) with 10’ handling pups above and below,RHC plug body installed h. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing i. GLM, 2-7/8” x 1”, DV installed with 10’ handling pups above and below j. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing k. Packer, Viking ESP retrievable with dual vent valves (setting depth = ±2,100’ MD) 15. PU and MU the Viking packer. Verify that there are 4 setting shear pins and confirm w/ OE number of release shear pins. a. Shear pins will be dependent upon expected PUW of completion. Initial target is 20k overpull to release. b. Document packer with photos above and below all jewelry as installed on 2-7/8” tubing. 16. Terminate the ESP cable and MU the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 17. MU the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in report). Bleed the pressure to 500 psi and lock it in to maintain 500 psi while RIH. 18. Continue to RIH with ESP completion. Check electrical integrity test every 1,000’. a. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd tubing b. GLM, 2-7/8” x 1”, DV installed with 10’ handling pups above and below (setting depth ±2,060’ MD) c. Multiple joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing d. GLM, 2-7/8” x 1”, DV installed with 10’ handling pups above and below (setting depth ±175’ MD) e. 4 joints, 2-7/8”, 6.5#, L-80, EUE 8rd tubing 19. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator, MU the control line to the tubing hanger and dummy off any additional control line ports if present. 20. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in report). Bleed the pressure to 500 psi and lock it in to maintain 500 psi while landing the hanger. 21. Land tubing hanger with extreme caution to avoid damaging the ESP cable, penetrator or control line. RILDS. Record PU and SO weights on tally and AWGRS. 22. Drop the ball & rod and allow time for it to gravitate to the ball seat. 23. Pressure up on the tubing to 4,000 psi and hold for 15 minutes to set the packer. Bleed the tubing pressure to 0 psi. Pressure back up to 4,000 psi and hold for 5 minutes then bleed to 0 psi. 24. Bleed the control line pressure to 0 psi to close the vent valves. Slowly pressure up at 50 psi/min on the IA to 1,500 psi and hold for 30 minutes on chart recorder. 25. Set BPV. ND the BOP stack. Set CTS Plug. 26. NU the tubing head adapter and 2-9/16”, 5M tree. Well: MPU L-43 Scope: TTC to Conventional ESP Swap Date: 03/09/2023 27. PT tubing hanger void to 500/5000 psi. PT the tree to 250/5000 psi. 28. Pull CTS plug and BPV. 29. Replace gauge(s) if removed. Secure the tree and cellar. 30. RDMO Post-Rig Procedure: 1. Turn well over to production via handover form. 2. RU well house and flowlines. 3. RU HES slickline. 4. Pull the ball and rod. 5. Pull DV from GLM #4 and install OV. 6. Pull RHC plug body. 7. RD HES slickline. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: DH 9/20/2017 SCHEMATIC Milne Point Unit Well: MP L-43 Last Completed: 12/26/2013 PTD: 203-224 TD = 9,645’ (MD) / TD = 7,484’(TVD) 20” OKB Elev.: 50.8’/ Orig. GL Elev.: 16.3’’ Doyon 16 RT to TTbg spool= 21.84’ 7” 9 9-5/8” Howco ES Cementer @ 1,930’ 9-5/8” 5 PBTD = 9,559’(MD) / PBTD = 7,398’(TVD) 11 & 12 1 2 3 4 6 7 8& 9 10 4-1/2” 99 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,097’ 0.0758 7" Intermediate 26 / L-80 / BTC-M 6.276 Surface 8,953 0.0383 4-1/2" Production 12.6 / L-80 / IBT-M 3.958 8,828’ 9,645’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / Hydril 521 3.958 Surface 8,761’ 0.0152 JEWELRY DETAIL No Top (MD) Item 1 8,715’ D&D tubing stop (set 9/14/2017) 2 8,717’ D&D Packoff assembly Top (set 9/13/2017) 3 8,723’ Centrilift TTC-ESP Top (Model 380 SXD Type 116-P18 P2P) 4 8,761’ TTC drilled tubing crossover 5 8,772’ Tandem seal sections (Model GSB3 DB UT/LT HL H6 PFS) 6 8,786’ Motor, MSP1-250, 126 HP, 2445 volt, 31 amp 7 8,797’ Phoenix PumpMate Sensor with 6 fin Centralizer 8 8,828’ Baker Tie-Back Sleeve 9 8,835’ Baker 7” x 4-1/2” “ZXP’ Liner Top Packer 10 8,842’ Baker 7” x 4-1/2” Flex Lock Liner hanger 11 9,559’ 4-1/2” Baker Landing Collar 12 9,645’ 4-1/2” Halliburton Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C1/B6 9,312’ 9,332’ 7,153’ 7,172’ 20 8/12/2004 Open Kup. A3 9,394’ 9,414’ 7,234’ 7,254’ 20 8/12/2004 Open Kup. A2 9,415 9,435’ 7,255’ 7,275’ 20 6/30/2004 Open Kup. A1 9,449’ 9,469’ 7,289’ 7,309’ 20 6/30/2004 Open Ref Log: PDC GR/ CCL - 6/29/2004 OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I in 24” Hole 9-5/8”250 sx Lite-crete in 12-1/4” hole plus 225 sx Class “G” followed by 215 sx Lite-crete through ES cementer 7" 120 sx Class “G” in 8-3/4” hole, est. TOC= 8,453’ 4-1/2”” 120 sx Class “G” in 6-1/8” hole, est. TOC= 8,820’ WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 54 deg. @4,700’ Max Hole Angle through perforations = 6 deg. TREE & WELLHEAD Tree 5M CIW 4” Wellhead 11” 5M FMC Gen 5A, w/ 4-1/2” FMC Tbg. Hngr., 4-1/2” Hydril 521 Top & Btm. Hanger thread and 4” “H” BPV profile GENERAL WELL INFO API: 50-029-23190-00 Orig. Drilling by Doyon 14 – 6/26/2004 Orig. Completion by Nabors 4-ES – 8/14/2004 RWO w/ Nabors 4-ES, ESP c/o and FCO – 12/6/2007 RWO w/ Nabors 3S, ESP c/o and install screen – 10/4/2008 RWO w/ Nabors 3S, ESP c/o, pull screens, and FCO – 6/2/2009 RWO w/Doyon 16, ESP c/o and FCO – 3/31/2011 RWO w/Doyon 16, install TTC ESP and FCO – 12/26/2013 _____________________________________________________________________________________ Revised By: TDF 3/10/2023 PROPOSED Milne Point Unit Well: MP L-43 Last Completed: 12/26/2013 PTD: 203-224 TD =9,645’ (MD ) / TD = 7,484’(TVD) 20” OKB Elev.: 50.8’/ Orig. GL Elev.: 16.3’’ Doyon 16 RT to TTbg spool= 21.84’ 7” 9 10 11 & 12 13 9-5/8” Howco ES Cementer @ 1,930’ 9-5/8” 8 14 PBTD = 9,559’(MD) / PBTD = 7,398’(TVD) 18 & 19 1 2 3 15 & 16 17 4-1/2” 4 5 6 7 KUPARUK RIVER OIL CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,097’ 0.0758 7" Intermediate 26 / L-80 / BTC-M 6.276 Surface 8,953 0.0383 4-1/2" Production 12.6 / L-80 / IBT-M 3.958 8,828’ 9,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 2.441 Surface ±X,XXX’ 0.0058 JEWELRY DETAIL No Top (MD) Item 1 ±XXX’GLM #4: 2 ±X,XXX’GLM #3: 3 ±X,XXX’ Packer: 4 ±X,XXX’GLM #2: 5 ±X,XXX’ 2-7/8” X-Nipple (2.313 ID) 6 ±X,XXX’GLM #1: 7 ±X,XXX’ 2-7/8” XN-Nipple (2.205 No-go ID) 8 ±X,XXX’ Discharge Head 9 ±X,XXX’ Pump: 10 ±X,XXX’ Gas Separator: 11 ±X,XXX’ Upper Tandem Seal: 12 ±X,XXX’ Lower Tandem Seal: 13 ±X,XXX’ Motor 14 ±X,XXX’ Sensor & Centralizer: Bottom @ ±X,XXX’ 15 8,828’ Baker Tie-Back Sleeve 16 8,835’ Baker 7” x 4-1/2” “ZXP’ Liner Top Packer 17 8,842’ Baker 7” x 4-1/2” Flex Lock Liner hanger 18 9,559’ 4-1/2” Baker Landing Collar 19 9,645’ 4-1/2” Halliburton Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C1/B6 9,312’ 9,332’ 7,153’ 7,172’ 20 8/12/2004 Open Kup. A1B ±9,320’ ±9,360’ ±7,160’ ±7,200’ ±40 Future Future Kup. A3 9,394’ 9,414’ 7,234’ 7,254’ 20 8/12/2004 Open Kup. A2 9,415’ 9,435’ 7,255’ 7,275’ 20 6/30/2004 Open Kup. A1 9,449’ 9,469’ 7,289’ 7,309’ 20 6/30/2004 Open Kup. B ±9,480’ ±9,500’ ±7,320’ ±7,339’ ±20 Future Future Ref Log: PDC GR/ CCL - 6/29/2004 OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I in 24” Hole 9-5/8”250 sx Lite-crete in 12-1/4” hole plus 225 sx Class “G” followed by 215 sx Lite-crete through ES cementer 7" 120 sx Class “G” in 8-3/4” hole, est. TOC= 8,453’ 4-1/2”” 120 sx Class “G” in 6-1/8” hole, est. TOC= 8,820’ WELL INCLINATION DETAIL KOP @ 200’ Max Hole Angle = 54 deg. @4,700’ Max Hole Angle through perforations = 6 deg. TREE & WELLHEAD Tree 5M CIW 4” Wellhead 11” 5M FMC Gen 5A, w/ 4-1/2” FMC Tbg. Hngr., 4-1/2” Hydril 521 Top & Btm. Hanger thread and 4” “H” BPV profile GENERAL WELL INFO API: 50-029-23190-00 Orig. Drilling by Doyon 14 – 6/26/2004 Orig. Completion by Nabors 4-ES – 8/14/2004 RWO w/ Nabors 4-ES, ESP c/o and FCO – 12/6/2007 RWO w/ Nabors 3S, ESP c/o 10/4/2008 & 6/2/2009 RWO w/Doyon 16, ESP c/o and FCO – 3/31/2011 & 12/26/2013 Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2022 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - J..;¡t;. Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: I?J <is (Count does include cover sheet) Page Count Matches Number in Scann',ng :~e aration: V YES BY: r:: Maria ") Date: d- / (p 0 (, , Stage 1 If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 111111111 1111111111 R,CAN '¢' Color Items: o Greyscale Items: DIGITAL DATA ~iskettes, No.4 o Other, No/Type: o Poor Quality Originals: o Other: NOTES: BY: ~ Ihlo~ Date: ~ Project Proofing Date: &-., It? I Ób J:; X 30 = /{5:0 + Date:;}, , Jb 10f, BY: ~ Maria ) Scanning Preparation BY: C Maria ") BY: Date: Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Date: Maria Comments about this file: D Rescan Needed 1111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: w¡-O IIIIIIIIIIII~ 1I1II J 151 'Wi' 151 /7 = TOTAL PAGES li/7 (Count does not include cover shee~ nil (] 151 , r . t'" 1111111111111111111 YES NO /5/ W/J NO 151 1111111111111111111 1111111111111111111 Is/ Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page. doc STATE OF ALASKA - H",SKA OIL AND GAS CONSERVATION CGrviMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS JAN 21 2014 1. Operations Performed: AOGCC ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 'O 203424 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 V 50-029-23190-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025509 ! a MPL-43 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): r. Milne Point Unit/Kuparuk River Oil 11. Present well condition summary: Total depth: measured • 9645' feet Plugs:(measured) None feet true vertical 7484' feet Junk:(measured) None feet Effective depth: measured • 9559' feet Packer: (measured) None feet true vertical 7398' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34'- 112' 34'- 112' 1490 470 Surface 6062' 9-5/8" 35'-6097' 35'-4439' 5750 3090 Intermediate Production 8920' 7" 33'-8953' 33'-6803' 7240 5410 Liner 817' 4-1/2" 8828'-9645' 6685'-7484' 8430 7500 Perforation Depth: Measured Depth: 9312'-9469' feet True Vertical Depth: 7153'-7309' feet Tubing(size,grade,measured and true vertical depth): 2-7/8",6.5# L-80 8800' 6658' Packers and SSSV(type,measured and true vertical depth): None None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): 4 Treatment description including volumes used and final pressure: SCANNED JUL �� �BD� MAY 16 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 150 24 161 300 266 Subsequent to operation: 0 0 0 0 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: • 0 Exploratory 0 Stratigraphic ® Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: % ®Oil 0 Gas 0 WDSPL ®Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 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: Abby Warren,564-5720 Email:Abigail.Warren@bp.com N/A Printed Name: Joe Lastu , Title: Drilling Technologist Signature: 'hone: 564-4091 Date: I h i/I4- Form 10-404 Revised 10/2012 (�L f, 5-10IfI 14-- ,4 f/2�/y Submit Original Only { North America-ALASKA-BP Page 1 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date: 12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud DateTme:1/6/2004 12:00:00AM Rig Release: Rig Contractor.DOYON DRILLING INC. UWI:500292319000 Active datum:MPL-43:©50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/18/2013 16:00 - 17:30 1.50 MOB P PRE MOVE RIG OFF MPL-25. 17:30 - 20:00 2.50 MOB P PRE PREPARE TO BACK RIG OVER WELL. -LAY MATS,LEVEL AND SHIM RIG. 20:00 - 20:30 0.50 MOB P PRE PJSM,BACK RIG OVER MPL-43. -NOTIFY PAD OPERATOR. -SPOT RIG OVER MPL-43. -WSLAND NIGHT TOOLPUSHER PRESENT. 20:30 - 21:00 0.50 MOB P PRE i SPOT CUTTINGS TANK,FUEL AND CREW TRAILERS. -BERM AROUND CELLAR. 21:00 - 00:00 3.00 MOB P PRE R/U LINES TO TREE AND KILL MANIFOLD. -STEAM LINES,CHECK CONNECTIONS AND BLOW DOWN LINES. -LOAD PITS WITH 8.5 PPG,105 F SEAWATER. PIT WATCHER CONFIRM 8.5 PPG SEAWATER IN PITS. ACCEPT DOYON 16 RIG AT 21:00 HRS 12/18/2013 ON MPL-43. 24 HR LOSSES=0 BBLS. 12/19/2013 00:00 - 01:30 1.50 BOPSUR P PRE SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. R/U SURFACE LINES FOR WELL KILL. -PRESSURE TEST SURFACE TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. 01:30 - 02:30 1.00 BOPSUR P PRE FIRE RIG EVACUATION DRILL. -MR WITH WSL AND ALL PERSONAL ON LOCATION. -DISCUSSED WITH CREW DIFFERENT ALARM SYSTEMS ON THE RIG AND ASSOCIATED MEANINGS. 02:30 - 04:30 2.00 BOPSUR P PRE PJSM,R/U WELL SUPPORT LUBRICATOR. -PRESSURE TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -PULL BPV. -R/D WELL SUPPORT LUBRICATOR. Printed 1/6/2014 1:58:10PM North America-ALASKA-BP Page 2 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date:12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292319000 Active datum:MPL-43:©50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 08:30 4.00 BOPSUR P PRE PJSM,WELL KILL. -REVIEW DDI WELL KILL S.O.P. -BRIDGING DOCUMENT. -DISCUSSED INDIVIDUAL ROLLS AND RESPONSIBILITIES. -DWSL AND TOOL PUSHER PRESENT FOR OPERATION. SITP=40 PSI, SICP=175 PSI, OA=40 PSI. KWF=8.5 PPG HEATED 120 DEG.SEAWATER. -WSL/TOOL PUSHER VERIFY VALVE ALIGNMENT. -BLEED GAS FROM THE IA.F/175 PSI TO 0 •PSI IN 8 MIN.SITP=40 PSI. -NO FLUID RETURNS. PUMP 50 BBLS KWF DOWN THE TBG UP THE IA THROUGH THE CHOKE TO THE FLOW BACK TANK. -ICP=3 BPM/75 PSI. -FCP=3 BPM/590 PSI. -FLUID RETURNS TO SURFACE AFTER 50 BBLS PUMPED.WITH 5 BBLS CRUDE RECORDED. -BULL HEAD ON THE FLY:19 BBLS KWF,3 BPM/827 PSI. PUMP 465 BBLS KWF DOWN THE TBG UP THE IA THROUGH THE CHOKE TO THE FLOW BACK TANK. -ICP=4 BPM/600 PSI. -FCP=5 BPM/1380 PSI. -OBSERVED 309 BBLS CRUDE. -LOST 120 BBLS KWF TO THE FORMATION. -172 BBLS CRUDE SENT TO MPU-ORT, RECYCLE. -80 BBLS CRUDE SENT TO PBU RECYCLE. 08:30 - 09:00 0.50 BOPSUR P PRE MONITOR WELL FOR 30 MIN.TBG AND IA ON A VACUUM IN 15 MINUTES. -BLOW DOWN SURFACE LINES. -R/U 2ND KILL LINE. -CONTINUE TO FILL DOWN IAAT 20 BPH. RWO WTLAND SUPERINTENDENT VISIT RIG CREW. 0900 - 11:00 2.00 BOPSUR P PRE PJSM,WITH DRILL SITE MAINTENANCE TO SET TWC. -R/U DRILL SITE MAINTENANCE LUBRICATOR TEST TO 250 PSI LOW,3500 PSI HIGH. -SET TWC. R/D LUBRICATOR. 11:00 - 12:00 1.00 BOPSUR P PRE PERFROM ROLLING TEST FROM BELOW TWC TO 500 PSI FOR 5 MINUTES. -61 BBLS PUMPED. -TEST TWC FROM ABOVE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES. 12:00 - 12:30 0.50 BOPSUR P PRE R/D LINES AND BLOW DOWN. 12:30 - 14:30 2.00 BOPSUR P PRE BLEED VOID,N/D TREE AND ADAPTER FLANGE. Printed 1/6/2014 1:58:10PM North America-ALASKA-BP Page 3 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date:12/26/2013 X4-OOYCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad H Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM Rig Release: Rig Contractor.DOYON DRILLING INC. UWI:500292319000 Active datum:MPL-43:©50.80usft(above Mean n Sea Level) _ Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 15:30 1.00 BOPSUR P PRE PJSM,N/U BOPE. -N/U TURNBUCKELS,KOOMEY LINES, MOUSE HOLE AND RISER. -R/U TEST EQUIPMENT. 15:30 - 22:00 6.50 BOPSUR P PRE PJSM,TEST FOUR PREVENTER 13-5/8"BOP AND RELATED EQUIPMENT. -TEST BOP ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES. -TEST ANNULAR WITH 2-7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8" AND 4-1/2"TEST JOINT TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. TEST WITH FRESH WATER. JEFF JONES OF AOGCC WAIVE STATES RIGHT OF WITNESS TO BOPE TEST. 22:00 - 23:00 1.00 BOPSUR P DECOMP R/D TEST EQUIPMENT. -BLOW DOWN LINES AND FLUSH OUT STACK. 23:00 - 00:00 1.00 BOPSUR P DECOMP PJSM,WITH DRILL SITE MAINTENANCE TO PULL TWC. -R/U DRILL SITE MAINTENANCE LUBRICATOR TEST TO 250 PSI LOW,3500 PSI HIGH. FILL RATE=20 BPH 24 HOUR FLUID LOSS=376 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=376 BBLS. 12/20/2013 00:00 - 01:00 1.00 P , DECOMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. j - CONTINUE WITH DRILL SITE MAINTENANCE TO PULL TWC. -PULL TWC. -R/D LUBRICATOR. 01:00 - 05:00 4.00 BOPSUR P DECOMP PJSM,PULL TBG HANGER. -M/U 4"DP LANDING JOINT TO TOP DRIVE. -FMC REP BOLDS. -PULL TBG HANGER OFF SEAT AT 106K. -PUW=102K,SOW=80K,INCLUDES 40K TOP DRIVE. -CLOSE ANNULAR CIRCULATE SURFACE TO SURFACE THROUGH GAS BUSTER-3800 STKS. 05:00 - 05:30 0.50 BOPSUR P DECOMP LAY/DN HANGER AND LANDING JOINT. -B/D LINES&TD. 05:30 - 06:30 1.00 BOPSUR P DECOMP SECURE ESP CABLE TO SPOOLING UNIT AND PULL OVER SHEAVE AND D/N TO UNIT. 06:30 - 17:30 11.00 PULL P DECOMP PJSM,PULL 2-7/8"6.5#L-80 EUE 8RD ESP COMPLETION FROM 8755'TO SURFACE. -PUMP 20 BPH IN IA. -BP HSSE REP ONSITE RIG VISIT Printed 1/6/2014 1:58:10PM North America-ALASKA-BP Page 4 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date: 12/18/2013 End Date:12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM ,Rig Release: Rig Contractor.DOYON DRILLING INC. UWI:500292319000 Active datum:MPL-43:@50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 21:30 4.00 BOPSUR P DECOMP PJSM,UD PUMP AND MOTOR. -REVIEWED CONTINGENCY PLAN FOR NON-SHEARABLES ACROSS STACK -CENTRILIFT REP VERIFIED GOOD CONDUCTIVITY,BROKEN MOTOR SHAFT FOUND. 21:30 - 23:00 1.50 CLEAN P DECOMP CLEAR AND CLEAN RIG FLOOR. -R/D ESP SHEAVE AND ELEPHANT TRUNK -P/U RUNNING TOOL TO SET WEAR RING. WEAR RING ID=6-15/16" 23:00 - 00:00 1.00 CLEAN P DECOMP PJSM,WITH BAKER REP TO P/U BHA#1. -M/U 7"CASING SCRAPING BHA#1. CONTINUAL HOLE FILL =20 BPH WITH KWF. 24 HOUR FLUID LOSS=600 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=976 BBLS. 12/21/2013 00:00 01:30 1.50 CLEAN P DECOMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. PJSM,WITH BAKER REP TO P/U BHA#1. .-CONTINUE M/U 7"CASING SCRAPER BHA #1. 01:30 - 03:30 2.00 CLEAN P DECOMP •RIH WITH 7"CASING SCRAPER BHA#1. -P/U DP SINGLES FROM PIPE SHED. -RIH FROM 225'MD TO 1495'MD. 03:30 - 04:00 0.50 CLEAN P DECOMP PERFORMED KICK WHILE TRIPPING DRILL (D1)WITH CREW. '-HELD AAR AND DISCUSSED ROLES AND RESPONSIBILITIES OF CREW MEMBERS IN NEW POSITIONS. 04:00 - 12:00 8.00 CLEAN P DECOMP j RIH WITH 7"CASING SCRAPER BHA#1. -P/U DP SINGLES FROM PIPE SHED. -RIH FROM 224'MD to 7770'MD. 12:00 - 12:30 0.50 CLEAN P DECOMP RIG SERVICE. 12:30 - 14:00 1.50 CLEAN P DECOMP RIH WITH 7"CASING SCRAPER BHA#1. -P/U DP SINGLES FROM PIPE SHED. -RIH FROM 7770'MD TO 8815'MD. 14:00 - 15:00 1.00 CLEAN P DECOMP WORK MILLS ACROSS PACKER SETTING 'AREA,OBTAIN SPR 2BPM 30 PSI. 15:00 15:30 0.50 CLEAN P DECOMP CBU 8.5 BPM,1400 PSI MONITOR WELL (TOTAL STROKES 5100). -BLOW DOWN TOP DRIVE. 15:30 - 16:30 1.00 CLEAN P ! DECOMP CUT AND SLIP 68'OF DRILLING LINE. -ADJUST ROLLERS. -CHECK BRAKES. 16:30 - 22:00 5.50 CLEAN P DECOMP POH WITH 7"CASING SCRAPER BHA#1. -STAND BACK STANDS IN DERRICK -POH FROM 8815'MD to 224'MD. 22:00 - 23:00 1.00 CLEAN P I DECOMP PJSM,UD BHA#1. -REVIEW NON-SHEARABLES ACROSS STACK CONTINGENCY PLAN. -CLEAN AND CLEAR RIG FLOOR. Printed 1/6/2014 1:58:10PM North America-ALASKA-BP Page 5 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date: 12/18/2013 End Date:12/26/2013 'X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UW:500292319000 Active datum:MPL-43:@50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ; Phase I Description of Operations (hr) (usft) 23:00 - 00:00 1.00 DHB P DECOMP PJSM,P/U 7"HES RBP. -M/U ON DP AND TIH TO 488'MD. OD OF RBP=5.75" -RIH ON 4"DP FROM DERRICK CONTINUAL HOLE FILL =20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=540 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=1516 BBLS. 12/22/2013 00:00 - 00:30 0.50 DHB P DECOMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. SERVICE AND INSPECT EQUIPMENT. 00:30 - 03:30 3.00 DHB P DECOMP RIH WITH 7"HES RBP ON DP FROM DERRICK RIH FROM 488'. -OD OF RBP=5.75". -RH ON 4"DP FROM DERRICK. RIH TO 8,700'. 03:30 - 04:00 I 0.50 DHB P DECOMP KICK WHILE TRIPPING DRILL. AAR. -QUICK TO ARRIVE TO ASSIGNED LOCATIONS AND COMMUNICATE STATUS. -SAFETY VALVE-JOINT WAS EASILY ACCESABLE. -DISCUSSED RESPONSIBILITIES OF INDIVIDUALS IN NEW POSITIONS. 04.00 - 05:00 1.00 DHB P i DECOMP PJSM,SET 7"RBP. RIH&OBTAIN PARAMETERS. -PUW=181 K,SOW=110 K. -SET AT DEPTH OF 8800 COE. 05:00 - 06:00 1.00 DHB P i DECOMP PJSM,MIT-IA TEST HES 7"RBP. R/U TEST EQUIPMENT. -LINE UP TO TEST. -MIT-IA AGAINST RBP 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. 06:00 - 06:30 0.50 DHB P DECOMP BLOW DOWN TOP DRIVE AND KILL LINE. -GREASE GOOSE NECK ON TOP DRIVE. 06:30 - 09:00 2.50 DHB P DECOMP POH WITH 7"RBP RUNNING TOOL. -STAND BACK STANDS IN DERRICK -POH FROM 8800'MD to 3141'MD. 09:00 - 10:30 1.50 DHB P DECOMP PJSM,P/U HES 7"RTTS. -RIH ON 1 STAND. -SET RTTS AS PER HALLIBURTON REP. -TEST RTTS TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. -BLOW DOWN SURFACE LINES. 10:30 - 13:00 2.50 BOPSUR P DECOMP PULL WEAR RING. -POWER DOWN ACCUMULATOR UNIT TO N/D BOPE. -N/D ROPE. 13:00 - 16:00 3.00 T WHSUR P DECOMP PJSM,INSTALL NEW 11"TC SPOOL. 16:00 - 17:00 1.00 WHSUR P DECOMP BODY TEST NEW 11"TC SPOOL. -TEST AGAINST RTTS TO 250 PSI LOWFOR 5 CHARTED MINUTES AND 3500 PSI HIGH FOR 30 CHARTED MINUTES. 17:00 - 17:30 0.50 BOPSUR P DECOMP R/D TEST EQUIPMENT. -BLOW DOWN LINES. -SET WEAR RING.6-15/16"ID. Printed 1/6/2014 1.58.10PM • North America-ALASKA-BP Page 6 of 10 Operation Summary Report Common Well Name.MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date:12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. _ I UWI:500292319000 Active datum:MPL-43:©50.80usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth I Phase I Description of Operations (hr) (usft) 17:30 - 19:00 1.50 DHB P DECOMP 'P/U HES RUNNING TOOL. -M/U ON 1 STAND AND RIH TO RELEASE RTTS. -PULL TO FLOOR AND L/D. 19:00 - 22:00 3.00 DHB P DECOMP RIH WITH 7"HES RBP RUNNING TOOL ON 4" DP FROM DERRICK -RIH FROM 3141'TO TOP OF RBP 8800'. -PUW=175K,SOW=112K 22:00 - 22:30 0.50 DHB P DECOMP M/U TOP DRIVE. -OBTAIN SPR:2 BPM=30 PSI,3 BPM=190 PSI. -SET DOWN 20K,PICK UP 25K OVER TO 4-- -- _- RELEASE RBP. 22:30 - 23:00 I 0.50 DHB P DECOMP BULLHEAD 20 BBLS DOWN DP AND ANNULUS. -2 BPM=190 PSI,FINAL 4 BPM=900 PSI. -SHUT DOWN PUMPS AND MONITOR WELL. -WSL CONFIRM,WELL ON VACUUM. '23:00 - 00:00 1.00 DHB P DECOMP PJSM,POOH WITH 7"RBP. -L/D DP TO PIPE SHED. -POOH FROM 8800'MD to 8382'MD. CONTINUAL HOLE FILL =20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=189 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=1705 BBLS. 12/23/2013 00:00 - 08:00 8.00 DHB P DECOMP SPCC CHECKS AND PRE-TOUR MEETING. I CHECK CROWN-O-MATIC. CONTINUE POOH WITH 7"RBP. -L/D DP TO PIPE SHED. -POOH FROM 8382'MD TO SURFACE. -L/D HES RBP. 08:00 - 08:30 0.50 BOPSUR P DECOMP MAKE UP WEAR RING PULLING ASSEMBLY -PULL WEAR RING -CLEAN AND CLEAR RIG FLOOR 08:30 - 11:00 2.50 RUNCOM P RUNCMP PREP FOR COMPLETION MAKE UP. -R/U POWER TONGS. -MOBILIZE CENTRILIFTAND BAKER TOOLS TO RIG FLOOR. -POSITION EQUIPMENT IN PIPE SHED. 11:00 - 14:00 3.00 RUNCOM P RUNCMP PJSM WITH CENTRILIFT AND RIG CREW FOR PICKING UP AND SERVICING MOTOR ASSEMBLY -MAKE UP&SERVICE MOTOR ASEMBLY, THEN LAY MOTOR DOWN IN PIPE SHED. Printed 1/6/2014 1 58 10PM • North America-ALASKA-BP Page 7 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date:12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM Rig Release: Rig Contractor DOYON DRILLING INC. UWI:500292319000 Active datum:MPL-43:@50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:00 2.00 WHSUR P RUNCMP PJSM WITH CENTRILIFT,BAKER,DOYON CASING AND RIG CREW FOR PICKING UP MOTOR ASSEMBLY,DUMMY HANGER. -PICK UP MOTOR ASSEMBLY FROM PIPE SHED. -MAKE UP SEAL ASSEMBLY. -BOLT ON TTC DRILLED TUBING CROSSOVER TO SEAL ASSEMBLY. -TORQUE 4-1/2"521 HYDRIL X 4-1/2"NSCT PIN X/O ONTO TTC DRILLED CROSS-OVER. LAY DOWN 4'HYDRIL 521 HANDLING PUP. -MAKE UP&TORQUE HYDRIL PUP AND • HYDRILJOINT.MAKE UP 11"FMC DUMMY TUBING HANGER W/TC-II LANDING THREADS -LAND HANGER PER FMC REP. -RUN IN LOCK DOWN SCREWS PER FMC REP. -LAY DOWN LANDING JOINT. 16:00 - 19:00 3.00 WHSUR P RUNCMP PJSM WITH RIG CREW AND BOT TO MAKE UP PUMP RUNNING ASSEMBLY. -CLOSE BLIND RAMS. -PICK UP 3 JTS 2-7/8"PAC DRILL PIPE AND 3-1/2"BUMPER SUB. •-OPEN BLINDS TORQUE CONNECTIONS. -R/U CENTRILIFT SHEAVE. 19.00 - 22.00 3.00 RUNCOM P RUNCMP PJSM,TO P/U AND RUN TT ESP ASSEMBLIES. -RUN PUMP ASSEMBLY#1. • -ATTACH 3"GS SPEAR TO PUMP RUNNING ASSEMBLY. -PICK UP PUMP ASSEMBLY#1 AND ENGAGE 3"GS SPEAR. RIH AND LAND ON TTC COUPLING. -PUMP 1 BPM=1000 PSI TO RELEASE GS SPEAR. '-POOH AND CHANGE OUT 3"SPEAR FOR 4". MEET WITH MPU PE TO DISCUSS DS TOOL RUNNING AND PRESSURE TEST. 22:00 - 23:00 1.00 RUNCOM P RUNCMP RUN PUMP ASSEMBLY#2. -PICK UP PUMP ASSEMBLY#2 AND ENGAGE 4"GS SPEAR. -RIH AND LAND ON PUMP ASSEMBLY#1. -PUMP 2 BPM=900 PSI TO RELEASE GS SPEAR. 23:00 - 23:30 0.50 RUNCOM P RUNCMP RUN PACK OFF ASSEMBLY#1. -ENGAGE GS SPEAR ONTO PACKOFF ASSEMBLY. -RIH LAND ON TOP OF RECEPTACLE. -PUMP 2 BPM=900 PSI TO RELEASE GS SPEAR. Printed 1/6/2014 1:58:10PM • North America-ALASKA-BP Page 8 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date:12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UW:500292319000 Active datum:MPL-43:@50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 RUNCOM P RUNCMP MAKE UP PACK OFF TEST TOOL. -MAKE UP WIRELINE DS TOOL AND TEST TOOL. RIH AND STING INTO PACK OFF ASSEMBLY. -PUMP 2 BPM=640 PSI TO RELEASE. CLOSE BLIND RAMS. -PRESSURE TEST PACK OFF FROM ABOVE •TO 1000 PSI FOR 5 CHARTED MINS. -RIH AND STING INTO PACK OFF TEST TOOL. -POH AND UD PACK OFF TEST TOOL. CONTINUAL HOLE FILL =20 BPH WITH KWF. NO RETURNS. 1 24 HOUR FLUID LOSS=480 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=2185 BBLS. 12/24/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. LAND TUBING STOP. -RIH ENGAGE TUBING STOP ON TOP OF PACKOFF. -PICK UP 1000 LBS AND SHEAR THE BRASS PIN. •-POOH AND UD RUNNING ASSEMBLY AND 2-7/8"DP. 01:00 - 02:00 1.00 RUNCOM P RUNCMP PJSM,PULL ESP OVER WINDWALL. -STRING KEVLAR ROPE TO SPOOLING UNIT. -PULL FLAT LEAD ESP CABLE TO RIG FLOOR USING SNAKE ATTACHMENT. 02:00 - 06:00 4.00 RUNCOM P RUNCMP CENTRILIFT PERFORM ESP SLICE AT RIG FLOOR. 06:00 - 07:30 1.50 RUNCOM P RUNCMP CENTRILIFT PERFORM TIE IN ESP CABLE TO MOTOR. -PERFORM TESTS ON MOTOR. -INSTALL 3 PROTECTORS,2 PLAT GUARDS,2 MID JOINT CLAMPS ON BHA. 07:30 - 12:00 4.50 RUNCOM P RUNCMP PJSM,RIH WITH 4.5 12.6#HYDRIL 521 TUBING. -CANNON CLAMP EVERY JOINT. -TEST CONDUCTIVITY EVERY 1000'MD. -PUMP 5 BBLS DOWN TUBING EVERY 2000' MD. -AT 2000'MD 1 BPM=980 PSI. RIH FROM 0'MD TO 2035'MD. 12:00 - 13:00 1.00 RUNCOM P RUNCMP SERVICE RIG. -INSPECT FLOOR EQUIPMENT. 13:00 - 00:00 11.00 RUNCOM P RUNCMP CONTINUE RIH WITH 4.5 12.6#HYDRIL 521 TUBING. -CANNON CLAMP EVERY JOINT. -TEST CONDUCTIVTY EVER 1000'MD. -PUMP 5 BBLS DOWN TUBING EVERY 2000' MD. -AT 4000'MD 1 BPM=700 PSI,AT 6000'MD 1 BPM=880 PSI. -RIH FROM 2035'MD TO 6936'MD. CONTINUAL HOLE FILL =20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=485 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=2670 BBLS. Printed 1/6/2014 1:58:10PM • North America-ALASKA-BP Page 9 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date:12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:00AM i Rig Release: Rig Contractor:DOYON DRILLING INC. _ UW:500292319000 Active datum:MPL-43:@50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/25/2013 !00:00 - 01:30 1.50 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. CONTINUE RIH WITH 4.5 12.6#HYDRIL 521 TUBING. -CANNON CLAMP EVERY JOINT. -TEST CONDUCTIVTY EVER 1000'MD. -PUMP 5 BBLS DOWN TUBING EVERY 2000' MD. -RIH FROM 6936'MD TO 7308'MD. 01:30 - 05:00 3.50 RUNCOM P RUNCMP CENTRILIFT SPLICE ESP CABLE. -CIRCULATE 5 BBLS,240 PSI. -MOVE TREE INTO CELLAR AND ATTACH 1502 ADAPTER FLANGE. 05:00 - 08:30 3.50 RUNCOM P RUNCMP CONTINUE RIH WITH 4.5 12.6#HYDRIL 521 TUBING. -CANNON CLAMP EVERY JOINT. -TEST CONDUCTIVTY EVER 1000'MD. -PUMP 5 BBLS DOWN TUBING EVERY 2000' MD. -RIH FROM 7308'MD TO 8778'MD. 08:30 - 09:30 1.00 RUNCOM P RUNCMP FMC REP INSTALL TWC INTO HANGER ON RIG FLOOR. -C/O ELEVATORS. -P/U LANDING JOINT. -M/U HANGER. PUW=149K,SOW=111K -TOTAL EQUIPMENT RUN:220 CANNON CLAMPS,3 PROTECTOLIZER,2 FLAT GUARDS,1 CROSS SPLICE CLAMP. 09:30 - 11:30 2.00 RUNCOM P RUNCMP CENTRILIFT CONDUCT EIW CONNECTOR SPLICE. 11:30 - 13:00 1.50 RUNCOM P RUNCMP LAND HANGER. -FMC REP TO RILDS. '13:00 - 15:00 2.00 RUNCOM P RUNCMP TEST TWC FROM BELOW. -PUMP 5 BPM=500 PSI FOR 5 CHARTED MINUTES. -TEST FROM ABOVE 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. 15:00 - 17:00 2.00 RUNCOM P RUNCMP CLEAN AND CLEAR FLOOR OF CENTRILIFT !EQUIPMENT. -PULL ESP CABLE OVER SHEAVE AND LAY/DN. -FLUSH OUT BOP STACK. -BLOW DOWN TEST LINES. 17:00 - 19:00 2.00 RUNCOM P RUNCMP PJSM,ND BOPE. 19:00 - 23:00 4.00 RUNCOM P RUNCMP M/U ADAPTER. -FMC REP TO TEST VOID TO 5000 PSI FOR 30 CHARTED MINUTES. -NU 4-1/16"TREE AND TEST TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES. -CENTRILIFT TO MAKE FINAL CHECK ON ESP.120 F,2915 PSI. 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM,P/U WELL SUPPORT LUBRICATOR AND TEST LUBRICATOR. -M/U RUNNING TOOLS. CONTINUAL HOLE FILL=20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=176 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=2846 BBLS. Printed 1/6/2014 1:58:10PM • North America-ALASKA-BP Page 10 of 10 Operation Summary Report Common Well Name:MPL-43 AFE No Event Type:WORKOVER(WO) Start Date:12/18/2013 End Date:12/26/2013 X4-00YCR-E:(2,200,000.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/6/2004 12:00:OOAM Rig Release: Rig Contractor DOYON DRILLING INC. UWI:500292319000 Active datum:MPL-43:@50.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/26/2013 00:00 - 02:00 2.00 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. -CONTINUE TO M/U WELL SUPPORT LUBRICATOR. -TEST LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -PULL TWC. -TEST LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -SET BPV. 02:00 - 05:30 3.50 RUNCOM P RUNCMP PJSM,LRS PUMP FREEZE PROTECT. -TEST LINES 250 PSI LOW,3500 PSI HIGH. -PUMP 45 BBLS DOWN TUBING AT 1.5 BPM= 500 PSI. PUMP 53 BBLS DOWN IA AT 1.75 BPM=600 PSI. 05:30 - 06:00 0.50 RUNCOM P RUNCMP R/D HOT OIL UNIT. -SECURE WELL. RELEASE DOYON 16 RIG FROM MPL-43 AT 06:00 HRS 12/26/2013 FOR MOVE TO MPK-PAD. Printed 1/6/2014 1:58:10PM • Tree: 4' -5M CIW M P L-43 elev.= 50.30' (Doyon 14) Wellhead: 11" 5M FMC Ge6.. , a w/ ,.. -Tbg Hgr elev=16.3' 4.5"FMC Tbg. Hgr 4.5"Top&Btm hanger thread 4'""H" BPV profile 4 20"91.1'#t H-40 112' 9 5/8"40#L-80 BTRC casing 6097' Sidetrack on Whipstock at 9340' A KOP @ 200' Max. hole angle=54° @ 4700' Angle @ SSD = 20° Hole angle @ perfs=6° D&D Tbg Stop 8715' 4.5"12.6 ppf,L-80,Hydril-521 TBGit D&D Packoff Assy Top 8717' (Drift ID=3.958", Cap.=.0152 bpf Centrilift TTC-ESP Top 7" 26# L-80 BTRC-Mod casing Model 380 SXD Type 116-P18 P2P 8723' (drift ID=6.151",cap =0.0382 bpf) TTC Drilled Tbg Crossover 8761' • Tandem Seal Sections IR 1 Model GSB3 DB UT/LT HL H6 PFS 8772' IBM Doyon 16 FCO to 8,815' 12-24-2013 Motor, 126 HP,2445 volt, 8786' 31 amp,Model MSP1-250/126 116 7 Phoenix PumpMate 8798 w/6 fin Centralizer Perforation Summary Ref log:Tied Jewelry log into Baker Tie Back Sleeve 8828' Size SPF Interval (TVD) Baker'ZXP'Liner Top Pkr 8835' 3-3/8" 12 9,415'-9,435' 7,250'-7,270' 8842' Baker Flex Lock Liner Hgr 2 7/8" 6 9,449'-9,469' 7,284'-7,304' 3-3/8"HS 3412 Powerflow HMX guns 7"PESI Float Collar(PBTD) 8868' 2-7/8"HSD,38C CP Big Hole guns 7"PESI Float Shoe 8953' Size SPF Interval (TVD) 3 3/8" 6 9,312'-9,332' 7,152'-7,172' 3 3/8" 6 9,394'-9,414' 7,233'-7,253' 3-3/8"PJ 3406 HMX,6 SPF HSD 4.5"Landing collar(PBTD) 9559' Affinink 4.5"12.6#,L-80 float shoe 9645' DATE REV.BY COMMENTS MILNE POINT UNIT Drill and Complete7 Doyon 14 8/13/04 LeeHulme Pulled Frac string run ESP 4-ES WELL M PL-43 12/6/07 REH Nabors 4ES RWO-ESP c/o&FCO API NO: 50-029-23190-00 10/2/08 Hulme Nabors 3S RWO-ESP c/o,screen install 6/02/09 REH *labors 3S RWO-ESP c/o,pul screens,test csg,EGO 3/30/11 Hulme _Doyon 16 RWO-ESP do,FCO 12/27/2013 B.Bixby Doyon 16 RWO-ESP do,FCO,Install TTC ESP BP EXPLORATION (AK) STATE OF ALASKA ALASK/ . AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERANS 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 ❑ Perforate ❑ Time Extension Change out ESP / Pull Screen 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 203 - 224 3. Address: ❑ Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 ' 50 - 029 - 23190 - 00 - 00 7. Property Designation: 8. Well Name and Number. ADL 025509 -r MPL 9. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 9645' feet Plugs (measured) None feet true vertical 7484' feet Junk (measured) None Effective depth: measured 9559' feet Packer. (measured) N/A feet true vertical 7398' feet Packer. (true vertical) N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1530 520 Surface 6097' 9-5/8" 6097' 4439' 5750 3090 Intermediate Production 8920' 7" 8953' 6803' 7240 5410 Liner 817' 4-1/2" 8828' - 9645' 6685' - 7484' 8430 7500 Perforation Depth: Measured Depth: 9312' - 9469' ) APR 2, 8 2011 True Vertical Depth: 7153' - 7309' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 8759' 6620' Packers and SSSV (type, measured and true vertical depth): ( F - N r:7. ' t /'4 None A -.01 - A ii 11. Stimulation or cement squeeze summary: Intervals treated (measured): Afa4kiit Oil & OM 1flIS$lQry Treatment description including volumes used and final pressure: SNOW 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 248 132 123 300 270 Subsequent to operation: 102 17 252 360 263 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory - Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ _ ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. 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 Jesse Rosenbaum, 564-5155 N/A Printed Name Terrie Hubble Title Drilling Technologist V ' / Prepared By Name/Number Signature Phone 564 - 4628 Date / It Terne Hubble, 564-4628 Form 10-404 Revised 10/2010 1 , y. f�� RBDMS APR 2'8 2011 .,-, Submit Original Only • 0 i North Americo'- ALASKA BP a , O perati on S ummary R eport Common Well Name: MPL -43 I AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 1 End Date: 3/31/2011 1X4- 00T92 -E (775,000.00 ) Project: Milne Point I Site: M Pt L Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 1/6/2004 12:00:OOAM Rig Release: 3/31/2011 Rig Contractor: DOYON DRILLING INC. !UWI: 500292319070 — Active Datum: MPL -43: @50.80ft (above Mean Sea Level) Date ! From - To Hrs Task Code I NPT I NPT Depth I Phase I Description of Operations (hr) ' (ft) 3/25/2011 06:00 - 10:00 4.00 MOB P PRE MOBOLIZE RIG FROM MPL -20 TO MPL -43. I- WELL TO WELL MOVE, MOVED WITH THE DERRICK UP. - SPOTTED OVER WELL, LEVELED UP THE 'RIG. I - SPOTTING MODULES - CALLED GREASE CREW TO COME OUT AND rGREASE THE TREE AND VALVES. - HOOK UP CIRCULATION LINES TO MANIFOLD IN CELLAR 10:00 - 14:30 4.50 RIGU P PRE I HOOKUP HARD LINE TO THE TIGER TANK r- PU & MU HYD LUBRICATOR ON THE RIG FLOOR. DSM WORKING ON THE LUBRICATOR I SHOULDER. I - WAITING ON HEATED SEA WATER FROM _ PRUDHOE,LIMITED TRUCK AVAILABILITY { 14:30 - 15:00 0.50 RIGU P PRE ' RIG EVACUATION DRILL HELD. - DRILLER CALLED THE H2S DRILL, ALL RIG PERSONAL AND THIRD PARTIES MUSTERED TO THE APPROPRIATE AREA FOR A HEAD COUNT. `HELDAAR: AAR IDENTIFIED THAT ONE TRUCK DRIVER WAS NOT SIGNED IN, THE _ •TRUCK PUSHER TOOK RESPONSIBILITY HE ■ ITOLD THE DRIVER HE WAS GOING TO DO IT. WHEN THE HEAD COUNT WAS TAKEN, THE DRILLER REALIZED THAT THE DERRICK MAN WAS AT THE CROWN AT THE TIME OF DRILL. - LESSON LEARNED, THE DERRICKMAN NEEDS TO HAVE A RADIO WITH HIM WHEN HE IS AT THE CROWN. 15:00 16:30 1.50 WHSUR P I DECOMP MU LUBRICATOR TO TREE, GETTING READY I TO PRESSURE TEST. I ; 1 CREWS MAKING CHANGE OUT. 1 - LUBRICATE OUT THE BPV. i - SET BACK THE LUBRICATOR FOR USE i AFTER THE WELL KILL 16:30 - 18:00 1.50 WHSUR P DECOMP I PJSM FOR TESTING SURFACE LINES - TESTING TO 3500 PSI UPSTREAM OF THE I CHOKE & 500 PSI DOWNSTREAM I -1600 PSI ON TBG & IA. 18:00 18:30 0.50 WHSUR I P -- -- ' ,RIG EVACUATION DRILL & AAR. 18:30 - 23:00 4.50 1 WHSUR P DECOMP LINE UP TO IA, THROUGH CHOKE TO FLOWBACK TANK. -OPEN UP WELL, BLEED DOWN PRESSURE. - MISTING EVENT OCCURED. SHUT IN. - BAFFLE ON TOP OF TANK RELEASED MIST. - MAKE APPROPRIATE CALLS. SRT CAME OUT TO LOCATION. 23:00 - 00:00 1.00 I WHSUR P DECOMP OPEN UP WELL, BLEED DOWN PRESSURE F/ 1600 TO 1050 PSI. 1 3/26/2011 00:00 - 01 :00 1.00 WHSUR P 1 DECOMP I SHUT IN WELL. BLEED OFF CIRC LINES. T /I /O = 1140/1140/0 I I - DISCUSS BULLHEAD OPERATION W/ FIELD SUPERINTENDENT. Printed 4/25/2011 10:56:31AM • orthAmertca-ALASKA-BP. Pa g e zot7 , , , C}peratr Summary Report , Common Well Name: MPL-43 L AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 3/31/2011 X4- 00T92 -E (775,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 1/6/2004 12:00:OOAM Rig Release: 3/31/2011 Rig Contractor: DOYON DRILLING INC. UWI: 5 Active Datum: MPL -43: @50.80ft (above Mean Sea Level) Date 1 From - To Firs Task Code NPT I NPT Depth Phase Description of Operations I (hr) i (ft) 01:00 - 04:30 3.50 WHSUR P DECOMP PJSM. LINE UP & BULLHEAD 530 BBLS OF 8.5 ' PPG SEAWATER. -ICP= 1220 PSI. FCP= 2140 PSI. 1 -LINE UP ON CHOKE &MONITOR. INITIAL SITP= 2140 PSI, INITIAL SICP= 1840 PSI. -IN 1 .5 HRS= SITP= 1250 PSI, SICP= 1280 PSI. _ 1.50 WHSUR P 1 DECOMP , 04:30 DISCUSSION W/ FIELD SUP & TOWN, 06:00 DECISION WAS MADE TO MAKE A SECOND BULLHEAD WITH SEA WATER. I -UNE UP & BULLHEAD 530 BBLS OF 8.5 PPG SEAWATER. DOWN THE TBG AND IA AT THE j I SAME TIME - PUMPED AT 7 BPM ' -TBG PRESSURES FROM 1250 INITIAL & 1660 [ FINAL' - IA PRESSURES FROM 1350 INITIAL - 1500 FINAL. 06:00 - 09:30 3.50 WHSUR P DECOMP MONITORED WELL WHILE WAITING FOR PRODUCED WATER. - TBG WENT F/ SHUT IN PRESSURE OF 870 AT 0545 TO 390 PSI AT 0845. ,- IA WENT FROM SHUT IN PSI OF 800 AT 0545 TO 480 AT 0845. I 11 - DISCUSSION W/ FIELD SUPT AND TOWN ENGINEER, DECISION WAS MADE TO PUMP A THIRD BULL HEAD WITH PRODUCED WATER. DISCUSSION W/ FIELD SUP & TOWN, 09'30 11:00 1.50 WHSUR P DECOMP DECISION WAS MADE TO MAKE A THIRD II BULL HEAD WITH PRODUCED -LINE UP & BULLHEAD 530 BBLS OF 8.5 PPG ' OF PRODUCED DOWN THE TBG AND IA AT THE SAME TIME STRAIGHT FROM THE 1 TRUCKS. ,I - PUMPED AT 7 BPM -TBG PRESSURES FROM 550 INITIAL TO 1670 ■ FINAL 1 1- IA PRESSURES FROM 420 INITIAL TO 1540 FINAL. Printed 4/25/2011 10:56:31AM , Pam 3 �i 7 Operation Summary Report Common Well Name: MPL-43 1 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 1 End Date: 3/31/2011 !X4- 00T92 -E (775,000.00 ) Project: Milne Point i Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/6/2004 12:00:OOAM Rig Release: 3/31/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292319070 Active Datum: MPL -43: @50.80ft (above Mean Sea Level) Date 1 From - To I Hrs I Task Code NPT 1 NPT Depth Phase ' Description of Operations (hr) (ft) �I 11:00 - 14:00 3.00 WHSUR P j DECOMP I MONITORED WELL WHILE WAITING FOR 'PRODUCED WATER. 1 1 - TBG WENT F/ SHUT IN PRESSURE OF 710 � TOOIN35MIN 1 I I- IA WENT FROM SHUT IN PSI OF 660 AT 0545 TO 550 IN THE SAME TIME CONTINUED TO MONITOR FOR ANOTHER HOUR. - TBG STAYED AT ZERO AND IA CONTINUED i TO FALL FROM 550 TO 410. j - OPENED & VERIFIED THAT THE TBG WAS 1 ON A VAC. I- `DISCUSSION WITH THE RWO SUPT AND TOWN ENGINEER; WAS DECIDED THAT 1 THERE WAS TRAPPED PRESSURE ON THE 1 BACK SIDE AND WE WERE GOING BLEED 1 . OFF THROUGH THE GAS BUSTER. LINED UP THRU THE CHOKE TO UTALIZE ,- , TI-IE MANUAL CHOKE TO THE GAS BUSTER, I 1 BLED OFF 1 00 PSI AND SHUT IN TO 1 • I MONITOR, MONITORED FOR 10 MIN THE PRESSURE DROPPED FROM 310 TO 300 PSI. CONFIRMING THE PRESSURE IN THE IA TO '.BE TRAPPED PRESSURE. - =BLED THE REST OF THE PRESSURE OFF, THROUG H THE GAS BUSTER. TBOTH THEIAANDTHE TBG WERE BOTH ON A VAC. I - CONFIRMED THAT ,LINED UP TO FILL THE HOLE. 14:00 - 18:00 4.00 WHSUR I`, P DECOMP RIGGED UP TO FILL THE IA '- FILLED THE HOLE WITH THE CHARGE PUMP 1 I- FILLED WITH 142 BBLS- I - SHUT DOWN PUMP TO ESTABLISH LOSS RATE 1- LOSS RATE AT 30 -45 BPH. 1 1 - CONTINUE WITH A MIN HOLE FILL OF 20 BPH AS DIRECTED BY WELL PLAN 1 18:00 - 22:30 4.50 WHSUR P DECOMP I PJSM. P /U, M/U & STAB LUBRICATOR. TEST SAME. I -TEST TO 250 PSI LOW & 3500 PSI HIGH I PRESSURE - OK. -SET TWC. TEST TWC F/ ABOVE 250 / 3500 PSI - 10 MINUTES EACH - OK -ATTEMPT ROLLING TEST FROM BELOW TO 500 PSI.- UNABLE. 22:30 - 23:00 0.50 WHSUR P DECOMP R/D DSM & LUBRICATOR. — - -BLOW DOWN SURFACE LINES. 23 :00 - 00:00 1.00 WHSUR P DECOMP I R/D CIRCULATING MANIFOLD & LINES IN CELLAR. 3/27/2011 00 :00 - 02:00 2.00 WHSUR , P DECOMP I PJSM. N/D TREE & ADAPTOR. PREPARE 1 WELLHEAD. I -CHECK HANGER THREADS 2 -7/8" 8RD xo M/U I IS 9-1/2 TURNS. 02:00 - 04:00 I 2.00 1 WHSUR P 1 DECOMP N/U 11" x 13-5/8" SPACER SPOOL & BOPE 04 :00 - 04:30 0.50 WHSUR P I DECOMP R/U TO TEST BOPE. " Printed 4/25/2011 10:56:31AM • Orth America - ALASKA Page 4 of T x ? operation Summary Report Common Well Name: MPL -43 .,, f AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 3/31/2011 X4- 00T92 -E (775,000.00 ) i Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/6/2004 12:00:OOAM Rig Release: 3/31/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292319070 Active Datum: MPL -43: @50.80ft (above Mean Sea Level) Date From - To Hrs I Task 1 Code NPT I NPT Depth Phase Description of Operations 04:30 - 08:30 4.00 WHSUR P ! O DECOMP ll TEST BOPE 13 -5/8" 5M HYDRILL ////���� -TEST WITNESS BY BP WSL & DDI TP. -TEST TO 250 PSI LOW & 3500 PSI HIGH PRESSURE. -TEST W/ 2 -7/8" TEST JT. -TESTS WITNESSED BY DDI TP, DRILLER & BP WSL I L- CONTINUOUSLY FILLING THE HOLE DURING THROUGH THE IA @ 20 BPH I BOB NOBLE AOGCC WAIVED WITNESS. 08:30 11:30 3.00 PULL P 1 DECOMP PU & MU OPSO LOPSO -RU MPU MANUAL LUBRICATOR & TEST - 250 PSI LOW, 3500 PSI HIGH , EACH FOR 5 1 I CHARTED MIN , - MPU WELLSUPPORT PULLED TWC 11:30 13:03 1.55 I PULL P DECOMP rPU AJNTOF 2-7/8" EUE TUBING WITH A TIW & CIRC SUB MADE UP ON TOP - Nil 1 R I. AY 1 - 120 K TO PULL OFF SEAT DUE TO WELL I BEING ON A VAC. r '- CBU NOT PRACTICAL , CLOSED IN AND � BULL HEADED 75 BBLS OF SEAWATER I i - PUMPING 7 BPM @ 1850 PSI. 13:03 18:00 �_ 1 — — 4.95 PULL P DECOMP ! POH WITH ESP, STANDING BACK 2 -7/8" EUE 8RD TBG IN DERRICK. - POH TO THE GLM, LAY DOWN TO THE PIPE ISHED - POH WITH 7 STANDS, GOT TO SPLICE, C/0 � I ' SPOOL I CONT POH WITH 15 STANDS I 1 1 - WENT THRU DRY RUN OF A KICK WHILE DRILLING. I HELD AAR: DISCUSSED THE NEED TO I COMMUNICATE WITH THE SPOOLER I OPERATOR OF WHEN WE ARE SPACING OUT TO CUT THE ESP CABLE. ALSO FOUND THE NEED TO HAVE A LADDER CLOSE BY TO UNDO THE LIFTING EYE ON TOP OF THE TIW. 18:00 - 00:00 6.00 PULL P DECOMP CONTINUE TO P011 WITH ESP, STANDING BACK 2 -7/8" EUE 8RD TBG IN DERRICK. I -DAILY LOSSES TO WELL = 591 BBLS. -TOTAL LOSSES TO WELL = 1032 BBLS 3/28/2011 00:00 - 04:30 4.50 PULL P DECOMP 1 CONTINUE TO POH WITH ESP, STANDING BACK 2 -7/8" EUE 8RD TBG IN DERRICK. 1 -BREAK DOWN ESP (SHAFT SHEARED). UD ESP. I -UD SHEAVE & ELEPHANT TRUNK. ,- CONTINOUS HOLE FILL @ 20 BPH MINIMUM. 104 30 05:00 0.50 PULL ! P DECOMP ! CLEAR & CLEAN RIG FLOOR. -SHOOT FLUID LEVEL @ 2750' MD. Printed 4/25/2011 10:56:31AM - , - - or A rne BP Page 5 of 7 iperattan Summary Report Common Well Name: MPL -43 1 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 ' End Date: 3/31/2011 X4- 00T92 -E (775,000.00 ) Project: Milne Point Site: M Pt L Pad I II Rig Name /No.: DOYON 16 Spud Date/Time: 1/6/2004 12:00:OOAM j Rig Release: 3/31/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292319070 Active Datum: MPL -43: @50.80ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth 1 Phase I Description of Operations (hr) (ft) 105:00 - 14:00 9.00 ' CLEAN P —I DECOMP �MOBILZE, P/U & M/U DEPCK BAILER ASSEMBLY FOR FILL CLEAN OUT. - BAILER SHOE, FLAPPER VALVE, FLAPPER VALVE, 1 JT TBG, FLAPPER VALVE, -18 JTS TBG, LOWER DRAIN SUB, 39 JTS TBG, I !I PUP TBG, UPPER DRAIN SUB, -DEPCK BAILER MAIN VALVE, I PUP TBG, 72 SIDS INSTALL.W EAR RING 9" I.D 1-RIH WITH TBG BAILER ON 2 -7/8" TBG FROM I ! 'THE DERRICKTO8,655' -CONT TIH WITH SINGLES FROM THE PIPE SHED TO ?TOP OF FILL @ 9,549' =pPEND VALVE OIV BAKER TUBING VALVE 'AND CLEANED OUT FILL DOWN TO 9,559' (PBTD) : _ �� - CLOSED DSPC BAILER AND PREP FOR TOH. 14:00 - 16:00 2.00 CLEAN P DECOMP ;POOH WITH TBG BAILER CLEAN OUT BHA 1 W1TH SINGLES LAYING DOWN TO THE PIPE SHED 1- ; FILLING THE HOLE WITH 20 BPH 16:00 - 21 :00 5.00 CLEAN P DECOMP 1CONTINUE TO POH WITH TBG BAILER CLEAN I OUT BHA STANDING BACK 2 -7/8" EUE 8RD 1 i TBG IN DERRICK. POH TO BHA. 1 21:00 - 22:30 1.50 CLEAN fi P DECOMP BREAK & UD BAKER FLAPPFRS I -CLEAN OUT +/- 45' OF FRAC SAND F/ LAST STD. - WHILE BREAKING DOWN THE TBG BAILER IT WAS NOTICED THAT THERE WAS A HARD RUBBER PIECE MISSING FROM THE BHA - DISCUSSION WITH TOWN ENGINEER AND RWO TL , DECISION WAS MADE TO CALL OUT I/ A REVERSE CIRCULATING JUNK BASKET E FOR THE RUBBER PIECE I __ SAND GO FISH O I 22:30 - 00 :00 1.50 CLEAN P DECOMP AAR F/ BAKER FLAPPER BHA. -CUT & SLIP 73' OF 1 -1/4" DRLG LINE. 3/29/2011 00:00 - 01:00 1.00 CLEAN N DFAL I DECOMP I SERVICE RIG. WORK ON MP2 WORK ORDERS. -WAIT ON RCJB BHA. 02:30 1.50 1 01:00 - CLEAN N DFAL DECOMP P/U & MIU RCJB BHA 1- 3 -5/8" RCJB, (2)- 3 -3/4" BOOT BASKETS, SUB, 3 -1/8" LBS, SUB, 1 JT TBG. 02:30 - 08:00 ! 5.50 CLEAN , N DFAL 1 DECOMP RIH W/ RCJB BHA ON 2 -7/8" TBG F/ DERRICK. 1 1 - RIH TO 8811' JUST ABOVE THE LINER TOP, DROPPED THE BALL FOR THE RCJB. 1 - CIRCULATE THROUGH THE 4 -1/2" LINER TOP@ 8828'. I -50 SPM / 1400 PSI. - RIH HALF A JOINT 1 08:00 10:00 2.00 1 CLEAN ! N HMAN I DECOMP WHILE MADE UP TO THE TUBING, THE MOTOR MAN PULLED UP WITH THE 1 ELEVATORS LATCHED AND GOT THE ELEVATORS BIT WHILE MADE UP IN THE TOP DRIVE. -CUT TBG JT TO REMOVE. 10:00 - 12:00 2.00 CLEAN 1 N DFAL ! I DECOMP I CONT RIH WITH RCJB BHA ON SINGLES I I FROM THE PIPE SHED I 1 1 - RIH TO FISH MISSING PART FROM TBG BAILER CLEAN OUT BHA. I 1 RIH TO 9219' MD. PUW= 92K, SOW= 76K. Printed 4/25/2011 10:56:31AM arth America - ALASKA - BP Pages of 7 40 Ope ration S ummary R e port Common Well Name: MPL -43 -... ' AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 3/31/2011 1 X4- 00T92 -E (775,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/6/2004 12:00:OOAM I Rig Release: 3/31/2011 Rig Contractor: DOYON DRILLING INC. ' UWI: 500292319070 Active Datum: MPL -43: @50.80ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) 1 (ft) 12:00 - 14:00 2.00 CLEAN N DECOMP ! CONTINUE TO RIH 1X1 TAG FILL @ 9564' MD. -PUMP 5 BPM / 2560 PSI. RECIPROCATE PIPE. ' -TAG BOTTOM 4X F/ RCJB. 14:00 - 15:30 [ 1.50 CLEAN N Ir III DECOMP POH, UD 32 JTS OF 2 -7/8" TBG 1X1 TO PIPE SHED. 15:30 - 19:30 4.00 CLEAN 1 N DECOMP t POH T/ RCJB. RACK BACK TBG IN DERRICK. 19:30 - 20:00 0.50 CLEAN N DECOMP -['BREAK & UD RCJB. RECOVERED: -1 PC OF METAL 3/4" WIDE 8" LONG 1/16" THICK. I -1 PC OF RUBBER DEBRIS (MOST OF 1MISSING PIECE). 20:00 - 21:00 1.00 RUNCOM P RUNCMP ' PJSM. R/U ESP SHEAVE & LINE. PULL WEAR RING. ' 21:00 - 00:00 3.00 RUNCOM P RUNCMP P/U & M/U ESP ASSEMBLY. & FILL W/ OIL. CENTRALIZER, PUMPMATE XTO SENSOR, KMI4 MOTOR 152 HP /2325V/40AMP. ; -LOWER &UPPER TANDEM SEAL SECTIONS, I GAS SEPERATOR, 3/30/2011 00:00 - 14:00 14.00 RUNCOM P RUNCMP I RUN:ESP ASSEMBLY. - SEVICE & FILL W/ OIL. [ - RUNNING ORDER AS FOLLOWS: .CENTRALIZER, PUMPMATE XTO SENSOR, KMH MOTOR 152 HP /2325V/40AMP. -LOWER & UPPER TANDEM SEAL SECTIONS, GAS SEPERATOR, -63 -012 MVP SXD PUMP, SXD 66 -P6, SXD 1 141-P6, FPHVDIS DISCHARGE HEAD, -PUP, ADV, 3 -PUPS, XN NIPPLE, 3 -JTS TBG, PUP, PUP GLM W/ 2 -7/8" X 1" KBMM DGLV, -PUP, 268 JTS OF TBG, PUP, GLM W/2-7/8" x 1" KBMM W/ DPSOV, PUP, 3 JTS, PUP, -FMC 11" x 2 -7/8" ESP TBG HANGER. DOYON 1 16 RKB = 22.81' -NOTED DAMAGED PUP ONTOP OF ADV & CHANGED IT OUT. PUP ON TOP OF GLM DPU O -NOTED DAMAGED GLM, SWAPPED GUTS OUT OF GLM'S. I I - REPLACED GLM. -RAN IN HOLE TO 7400' MD. PUW= 80K, SOW= 70K. _L -FULL CNNON CLAMPS EVERY OTHER JT. 14:00 2.00 RUNCOM 16 :00 P — RUNCMP 'SPLICE ESP. SERVICE TOP DRIVE. 16:00 - 18:00 2.00 RUNCOM 1 P RUNCMP CONTINUE TO RUN ESP TO 8758' MD. PUW= 103K, SOW= 80K. -M /U CIRCULATING HEAD PIN, PUMP 10 BBLS. 3.5 BPM / 300 PSI. I -RAN: 6 PROTECTOLIZERS, 2 FLAT GUARD 1 [ I CLAMPS, 13 PUMP CLAMPS -146 FULL CANNON CLAMPS. 18:00 - 21:00 3.00 RUNCOM P RUNCMP ! M/U LANDING JT TO TBG HANGER. -TERMINATE ESP CABLE IN HANGER. CHECK 'CONTINUITY. 1 , -LAND HANGER PER FMC. RILDS. -CLEAR FLOOR. R/D SHEAVE & TBG EQUIPMENT. Printed 4/25/2011 10:56:31AM I Operation Summary Report 1 ,.v Common Well Name: MPL -43 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 I End Date: 3/31/2011 IX4- 00T92 -E (775,000.00 ) 1 Project: Milne Point I Site: M Pt L Pad -- I Rig Name /No.: DOYON 16 1 Spud Date/Time: 1/6/2004 12:00:OOAM Rig Release: 3/31/2011 Rig Contractor: DOYON DRILLING INC. jUWI: 500292319070 Active Datum: MPL -43: @50.80ft (above Mean Sea Level) ! Date From - To Hrs Task Code NPT I NPT Depth I Phase Description of Operations (hr) I (ft) ,_ 21:00 - 22:30 1.50 WHSUR ` P ? WHDTRE I INSTALL TWC & TEST F/ ABOVE. I , j 1 I -250 LOW / 3500 HIGH PSI FOR 10 MINUTES EACH -OK. � I - ATTEMPT TO TEST F/ BELOW, 3 BPM / 0 -80 IPSI - UNABLE. -BLOW DOWN SURFACE LINES, DRAIN — S 1 22:30 - 00:00 1.50 WHSUR P WHDTRE - PREP RIG FLOOR F/ MOVE. -R/D BOP STACK. 3/31/2011 00:00 - 01:00 1.00 WHSUR P j WHDTRE ICONTINUE TO N/D TREE. 01:00 - 06:00 5.00 WHSUR P WHDTRE INSTALL TREE. TEST ESP CABLE. 1 -PT HANGER VOID 250 / 5000 PSI F/ 10 MINUTES EACH -OK. I -FILL TREE W/ DIESEL. -PT TREE 250 / 5000 PSI F/ 30 MINUTES. - OK. -R/U DSM, PT LUBRICATOR 250 / 3500 PSI - WOK. I � -PULL TWC. SET BPV. -ATTEMPTTO TEST FROM BELOW AT 7 BPM / I 100 PSI AND PUMPED 55 BBLS KWF. ,-SECURE TREE VALVES. I RELEASE RIG AT 06:00 HRS 3/31 /2011 FOR l MOVE TO MPF -96. Printed 4/25/2011 10:56:30AM Tree: 2 9/16" - 5M CIW M P L -43 KB ele 50.30' (Doyon 14) , Wellhead: 11" 5M FMC Gen. 5a110 RT - gr elev = 16.3' 2 -7/8" FMC Tbg. Hgr - - - 2-7/8" Top & Btm hanger thread 2.5" "H" BPV profile 4 20" 91.1'#t H -40 112' I Camco 2 -7/8" x 1" KBMM GLM 123 ' 9 5/8" 40# L -80 BTRC casing Sidetrack on Whipstock at 9340' 6097' 4 IL KOP @ 200' Max. hole angle = 54 @ 4700' ' Camco 2 -7/8" x 1" KBMM GLM 8532' Angle @ SSD = 20° Hole angle @ perfs = 6° I I XN Nipple - 2.313" pkg. bore I 8642' 2.250" NO -GO — Centrilift Tandem ESP's 8689' SXD 141- P6 & 68 - P6 & 2 -7/8" 6.5 ppf, L -80, 8rd EUE tbg. 1 .y , PMSSD 63 - G12 ( drift ID = 2.347 ", cap. = .00579 bpf) ,. Centrilift Tandem Gas Separator 8725` 7" 26# L -80 BTRC -Mod casing GRSFXTARH6 ( drift ID = 6.151 ", cap = 0.0382 bpf) Centrilift Tandem seal section 8730' ■ r GSB3DB UT /LT SB /SB PFSA /FSA CL6 . 57 Centrilift KMH series 8744` 114 hp motor, 2230 / 30 amps MO I • PumpMate XTO multi- sensor I 8755' and Centralizer XTO = 6,616' TVD Baker Tie Back Sleeve 1 8828' Baker 'ZXP' Liner Top Pkr 1 8835' Baker Flex Lock Liner Hgr 1 8842' 1 Perforation Summary Ref log: Tied Jewelry log into Size SPF Interval (TVD) 4 , 7" PESI Float Collar (PBTD) 1 8868` 3 -3/8" 12 9,415' - 9,435' 7,250' - 7,270' 7" PESI Float Shoe I 8953' 2 7/8" 6 9,449' - 9,469' 7,284' - 7,304' 3 -3/8" HS 3412 Powerflow HMX guns 2 -7/8" HSD, 38C CP Big Hole guns Size SPF Interval (TVD) 3 3/8" 6 9,312' - 9,332' 7,152' - 7,172' 3 3/8" 6 9,394' - 9,414' 7,233' - 7,253' 3 -3/8" PJ 3406 HMX, 6 SPF HSD 4.5" Landing collar (PBTD) 9559' 1 Doyon 16 FCO to 9559' 3/30/11 4.5" 12.6 #, L -80 float shoe 9645' DATE REV. BY COMMENTS M I LN E POINT UNIT 6/26/04 Lee Hulme Drill and Complete by Doyon 14 WELL M P L -43 8/13/04 MDO Pulled Frac string run ESP 4 -ES 12/6/07 REH Nabors 4ES RWO - ESP c/o & FCO API NO: 50- 029 - 23190 -00 10/2/08 Hulme Nabors 3S RWO - ESP c/o, screen install 6/02/09 REH Nabors 3S RWO - ESP c/o, pul screens, test csg, FCO 3/30/11 Hulme Doyon 16 RWO -ESP c/o, FCO BP EXPLORATION (AK) . ~~,~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ MAR 2 ~ ZtI~PORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon air Well ^ Plug Perforations ^ Stimulate^ Other Q ACID Performed: ( Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ TREATMENT Change Approved P Operat. Shutdown^ Perforate ^ Re-enter uspended Well ^ ESP 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ^ 203-2240 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-23190-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-025509 MPL-43 10. Field/Pool(s): ~~ MILNE PO INT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 9645 feet Plugs (measured) None feet true vertical 7483.83 feet Junk (measured) None feet Effective Depth measured 9559 feet Packer (measured) true vertical 7398 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 91.1# H-40 SURFACE - 112 SURFACE - 112 1530 520 Surface 6097 9-5/8" 40# L-80 SURFACE - 6097 SURFACE - 4439 5750 3090 Intermediate Production 8920 7"26# L-80 SURFACE - 8953 SURFACE - 6803 7240 5410 Liner 817 4-1 /2" 12.6# L-80 8828 - 9645 9985 - 7484 8430 7500 Liner Perforation depth: Measured depth: 09415-9435 O 9449 - 9469 O 9312-9332 O 9394 - 9414 _ True Vertical depth: 7254.83 - 7274.73 7288.67 - 7308.57 7153 - 7172 7234 - 7254 _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 30 - 8739 30 - 6601 '`~"r''~"'~~~`°~'" ' ~' ~ _~ Packers and SSSV (type, measured and true vertical depth) NONE ~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 167 32 118 263 Subsequent to operation: 166 28 110 269 14. Attachments: ~. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ 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: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature ~ Phone 564-4944 Date 3/26/2010 ruin iu-wu~+r~viseti iiz ~uuimivnyniaivniy ~-~ X12 /o ~ - ~~~® • MPL-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/8/2010~T/I/0=460/500/0 Pre-Acid Treatment Infectivity test. Pumped 32 bbls total down ~tbg. Tbg caught pressure arouns 22 bbls away. Injection rate for 10 bbls at 2500 psi=0.13 bpm. Pumped remaining 18 bbls crude down flowline. Final WHP=800/500/0 SV, WV, SSV=C...MV, IAV, OAV=O 3/9/2010 CTU #9 w/1.50" OD CT. Job scope -MIRU, Acidize ESP. Move to MPL pad and standby for WS to RU surface equ. MIRU CTU. MU 1.75" DJN BHA and RIH to ESP jetting w/diesel. Tagged ESP at 8666' CTM. Washed off top of ESP w/diesel. Could not get any injection through ESP before acid treatment. Inj 4 bbls 10% acid through ESP. Start ESP, pump running in reverse. Inj 3 bbls acid through ESP, soak 10 min, inj 3 bbls through ESP running forward, soak 10 min, inj 3 bbls acid through ESP running in reverse. Est inj through ESP not running at 1 bpm @ 126 psi. Circ 50 bbls KCL to ESP, close choke and inject 50 bbls through ESP @ .6 bpm @ 1919 psi. .... Continued on WSR 03/10/2010 ..~ ..~_ ~... ..~ ~.A ~ m a~. ~ m_ 3/10/2010'CTU #9 w/1.50" OD CT. Job scope -Acidize ESP, RDMO. Continued from ~ ~WSR 03/09/2010. Finish injecting KCL through ESP. FP well. POOH. RDMO. I**'""*''Job complete. FLUIDS PUMPED BBLS 52 60/40 MEOH 12.4 10% HCL 52 1 % KCL XS 145 DIESEL 261.4 TOTAL Tree: 2 9/16" - 5M CIW ~ M PL-43 ~lev. = 50.30' (Doyon 14) Wellhead: 11" 5M FMC Ge w/ RT -Tbg Hgr elev = 16.3' 2-7/8" FMC Tbg. Hgr ~~ 2-7/8" Top & Btm hanger thread 2.5" "H" BPV profile 20" 91.1' #t H-40 Camco 2-7/8" x 1" KBMM GLM 164 ' 9 5/8" 40# L-80 BTRC casing .6097` Sidetrack on Whipstock at 9340' ~ KOP @ 200' Max. hole angle = 54° @ 4700' Angle @ SSD = 20° Hole angle @ perfs = 6° 2-7/8° 6.5 ppf, L-80, Srd EUE tbg. ( drift ID = 2.347", cap. _ .00579 bpf) 7" 26# L-80 BTRC-Mod casing (drift ID = 6.151", cap = 0.0382 bpf ) Camco 2-7/8" x 1" KBMM GLM 8,510' XN Nipple - 2.313" pkg. bore 8,652' 2.250" NO-GO Centrilift Tandem ESP's 8,673` SXD 140-P10 PMSSD 63/G12 MVP Centrilift Tandem Gas Separato 8,703' GRSFTXARH6 Centrilift Tandem seal section 8 707, GSB3DB UT/LT SB/SB PFSA/FSA CL6 ' Centrilift KpOH series 8 721, 152 hp mo or, 2325 / 40 amps PumpMate XTO multi-sensor 8,735' and Centralizer Perforation Summary Ref IOg: Tied Jewelry log into Size SPF Interval (ND) 3-3/8" 2 7I8" 12 6 9,415' - 9,435' 9,449' - 9,469' 7,250' - 7,270' 7,284' - 7,304' 3-3/8° HS 3412 Powerflow HMX guns 2-7lB" HSD, 38C CP Big Hole guns Size SPF Interval (TVD) 3318" 3 318° 6 6 8,312'-9,332' 9,384' - 9,414' 7,152'-7,172' 7,233' - 7,253' Baker Tie Back Sleeve 8828' Baker'ZXP' Liner Top Pkr 8835' Baker Flex Lock Liner Hgr 8842' 7" PESI Float Collar (PBTD) 8868' 7" PEST Float Shoe 8953' 33/8" PJ 3406 HMX, 6 SPF HSD Nabors 4ES FCO to 9530' 12/6/07 Nabors 3S FCO to 9560' 6/2/09 4.5" Landing collar (PBTD) 9559` 4,5" 12.6#, L-80 float shoe 9645` DATE REV. BY COMMENTS M I LN E POINT U N IT 8/13/04 Le8MD0 a Pulled Frac string run ESP 4ES r~ WELL M P L-43 12/6/07 REH Nabors 4ES RWO - ESP Go & FCO API NO: 50-029-23190-00 10/2/08 Hulme Nabors 3S RWO -ESP do, screen install 6rovos REH Nabors 3S RWO - ESP clo, pul screens, ~u csg, FCO B P EX P LO RATI Q N { STATE OF ALASKA • ALA~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ,~~9 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 / Pull Screen ^ PerForate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 203-224 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23190-00-00 - 7. KB Elevation (ft): KBE = 50.80' ~ 9• Well Name and Number: MPL-43 ~ 8. Property Designation: 10. Field / Pool(s): , ADL 025509 - Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 9645' ~ feet true vertical 7484' - feet Plugs (measured) N!A Effective depth: measured 9559' feet Junk (measured) N/A true vertical 7398' feet Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' 1530 520 Surface 6097' 9-5/8" 6097' 4439' 5750 3090 Intermediate Production 8920' 7" 8953' 6803' 7240 5410 Liner 817' 4-1/2" 8828' - 9645' 6685' - 7484' 8430 7500 ~ V f .t~ 1~9 ( 410~ 4~E'~:~' ~2'~ :S~'9~y.-:~J ~ ` Perforation Depth MD (ft): 9312' - 9469' , Perforation Depth TVD (ft): 7153' - 7309' 2-7/8", 6.5# L-80 8739' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ~j ~~~~ ~ 12. Stimulation or cement squeeze summary: ~nterva~s treated (measured): AIBSke Oil &~~~ C~tIY. COmmiss'tOn Treatment description including volumes used and final pressure: AflCh0~~~1 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1530 Subsequent to operation: 137 42 94 320 286 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 if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number. ' nature Phone 564-4750 Date '~ ondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~"~. ,,~,~? g~ Z~J(j~ Submit Original Only f ~a Tree: 2 9/16" - 5M CIW Welihead: 11" 5M FMC Ge . w/ 2-7/8" FMC Tbg. Hgr 2-7/8" Top & Btm hanger thread 2.5" "H" BPV profile 20" 91.1'#t H-40 M P L~`t~ ~lev. = 50.30' (Doyon 14) RT - Tbg Hgr elev = 16.3' Camco 2-7/8" x 1" KBMM GLM 164 ' 9 5/8" 40# L-80 BTRC casing Sidetrack on Whipstock at 9340~ 6097` ~ KOP @ 200' Max. hole angle = 54° @ 4700` Angle @ SSD = 20° Hole angle @ perfs = 6° 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. _.00579 bpf) 7" 26# L-80 BTRC-Mod casing ( drift ID = 6.151", cap = 0.0382 bpf ) Camco 2-7/8" x 1" KBMM GLM 8,510' XN Nipple - 2.3~3" pkg. bore 8,652' 2.250" NO-GO Centrilift Tandem ESP's g,673` SXD 140-P~ Q PMSSD 63/G12 MVP Centrilif# Tandem Gas Separato g,703' GRSFTXARH6 Centrilift Tandem seal section $ 7~7, GS63D8 UT/LT SBISB PFSA/FSA CL6 Centrilift K~QH series $ 721, 152 hp mo~ar, 2325 / 40 amps PumpMate XTO multi-sensor 8,735' and Centralizer Perforation Summary Ref log: rlea Jewe~ry ~oy ineo Size SPF Interval (ND) 3-3/8" 2 7/8" 12 6 9,415' - 9,435' 9.449' - 9,469' 7,250' - 7,D0' 7,284' - 7,304' 3-3/8" HS 3412 Powerflow HMX guns 2-7/8" HSD, 38C CP Big Hole guns Size SPF Interval (TVD) 3 3/8" 3 3/8" 6 6 9,312' - 9,332' 9,394' - 9,414' 7,152' - 7,172' 7,233' - 7,253' Baker Tie Back Sleeve 88z8~ Baker'ZXP' LinerTop Pkr 8835' Baker Flex Lock Liner Hgr 8842~ 7" PESI Float Collar {PBTD) 8868' 7" PESI Float Shoe 8953' 3-3/8" PJ 3406 HMX, 6 SPF HSD Nabors 4ES FCO to 9530' 12/6/07 Nabors 3S FCO to 9560' 6/2/09 4.5" Landing collar (PBTD) 9559` 4.5" 12.6#, L-80 float shoe 9645' DATE REV. BY COMMENTS MILNE POINT UNIT 6/26l04 8/13/04 Lee Hulme MDO Drill and Complete by Doyon 14 Pulled Frac string run ESP 4-ES W E LL M P L-43 12/6/07 REH Nabors 4ES RWO - ESP c/o & FCO API NO: 50-029-23190-00 10/2/08 Hulme Nabors 3S RWO - ESP c/o, screen install 6/02/09 REH Nabors3SRW0-ESPc/o,pulscreens,testcsg,F~o BP EXPLORATION~AK~, u • gp Pag~:1 of 5 Qperations Summary Report Legal Well Name: MPL-43 Common Well Name: MPL-43 Spud Date: 1/6/2004 Event Name: WORKOVER Start: 5/24/2009 End: 6/2/2009 Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 6/2/2009 Rig Name: NABORS 3S Rig Number: N3S ' Date From - To Hours Task Code NPT Phase Description of Operations 5/24/2009 04:00 - 06:00 2.00 RIGD P PRE Scope down and lower Derrick. 06:00 - 09:00 3.00 RIGD P PRE R/D Rig complexes for move. 09:00 - 10:00 1.00 MOB P PRE Move Rig Camp, Shop and Pits to MPL-Pad. 10:00 - 12:00 2.00 MOB P PRE Pull Carrier off MPF-80 with Pad operator, NAD Toolpusher and BP WSl present. Move Carrier, Pipe shed and Genset to MPL-Pad. 12:00 - 13:00 1.00 MOB P PRE Lay mats and BOPE components behind Well head. 13:00 - 15:00 2.00 MOB P PRE Back Carrier over MPL-42 with Pad operator, NAD 7oolpusher and BP/WSL present. Spot pipe shed. 15:00 - 16:00 1.00 RIGU P PRE Build berm and spot UP-right tank and LRS. Hook up lines to complexes. 16:00 - 18:00 2.00 RIGU P PRE Scope and raise Derrick and raise the wind walls. 18:00 - 20:00 I 2.001 RIGU I P 20:00 - 20:30 0.50 WHSUR P 20:30 - 22:00 1.50 WHSUR P 22:00 - 00:00 2.00 WHSUR P 5/25/2009 100:00 - 02:30 I 2.501 WHSUR I P 02:30 - 08:00 I 5.501 WHSUR I P 08:00 - 08:30 0.50 WHSUR P 08:30 - 09:30 1.00 WHSUR P PRE Rig up the kill manifold, hook up the hard line to the tiger tank, and secure the service lines. W HDTRE Pick u and test the lubricator to 500 si and ull the BPV. WHDTRE Waiting on heated seawater to arrive. WHDTRE Offload heated seawater into the pits and into the upright tank. Pressure test the kill manifold lines to 3500 psi. Pressure test the tiger tank lines down stream of the choke to 500 psi. WHDTRE Bleed oressure off of the IA and TBG from SITP 1640 nsi / SICP 1600 psi to 0. WHDTRE Held fluid displacement meeting with crew. Displace Well with 50 bbls of heated 8.45 ppg seawater at 4 bpm / 400 psi down the tubing up the IA through choke to the Tiger tank. Bulihead 141 bbls at 2 bpm / 250 psi into formation. Resume displacing 8.45 ppg heated seawater in at 4 bpm, returns began at 19000 stks. Lost returns and recovered 85 bbls crude. Tubing and IA on a vacuum. WHDTRE ow own i manifold and lines. WHDTRE Dry rod TWC with FMC wellhead tec_h_Pressure t_e_st TWC, p_e_rform rolling injection test from below at 3 bpm, pumped 20 bbls at 0 si Well on a vacuum. 09:30 - 11:00 1.50 WHSUR P DECOMP RD kill manifold and lines. ND production Tree. Tubing hanger top threads = 9 turns on 2-7/8" 8rd EUE. 11:00 - 15:00 4.00 BOPSU P DECOMP Load ram blocks into ram body, PU / MU single BOP components to confiqure 3 ram stack on Riq mats. 15:00 - 20:30 5.50 BOPSU P DECOMP Stab BOP stack on to tubing spool and N/U. Install the blind rams in the top set of rams. Instal( the turnbuc es an measure the RKB. Charge the Koomy and function test all of the rams. BOP Configuration: -Annular -Blind Rams -Mud Cross -2 7/8" x 5" VBR -Test Spool 20:30 - 00:00 3.50 BOPSU P DECOMP Pressure test BOPE to 250 si low and 3 500 si hi h per BP / AOGCC Regulations. Each test held for 5 minutes. The top VBRs (2-7/8" X 5"), Blind rams, lower pipe rams (2-7/8") and Annular were tested with a 2-7/8" and 3.5" test Joints against TWC. The test was witnessed by NAD Toolpusher Rick Printed: 6/8/2009 11:39:20 AM • Opera~ions Legal Well Name: MPL-43 Common Well Name: MPL-43 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date I From - To I Hours I Task I Cod~ I NPT 5/25/2009 120:30 - 00:00 I 3.501 BOPSUR P 5/26/2009 100:00 - 01:00 I 1.001 BOPSURP 01:00 - 02:00 1.00 BOPSU P 02:00 - 03:00 1.00 BOPSU P 03:00 - 06:00 3.00 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 23:30 17.00 PULL P 23:30 - 00:00 0.50 PULL P 5/27/2009 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:00 1.00 CLEAN P 02:00 - 03:30 1.50 CLEAN P 03:30 - 05:00 1.50 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 07:00 1.00 CLEAN P 07:00 - 20:30 13.50 CLEAN P 20:30 - 21:30 I 1.00 i CLEAN I P 21:30 - 00:00 I 2.501 CLEAN I P • Page 2 c ~ary Report Start: 5/24/2009 Rig Release: 6/2/2009 Rig Number: N3S i Spud Date: 1/6/2004 End: 6/2/2009 ~ _ ~ .,N., ..,r,.. DECOMP Bjorhus, and BP WSL Chris Kobuck. AOGCC rep. Bob Noble waived witness of test. DECOMP Finish up testing the BOPE with the 3.5" test joint to 250 psi low / 3500 psi high. Good test. The test was witnessed by NAD Toolpusher Rick Bjorhus, and BP WSL Chris Kobuck. AOGCC rep. Bob Noble waived witness of test. DECOMP Laydown the test joints, blow down the choke manifold, and drain the stack. DECOMP Rig up the Opso Lopso and lubricator. Test to 500 psi. Good test._Pull the TWC and rig down the lubricator and Opso Lopso. Well is on a vac. DECOMP Make up the landing joint and screw into the hanger 9 turns. BOLDS. Pull hanger off seat with 80k up wt. Disconnect the ESP cable and inspect the hanger (Good to re-run). Break out the hanger and begin to pull out of the hole with 2 7/8" tubing. DECOMP Snake ESP cable over sheave in Derrick to spooling unit. POH with ESP completion assembly and lay down 2-7/8" tubing into pipe shed. Maintain continuous fill rate at - 20 bph. DECOMP Pull out of the with 2 7/8" tubing and ESP completion assembly. Recovered 275 full joints of 2 7/8" completion, the ESP, 2 GLM's, 1 XN Nipple, 2 Screens, 143 Lasalle clamps, 3 armster guards, and 6 protectolizers. DECOMP Clean and clear the floor of all Centrilift tools and prepare to rig up for scraper run. DECOMP Finish rigging down from pulling out of the hole with 2 7/8" tubing and ESP completion. Clean and clear the floor. DECOMP Install the wear ring and pick up Scraper BHA tools. Rig up tongs and prepare to run in the hole on 3.5" drillpipe. DECOMP Finish loading the drillpipe into the shed. Then strap and tally all of the drilipipe. DECOMP Make up Dual Scraper BHA to 131'. Torquing all to appropriate ft/Ibs. BHA consists of: -Mule Shoe -Pin x Pin Cross over -4.5" Scraper -Box x Box Cross over -(4) 3.t25" Spiral Drill CoAars -Pin x Pin Cross over -7" Scraper -Box x Box Cross over DECOMP Be in to sin le in the hole on 3.5" drill i e. DECOMP Service the Rig and pre-tour checks. DECOMP RIH with BHA #1 on 3-1/2" Drill Pipe. Purpose of BHA is to__, scra e/ drift the 7" Casin and to of 4-1/2" Liner in preqaration for settinq an RBP in the Liner. Stop every 80 Joints in the hole and pump down the string to ensure it is clear and not plugged up. Enter the 4-1/2" liner top with no roblems. Up Wt. 130k / Down Wt. 68k DECOMP Reverse circulate a drillpipe volume {66bbls) at 4bpm and 100 psi. No returns to surface. DECOMP Monitor well for 10 minutes static. Begin tripping out of the Printed: 6/8/2009 11:39:20 AM ~ ~ B P Page 3 of 5 Operations Summary Report Legal Well Name: MPL-43 Common Well Name: MPL-43 Spud Date: 1/6/2004 Event Name: WORKOVER Start: 5/24/2009 End: 6/2/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2009 Rig Name: NABORS 3S Rig Number: N3S ' Date From - To Hours Task Code NPT Phase Descriptian of Operations 5/27/2009 21:30 - 00:00 2.50 CLEAN P DECOMP hole from 8940'. Racking back drillpipe in the derrick. -Filling 20 bbl/hr. 5/28/2009 00:00 - 05:00 5.00 CLEAN P DECOMP Continue out of the hole with the Dual Scraper BHA racking back the drillpipe in the derrick. Laydown the BHA and clean clear the floor. 05:00 - 06:00 1.00 EVAL P DECOMP Pick up 4.5" RBP with Halliburton rep. The purpose of the RBP is to pressure test the 7" Casing to surface along with the u er ortion of the 4-1/2" Liner. 06:00 - 06:30 0.50 EVAL P DECOMP Pre-tour checks and service the Rig. 06:30 - 09:00 2.50 EVAL P DECOMP TIH with 4-1/2" Halliburton RBP on 3-1/2" Drill Pipe from the Derrick maintaining hole fill with 20 bbls per hour of seawater. 09:00 - 10:30 1.50 EVAL P DECOMP Stop with 40 stands (80 Jts) in the hole. Slip and cut 70' of drilling line. 10:30 - 14:30 4.00 EVAL P DECOMP Continue TIH with 4-1/2" RBP with hole fill at 20 bbls per hour of seawater. 14:30 - 18:00 3.50 EVAL P DECOMP Establish PUW and SOW prior to entering the 4-1/2" Liner Top. PUW = 115K , SOW = 75K. Set the 4-1/2" RBP at 8,860' Center of Element. Had trouble with upper slips on the RBP setting properly, allowing the RBP to move up hole slightly every time we tried to get it to overpull. Set 25K down and confirm it is set. Fill the hole with 75 bbls but the hole is taking fluid not maintainin the fluid column. Establish hourly loss rate of -60 bbls er hour. Unseat the RBP and re-set at ,892' Center of Element (one Joint deeper). Fill the hole again and it is still losinq fluid like before. Discuss wit nc orage Engineering to confirm plan forward. 18:00 - 19:00 1.00 EVAL P DECOMP Attempt to release from 4-1/2" RBP without success. After second attem t released the RBP and prepare to trip out of the ~ hole with the RBP. 19:00 - 00:00 5.00 EVAL P DECOMP Trip out of the hole with the 4 1/2" RBP. Up Wt. 120k / Down Wt. 70k 5/29/2009 00:00 - 04:00 4.00 EVAL P DECOMP Continue out of the hole with the 4 1/2" RBP and rack back the drillpipe. Lay down the 4 1/2" RBP and clean and clear the floor. 04:00 - 10:30 6.50 EVAL P DECOMP Pick up and make up the 7" RTTS and run in the hole on 3.5" drill i e. The purpose of this BHA is to pressure test the 7" Casing above the 4-1/2" Liner to surface and prove its integrity. 10:30 - 11:00 0.50 EVAL P DECOMP In with 284 Joints of 3-1/2" Drill Pipe. Establish parameters of PUW = 118K , SOW = 66K. Set the 7" RTTS at 8,781' center of element. 11:00 - 12:00 1.00 EVAL P DECOMP Fill the backside with 24 bbls of seawater. Allow the air to work itself out. Pressure test the 7" Casing from 8,781' to surface to 2 000 si for 30 charted mins - good te . 12:00 - 17:00 5.00 EVAL P DECOMP Release the RTTS with Halliburton re s. POOH standing back Drill Pipe in the Derrick maintaining hole fill at 20 bbis per hour with seawater. 17:00 - 18:00 1.00 EVAL P DECOMP On surface with the 7" RTTS. Break out and lay down with Halliburton reps. 18:00 - 00:00 6.00 EVAL P DECOMP Pick u and make u 4 1/2" RTTS and RIH on (4) 3.125" Drill Collars crossed over to 3.5" Drillpipe. Run in the hole to 8750' and establish parameters of Up Wt. 127k / Down Wt. 62k. 5/30/2009 00:00 - 04:00 4.00 EVAL P DECOMP Continue in the hole from 8750' to 8890' and set the RTTS. Fill t e o e with 61 bbls, shut down the pumps and fluid level was Printed: 6/8/2009 11:39:20 AM -~J • ' ^ - -'---_• -`°--- -r- - - - Legal Well Name: MPL-43 Common Well Name: MPL-43 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S I Date From - To Hours Task Code NPT 5/30/2009 00:00 - 04:00 4.00 EVAL P 04:00 - 10:30 6.50 EVAL P 10:30 - 11:00 0.50 EVAL P 11:00 - 13:30 2.50 CLEAN P 13:30 - 18:00 4.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 22:30 4.00 CLEAN P 22:30 - 23:00 0.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 5/31/2009 00:00 - 06:00 6.00 CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 09:30 3.00 CLEAN P 09:30 - 22:00 12.50 CLEAN P 22:00 - 23:00 1.00 CLEAN P 23:00 - 00:00 1.00 RUNCO 6/1/2009 00:00 - 18:00 18.00 RUNCO P ~port Start: 5/24/2009 Rig Release: 6/2/2009 Rig Number: N3S Spud Date: 1/6/2004 End: 6/2/2009 Phase ue~ce,puor~~ ~i v~ar~~~uri5 DECOMP falling away. Release the RTTS and pull up to 8860' and rese~. Fill the hole with 10 bbis, shut down the pumps, well static. Pressure test to 2000 psi for 30 minutes. Good Test. Release the RTTS and run back down to 8890' and set. Fill the hole.~ with 13 bbls, shut down the pumps, well static. ressure test to 2000 psi for 30 minutes. Good Test. Up Wt. 130k / Down Wt. 64k inside t e liner. DECOMP Pull out of the hole from 8890' racking back drill pipe. Maintain hole fill at 20 bbls per hour with seawater. DECOMP Break out and lay down 4-1/2" RTTS with Halliburton reps. DECOMP Clear and clean rig floor. Check all equipment with Baker Fishing rep. Load and strap 70 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing in the Pipe Shed. RD 3-1/2" Handling Equipment and RU 2-7/8" Handling Equipment. DECOMP PUMU BHA #2 as follows: Tooth Type Bailer Shoe, Flapper Valve, 1 Jt o 2- u ing, 2 ea Flapper Valves, 24 Jts of 2-7/8" Tubing, Lower Drain Sub, 45 Jts of 2-7/8" Tubing, Upper Drain Sub, Main Valve, XO. OAL = 2,198.88'. The purpose of this BHA is to clean out to a tarqet depth of 9,560' cleaninq out the welibore. DECOMP Clear rig floor of un-needed equipment and tools and prepare to run in the hole. DECOMP TIH with BHA #2 on 3-1/2" Drill Pipe from the Derrick. Regulate hole fill at 20 bbls per hour with seawater while RIH. Run in to 9540' where we tagged up on fill. Clean out the fill from 9540' to 9561' with the Depck ai er. p . 6k / Down Wt. 54k DECOMP Trip out of the hole from 9561' to 8783' racking back the drill pipe. Monitor the well for 15 minutes. Static. DECOMP Continue out of the hole laying down the 3.5" drillpipe. DECOMP Pull out a total of 62 jts. RIH with 60 jts. from the derrick. Back stop on the skate broke, so had to take it to the shop for repairs. Began loading and strapping 2 7/8" tubing in the pipeshed. DECOMP Service the Rig and pre-tour checks. DECOMP Continue loading and strapping Joints of 2-7/8" Tubing in the Pipe Shed. Complete work on the Pipe Shed and function test multiple times - OK. DECOMP Resume POOH with De ck Bailer la in down Joints of 3-1/2" Drill Pipe in the Pipe Shed. Keep hole fill regulated at 20 bbls per hour with seawater while POOH. Change out elevators and start racking back 2 7/8" tubing in the derrick to be re-run. Last 2 joints above the flapper valve were full of small metal slivers and what appears to be frac sand. Last 3 joints were changed out for the completion due to build up ot debris inside. DECOMP Clean and clear the floor of all the unused tools and BHA. RUNCMP Pick up tools and rig up to run 2.875" ESP completion RUNCMP RIH with ESP completion on 2.875", L-80, 6.5#, EUE 8rd. Completion consists of: -ESP Pump -2 Pup jts. -XN Nipple -4 jts. of 2.875" tubing Pflnt2tl: (i/f3/20Uy 11::ty:1U AM , , w ~ • Operations Legal Well Name: MPL-43 Common Well Name: MPL-43 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date I From - To I Hou'rs I Task I Code I NPT 6/1/2009 100:00 - 18:00 I 18.001 RUNCOf~9P 18:00 - 21:30 3.50 RUN 21:30 - 23:00 1.50 RUN 23:00 - 00:00 1.00 RUN 6/2/2009 00:00 - 02:00 2.00 RUN 02:00 - 03:00 1.00 RUN 03:00 - 04:30 ~ 1.50 ~ W HSUR ~ P 04:30 - 08:00 3.50 BOPSU P 08:00 - 09:30 1.50 WHSUR P 09:30 - 11:00 1.50 WHSUR P 11:00 - 12:00 I 1.00 I W HSU R I P Spud Date: 1 /6/2004 Start: 5/24/2009 End: 6/2/2009 Rig Release: 6/2/2009 Rig Number: N3S ~ RUNCMP -1 GLM assembly - Camco 2 7/8" x 1" KBMM w/ DGLV -251 jts. of 2.875" tubing Flushed the pump at Jt. 251 with 10 bbls of seawater at 25 spm and 780 psi. RUNCMP Stop to do a reel to reel splice with the ESP cable. RUNCMP RIH with remainder of completion. Consists of: -20 jts. of 2.875" tubing -1 GLM assembly - Camco 2 7/8" x 1" KBMM w/ DPSOV -4 jts. of 2.875" tubing -1 Pup jt. -FMC 11" x 2.875" ESP tubing hanger with pup jt. Flushed the pump with 10 bbis of seawater at 25 spm and 880 psi. Completion had a total of: -144 LaSalle Clamps -5 protectolizers -2 armster guards Up Wt. 70k / Down Wt. 43k RUNCMP Make up the landing jt. and assembly to the string. Install the ESP penetrator in the hanger. RUNCMP Make the penetrator splice, terminate and check the cable. RUNCMP Land the tubin han er and run in the lock down screws. Break out and lay down the landing joint. Up Wt. 70k / Down W t. 43k. WHDTRE Rig up and set the TWC. Test the TWC from above to 3500 psi for 10 minutes. Good Test. Attempt to test the TWC from WHDTRE Set cradle behind the BOPE, bleed off the accumulator, and remove the hoses. WHDTRE NU Adapter Flange and 2-9/16" Tree with FMC rep. WHDTRE Pressure test the Hanger void to 5,000 psi for 30 minutes with FMC rep - good test. Fill the Tree with diesel and pressure test to 5,000 si - ood test. Centrilift perform final ESP conductivity checks: Phase to phase = 3.4 Ohms , phase to ground = 1.5 Giga-Ohms , pressure at intake = 2121 psi , Temp at intake = 147 degF , Temp at motor = 144 degF. WHDTRE PUMU Lubricator with Well Support Techs. Pressure test to 500 psi - OK. Pull 2-1/2" Type "H" TWC. Set BPV. LD Lubricator. *" The Rig was released at 1200 hrs oni 06/02/2009. "' Printed: 6/8/2009 11:39:20 AM < • ~ ~ ~ MPL-43 Well History Date Summary 04/15/09 T/I/0=500/500/0 Tubing and IA flush Pumped 22 bbls dead crude down tubing. Tubing pressured up to 1000 psi. Bleed pressure back to 750 psi. Tubing pressured back up once tree cap was on and before pumping down IA. Pumped 103 bbls dead crude down IA. FWHP-1050/420/40 Master, IA, and OA open. Wing, SSV, and Swab closed. 04/15/09 T/I/0=250/260/0. (IA flush/ ESP trouble). Pump 21 bbls crude down IA while DSO tries to get ESP to lift fluid. ESP temp started to get too high. Shutdown pumping. RU to tree cap. Flush FL w/ 22 bbis crude. Swap to tbg. Pressure up on ESP to 1400 psi w/ 6.7 bbls crude. Monitor tbg pressure for 15 minutes. Tbg lost 1200 psi in 15 minutes. FWHP=200/220/0. 04/19/09 CTU #5 w/1.75" OD CT. MIRU. MU and RIH with 2.0" DJN. Pump 17 bbls 7.5% HCL - inj 5 bbls acid - let soak 1 hr - Pad Op conduct forward / reverse mode of ESP - Pump remaining acid away prior soak inj rate at 1900 whp/1 bpm - post soak inj rate 175 w p pm su ace equip an c well. 04/26/09 (ESP Flush) Pumped 48 bbls diesel down Tbg to determine injectivity rate. Round tripped to GPB to load diesel xylene. Pumped 15 bbls diesel xylene followed by 40 bbls diesel down Tbg. DSO notified swab wing ssv shut, master ia oa open FWHP's=400/560/0 05/10/09 T/I/0=600/600/0 Pre-RWO Freeze Protect Continued from 05-09-09 WSR. Pumped 15 bbls Diesel down tubing. Pumped 3 bbls 60/40 methanol, 3 bbls Diesel, and 3 bbls 60/40 methanol down Production and test flowlines. Closed root valves on production and test line and bleed pressure down to 0 psi. FWHP=600/600/0 Master, IA, and OA open. Wing, choke, Roots, Swab and SSV closed. 05/20/09 RAN 2.10" CENT, S.ABSORBER, AND DUAL SPARTEK GAUGES AS PER PROGRAM. PULLED 1" BK-DGLV FROM 8,543' MD, PULLED 1" BEK-DPSOV FROM 161' MD. SET 1"- BK-DGLV @ 161' MD. ASSIST WELL SUPPORT TO INSTALL BPV. WELL LEFT S/I, TURN OVER TO DSO. Page 1 of 1 A~ OIL AND GAS CONSE VA ON CO~SIO ~~ ~ , REPORT OF SUNDRY WELL OPERATIONS~C-r ~ Li~i;l 1. Operations Performed: C~ i" ~ ~ ~~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate n uspended Well e- e ^ 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 203.224 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23190-00-00 7. KB Elevation (ft): KBE = 50 80' 9• Well Name and Number: . MPL-43 ' 8. Property Designation: 10. Field /Pool(s): ADL 025509 Milne Point Unit / Kuparuk River Sands j 11. Present well condition summary Total depth: measured 9645' • feet true vertical 7484' ' feet Plugs (measured) N/A Effective depth: measured 9559' feet Junk (measured) N/A true vertical 7398' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1530 520 Surface 6097' 9-5/8" 6097' 4439' 5750 3090 Intermediate Production 8920' 7" 8953' 6803' 7240 5410 Liner 817' 4-1/2" 8828' - 9645' 6685' - 7484' 8430 7500 '~33'~~;~ '~'~~~SJ `l!1l~3 ;iv5 - Perforation Depth MD (ft): 9312' -9469' Perforation Depth TVD (ft): 7153' - 7309' 2-7/8', 6.5# L-80 8791' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker Safety Joint /Cup Packer 8836' 12. Stimulation or cement squeeze summary: R Intervals treated (measured): ~~~~'Q~ ~~ Treatment description including volumes used and final pressure: ~ i;~~a~ 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: 0 0 0 150 Subsequent to operation: g2 28 97 300 253 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 if C.O. Exempt: Contact David Bjork, 564-5683 N/A Printed Name ondra Stewman Title Drilling Technologist Prepared By Name/Number: Sig ture Phone 564-4750 Date 1'~ " Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~ 1 j ~ Submit Original Only Tree: 2 9/16" - 5M CIW ~ M P L-4'3 ~ elev. = 50.30' (Doyon 14) Wellhead: 11" 5M FMC a w/ Tbg Hgr elev = 16.3' 2-7/8" FMC Tbg. Hgr 2-7/8" Top & Btm hanger thread 2.5" "H" BPV profile 20" 91.1~#t H-40 I 112` Camco 2-7/8" x 1"KBMM-2 GLM 161 ' 9 5/8" 40# L-80 BTRC casing 6097' Sidetrack on Whipstock at 9340` KOP @ 200' Max. hole angle = 54° @ 4700' Angle @ SSD = 20° Hole angle @ perfs = 6° Camco 2-7/8" x 1" KBMM-2 GLM 8,543' XN Nipple - 2.313" pkg. bore 8,658' 2.250" NO-GO 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. _ .00579 bpf) 7" 26# L-80 BTRC-Mod casing ( drift ID = 6.151 ", cap = 0.0382 bpf ) Perforation Summary Ref log: Tied Jewelry log into Size SPF Interval (TVD) 3-3/8" 2 7/8" 12 6 9,415' - 9,435' 9,449' - 9,469' 7,250' - 7,270' 7,284' - 7,304' 3-3/8" HS 3412 Powerflow HMX guns 2-7/8" HSD, 38C CP Big Hole guns Size SPF Interval (TVD) 3 3/8" 3 3/8" 6 6 9,312' - 9,332' 9,394' - 9,414' 7,152' - 7,172' 7,233' - 7,253' 3-3/8" PJ 3406 HMX, 6 SPF HSD DATE I REV. BY I COMMENTS Centrilift Tandem ESP's 8,666' SXD, 160 P11 / 18 P75 Centrilift Tandem Gas Separator 8,695` GRSFTXARH6 Centrilift Tandem seal section g 700` GSB3D6 UT/LT SB/SB PFSA/FSA CI5 Centrilift KMH series 8,713' 228 hp motor, 2305 / 60 amps PumpMate XTO multi-sensor 8,733' Sensor TVD = 6596' Baker Cup Pkr. w/ 44k. Safety $,736` Shear Joint Duragrip 500 Micron Screen Top 8,751 ` Screen Bottom 8,791' Baker Tie Back Sleeve 8828' Baker'ZXP' Liner Top Pkr 8835' Baker Flex Lock Liner Hgr 8842' 7" PESI Float Collar (PBTD) 8868' 7" PEST Float Shoe 8953' Nabors 4ES FCO to 9530` 12/6/07 4.5" Landing collar (PBTD) 9559` 4.5" 12.6#, L-80 float shoe 9645' ' 6/26/04 'Lee Hulme I Drill and Complete by Doyon 14 I 8/13/04 MDO Pulled Frac string run ESP 4-ES 12/6/07 I REH I Nabors 4ES RWO -ESP c/o & FCO 10/2/08 Hulme Nabors 3S RWO -ESP c/o, screen install MILNE POINT UNIT WELL MPS-43 API NO: 50-029-23190-00 BP EXPLORATION (AKl Page 1 of 1 Well: MPL-43 ~ • Well History Well Date Summary MPL-43 9/4/2008 RWO PREP *** WELL S/I ON ARRIVAL *** PULLED 1" BK-DGLV @ 8547' MD (STA # 1) ««POCKET LEFT OPEN»». PULL 1"BEK-DPSOV & SET 1" BK-DGLV C~3 131' MD (STA # 2). 30 MIN STOP @ 8202' MD. TAGGED ESP @ 8700' SLM (8702' MD~3 HOUR STOP C~ 8701' MD. ***WELL S/I ON DEPART*** MPL-43 9/5/2008 T/I/0=100/150/0 Freeze Protect (Pre-RWO) -Flushed/freeze protected both production & test laterals w/2 bbls 60/60 methanol, 3 bbls diesel & 2 bbls 60/40 methanol each. SI laterals C header & bled to 0 psi. Top off tbg freeze protect w/9 bbls diesel. IA/OA & master open. Swab, ssv & wing closed, tag well & notify operator. Final WHP's=0/150/0 MPL-43 9/6/2008 SET DPSOV AND CHECKED DGLV IN MANDRELS FOR 3S. MANDREL WITH DPSOV FLAGGED AND TAGGED. MPL-43 9/18/2008 Well Support Techs. Set BPV / demobe /well house both flow lines and grating, also foundation package. Tree is a 2 9/16. MPL-43 10/1/2008 ***SURFACE WORK 3S*** SET 1 "BEK-DPSOV IN SPM TO BE RUN ON TOP (MARKED AND FLAGGED) VERIFIED 1" BK-DGLV IN SPM TO BE RUN ON BOTTOM (MARKED "dummy") ***NOTIFIED COMPANY REP OF STATUS OF MANDRELS*** MPL-43 10/5/2008 (Freeze Protect) T/I/0= 0/0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. FWHP= 0/0/0 (IA and OA open to gauges. /swab-shut /wing-shut / master-shut /ssv-shut ) MPL-43 10/5/2008 The Well Support Techs rigged up and set the foundation, installed the flowlines and set the wellhouse. They then rigged up and pulled the back pressure valve and leak tested the flowlines to 1150 psi. NOTE: The BPV was left OUT and the leak test was GOOD. Print Date: 10/16/2008 Page 1 of 1 • ! gp Page 1 of 3 Operations Summary Report Legal Well Name: MPL-43 Common Well Name: MPL-43 Spud Date: 1/6/2004 Event Name: WORKOVER Start: 9/28/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/4/2008 Rig Name: NABOBS 3S Rig Number: I I Date I From - To ' Hours I Task Code I NPT Phase Description of Operations 9/28/2008 16:00 - 20:00 4.00 RIGD P PRE R/D Floor and cellar, Secure derrick and prep for rig move. 20:00 - 23:00 3.00 MOB P PRE Move from MPI pad to MPL pad. 23:00 - 00:00 1.00 RIGU P PRE Spot camp, shop, generator, and parts house. Spot mats and BOP stack around well. 9/29/2008 00:00 - 01:30 1.50 RIGU P PRE Spot carrier over well. Jack and level carrier, WSL, Toolpusher and Pad Operator were present while spotting carrier over well. 01:30 - 03:00 1.50 RIGU P PRE Spot pipeshed and pits. Set mats and level. 03:00 - 04:00 1.00 RIGU P PRE Hook up electrical, steam, air, mud and water lines between modules. Set walk ways and stairs. Berm cellar area. 04:00 - 06:00 2.00 RIGU P PRE Inspect derrick, raise off of carrier and scope up. R/U derrick and rig floor. The 'a was accented at 0600 hrs on 9/29/2008., 06:00 - 09:30 3.50 KILL P DECOMP RU hardline to the Tiger Tank. RU circulating lines and kill manifold. RU to the Tree. Take on heated seawater to the Pits - 8.4+ppg at 100 degF measured in the Pits. Pressure test lines to a closed Choke to 3,500 psi - OK. Pressure test the hardline to the Tiger Tank to 500 psi - OK. 09:30 - 10:30 1.00 WHSUR P DECOMP P ricator and make u to the Tree. Pressure test to 500 si with diesel - OK. Pull 2" Type "H" BPV with Well Su ort Techs. 10:30 - 11:00 0.50 KILL P DECOMP Hold pre-kill safety meeting with the crew and vac truck drivers. 11:00 - 14:00 3.00 KILL P DECOMP Open the well to a closed Choke. Bleed 150 psi off the IA to the Tiger Tank. Line up to bullhead down the IA into the formation. Break circulation at a rate of 3.5 bpm / 80 psi on the Tubing and 0 psi on the IA. Catch fluid with 60 bbls away, slow the pump and observe the pressure keep building. Unable to ullhead into the formation, final rate of 0.25 bpm / 1,350 psi. Bleed the pressure back to the Tiger Tank. Line up to pump down the Tubing and circulate 50 bbls of heated seawater down the Tubing taking returns up the IA, through the Choke to the Tiger Tank at a rate of 3.25 bpm / 380 psi on the Tubing and 80 psi on the IA. Close the Choke and attempt to bullhead down the Tubing into the formation - no Joy. Open the Choke and resume circulating the well the long way until clean seawater returns observed on surface. Final circulating rate was 4 bpm / 950 psi on the Tubing with 80 psi on the IA. Pumped a total of 370 bbls surface to surface the long way with 350 bbls returns (95% returns). MW in = 8.4 ppg , MW out = 8.4 PPg• 14:00 - 14:30 0.50 KILL P DECOMP Monitor the well for 30 minutes - Tubin and IA on a vacuum. 14:30 - 15:00 0.50 KILL P DECOMP Blow down and RD kill lines and kill manifold. 15:00 - 16:00 1.00 WHSUR P DECOMP PU T-bar and set 2" T e "H" TWC with FMC re Pressur _ test to 3 500 psi from above for 10 charted mins - OK. 16:00 - 17:00 1.00 WHSUR P DECOMP ND the Tree and Adapter Flange with FMC rep. Check the Hanger threads and screw a 2-718", EUE 8rd Pup Joint into the profile - 9-1/2 turns and good threads. 17:00 - 19:30 2.50 BOPSU P DECOMP N/U BOPE, install Choke, Kill and Koomey lines. Install riser and turnbuckles. 19:30 - 23:00 3.50 BOPSU P DECOMP Fill BOP stack and Choke Manifold with water and purge air. Test Annular VBR's, Blinds, Manual Choke, HCR Choke Valve, Manual Kill Valve, HCR Kill Valve, Floor Valve, Dart Valve, Inner Test Valve, Outer Test Valve, and Choke Manifold to 250 psi low and 3,500 psi high pressure. Hold each test from 5 minutes on the chart. Used 2-7/8" Test Joint. No Failures. Printed: 10/16/2008 10:39:32 AM gp Page 2 of 3 Operations Summary Report Legal Well Name: MPL-43 Common Well Name: MPL-43 Spud Date: 1/6/2004 Event Name: WORKOVER Start: 9/28/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/4/2008 Rig Name: NABOBS 3S Rig Number: Date. f From - To Hours Task I Code NPT ~ Phase ~ Description of Operations 9/29/2008 19:30 - 23:00 3.50 BOPSU P DECOMP AOGCC witness of test was waived by Bob Noble. 23:00 - 22:30 23.50 BOPSU P DECOMP R/D BOP test assembly and drain stack. 22:30 - 00:00 1.50 PULL P DECOMP M/U Opso Lopso and screw into hanger. 9/30/2008 00:00 - 01:30 1.50 PULL P DECOMP M/U Lubricator and test to 500 psi with diesel. Pull TWC. Tubing on a slight Vac. L/D lubricator and Opso Lopso 01:30 - 02:00 0.50 PULL P DECOMP M/U Landing joint and screw into hanger. Back out lock down screws. Pull hanger off seat, Up weight 75,000# 02:00 - 03:00 1.00 PULL P DECOMP Circulate bottoms up with seawater, 3.5 bpm at 650 psi. No Losses. 03:00 - 04:00 1.00 PULL P DECOMP Pull han er to floor and remove ESP cable. L/D Han er. 04:00 - 13:00 9.00 PULL P DECOMP POOH with ESP com letion standin back 136 stands of 2-7/8" __ - derrick. Maintain continuous hole fill. Recover 276 total joints of 2-7/8" tubing in good shape without any noticeable corrosion, 146 LaSalle Clamps, 5 Protectors, 3 Flat Protectors. 13:00 - 17:00 4.00 PULL P DECOMP POOH and L/D ESP pump and motor assembly. 10' pup above ESP and ESP full of Frac Sand. 17:00 - 18:00 1.00 CLEAN P DECOMP Clear and clean rig floor. 18:00 - 00:00 6.00 CLEAN P DECOMP P/U muleshoe and RIH on 2-7/8" EUE rd B fr m Berri 10/1/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Continue to RIH with muleshoe on 136 stands of 2-7/8" EUE 8rd TBG to 8482'. 01:00 - 02:00 1.00 CLEAN P DECOMP Continue to RIH with muleshoe on 29 joints of 2-7/8" EUE 8rd TBG 1 x 1 from pipe shed. Tai fill at 9373'. 02:00 - 02:30 0.50 CLEAN P DECOMP L/D joint 29 and M/U circulating head. P/U joint 29 and Establish parameters of P/U Wt- 64,000 Ibs; S/O Wt- 42,000 lbs. Break circulation down tubing at 1 BPM with 80 psi. 02:30 - 12:30 10.00 CLEAN P DECOMP R/U and reverse circulate at 2 BPM with 260 psi. Attempt to wash through fill with 1-3K WOB with no success. R/U and circulate long to wash to 9384' at 3 at 520 psi. R/U and reverse CBU at 3 BPM with 550 psi. Continue to reverse circulate out fill at 3 BPM with 420 psi. Clean out to 9,418' Work through hard spot. Pump sweep around. Clean out to 9 433' losses increased to 150 b h. 12:30 - 13:30 1.00 CLEAN P DECOMP Reverse circulate sweep out at 4 bpm at 350 psi. 13:30 - 18:00 4.50 CLEAN P DECOMP POOH with 2-7/8" tubing and muleshoe. L/D 7 joints, then stand back148 stand of 2-7/8" EUE 8rd TBG in derrick. L/D muleshoe. 18:00 - 19:00 1.00 CLEAN P DECOMP Clear and clean rig floor. Gather Baker Depck TBG bailer. 19:00 - 20:00 1.00 CLEAN P DECOMP P/U and RIH with Baker Depck TBG Bailer BHA consisting of bailer shoe, flapper valve, 1 jt TBG, double flapper valve, 24 jts of TBG, lower drain valve, 44 jts TBG, upper drain valve, and main valve. Total length of BHA- 2166.51' 20:00 - 00:00 4.00 CLEAN P DECOMP RIH with Baker Depck TBG Bailer on 114 stands of 2-7/8" TBG from derrick to 9270'. Establish parameters of P/U Wt- 52,000 Ibs; S/O Wt- 33,000 Ibs. 10/2/2008 00:00 - 02:00 2.00 CLEAN P DECOMP Continue to RIH with Baker Depck TBG Bailer on 114 stands of 2-7/8" TBG from derrick to 9270'. 02:00 - 03:00 1.00 CLEAN P DECOMP Establish parameters of P/U Wt- 52,000 Ibs; S/O Wt- 33,000 lbs. R/U and shoot fluid level at 1100'. Single in hole with 2-7/8" EUE 8rd TBG, tag fill at 9433'. Bail out fill to 9563' with 3K WOB., Slight overpull (5-10K) noted while working bailer through pert. Overpull up to 45K while pulling off PBTD. P/U Wt on Bottom- 60,000 Ibs. Printed: 10/16/2008 10:39:32 AM BP Page 3 of 3 Operations Summary Report Legal Well Name: MPL-43 Common Well Name: MPL-43 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From - To Hours Task Code ~ NPT Start: 9/28/2008 Rig Release: 10/4/2008 Rig Number: Spud Date: 1 /6/2004 End: 10/2/2008 103:00 - 04:00 I 1.00 I CLEAN I P 04:00 - 06:00 I 2.001 CLEAN I P 06:00 - 16:30 I 10.501 CLEAN I P 16:30 - 19:30 3.00 CLEAN P 19:30 - 20:30 1.00 BUNCO 20:30 - 00:00 3.50 10/3/2008 100:00 - 01:00 I 1.00 01:00 - 02:00 I 1.00 02:00 - 03:00 I 1.00 03:00 - 16:00 I 13.00 16:00 - 20:00 4.00 20:00 - 21:00 ~ 1.00 ~ RNTBHC~ P 21:00 - 21:30 0.50 RNTBH P 21:30 - 22:30 1.00 WHSUR P 22:30 - 00:00 1.50 WHSUR P 10/4/2008 00:00 - 02:00 2.00 WHSUR P 02:00 - 03:30 1.50 WHSUR P 03:30 - 04:00 ~ 0.50 ~ W HSUR ~ P 04:00 - 05:00 1.00 WHSUR P 05:00 - 06:00 1.00 WHSUR P Phase ~I Description of Operations DECOMP P/U to 9301'. Shoot fluid level at 1100', wait 15 minutes and shoot fluid leve a DECOMP RIH to 9560' without tagging fill. POOH and UD 34 joints. Stand back the rest of the 2-7/8" EUE 8rd TBG in derrick. DECOMP Continue to POOH with Depck bailer standing back 102 stands of 2-7/8" EUE 8rd TBG in derrick. B/O and UD bailer Main Valve. Continue to stand back a total of 124 stands in derrick. B/O and UD bailer lower drain sub. Continue to POOH and stand back a total to 130 stands where TBG came full of sand. Continue to P an sing es w i e empting sand in drums and using Super Sucker to empty drums on rig floor. Relieve tripped pressure with tubing punch on joints above and below dual flapper valve. UD the rest of the Baker Depck DECOMP Clear and clean rig floor. RUNCMP UD ESP cable containment trunk and R/U rig floor to P/U and RIH with ESP assembly. RUNCMP P/U and M/U ESP assembl ,consisting of Weatherford DURAGRIP 500 micron screen, Baker Cup type packer assembly, and Centrilift ESP assembly. RUNCMP Continue to P/U and M/U ESP assembly consisting of Weatherford DURAGRIP 500 micron screen, Baker Cup type packer assembly, and Centrilift ESP assembly. Attach cable. RUNCMP RIH with ESP completion assembly on 21 stands of 2-7/8" EUE 8rd TBG from derrick. RUNCMP POOH and stand back 21 stands of 2-7/8" EUE 8rd TBG in derrick due to a modification in the running order. RUNCMP Install bottom GLM assembly and RIH with ESP assembly on 275 joints of 2-7/8" EUE 8rd TBG from derrick. Use Best-O-Life 2000 Pipe Dope. M/U torque 2,300 Wlbs. Maintain 30 bbls hour holefill with seawater. Test ESP cable and flush ESP pump with 10 bbls of seawater every 2,000'. Run ESP completion with 144 LaSalle Clamps, 6 Protectolizers, 3 Flat Guards. RUNCMP P/U landing joint and M/U hanger. Install penetrator and make ESP hanger splice. TUBHGR Establish P/U Wt- 80,000 Ibs; S/O Wt- 45,000 lbs. RIH and land ha er into tubin s ool. RILDS. B/O landing joint and POOH. TUBHGR R/U and set TWC. R/U and test TWC to 3500 psi from above for 10 charted minutes. OTHCMP PJSM with rig crew discuss N/D BOPE operation, procedures, and hazards. Blow down circulating lines and drain BOP stack. OTHCMP N/D BOPE OTHCMP N/D BOPE and lay down in rig cradle. OTHCMP FMC install new seal sleave, N/U adapter flange and production tree. OTHCMP Test adapter flange to 5000 psi for 30 minutes, good test. Test production tree to 5000 psi, good test. OTHCMP Fill tree and test to 5000 psi for 5 charted minutes, good test. OTHCMP Make final cable test. R/U DSM and pull TWC. Set BPV Secure Well. Rig released at 06:00 Hours on 10/4/2008 Printed: 10/16/2008 10:39:32 AM 11/14/07 D~L AN~ GAS Ci-~~w7~~~~~~~~ ~~~~~~0~ BODE Test Report Submit. to: Contractor: Nabors Rig No_: 3S DATE: 9/29/2008 Rig Rep.: J. Greco / J. Fritts Rig Phone:: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659628 Rep.: W. Hoffman / B. Burson Field/Unit & Well No.: MP L-43 PTD# Operation: Drtg: Workaver: x Exp1Qr.: Test: Initial:: x Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS. Test Result Test Result Location Gen.: P Weli Sign P Housekeeping: P EJkf. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 118" 5000 P Kill Line Vahres 1 2 1116" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test. Alarm Test 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: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Cla~tsre 1800 P 200 psi Attained 31sec P Fuff Pressure Attained 1 min 59 sec P Blind Switch Covers: All stations P Nitgn. Bottles {avg): 1975 Test. Results. Number of Failures: 0 Test. Time:. 4 Hours. Repair or replacement of equipment. will be made withirt Inspector 659-3607, fattaow with written con€rrmation to Soperviser at: Remarks: Tested with 2 7/8" test ioint against Two way deck 24 HOUR NOTICE. GIVEN. YES X NO Date 09/28/08 Time 1630 hrs Test start 1930 hrs Finish F' ~ ~ 200 BOP Test (for rigs) BFL 11/14/07 Components tested ALL days. Notify the North Slope By _ Bob Noble Witness J. Fritts / B. Burson Nabors 3s BOP Test MP L-43a 9-29-2008 Revised.xls STATE OF ALASKA ~~~ ~~, ALA OIL AND GAS CONSERVATION COMf~ION REPORT OF SUNDRY WELL OP~~T~ ~a COOS `~ ~t~ -~ 9-9~1 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q O.tHer ~ ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory 1"! ° 2o3-22ao 3. Address: P.O. Box 196612 Stratigraphic Service #' 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-23190-00-00 7. KB Elevation (ft): Well Name and Number: 3 ~ 50.8 KB MPL-4 8. Property Designation: 10. Field/Pool(s): ADLO-025509 ~ MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 9645 feet Plugs (measured) None true vertical 7483.83 feet Junk (measured) None Effective Depth measured 6077 feet true vertical 4425.91 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" Surface - 112' Surface - 112' 1530 520 Surface 6097' 9-5/8" 40# L-80 Surface - 6097' Surface - 4439' 5750 3090 Production 8920' 7" 26# L-80 Surface - 8953' Surface - 6803' 7240 5410 Liner 817' 4-1/2" 12.6# L-80 8828' - 9645' 6685' - 7484' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured. depth) 2-7/8" 6.5# L-80 30 - 8711 0 0 - Packers and SSSV (type and measured depth) 4-1 /2" Baker ZXP Packer 8835 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: `^r~~i ;f~ ~ "^ ~ ~ ~~~~ ~''`~~ ~"}~ Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 108 37 125 265 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~`' Service ~'. Daily Report of Well Operations X 16. Well Status after proposed work: Oil ! Gas WAG ~' GINJ WINJ ~' WDSPL I I 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: N/A Contact Gary Preble Printed Name Gary Preble ~~ Title Data Management Engineer Signature ~ ~/ Phone 564-4944 Date 7/24/2008 Form 10-404 Revised 04/2006 ~ ~ ~ ~ ~ l,I L~ Lr-=~~ ~,, ~s~ ~~`~ ~ ~ I ~~~ ~~ Submit Original Only ~~C-3~ MPB-50 204-252 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPL-43 6/30/04 PER 9,415. 9,435. 7,254.83 7,274.73 MPL-43 6/30/04 PER 9,449. 9,469. 7,288.67 7,308.57 MPL-43 8/12/04 APF 9,312. 9,332. 7,152.53 7,172.37 MPL-43 8/12/04 APF 9,394. 9,414. 7,233.95 7,253.84 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • MPL-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ' 7/16/2008: T/I/0=300/340/0. (ESP acid treatment) Pump 3.3 bbls crude down tbg for '„ injectivity. Tbg pressured up to 3000 psi. Could not maintain injectivity for acid ;treatment. Pump 50 bbls crude down FL for flush. FWHP=300/350/0. ', Swab shut, SSV shut, wing open, IA & OA open. 7/17/2008 ESP TROUBLESHOOT "*'`WELL S/I ON ARRIVAL*** ::RAN 1.75" LIB, TAGGED ESP @ 8706' SLM (8702' MD), SIDE OF L.I.B. LAYED OVER, NO IMPRESSION. =PULL 1" BK-DGLV C~ 854T MD (STA #1), ««««POCKET LEFT ;;OPEN»»»» "`'`'`WELL LEFT S/I *"" 7/18/2008 (Injectivity Test) T/I/0= 150/300/O Pump 50 bbls dead crude down TBG for ',injectivity test @ 1 bpm 3000 Psi max press. Awgers continued on 07-19-08. 7/19/2008;( Injectivity Test) T/I/0= 150/300/0 Pump 50 bbls dead crude down TBG @ 1 bpm 3000 max press. FWHP= 100/300/0 wing closed / ssv closed /master open /swab closed / IA and OA open to gauges. _~. 7/19/2008 T/I/0=350/150/0. (ESP acid wash). Spear into tbg w/ 10 bbls crude for injectivity 'test. Pump 10 bbls 10% DAD acid followed by 3 bbls 60/40 meth & 45 bbls crude ':to spot acid at ESP. Have DSO run ESP forward for 10 minutes, then reverse for '"5 minutes, and forwar again for 5 minutes. Pump 5 bbls cru e own g g o ';flush acid away for ESP. Load more fluid. Overdisplace tbg w/ 90 bbls crude & '10 bbls diesel to push acid back into formation. FWHP=0/150/0. 7/20/2008';. (Injectivity test/ pre-acid) T/I/0=50/100/0. Pump 15.6 bbls crude down tbg for ;injectivity test. Tbg pressured up to 3000 psi. Lost 450 psi in 8 minutes. Flush FL w/ 35 bbls crude. FWHP=200/100/0. 7/21/2008' CTU #5 1.75" coil. MIRU to spot acid into ESP pump. RIH jet 4' of fill off of pump ''circ bottom ups pump acid lay in on top of pump. Let acid soak. POOH pump '1llfreed up flowing to tank. RDMO to MPI - 15 """"` o is omp ete FLUIDS PUMPED BBLS 10 diesel 3 60/40 METH 10 10% DAD ACID 90 CRUDE 113 Total • • ~._ -~- -~ MICROFILMED 03/01 /2008 DO NOT PLACE .-.~: ~~. - ;~: ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CWrPgs_Inserts\Microfilm_Marker. doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 203-224 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23190-00-00 7. KB Elevation (ft): KBE = 50.80' 9. Well Name and Number: MPL-43 ' 8. Property Designation: 10. Field /Pool(s): ~= r P ADL 025509 ~ Milne Point Unit / Kuparuk River s ~ f. ~G 11. Present well condition summary Total depth: measured 9645' ~ feet true vertical 7484' ~ feet Plugs (measured) 6077' Effective depth: measured 9531' feet Junk (measured) N/A true vertical 7370' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1530 520 Surface 6097' 9-5/8" 6097' 4439' 5750 3090 Intermediate Production 8920' 7" 8953' 6803' 7240 5410 Liner 817' 4-1/2" 8828' - 9645' 6685' - 7484' 8430 7500 ~' J/~~ ~ ~~ 200 Perforation Depth MD (ft): 9312' - 9469' Perforation Depth TVD (ft): 7153' - 7309' Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 8771' Packers and SSSV (type and measured depth): Baker ZXP Liner Top Packer ~ ~ ~ 8835' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 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 PUA ff C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist i 1 Prepared By Name/Number: ~ ~ ~ gnature Phone 564-4750 Date ! . ~ ~ Sondra Stewman, 564-4750 Form 10-4 4 Revised 04/2006 ,~ Submit Original Only Tree: 2 9/16" - 5M CIW M PL-`~~ KB elev. = 50.30' (Doyon 14) Wellhead: 11" 5M FMC Gen. 5a w/ RT -Tbg Hgr elev = 16.3' 2-7/8" FMC Tbg. Hng. r-r 2-7/8" Top & Btm hanger trd. I I 2.5" "H" BPV profile top and btm., 2.5" CIW Camco 2-7/8" x 1" KBMG GLM 131 ` 9 5/8" 40# L-80 BTRC casing 6097` Sidetrack on Whipstock at 9340' KOP @ 200' Max. hole angle = 54° @ 4700` Angle @SSD = 20° Hole angle @ perfs = 6° 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. _ .00579 bpf) 7" 26# L-80 BTRC-Mod casing (drift ID = 6.151", cap = 0.0382 bpf ) Perforation Summary Ref log: Tied Jewelry log into Size SPF Interval (ND) 3-3/6" 2 7/8" 12 6 9,415' - 9,435' 9,449' - 9,469' 7,250' - 7,270' 7,284' - 7,304' 3-3/8" HS 3412 Powerflow HMX guns 2-7/8" HSD, 38C CP Big Hole guns Size SPF Interval (ND) 3 3/8" 3 3/8" 6 6 9,312' - 9,332' 9,394' - 9,414' 7,152' - 7,172' 7,233' - 7,253' 3-3/8" PJ 3406 HMX, 6 SPF HSD DATE REV. BY COMMENTS 6/26/04 Lee Hulme Drill and Complete by Doyon 14 8/13/04 MDO Pulled frac string run ESP 4-ES 12/6/07 REH Nabors 4ES RWO -ESP Go & FCO Camco 2-7/8" xT' 8 547 sidepocket KBMG GLM XN- Nipple - 2.313"pkg. bore 8,658' 2.250" NO-GO CentriliftTandem ESP's $,702` SSD, 146 P6 / 180 P6 Centrilift Tandem Gas Separato 8,734` GRSFTXARH6 Centrilift Tandem seal section 8 739, GS63DBFER SSCV HL H6 PFSA Centrilift KMH series 152 hp motor, 2325 / 40 amps 8,753` Phoenix XT-1 multi-sensor 8,767' Baker Tie Back Sleeve 8828' Baker'ZXP' Liner Top Pkr 8835' Baker Flex Lock Liner Hgr ~2' 7" PEST Float Collar (PBTD) 8868` 7" PESI Float Shoe 8953` Nabors 4ES FCO to 9530' 12/6/07 4.5" Landing collar (PBTD) 9559` 4.5" 12.6#, L-80 float shoe 9645` MILNE POINT UNIT WELL MPL-43 API NO: 50-029-23190-00 BP EXPLORATION (AKA BP Operations Summary Report Page 1 of 2 Legal Well Name: MPL-43 Common Well Name: MPL-43 Spud Date: 1/6/2004 Event Name: WORKOVER Start: 11/30/2007 End: 12/6/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/6/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/2/2007 08:00 - 10:00 2.00 RIGD P PRE PJSM. Rig down rig and rig components. Lower & lay over 12:00 - 15:00 3.00 R GU I P 15:00 - 18:00 I 3.001 KILL I P 18:00 - 18:30 I 0.501 KILL I P 18:30 - 19:00 0.50 KILL P 19:00 - 22:00 3.00 KILL P 22:00 - 22:30 0.50 KILL P 22:30 - 23:30 1.00 KILL P 23:30 - 00:00 0.50 KILL P 12/3/2007 00:00 - 00:30 0.50 KILL P 00:30 - 01:30 1.00 WHSUR P 01:30 - 03:00 1.50 WHSUR P 03:00 - 05:00 2.00 BOPSU P 05:00 - 09:00 4.00 BOPSU P 09:00 - 10:00 1.00 BOPSU P 10:00 - 10:30 0.50 EVAL ( P 10:30 - 11:30 1.00 PULL P derrick. Prep for move. PRE PJSM. Move rig & rig components from MPL-20 to MPL-43. PRE PJSM. Rig up on MPL-43. Raise and scope derrick. Assemble rig components. Rlg accepted @ 15:00 hrs, 12/02/2007. DECOMP PJSM. Spot tiger tank, rig up lines to same. Rig up lines to wellhead. Rig up lubricator, PT lubricator to 1000 psi, OK. Pull BPV. Check pressures, SITP = 0 psi, SICP = 0 psi, O/A = 0 psi. Take on heated seawater to pits. Prep for well kill. DECOMP Crew change. Service rig, check PVT alarms, perform derrick inspection, OK. DECOMP Continue to rig up lines to wellhead and tiger tank. Fill pits DECOMP Circulate well through tubing. Pump rate 4.5 bpm, tubing pressure 800psi, IA pressure 120psi. Pumped 555 bbls (1.7 times hole volume). Returns were gas to gas and crude (returns never cleaned up during circulation). DECOMP Blow down lines to tiger tank. RU to bullhead down IA. DECOMP Bullhead 267 bbls fluid down IA. Pump rate 4 bpm, tubing pressure 400psi, IA pressure 600psi. DECOMP Shut down and monitor well. Pressures on tubing and IA Opsi/Opsi. DECOMP Continue to monitor well DECOMP Set TWC. Test TWC from above to 3500psi for 10 charted minutes. Test from below by pumping 3bpm down backside. Able to reach 180psi for 12 bbl total. Charted test. DECOMP Bleed void and ND tree. DECOMP N/U BOPE DECOMP Prep to Test BOPE. Conduct full test on BOPE. AOGCC rep Chuck Scheve waived witnessing the test. Test witnessed by Nabors Tool Pusher and BP Well Site Leader. No failures. DECOMP PJSM. P/U lubricator, test to 1000 psi, OK. Pull Two way check valve, OK. UD lubricator. DECOMP PJSM. Shoot fluid level, fluid level @ 3300'. DECOMP P/U & M/U 2 7/8" landing jt. Screw into hanger. BOLDS. Pulled free w/ 82K. Pull hanger to floor w/ 80K. L/D hanger & landing 11:30 - 12:00 0.50 PULL P DECOMP Circulate tubing volume. 4.2 BPM @ 90 psi, pumped 50 bbls. 12:00 -15:00 3.00 PULL P DECOMP POOH w/ W/ ESP completion to 4500' Stand back 2 7/8" tubing. 15:00 - 15:30 0.50 PULL P DECOMP Change out reel in spooling unit. 15:30 - 20:00 4.50 PULL P DECOMP Con't to POOH w/ ESP completion. Stand back 2 7/8" tubing. 20:00 - 23:00 3.00 PULL P DECOMP Drain & UD out ESP. Motor locked up & lead burned. 23:00 - 00:00 1.00 CLEAN N WAIT DECOMP S/D operations due to high winds. Gusts to 71 mph. 12/4/2007 00:00 - 10:00 10.00 CLEAN N WAIT DECOMP Suspended operations due to high winds. Clean, paint & maintain rig. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. Make up Depck bailer assembly in conjunction w/ 2 7/8" tubing as per Baker Rep. (see BHA tab). 12:00 - 15:30 3.50 CLEAN P DECOMP PJSM. RIH w /Depck bailer on 2 7/8" tubing. Went thru liner top @ 8828', OK. Up wt 63K, down wt 40K. 15:30 - 17:30 2.00 CLEAN P DECOMP Continue in hole, tag @ 9451', 15' in on Jt # 303, this includes the tubing in the BHA. Cleanout to 9530'. Do this by setting down on fill w/ 5 - 10K WOB, taking initially 10' - 15' bites & picking up several times to ensure clean pickups, but observing Printed: 12/19/2007 2:22:49 PM ~ s gp Page 2 of 2 Operations Summary Report Legal Well Name: MPL-43 Common Well Name: MPL-43 Spud Date: 1/6/2004 Event Name: WORKOVER Start: 11/30/2007 End: 12/6/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/6/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/4/2007 15:30 - 17:30 2.00 CLEAN P DECOMP overpulls once we got below the bottom perfs @ 9469'. Take a few 10' bites and see some overpulling to 120K, so take 5' bites. Made it OK to 9530' and call 'er goooood. 17:30 - 22:30 5.00 CLEAN P DECOMP PJSM POH from 9530 to lower drain sub @787' 22:30 - 00:00 1.50 CLEAN P DECOMP PJSM with Baker Rep. LD 18 jts full of fluid and 7 jts + 5' of sand (100% sand recovery ) 12/5/2007 00:00 - 01:00 1.00 CLEAN P DECOMP con't LD sand filled 2 7/8" jts. Photos. can be found on 'S' Drive that will be used for new Bailing procedure. 01:00 - 03:00 2.00 CLEAN P DECOMP Clean rig floor and remove drums with sand from floor. 03:00 - 04:00 1.00 CLEAN P DECOMP PU 27 jts 27/8 tbg RIH & flush w/rig pump 04:00 - 04:30 0.50 CLEAN P DECOMP POH 9 std 04:30 - 06:00 1.50 RUNCO RUNCMP RU to run ESP 06:00 - 06:30 0.50 RUNCO RUNCMP Service rig, check PVT system, crown o matic, OK. 06:30 - 10:30 4.00 RUNCO RUNCMP PJSM. Pick up ESP assembly, attach cable, test same. 10:30 - 15:00 4.50 RUNCO RUNCMP PJSM. RIH w/ ESP assembly on 2 7/8" EUE 8 rnd tubing, torquing tubing connections to 2300 ft/Ibs. We test the cable after running in the hole every 2000' and pump down the tubing @ 1/2 bpm / 1900 psi to clear the motor, also every 2000'. 15:00 - 18:30 3.50 RUNCO RUNCMP PJSM. Change reels, make cable to cable splice, 76 stands in the hole, (7400'). 18:30 - 20:00 1.50 RUNCO RUNCMP Con't RIH (2 flatguards, 5 protectolizers and 147 IaSalle clamps) up wt =82k DN wt =46k 20:00 - 22:00 2.00 RUNCO RUNCMP PU landing jts, MU tbg hanger, install penetrator & attach field conn. plug in & test 22:00 - 22:30 0.50 RUNCO RUNCMP Land tbg.hanger, RILDS,LD landing jts. 22:30 - 23:00 0.50 RUNCO RUNCMP Install TWC, Test from above 1000 psi charted for 10 min. 3 bpm @ 50 psi Blow Dn lines. 23:00 - 00:00 1.00 RUNCO RUNCMP PJSM ND BOPE 12/6/2007 00:00 - 00:30 0.50 BOPSU P RUNCMP Continued ND ROPE. 00:30 - 03:00 2.50 WHSUR P RUNCMP NU tree. MP L-Pad operator declined to verify tree orientation. Tested tree and void space to 5000 psi. Made final ESP check. 03:00 - 04:00 1.00 WHSUR P RUNCMP RU lubricator and tested to 500 psi. Pulled and LD TWC. RD lubricator. Set BPV. Secured tree and cellar. Released rig @ 04:00 hrs, 12/6/2007. Printed: 12/19/2007 2:22:49 PM ) ) WELL LOG TRANSMITTAL fJO.J'· ~'é}~ To: State of Alaska Alaska Oil and Gas Conservation Cornn1. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 '()5(:)/t RE: MWD Formation Evaluation Logs MPL-43 + PB 1, The technical data listed below is being subnlitted herewith. Please address any problems or concerns to the attention of: Rob I(alish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPL-43 +PBl: SCANNED MP\H 0 ~~ 2.000 LAS Data & Digital Log Images: 50-029-23190-00, 70 1 CD Ronl ~ì 2/99"liD Permit to Drill 2032240 MD 9645 ~ REQUIRED INFORMATION 16 ñb DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Well Name/No. MILNE PT UNIT KR L-43 Operator BP EXPLORATION (ALASKA) INC TVD 7484 /' Completion Date 1/16/2004. Completion Status SUSP Current Status 1-01L SI! ~ to Jù~ ÀJJ~ f-l API No. 50-029-23190-00-00 UIC N Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, I FRlCASANDRA, RES, PWD, CCL Well Log Information: Log/ Electr Data Digital Dataset TypyMed/Frmt Number Name f'r=Ó D Asc Directional Survey ¡ Rpt i(ED ¡/ ...../ED ! RPj i ~pt . ! ,0/ ~D D Asc 12411 o Ase 12411 1 !l ¡ ,- ~ vtV\JP~ D Pdf D Pdf : Rpt ¡ Rpt J-r=fi i Rpt -~ ¡ED ¡ Rpt o Asc o Asc yo , Rpt iJ:Q.g o Asc (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 6047 9645 7/16/2004 IIFR IIFR GR, EWR4, ROP GR, EWR4, ROP GR, EWR4, ROP GR, EWR4, ROP Log Log Run Scale Media No Directional Survey I nd uction/Resistivity Rate of Penetration I nd uction/Resistivity Rate of Penetration Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Pressure 7/16/2004 1-3 67 9254 2/19/2004 1-3 67 9254 2/19/2004 1-3 67 9254 2/19/2004 1-3 67 9254 2/19/2004 0 9306 2/26/2004 0 9306 2/26/2004 0 9306 2/26/2004 0 9306 2/26/2004 6047 9645 7/16/2004 6047 9645 7/16/2004 0 9306 7/16/2004 0 9306 7/16/2004 0 9306 7/16/2004 0 9306 7/16/2004 5 Blu 9300 9500 Case 7/21/2004 WD Tap 12682 Gamma Ray Pt>f 67 9260 9/28/2004 I Rpt D Tap LIS Verification 67 9260 9/28/2004 --- MWD MWD MWD MWD IIFR PB1 IIFR PB1 MWD PB1 MWD PB1 BOTTOMHOLE PRESSURE SURVEY/GRlCCUPRESS/ TEMP GR, EWR4, ROP, ACAL, PWD GR, EWR4, ROP, ACAL, PWD, DSN 12682 "-'. DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2032240 Well Name/No. MILNE PT UNIT KR L-43 MD 9645 TVD 7484 Completion Date 1/16/2004 'kf:)- -,- C Pds 1"'12750 Gamma Ray ~ D Tap 12787 I nd uction/Resistivity ~ 12787 LIS Verification Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFOR~. ,ION Well Cored? r /v Chips Received? Y I N Analysis Received? Y I N-- Comments: Compliance Reviewed By: i z, Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23190-00-00 Completion Status SUSP Current Status 1-01L UIC N -----, 0 9562 1 0/15/2004 LDWG GR, CCl TENS I 67 9601 Open 10/20/2004 MWD/PWD/GRlEWR4/RO P 67 9601 Open 10/20/2004 MWD/PWD/GRlEWR4/RO P Sample -~-- Set Sent Received Number Comments Daily History Received? &: Formation Tops Date: r~ f~;¿~fo ~>, ( ~o 3 -72 c¡; " (t WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 24, 2004 RE: MWD Formation Evaluation Logs MPL-43, AK-MW-2851292 1 LIS fonnatted Disc with verification listing. API#: 50-029-23190-00 ) Þ 78"7 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 HP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: /f-ff ~~ R C IVED OCT 2 0 2004- AJaska 00 & Gas Cons. Commiæitm .Anmorage ( 070 3~¿ ¿~ RECE1VEI......¡ , .£>~ ~. oWHP § 4 t ~I' (. ( sr:-O ? n 0'10 ¡J .J".! _. U LL )L~ WELL LOG TRANSMIITAL i~I··\:!!t..b I"~I ," G C 1 "¡; ,~r.\~A ¡".}jr (í . as ons. Cûmfili58iOf! ßtnr;h¡jm~e ;1 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 22, 2004 RE: MWD Fonnation Evaluation Logs .MPL-43 PBI, AT(-MW-285129 1 LIS formatted Disc with verification listing. API#: 50-029-23190-70 1 :L, Co~1- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO TH.E ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: /oj'f(Oc/ Si~Jf-~~ , ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS SEP ~ 3 ?OQA Stimulate ŒJ AlañtaeOO:::& Gas Cons. Comm;s! WaiverD Time Extension 0 Anchorage Re-enter Suspended Well 0 Repair WellO Pull Tubing D Operation Shutdown D Pluç PerforationsD Perforate New Pool D Perforate D 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 50.80 8. Property Designation: ADL-025509 11. Present Well Condition Summary: Total Depth measured 9306 feet true vertical 7146.6 feet Effective Depth measured 6077 feet true vertical 4425.9 feet Stratigraphic D 9. Well Name and Number: MPL-43 5. Permit to Drill Number: ExploratoryD 203-2240 6. API Number Service D 50-029-23190-00-00 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development ]] 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk River Oil Pool, Milne Point Unit Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse Conductor 78 20" 94# H-40 34 112 34.0 112.0 1530 520 Liner 816 4-1/2" 12.6# L-80 8828 - 9644 6684.7 - 7482.8 8430 7500 Production 8835 7" 26# N-80 33 - 8868 33.0 - 6722.4 7240 5410 Production 53 7" 26# L-80 8868 - 8921 6722.4 - 6772.3 7240 5410 Surface 6062 9-5/8" 40# L-80 35 - 6097 35.0 - 4438.9 5750 3090 Perforation decth: Measured depth: 9312 - 9332,9394 - 9414,9415 - 9435,9449 - 9469 True vertical depth: 7152.53 -7172.37, 7233.95 -7253.84, 7254.83 - 7274.73, 7288.67 -7308.57 Tubing ( size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 30 8711 Packers & SSSV (type & measured depth): 4-1/2" Baker ZXP Packer @ 8835 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9312 - 9469 Treatment descriptions including volumes used and final pressure: 907 Bbls YF130LGw/2, 296 Bbls WF120, 172K 16/20 Carbolite @ 3440 psig Representative Daily Average Production or Injection Data Gas-Mef I Water-Bbl Casing Pressure Well not prior produced 3700 0.3 I 233 3700 13 Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 932 ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: Oil [!] Gas D DevelopmentŒ) Service D 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations. WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J:1, ~ Title Production Technical Assistant Signature Phone 564-4657 Date 9/21/04 ORIG\NAL RBONS BFL. SEP 2 "i Form 1 0-404 Revised 4/2004 ~ . (' f MPL-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07105/04 MIRU OS Frac equipment. Datafrac wI 150 bbls YF130LG at 10 bpm, followed by 154 bbls WF120 at 25 bpm. ISIP 1625 psi. Redesign Frac treatment. Pump frac at 25 bpm as follows: 175 bbls pad, 21 bbls 1 #, 22 bbls 2#, 23 bbls 3#, 24 bbls 4#, 25 bbls 5#, 95 bbls 6#, 98 bbls 7#, 135 bbls 8#, 140 bbls 9#, 178 bbls 10#. Displace with 138 bbls slickwater (slipstreamed 30 bbls diesel in flush). Underdisplaced by 5 bbls. 170,500#'s 16/20 CL behind pipe. Max treating psi of 4332 psi, max rate of 25 bpm, and max sand concentration of 10.2 #/gal. BBLS 1200 907 296 172,000 1 18 7 174429 FLUIDS PUMPED Fresh Water YF130LGw/2 W F120 Lbs 16/20 Carbolite L064 J877 J476 TOTAL Page 1 i ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 50.80 8. Property Designation: ADL-025509 11. Present Well Condition Summary: Total Depth measured 9306 feet true vertical 7146.6 feet Effective Depth measured 6077 feet true vertical 4425.9 feet 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 Casing Conductor Liner Production Production Surface Length 78 816 8835 53 6062 Perforation depth: Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate ŒJ Stimulate 0 OtherO WaiverD Time Extension 0 Re-enter Suspended Well 0 4. Current Well Class: Development ŒJ 5. Permit to Drill Number: 203-2240 6. API Number 50-029-23190-00-00 ExploratoryD Service D StratigraphicD 9. Well Name and Number: MPL-43 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit Plugs (measured) Junk (measured) None None Size 20" 94# H-40 4-1/2" 12.6# L-80 7" 26# N-80 7" 26# L-80 9-5/8" 40# L-80 MD TVD Burst Collapse 34 112 34.0 112.0 1530 520 8828 - 9644 6684.7 - 7482.8 8430 7500 33 - 8868 33.0 - 6722.4 7240 5410 8868 - 8921 6722.4 - 6772.3 7240 5410 35 - 6097 35.0 - 4438.9 5750 3090 4-1/2" 12.6# L-80 @ RI2C€1 6: ~:,~?() .. ~~~ lO¡l & G c:AJ4 ~r- )iI ~,4}\""Q:\> ("...... 1Y1J. , .. ""'1J tJ~~. ''''t!Jðìl'#f!y,'. . ~~ ~~ Measured depth: 9312 - 9332,9394 - 9414,9415 - 9435,9449 - 9469 D True vertical depth: 7152.53 -7172.37, 7233.95 -7253.84, 7254.83 -7274.73,7288.67 -7308.57 Tubing ( size, grade, and measured depth): 30 8838 Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef I Water-Bbl I Casing Pressure I New Well 233 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ßqG~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations. Signature Form 10-404 Revised 4/2004 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" Baker ZXP Packer @ @ 8802 8835 Oil-Bbl Tubing Pressure 932 0.3 o x 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Development ŒI ServiceD Title Production Technical Assistant Phone 564-4657 9/7/04 Date ORIGINAL RBDUS BFl SEP 1 3 20U~: ( (" MPL-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/30/04 (VERIFY PERFORATIONS ARE OPEN) PUMPED 6.4 BBLS DIESEL DOWN TUBING AT 3000 PSI (MAX PRESSURE) AND 0.25 BPM IWHP=O/O/O. FWHP=1600/0/0 06/30/04 PERFORATED 9449'-9469' AND 9415'·9435' MD (REF. SCHLUMBERGER PDC GR/CCL LOG DATED 29-JUNE-04) IN TWO RUNS OF 'BIG HOLE1 CHARGES. GOT SBHP READINGS BETWEEN THE FIRST AND SECOND GUN RUNS, AND THEN AFTER THE SECOND GUN RUN. AFTER FIRING THE FIRST GUNS (94491-9469') WE RAN IN HOLE WITH THE SBHP GAUGES AND GOT A BHP OF 3092 PSI. DECIDED TO PUMP 10 BBLS OF DIESEL TO BREAK DOWN PERFS TO ASSURE WE ARE COMMUNICATED WITH THE FORMATION. AFTER PUMPING THE DIESEL THE GAUGES WERE LEFT AT MID- PERF FOR ANOTHER 2 HOURS. AFTER THE SECOND GUN RUN (9415'-9435') A SBHP GAUGE WAS RUN AND LEFT ON BOTTOM FOR 2 HOURS. NO PROBLEMS RIH OR POOH. TAGGED TO ON FIRST RIH AT 95621 MD. FLUIDS PUMPED BBLS 11 Diesel 11 TOTAL Page 1 ~' Tree: 29/16" - 5M CIW t Wellhead: 11" 5M FMC ~ .. 5a wI 2-7/S" FMC Tbg. Hng. 2-7/8" Top & 8tm hanger trd. 2.5" "H" BPV profile ~ 20" 91.1' #t H-40 112' I top and btm., 2.5"CIW 9 5/8" 40# L-80 BTRC casing I I Sidetrack on Whipstock at 9340' 6097''' KOP @ 200' Max. hole angle = 540 @ 4700' Angle @ SSD = 200 Hole angle @ perfs = 60 2-7/S" 6.5 ppf, L-SO, Srd EUE tbg. ( drift ID = 2.347", cap. = .00579 bpf) 7" 26# L-80 BTRC-Mod casing (drift ID = 6.151", cap = 0.0382 bpf) Perforation Summary Ref log: Tied Jewelry log into Size SPF Interval (TVD) 7,250' - 7,270' 7,2S4' - 7,304' 3-3/S" 12 9,415' - 9,435' 27/S" 6 9,449' - 9,469' 3-3/S" HS 3412 Powerflow HMX guns 2-7/S" HSD, 3SC CP Big Hole guns Size SPF Interval (TVD) 33/S" 6 9,312'-9,332' 7,152'-7,172' 3 3/S" 6 9,394' - 9,414' 7,233' - 7,253' 3-3/8" PJ 3406 HMX, 6 SPF HSD DATE REV. BY 6/26/04 8/13/04 MPL-43 f/Æ ~ COMMENTS Lee Hulme Drill and Complete by Doyon 14 MDO Pulled frac string run ESP 4-ES ( '(B elev. = 50.30' (Doyon 14) FIT - Tbg Hgr elev = 16.3' ~ Camco 2-7/8" x 1" KBMG GLM ~ Camco 2-7/8" x1" sidepocket KBM M G LM XN- Nipple - 2.313" landing profile, 2.205" NO-GO Centrilift GC 1700 ESP series 513, GPMTAR 1:1 151 stages Centrilift Tandem Gas Separator GRSFTXARH6 Centrilift Tandem seal section GSB3DBUT/ILH6PFS GSB3DBL T Centrilift KMH 562 series 190 hp motor, 2415 / 48 amps Phoenix multi-sensor ~ Baker Tie Back Sleeve ~ Baker 'ZXP' Liner Top Pkr ~ Baker Flex Lock Liner Hgr ~ ... 7" PESI Float Collar (PBTD) 7" PESI Float Shoe 4.5" Landing collar (PBTD) 9559' 4.5 n 12.6#, L-80 float shoe 9645' 1138' I I 8,555' I I 8,666' I 8,711' 8,729' 8,734' 8,748' 8,769' 18868' 18953' MILNE POINT UNIT WELL MPL-43 API NO: 50-019-'3190-00 BP EXPLORATION (AK) " ( , STATE OF ALASKA ( ALASKAvlL AND GAS CONSERVATION COMMI~SION DECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LOci " SEP - 3 2004 1a. Well Status: iii Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 21. Logs Run: MWD, GR, IFR/CASANDRA, RES, PWD, CCL CASING, LINER AND CEMENTING RECORD ":$Ert!Ki«,¡i'~~' M¡J',II"'>n "" ISi=rl' Mr..,"I;:II:,cn:b'::11Inl"'I":'IIü.li,II' ':""'1" ',,' ."'" ., ' '. .." : '.'.. '. "'. ",... I~. . I, !J:,"I'i.'.'I.":~ ~'. .' ilV!. ,\":I:, II:, :'.",' .''''.' . . ., ", " :'~,~.'. "~ ~. i~~ "/', ,1'':1, "" ,!-Ii ",i, ," "1 ,i. ':". [!9. L;e I :' "'Ii I': .: I "I I' ' /1 'I ,II I, III: : I , , I " I ¡: ,I 'I " ' I;' II I I I ~ I, 1·1 ~ i' I' ,; I '" I " I' I, I'" ~ II,II~ 'I, I', I , I ,; , I I ": I ¡': ' ,I : I, ': ",II,TO!?,"",I", 'I ,o-:rmOM" :"",I""mCp, 'III" ,B~;J)IJ'ØNl" :I'I",II"S,IZ~I':,:II:", 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 35' 6097' 35' 4391' 12-1/4" 250 sx Class 'L', 225 sx Class 'G' 33' 8953' 33' 6803' 8-3/4" 106 sx Class 'G' 8828' 9645' 6685' 7484' 6-1/8" 122 sx Class 'G' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3636' NSL, 5040' WEL, SEC. 08, T13N, R10E, UM Top of Productive Horizon: 3718' NSL, 336' WEL, SEC. 06, T13N, R10E, UM Total Depth: 3751' NSL, 342' WEL, SEC. 06, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 544838 y- 6031825 Zone- ASP4 TPI: x- 544208 y- 6037195 Zone- ASP4 Total Depth: x- 544204 y- 6037216 Zone- ASP4 18. Directional Survey iii Yes 0 No 22. 20" 9-5/8" 92# 40# 26# 12.6# H-40 L-80 L-80 L-80 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-3/8" Gun Diameter, 12 SPF 2-7/8" Gun Diameter, 6 SPF MD TVD MD TVD ,,' 9415' - 9435' 7255' - 7275' 9449' - 9469' 7289' - 7309' 3-3/8" GD. 6 SPF 3-3/8" GD. 6 SPF 9312' - 9332' 9394' - 9414' 27. \ \ 10407 Revised 12/2003 One Other 5. Date Comp., Susp., or Aband. 6/30/2004 .. 6. Date Spudded 1/6/2004 ./ 7. Date T. D. Reached 6/21/2004 8. KB Elevation (ft): KBE = 50.80' 9. Plug Back Depth (MD+ TVD) 9531' + 7370' 10. Total Depth (MD+TVD) 9645' + 7484' 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL ./ 1ßA~~i~WI8:'6:as Cons. Commission ~.. Dev~loP'!l~ :Jh oQ,.¡¡xpl<?ratory o StratlgrafWIn~ ~ervlce 12. Permit to Drill Number 203-224 304-183 13. API Number 50- 029-23190-00-00 14. Well Name and Number: MPL-43 15. Field I Pool(s): Milne Point Unit / Kuparuk River Sands Ft Ft 16. Property Designation: ADL 025509 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) "'I"ð;Mr"l0NjJ:'i I":I~I"I~:,"I, ",,',1, ¡li'¡'II;RI:J~L.ED'I' , SIZE 4-1/2" 6.5#, L-80 PACKER SET (MD) ,i DEPTH SET (MD) 8771' DEPTH INTERVAL (MD) 9415' - 9469' AMOUNT & KIND OF MATERIAL USED Frac'd placed 170500 #'s of 16/20 C-Lite behind GAs-McF 46 W A TER-BsL 66 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 12, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BsL 8/30/2004 6 TEST PERIOD + 203 Flow Tubing Casing Pressure CALCULATED ........ OIL-BSL Press. 24-HoUR RATE"'" 814 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"" .....,."..,...."..,,) \ C::::'I.!,. ,,:::.;":C\] I, None, ¡", , c.t} ~ ···..~;~~i~··9;·Í~ .:¡ 0 R I G I N A L ~ ......-..Jþ.. ~~: ;: a! 1,.." ."""",,,,"rl·''-'''''''''~· GAs-McF 185 W A TER-BsL 263 CONTINUED ON REVERSE SIDE CHOKE SIZE GAS-OIL RATIO 227 OIL GRAVITY-API (CORR) Bfl, SEf> 2 ~~ ¡mv\ (,p G · . A \ GEOLOGIC MARKERS { , 28. 29. (' NAME MD FORMATION TESTS TVO Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". THRZ BHRZ KLGM TKUD TKUC TKU8 TKUA TKA3 TKA2 TKA1 TMlV 8847' 8907' 8980' 9144' 9308' 9322' 9389' 9396' 9413' 9443' 9495' 6703' 6759' 6828' 6987' 7149' 7162' 7229' 7236' 7253' 7283' 7334' None RECEIVED SEP. ~ 3 2004 Alaska Oil 8& GI. Cons, Commission Anchorage 30. list of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and a Wellbore Schematic. 31. I hereby certify that the foregoing is true and correct to !he best of my knowledge. Signed 5ond~. _ Title Technical Assistant Date g _ 0'-- -O~ MPl-43 203-224 304-183 P,._ By NalTlQ/Number.' SonrJra Stewman, 564-4750 Well Number Permit No.1 ApProval No. DriHingEngine.,., Walter Quay, 564-4178 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. ITEM1a: Classification of Service Wells: Gas Injection, Water Injecüon, Water-Alternating-Gas Injection, Sail 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. Eadl segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly BUshing elevation in feet above mean /ow 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: 5Q..029-20123-OO_OO). 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. ,- 23: If this well is completed for separate production from more than one interval (mulöple completion), so state in item 1, and in item 23 show the Producing intervats for only the interval reported in item 26. (Submit a separate fonn for each additionat interval to be separately Produced, shoWing the data pertinent to such interval). ITEM 26: Method of Operation: FtoWing, 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 o q I ~ 1~I,4 L Submit Original Only , ' Tree: 29/16" - 5M CIW " MPL-43 Wellhead: 11" 5M FMC d: 5a wI 2-7/S" FMC Tbg. Hng. I 2-7/S" Top & Btm hanger trd. I .- 2.5" "H" BPV profile I I ... ~ I I 112' I I 20" 91.1 '#t H-40 I I I I top and btm., I I 2.5" CIW I I I I I I 95/8" 40# L-80 BTRC casing I 16097' I ~ I Sidetrack on Whipstock at 9340' .- ... I I I I I KOP @ 200' Max. hole angle = 540 @ 4700' Angle @ SSD = 200 Hole angle @ perfs = 60 2-7/8" 6.5 ppt, L-SO, Srd EUE tbg. ( drift ID = 2.347", cap. = .00579 bpf) 7" 26# L-SO BTRC-Mod casing (drift 10 = 6.151", cap = 0.0382 bpf) ~ Perforation Summary Ref log: Tied Jewelry log into Size SPF Interval 3-3/8" 12 9,415' - 9,435' 27/8" 6 9,449' - 9,469' (TVD) 7,250' - 7,270' 7,284' - 7,304' ~ 3-3/8" HS 3412 Powerflow HMX guns 2-7/8" HSD, 38C CP Big Hole guns Size SPF Interval (TVD) 33/8" 6 9,312'-9,332' 7,152'-7,172' 33/8" 6 9,394' - 9,414' 7,233' - 7,253' 3-3/8" PJ 3406 HMX, 6 SPF HSO DATE REV. BY COMMENTS 6/26/04 8/13/04 Lee Hulme Drill and Complete by Doyon 14 MDO Pulled frac string run ESP 4-ES t.· '(8 elev. = 50.30' (Doyon 14) , IT - Tbg Hgr elev = 16.3' Camco 2-7/8" x 1" KBMG GLM Cameo 2-7/8" x1" sidepoeket KBMM GLM XN- Nipple - 2.313" landing profile, 2.205" NO-GO Centrilift GC1700 ESP series 513, GPMTAR 1:1 151 stages Centrilift Tandem Gas Separator I GRSFTXARH6 Centrilift Tandem seal section GSB30BUT/ILH6PFS GSB30BLT Centrilift KMH 562 series 190 hp motor, 24 '15 / 48 amps Phoenix multi-sensor ~ Baker Tie Back Sleeve ~ Baker 'ZXP' Liner Top Pkr ~ Baker Flex Lock Liner Hgr ~ ... 7" PES I Float Collar (PBTD) 7" PESI Float Shoe 1138' I I 8,555' I I 8,666' 1 8,711' 8,729' 8,734' 8,748' 8,769' 18868' 18953' 4.5" Landing collar (PBTD) I 9559' 4.5" 12.6#, L-80 float shoe I 9645' I MILNE POINT UNIT WELL MPL-43 API NO: 50-029-23190-00 BP EXPLORATION (AK) 4" ( ( BP Page 1 of 14 Operations Summary Report Legal Well Name: MPL-43 Common Well Name: MPL-43 Spud Date: 1/6/2004 Event Name: DRILL+COMPLETE Start: 1/5/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/26/2004 Rig Name: DOYON 14 Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 1/5/2004 00:00 - 00:30 0.50 MOB P PRE Skid rig floor from drlg position to move position 00:30 - 01 :00 0.50 MOB P PRE Move rig off MPF-88 01 :00 - 02:00 1.00 MOB P PRE Move rig from MPF-Pad to MPL-Pad 02:00 - 03:30 1.50 MOB P PRE Move rig onto MPL-43 - Shim rig 03:30 - 04:00 0.50 MOB P PRE Skid rig floor from move position to drlg position - 04:00 - 07:00 3.00 MOB P PRE Spot and berm rockwasher - Rig up service lines to rig floor - Connect Top Drive electrical lines - Prepare pipe shed to recieve drill pipe (Accept rig at 07:00 hrs) 07:00 - 10:30 3.50 RIGU P PRE Nipple up divertor - Riser - Flowline - Hole fill lines - Load 5" Drill pipe in pipe shed 10:30 - 00:00 13.50 DRILL P SURF Pick up 5" drill pipe from pipe shed - make up in mouse hole - Due to ice plug in conductor pipe at 45' deep which caused more time picking up - stand back in derrick - Total 94 stands - (MPU went to phase 3 driving conditions @ 21:15 hrs) 1/6/2004 00:00 - 01 :30 1.50 DRILL P SURF Pick up 5" HWT - Stand back in derrick 01 :30 - 02:00 0.50 DRILL P SURF Clear rig floor 02:00 - 04:00 2.00 DRILL P SURF Change out saver sub from 4" HT -38 to 4 1/2" IF 04:00 - 04:30 0.50 DRILL P SURF Pre Spud meeting with all personnel - 04:30 - 05:30 1.00 RIGU P PRE Function test Divertor I Accumulator test, the right to witness test was wavier by Lou Grimaldi AOOGC 05:30 - 06:00 0.50 DRILL P SURF Pick up motor - make up bit - fill stack check for leaks, R/U wire line unit 06:00 - 06:30 0.50 DRILL P SURF Spud well @ 06:001/6/2004, Drilling from 112 to 131' 06:30 - 08:00 1.50 DRILL P SURF Picking up MWD,Flex des. 08:00 - 00:00 16.00 DRILL P SURF Directional drill 131 to 2,229' run gyro @ 182', 80 rpms 500 gals per min 1650 psi, AST 6.25, ART 4.08 1/7/2004 00:00 - 05:30 5.50 DRILL P SURF Directional drill 2,229' to 3050' 80 rpms 500 gals per min 1650 psi, 05:00 - 07:00 2.00 DRILL P SURF Circ, Three bottoms up 07:00 - 09:00 2.00 DRILL P SURF Pump out to HWDP with full drilling rate 09:00 - 10:00 1.00 DRILL P SURF Stand back BHA 10:00 - 11 :30 1.50 DRILL P SURF Pickup new bit, reset bend on motor to 1.22, trip in with Bha 11 :30 - 12:30 1.00 DRILL P SURF Trip to bottom, washed 60 ft to bottom 12:30 - 21 :30 9.00 DRILL P SURF Directional drill 3050' to 4549' 120 rpms 500 gals per min 2000 psi, AST .5 ART 6.08 21 :30 - 23:30 2.00 DRILL P SURF Circ, three bottoms up, 500 gals min. 1800 psi, 120 rpms 23:30 - 00:00 0.50 DRILL P SURF Pumping out to HWDP with full drilling rate 1/8/2004 00:00 - 02:30 2.50 DRILL P SURF Finish pumping out to HWDP, no problems 02:30 - 04:00 1.50 DRILL P SURF Trip to bottom, wash 60 ft to bottom 04:00 - 17:00 13.00 DRILL P SURF Directional drill 4549' to 6106' TD 120 rpms 500 gals per min 2080 psi AST 1.75 ART 6 17:00 - 19:00 2.00 CASE P SURF Circ Two bottoms up with 120 rpms 500 gals min, 1700 psi 19:00 - 23:30 4.50 CASE P SURF Pump out to HWP, with full drilling rate, no problems 23:30 - 00:00 0.50 CASE P SURF Trip to bottom 1/9/2004 00:00 - 01 :30 1.50 CASE P SURF Finish trip to bottom washed 60 f1. 01 :30 - 03:30 2.00 CASE P SURF Circ two bottoms up with 120 rpms, 500 gals per min., 1700 psi 03:30 - 09:30 6.00 CASE P SURF Slug pipe, Tripping out 09:30 - 10:30 1.00 CASE P SURF Rig up to run 9 5/8 csg 10:30 - 17:30 7.00 CASE P SURF PJSM, picking up 9 5/8 40# L-80 Btc csg 147 jts 6052' , shoe @ 6097', float collar 6052', landing collar 6010, ES cementer 1927' SO wt 150K 17:30 - 18:00 0.50 CASE P SURF Rig down Franks tool, Rig up cement head Printed: 6/29/2004 10: 15:53 AM to, ( (" BP Operations Summary Report Page 2 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 M PL -43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From - To Hours Task Code NPT Phase Descriptiortof Operations 1/9/2004 18:00 - 20:30 2.50 CASE P SURF Circ. and thin mud for cement job 9 bbls min 370 psi, no losses 20:30 - 23:00 2.50 CEMT P SURF Cement with Schlumberger, with 10bbls water,test lines to 4,000,15 bbls CW 100, mixed and pumped 40 bbls mud push mixed @ 10.2, drop bottom plug, load top plug, mixed and pumped 250 sxs. Artie set light, yield 4.45, 198 bbls mixed @ 1 0.7,tailed wI 225 sxs Class G yield 1.1646 bbls mixed @ 15.8, kicked out top plug with 30 bbls water, swap over to rig displace with 274 bbls mud,75 bbls water,follow with 72 bbls mud, displace @ 9 bbls min. 800 psi, bump plug with 1800 psi, float held, mud/cement interface @ surface last ten bbls of displacement 23:00 - 00:00 1.00 CEMT P SURF Load closing plug in head, open ES cementer with 2,300 psi, circ contaminated mud and cement out, 70 bbls good cement to surface 1/10/2004 00:00 - 01 :30 1 .50 CEMT P SURF Circ and condition mud for cement stage 2 01 :30 - 03:00 1.50 CEMT P SURF Cement with Schlumberger with 10 bbls water,test lines to 4000psi, 15 bbls CW 100, 45 bbls Mud push mixed @ 10.2, with 2 gals dye in spacer, mixed and pumped 215 sxs, 170 bbls Arctic set light mixed @ 10.7 6 bbls min 300 psi, Dye @ surface, kicked out closing plug with 30 bbls water, displace with rig with 116 bbls mud 6 bbls min 350 psi, close ES cementer with 1500 psi, checked for flow back tool closed, 100 bbls good cement to surface 03:00 - 05:30 2.50 CEMT P SURF Flush diverter system with water,Lay down landing jt, 05:30 - 07:00 1.50 CEMT P SURF Nipple down diverter 07:00 - 08:30 1.50 CASE P SURF M/U Speed head, Energize metal to metal seal, Test to 1,000 psi f/ 10 min. 08:30 - 10:30 2.00 CASE P SURF Nipple up BOPS 10:30 - 16:00 5.50 CASE P SURF Rig up and test BOPS and manifold to 250-3500 psi for 5 min. per test, hydrill 250-2500 psi for 5 min. per test, the test was witness by Jeff Jones w/ AOOGC, install wear ring 16:00 - 19:00 3.00 CASE P SURF Change Elevators and bails, Picking up BHA # 3, bit 8 3/4 Hcm 605 PDC with 5 14 jets, 7" sperry drill 1.22 bend,stab,float sub, 6 3/4 GR/RES/PWD, 6314 DM, hang off sub,6 3/4 ACAL,stab,3 flex DC,stab, 12 HWDP, jars,5 HWDP, 15 dril pipe,Ghost reamer 19:00 - 19:30 0.50 CASE P SURF Trip in to 1927 19:30 - 20:30 1.00 CEMT P SURF Drill ES cemnter @ 1927 with 400 gals min 500 psi, 60 rps, 5-8K bit wt. 20:30 - 22:00 1.50 CASE P SURF Trip in to 5924 22:00 - 23:30 1.50 CASE P SURF Cut and slip drilling line, service top drive 23:30 - 00:00 0.50 CASE P SURF Test csg to 2500 psi for 30 min. good test 1/11/2004 00:00 - 01 :00 1.00 CASE P SURF Finish Csg test 2500 psi for 30 min. 01 :00 - 02:00 1.00 CEMT P SURF Drill landing collar, float and shoe, drill new hole to 6126' 02:00 - 03:00 1.00 CASE P SURF Circ and displace hole with 8.4 new LSND mud 03:00 - 03:30 0.50 CASE P SURF FIT test with 8.4 mud, 830 psi, 4438 TVD, = EMW 12.0, good test 03:30 - 10:30 7.00 DRILL P INT1 Directional drill 6126' to 7190" 120 rpms 625 gals per min 2000 psi, 10:30 - 11 :00 0.50 DRILL P INT1 Circ change shaker screens, losing to much mud 11 :00 - 14:30 3.50 DRILL P INT1 Directional drill 7190' to 7705' 120 rpms 625 gals per min 2000 psi" losing mud over shakers, start angle drop from 50 degrees Printed: 6/29/2004 10: 15:53 AM ( ( BP Operations Summary Report Page 3 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PL -43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2004 14:30 - 15:30 1.00 DRILL P INT1 Circ change shaker screens, from 180 to 80s, losing to much mud 15:30 - 17:30 2.00 DRILL P INT1 Directional drill 7705' to 7990' 120 rpms 625 gals per min 2000 psi" losing mud over shakers 17:30 - 18:30 1.00 DRILL P INT1 Circ change shaker screens, from 80s to 200s, losing to much mud, change screens down to 100s 18:30 - 20:00 1.50 DRILL P INT1 Directional drill 7990' to 8270' 120 rpms 500 gals per min 1800 psi, next to no lost over shaker. 20:00 - 21 :30 1.50 DRILL P INT1 Screen up shakers from 100 to 230s with 400 gals min. near total lost to rock washer, screen down to 100s 21 :30 - 00:00 2.50 DRILL P INT1 Directional drill 8270' to 8540' 120 rpms 550 gals per min 2050 psi, AST 3.25 ART 6.25 ECD 10.4 1/12/2004 00:00 - 10:30 10.50 DRILL P INT1 Directional drill 8540' to 9306' 120 rpms 550- 625 gals per min 2300-3000 psi, at 8,700' raised mud wt to 9.8 as planned, ECD 10.6 to 11.0 ppg- With stand down at 9306', Check flow before connection - slight flow 10:30 - 11 :00 0.50 DRILL P INT1 Put pump back on and Circulate bottoms up at 625 gpms, 2750 psi, pit volume increase 8 bbls as circulation bottoms up - initial ECD 11.06 final ECD 10.6, - ~hut well in at 11 :08 am _- Monitor well. - SIDP 60 psi, SICP 100 psi - SPR at 9023 560 psi at 40 spm 11 :00 - 12:30 1.50 DRILL N DPRB INT1 Circ. thru choke with drillers method holding 650 psi, shut in pressure were 60 SIDPP 100 SICP slow pump rate 560-40 spm 12:30 - 15:30 3.00 DRILL N DPRB INT1 Begin Circ on choke kill wt mud 10.0, SIDPP 100, ICP 650 w/ 40 spm, mud wt returns 9.8, 15:30 - 16:00 0.50 DRILL N DPRB INT1 Pump down well shut in SIDPP 100 psi, SICP 180 psi 16:00 - 19:00 3.00 DRILL N DPRB INT1 Begin Circ.,on choke, 10.5 kill wt. mud ICP 650 w/ 40spm with 9.8 returns, 19:00 - 19:30 0.50 DRILL N DPRB INT1 Shut well in, check pressure, SIDPP 70, SICP 180 (lots of oil in mud 8%) 19:30 - 22:30 3.00 DRILL N DPRB INT1 Circ on choke, raise mud wt to 10.7 ICP 725 psi full circ mud returns 10.1, 22:30 - 23:30 1.00 DRILL N DPRB INT1 Circ on choke, raise mud wt to 10.8 ICP 700 psi, with choke wide open, started to lose mud. 23:30 - 00:00 0.50 DRILL N DPRB INT1 Open Hydrill and worked pipe, Circ with 700 psi 40 spm losing about 20 bbls hr. 1/13/2004 00:00 - 03:00 3.00 DRILL N DPRB INT1 Circ slow, rotate 50 rpms and reciprocate pipe, starting circ @ 40 spm with 700psi, hole taking mud up to 60 bbls per hr. slowed to 3 bbls per hr., increase circ rate up to 300 gpm 1040 psi mud wt return cut from 10.8 to 9.2, 8 % oil in mud ECD 11.4 with 300 gpm, lost total 1 00 bbls to hole 03:00 - 05:00 2.00 DRILL N DPRB INT1 Displace well with 580 bbls, new 10.8 LSND mud with 300 gals per min. - Gas breaking out in bell nipple, looks like boiling water. Oil in returns. 05:00 - 11 :30 6.50 DRILL N DPRB INT1 Circulate down flow line, increase mud wt from 10.8 to 11.0 - increase pump rate 300 to 338 gpm, ECD 11.4 - 11.6 ppg - lot of Gas and oil in returns. Initial loss rate 60-bbl/hr. Average loss rate 75-bbl/hr. Slow pump rate to 84-gpm. Rotate and reciprocate - 50-rpm, 20K torque. 11 :30 - 12:00 0.50 DRILL N DPRB INT1 Observe well. Flow observed. Pull out of hole one stand to 9,213-ft. Gained 5-bbl while standing DP in derrick. 12:00 - 17:30 5.50 DRILL N DPRB INT1 Circulate 11.1-lb/gal mud @ 84-gpm, 320-psi, 50-rpm, Printed: 6/29/2004 10: 15:53 AM E:- ~ ( (' BP Operations Summary Report Page 4 of 14 Legal Well Name: Common Wêll Name: Event Name: Contractor Name: Rig Name: MPL -43 MPL -43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From- To Hours Task Code NPT Phase Description of Operations 1/13/2004 12:00 - 17:30 5.50 DRILL N DPRB INT1 reciprocate pipe. 17:30 - 18:00 0.50 DRILL N DPRB INT1 MW In 11.3-lb/gal, MW Out 9.9-lb/gal (non-pressure balance), 11.3-lb/gal (pressurised balance). Increased flowrate to 244-gpm, 880-psi, 50-rpm, ECD 11.73-lb/gal, 80-bbllhr losses. 18:00 - 19:00 1.00 DRILL N DPRB INT1 Flow check: 5-bbl gain in 8-min. Circulate 11.3-lb/gal mud @ 120-gpm, 410-psi, 50-rpm, reciprocate pipe. MW Out 9.8 to 10.5-lb/gal 19:00 - 21 :00 2.00 DRILL N DPRB INT1 Circulate 11.3-lb/gal mud @ 250-gpm, 890-psi, 80-rpm. ECD climbed from 11.75 to 11.86-lb/gal. Losing 120-bbl/hr 21 :00 - 22:00 1.00 DRILL N IDPRB INT1 Slow pump to 140-gpm @ 500-psi 22:00 - 23:30 1.50 DRILL N DPRB INT1 Oil content 10%., Circ. 2 bbls min 240 psi, monitor well gain two bbls 23:30 - 00:00 0.50 DRILL N DPRB INT1 Circ. 2 bbls min with no returns, shut down and monitor well Flow check: 2-bbl gain in 12-min. 1/14/2004 00:00 - 01 :00 1.00 DRILL N DPRB INT1 Monitor well, no gains or losses 01 :00 - 02:00 1.00 DRILL N DPRB INT1 Poh 9213 to 8365 filling through DP 10 bbls gain taken pulling pipe 02:00 - 03:00 1.00 DRILL N DPRB INT1 Monitor well no gains no loss 03:00 - 03:30 0.50 DRILL N DPRB INT1 Close annular, dead head 50 bbls 11.5 down back side with 3 bbls min. 220 psi, shut down pressure 40 psi, trying to get back side to take mud 03:30 - 04:00 0.50 DRILL N DPRB INT1 Open annular, slight flow, close annular,dead head 50 bbls 11.5 down back side with 3 bbls min. 230 psi, shut down press 50 psi 04:00 - 04:30 0.50 DRILL N DPRB INT1 Open annular, flow more flow back 8 bbls, close Annular,dead head 50 bbls 11.5 down back side with 3 bbls min. 250 psi, shut down press 80 psi 04:30 - 05:00 0.50 DRILL N DPRB INT1 Open annular, well flowing, close annular,dead head 50 bbls 11.5 down back side with 3 bbls min. 260 psi, shut down press 90 psi, well flow 45 bbls 05:00 - 07:00 2.00 DRILL N DPRB INT1 Circ 11.5-lb/gal mud @ 2-bpm. 270 psi loss started @ 30 bbllhr. going up to 60 bbl/hr. Working and rotate pipe. 07:00 - 07:30 0.50 DRILL N DPRB INT1 Full losses. Shut down, blow down top drive, monitor well - reciprocate pipe, no rotation. 07:30 - 09:00 1.50 DRILL N DPRB INT1 Continue to monitor well. Slow gas bubbles to surface. Average gain 1-bbl/3-min (20-bbl/hr). 09:00 - 11 :30 2.50 DRILL N DPRB INT1 Flow increased, increased gas bubbling out. Circulate at 30-spm, 50-rpm. Increased gas to surface. Circulate at 20-spm. Losses 24-bbl/hr. 11 :30 - 13:00 1.50 DRILL N DPRB INT1 Continue to circulate at 20-spm. Losses cease, slight gain. Gas continued to boil out in the bell nipple. 13:00 - 13:30 0.50 DRILL N DPRB INT1 Continue to circulate at 20-spm. Slight losses. 13:30-14:30 1.00 DRILL N DPRB INT1 Stop circulation after 5,600-stk of 11.5-lb/gal mud. MW with pressurised balance In 11.8, Out 11.3-lb/gal. MW with un-pressurised balance In 11.6, Out 10.0-lb/gal. MU TIW valve, blow down top-drive, Close TIW valve, Close annular. Net 6-bbl gain from time of shut-down (15-min). Connect cement line to pump-in sub. Monitor pressures. Initial: SIDPP O-psi, SICP 60-psi (pressures are all re-calibrated based on low pressure gauges). Start pump and pump 5.5-bbl before float opens. SIDPP 40-psi, SICP 70-psi. Stop pump and monitor pressures every 15-min. Initial: SIDPP 20-psi, SICP 70-psi. 14:30 - 15:00 0.50 DRILL N DPRB INT1 Continue to monitor well. SIDPP O-psi. SICP gO-psi. Printed: 6/29/2004 10: 15:53 AM ttF- <:- ( (: BP Operations Summary Report Page 5 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From - To Hours Task Code NPT Phase Description of Operations 1/14/2004 15:00 - 16:00 1.00 DRILL N DPRB INT1 Continue to monitor well. SI DPP O-psi. SICP 120-psi. Conference call with office. 16:00 - 16:30 0.50 DRILL N DPRB INT1 PJSM. 16:30 - 17:00 0.50 DRILL N DPRB INT1 RU to pump out of hole. When annular was opened, a substantial transient flow was observed with a high oil content - the highest yet. Gas boiling in the bell nipple to the same extent as previously. 17:00 - 21 :30 4.50 DRILL N DPRB INT1 Start to pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 to 12 bbls per stand. 21 :30 - 22:00 0.50 DRILL N DPRB INT1 Monitor well with trip tank, loss 30 bbl hr. @ 5718' 22:00 - 22:30 0.50 DRILL N DPRB INT1 Pooh with out pump for 5 stands, well swabbing, took improper fill- 3 bbls 22:30 - 00:00 1.50 DRILL N DPRB INT1 Cont. pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 to 12 bbls per stand. to 4,414' 1/15/2004 00:00 - 04:30 4.50 DRILL N DPRB INT1 4414 to 1850' pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 to 12 bbls per stand. returns mud wt. 7.7 nearly all oil., 3 pulls 10,000 # over pull in csg as we were tripping out 04:30 - 05:00 0.50 DRILL N DPRB INT1 1850 getting good mud back, Monitor well no flow no loss, attempt to pull stand pull 30 ft. well swab, shut down. pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 bbls stand for one stand, pull one more stand gain one bbl, pull one more gain 10 bbls( total mud pumped poh 998 bbls total, left in well 661 bbls) 05:00 - 07:00 2.00 DRILL N DPRB INT1 Shut well in, @ 1573, Monitor pressures, blow down top drive, rig to circ thru choke 70 psi SI DPP 100 SICP( before we shut in got 45 bbl gain) 07:00 - 08:00 1.00 DRILL N DPRB INT1 Dump contaminated mud from pits, replace with clean 11.5-lb/gal mud. Prepare pits for well control operations. SIDPP 75psi, SICP 130-psi. 08:00 - 09:00 1.00 DRILL N DPRB INT1 Kill well using drillers method. Bring pump up to 20-stklmin holding casing pressure at 130-psi, DP pressure rose to 250-psi, then hold DP pressure at 250-psi, opening choke as required. Circulated 11 O-bbl through choke. Lost 31-bbl to well. Mud cut with moderate amount of oil. MW Out unpressurised scale 8.9 to 9.8-lb/gal, pressurised scale 10.8-lb/gal. Final DP pressure 240-psi, final casing pressure 50-psi. 09:00 - 09:30 0.50 DRILL N DPRB INT1 Shut down pump. Well flowing 1 to 2-bbl/min. Shut well in, open float. SIDPP 90-psi, SICP 100-psi. 09:30 - 10:00 0.50 DRILL N DPRB INT1 SI DPP 80-psi, SICP 11 O-psi. 10:00 - 10:30 0.50 DRILL N DPRB INT1 Fully open choke to bleed off 50-bbl to determine whether well is breathing. Record time every 5-bbl. 10-bbl 2.5-bbl/min, 20-bbl 3.4-bbl/min, 30-bbl, 5.7-bbl/min, 40-bbl, 3.8-bbl/min, 50-bbl 3.8-bbl/min. Shut in well - 50-bbl gain in 15-min. SIDPP 90-psi, SICP 190-psi. Monitor well. 10:30 - 13:30 3.00 DRILL N DPRB INT1 Monitor SIDPP and Casing pressure. Initial SIDPP-50 psi SICP-150 psi. Final SIDPP-160 psi and SICP-240 psi. Increase mud weight in pit 5 to 13.0 ppg. 13:30 - 15:00 1.50 DRILL N DPRB INT1 Displaced drill string to 1573' with 13.0 ppg mud. Pumped Printed: 6/29/2004 10: 15:53 AM ( ( BP Operations Summary Report Page 6 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PL -43 MPL -43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From.. To Hours Task Code NPT Phase Descriptionot Operations 1/15/2004 13:30 - 15:00 1.50 DRILL N DPRB INT1 down kill line and displaced 9-5/8" casing with 13.0 ppg mud. Displaced well with at 5 bpm. Initial pressure 350 psi and final pump pressure 80 psi. Pumped a total of 464 bbls. Shut down pump. No pressure on well. 15:00 - 16:00 1.00 DRILL N DPRB INT1 Open choke. No flow. Opened annular preventer and could not see mud in annulus. Pumped 50 bbls of 11.5 ppg mud in annulus. Still unable to see mud in annulus. Continued pumping 1 bpm into annulus. Pulled out of hole with BHA and stood in derrick. Had returns to surface just as BHA is racked back in derrick. Monitor well and well appeared to be taking 60 bbls per hour. 16:00 - 20:00 4.00 DRILL N DPRB INT1 Made up 5" mule shoe on stand of 5" drill pipe and float sub on top of first stand. Ran in hole with 5" drill pipe filling drill pipe every 5 stands. Hole standing full while running in hole. Hole taking displacement. Mule shoe @ 9294 20:00 - 22:00 2.00 DRILL N DPRB INT1 Well flowing, shut in on Hydrill, shut in with 80# build to 150 in 15 min. 150# drill pipe pressure final 170# SIDPP, 190# SICP 22:00 - 22:30 0.50 DRILL N DPRB INT1 Bleed back 60 bbls thru choke, flow 5bbls per 3 min., getting back 7.7 oily mud 22:30 - 23:00 0.50 DRILL N DPRB INT1 Secure well, monitor well SIDPP 120# SICP 170# 23:00 - 00:00 1.00 DRILL N DPRB INT1 Bleed back 75 bbls thru choke, flowing 5 bbls every 2.5 min., getting back 7.7 oily mud 1/16/2004 00:00 - 00:30 0.50 DRILL N DPRB INT1 Bleed back 35 more bbls, flowing slow to 6-7 min per 5 bbls, getting back 8.7 oily mud 00:30 - 02:00 1.50 DRILL N DPRB INT1 Shut in, SIDPP started and stayed 100#, SICP started 40# build to 170# 02:00 - 03:30 1.50 DRILL N DPRB INT1 Pumped down kill line and displaced 9-5/8" casing with 13.0 ppg mud. Displaced well with at 5 bpm. Initial pressure 350 psi and final pump pressure 80 psi. Pumped a total of 350 bbls. Shut down pump. No pressure on well. 03:30 - 04:00 0.50 CEMT N DPRB INT1 Pump cement plug with Schlumberger, with 5 bbls water, test lines to 2,000 psi,10 water, 48 bbls of 15.8 Class G with gas block, 5 bbls water, pumped @ 7bbls min., displace with rig with 148 bbls 11.5 mud, no returns to surface, cement plug should be from 9293 to 8683 04:00 - 04:30 0.50 DRILL N DPRB INT1 Pull 8 stands slow, pick up top drive pumped 30 bbls to clear pipe, no returns to surface, could not see mud in well bore 04:30 - 06:00 1.50 DRILL N DPRB INT1 Pull in to csg to 6000 ft, filling with 1 bbl per stand, hole filled up with 24 bbls, but was dropping in well bore, shut well in on hydrill and monitor pressure. 0 @ 6.00 06:00 - 15:00 9.00 DRILL N DPRB INT1 While waiting on cement, made up floor valve and cement line to monitor pressure on drill string. Fluid was at surface at 07:40 hrs. Pressure slowly increased from zero to SIDPP-O psi and SICP-250 psi. 15:00 - 17:00 2.00 DRILL N DPRB INT1 Opened choke and bled pressure off of annulus. Recovered approximately 10 bbls mud and 40 bbls of crude oil. Well stopped flowing through choke manifold. 17:00 - 17:30 0.50 DRILL N DPRB INT1 Opened annular preventer and flow check well. Hole standing full with gas bubbles working out of mud. Pumped 15 bbls of 11.5 ppg mud down drill string attempting to circulate out crude oil. Returns consist of 70% mud and 30% crude oil. 17:30 - 19:00 1.50 DRILL N DPRB INT1 Closed annular and opened kill line. Bullheaded 350 bbls of 13.0 ppg mud down annulus at 4-5 bpm. Initial pumping Printed: 6/29/2004 10: 15:53 AM { ( BP Operations Summary Report Page 7 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL -43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From - To Hours Task Code NPT Phase Description of Ope ratio ns 1/16/2004 17:30 - 19:00 1.50 DRILL N DPRB INT1 pressure 270 psi and final pump pressure 50 psi. Opened annular and well on vacuum. 19:00 - 20:30 1.50 DRILL N DPRB INT1 Trip in to 8784 tag top of cement with 5,000 set down,tag was witness by John Spalding AOOGC 20:30 - 22:00 1.50 CEMT N DPRB INT1 Cement with Schlumberger with 5 bbls water, test lines to 2000 psi,10 bbls water, 48 bbls of Class G mixed @ 15.8# mixed on fly, 5 bbls water, mixed and pumped 5 bbls min., displace with rig pump 98 bbls min 600 psi, no return to surface bottom cement pi ug 8760 top 8150 22:00 - 23:30 1.50 DRILL N DPRB INT1 Pull to 7974, pump 30 bbls mud to clear pipe 23:30 - 23:00 23.50 DRILL N DPRB INT1 Trip out to 6000 ft., fill hole with 1 bbl per stand well filled up after 23 bbls but was falling 23:00 - 00:00 1.00 DRILL N DPRB INT1 Monitor well 0 pressure at midnight 1/17/2004 00:00 - 10:30 10.50 DRILL N DPRB INT1 Monitor well with trip tank on top of hole. Hole taking 5 bbls per hour. 10:30 - 12:00 1.50 DRILL N DPRB INT1 Ran back in hole with cementing string to 7950'. Filled drill pipe and continued pumping 1.5 bpm. Washed down and tagged top of cement at 8187' (Calculated top of cement 8150'). 12:00 - 14:00 2.00 DRILL N DPRB INT1 Pumped 20 bbls of 13.0 ppg mud down drill pipe for a slug. Started out of hole. Hole swabbing. Started pumping out of hole at 25 spm to 6000'. 14:00 - 16:30 2.50 DRILL N DPRB INT1 Pulled out of hole wet fl 6000' to BHA. Reduced pulled speed to reduce swabbling. Hole began taking fluid at 3000'. 16:30 - 17:30 1.00 DRILL N DPRB INT1 Laid down mule shoe. Broke out bit from motor in derrick. Picked up HWDP, Jars, float sub, bit sub casing scrapper and re-run 8-3/4" bit. 17:30 - 20:00 2.50 DRILL N DPRB INT1 Run in hole at reduced speed for surge presure to 6077'. No returns while running in hole. 20:00 - 22:00 2.00 DRILL N DPRB INT1 Pulled out of hole to BHA at reduced rate to reduce swabbing. 22:00 - 23:00 1.00 DRILL N DPRB INT1 Laid down HWDP, Jars and scrapper assembly. 23:00 - 23:30 0.50 DRILL N DPRB INT1 Picked up a 9-5/8" EZSV cement retainer and float sub and made up on 5" drill pipe 23:30 - 00:00 0.50 DRILL N DPRB INT1 Tripping hole with EZSV cement retainer at a reduced rate to reduce surge. 1/18/2004 00:00 - 02:30 2.50 DRILL N DPRB INT1 Finished running in hole with 9-5/8" EZSV cement retainer to 6077' . 02:30 - 03:30 1.00 DRILL N DPRB INT1 Rigged up cement lines. Circulated through retainer. Set retainer at 6077'. Test casing to 2000 psi. Pulled out of retainer. Stung back into retainer with 30K weight. Established injection rate of 5 bpm at 610 psi. 03:30 - 04:30 1.00 CEMT N DPRB INT1 PJSM-Pump 5 bbls water-test lines to 4000 psi-pump 47 bbls (225 sxs) 15.8 ppg cement-5 bbls water behind. Displaced cement with rig pumps with 102 bbls of 10 ppg mud at 4 bpm. Left one bbl of cement in pipe. Final pressure 500 psi. Shut down pressure 270 psi. Pull out of retainer. 04:30 - 06:30 2.00 CEMT N DPRB INT1 Pulled one stand of pipe. Slug pipe with 13 ppg mud. Pulled out of hole to 3700'. Pipe started pulling wet. Mud aired up and having trouble mixing slug. 06:30 - 08:00 1.50 DRILL N DPRB INT1 Slip and cut drill line. Service top drive. Mix and pump dry job. 08:00 - 09:00 1.00 DRILL N DPRB INT1 Finish pulling out of hole with cementing string and laid down setting tool. 09:00 - 11 :30 2.50 DRILL N DPRB INT1 Run in hole with BHA from derrick. Laid down flex collars. Download MWD. Lay down MWD and motor. Printed: 6/29/2004 10:15:53 AM \ . ( (' BP Operations Summary Report Page 8 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From - To Hours Task Code NPT Phase Description of Operations 1/18/2004 11 :30 - 14:00 2.50 DRILL N DPRB INT1 Picked up rerun 8-3/4" bit, bit sub and float sub and tripped in hole with 5" drill pipe to 6036'. Filled drill pipe at 30 stands. 14:00 - 15:00 1.00 DRILL N DPRB INT1 PJSM-Filled drill pipe and washed and rotated from 6036' to EZSV retainer at 6077'. 15:00 - 15:30 0.50 DRILL N DPRB INT1 Displace mud in hole with new 9.6 ppg mud at 9.5 bpm. Rotated and reciprocated pipe during displacement. 15:30 - 17:30 2.00 DRILL N DPRB INT1 Laid down 99 jts of 5" drill pipe 17:30 - 18:30 1.00 DRILL N DPRB INT1 Rih with pipe from derrick to 6077 18:30 - 19:00 0.50 DRILL N DPRB INT1 Circ remainder of 10# mud from pit to flush drill pipe 90 bbls 19:00 - 00:00 5.00 DRILL N DPRB INT1 Clean pits and drip pans, solids equipment,suction lines of oil contamiation, with hot water from hot oil truck 1/19/2004 00:00 - 04:00 4.00 DRILL N DPRB INT1 Finish Cleaning pits and drip pans, solids equipment,suction lines of oil contamiation, Taking on Sea water to pits 04:00 - 06:00 2.00 DRILL N DPRB INT1 Displace mud in hole WI Sea water at 9.5 bpm., Displace Sea water W/ 9.8 Brine at 9.5 bpm. Rotated and reciprocated pipe during displacement. 06:00 - 10:00 4.00 DRILL N DPRB INT1 Laying down Drill pipe 10:00 - 11 :00 1.00 DRILL N DPRB INT1 Pull wear ring, install hanger with TWC, test to 1000 psi 11 :00 - 12:30 1.50 DRILL N DPRB INT1 Nipple down BOPS 12:30 - 14:00 1.50 DRILL N DPRB INT1 Nipple up dry hole tree,Test tree 4000 psi, install BPV, clean out cellar, rig release for move 1/19/2004 1600 hrs 6/13/2004 05:00 - 06:00 1.00 RIGU P PRE Accept rig @ 05:00 hrs on 6/13/2004 - Check upper annulus for pressure - No presssure - Back out LDS - Nipple down production tree - Pull tubing hanger out of tubing head - (BPV installed) - Install test plug - Record measurements from RF to GL 34.02 - RF to ULD 30.33 - RF to LLD 32.55 06:00 - 08:00 2.00 RIGU P PRE Nipple up BOP's 08:00 - 08:30 0.50 RIGU P PRE Rig up testing equipment 08:30 - 13:00 4.50 BOPSUR P PRE Test BOP's - Test Annular 250 low - 2500 high 5 mins each test - Test Pipe rams - Blind Rams - Choke manifold - HCR kill I Choke - Manual Kill I Choke - Upper I Lower IBOP - Floor safety valves - 250 low - 4000 high - 5 mins each test - Preform Accumulator test - John Crisp with AOGCC witnessed test 13:00 - 13:30 0.50 BOPSUR P PRE Rig down Testing equipment 13:30 - 16:30 3.00 DRILL P INT1 PJSM - RIH picking up 135 joints 4" DP 16:30 - 18:00 1.50 DRILL P INT1 Flow check - well static - POH 18:00 - 19:30 1.50 DRILL P INT1 Make up BHA for clean out 19:30 - 23:30 4.00 DRILL P INT1 RIH with BHA - Picking up 168 joints 4" DP - Tag up on EZSV retainer @ 6077' - PU 150 - SO 108 - ROT 125 23:30 - 00:00 0.50 DRILL P INn Dispalce hole from 9.8 Brine to 9.0 LSND mud - GPM 420 - 1350 psi - RPM 87 - TQ 6.5 K 6/14/2004 00:00 - 01 :00 1.00 DRILL P INT1 Con't Displace 9.8 brine with 9.0 LSND - GPM 420 - ICP 1350 - FCP 1010 - RPM 90 - TO 6.5 K - PU 150 - SO 108 - ROT 125 01 :00 - 02:00 1.00 EVAL P INT1 Rig up to test 9 5/8" casing and EZSV to 2000 psi for 30 mins - Recorded on chart - Rig down testing equipment 02:00 - 05:30 3.50 DRILL P INT1 Drill EZSV retainer from 6077' to 6082' Drill cement from 6082' to 6097' and 20' of open hole to 6117' - 80 RPM - TO 6K - 80 spm - 850 psi - WOB 15 to 40 - Firm Cement from 6090' to 6110' - 10 to 15 K WOB - 2 to 3 min foot Rap - 6110 to 6117' soft 05:30 - 06:00 0.50 DRILL P INT1 CBU for FIT - 90 SPM - PP 1150 psi - 80 RPM - TO 4K 06:00 - 06:30 0.50 DRILL P INT1 Rig up test equipment - Perform FIT test - MD 6097' - TVD 4438' - MW 9.0 - Surface 810 = EMW 12.5 - Rig down test Printed: 6/29/2004 10: 15:53 AM Date From - To Hours Task Code NPT Phase Descri ptionotOperations 6/14/2004 06:00 - 06:30 0.50 DRILL P INT1 equipment 06:30 - 07:00 0.50 DRILL P INT1 Clean out hole - Drill cement from 6117' to 6137' - Taking 10K to 15K WOB 07:00 - 08:00 1.00 DRILL P INT1 CBU - 90 SPM - PP 1200 - 80 RPM - TO 4K - Flow check - Pump dry job 08:00 - 10:00 2.00 DRILL P INT1 POOH to BHA @ 736' 10:00 - 10:30 0.50 DRILL P INT1 Lay down BHA 10:30 - 13:00 2.50 DRILL P INT1 Make up Drilling BHA - Shallow test MWD 13:00 - 14:30 1.50 DRILL P INT1 RIH with 4" DP to 6060' 14:30 - 15:30 1.00 DRILL P INT1 Record drilling parameters and Madd pass from 6060' to 6137' 15:30 - 16:00 0.50 DRILL P INT1 Cut trough on low side for side tract - Work trough from 6117' to 6137' 16:00 - 17:00 1.00 DRILL P INT1 Time drill from 6137' to 6143' 17:00 - 00:00 7.00 DRILL P INT1 Directional Drill from 6143' to 6563' - WOB 5 to 10 - RPM 80- TO on 7K - off 5K - GPM 544 - PP on 2650 - off 2450 - PU 145 - SO 115 - ROT 130 6/15/2004 00:00 - 05:30 5.50 DRILL P INT1 Directional Drill from 6563' to 7235' - WOB 10 to 20 - RPM 90 - TO on 10 - off 7 - GPM - 480 - PP on 2850 - off 2450 - PU 150 - SO 116 - ROT 135 05:30 - 07:30 2.00 DRILL P INT1 CBU 3 X - 90 RPM - TO 7K - 490 GPM - PP 2650 - Clay balls 07:30 - 09:00 1.50 DRILL P INT1 Flow Check - Pump out at drilling rate to shoe @ 6082' 09:00 - 10:00 1.00 DRILL P INT1 CBU 1 X at shoe - RPM 90 - TO 9K - GPM 480 - PP 2210 10:00 - 11 :30 1.50 DRILL P INT1 Cut drlg line - Top drive service 11 :30 - 18:00 6.50 DRILL N RREP INT1 Diagnose Rig power problem - (Bearing out # 2 generator - Power sharing problem between Gen # 1 and # 3 - change out power module in power factor corrector - This allowed Gen #1 and # 3 to balance out load) 18:00 - 19:00 1.00 DRILL P INT1 RIH to 7141' - Precauctionary wash from 7141' to 7235' 19:00 - 00:00 5.00 DRILL P INT1 Directional Drill from 7235' to 7813 - WOB 10 to 20 - RPM 80 - TO on 10 - off 7 - GPM - 540 - PP on 3000 - off 2450 - PU 185 - SO 116 - ROT 144 6/16/2004 00:00 - 06:30 6.50 DRILL P INT1 Directional Drill from 7813' to 8292' - WOB 17K - RPM 90 - TO on 13 - off 11 - GPM 475 - PP on 3180 - off 2800 - PU 210- SO 115 - ROT 150 06:30 - 09:00 2.50 DRILL P INT1 CBU 3 X - RPM 90 - TO 11 K - GPM 460 - PP 2750 09:00 - 11 :30 2.50 DRILL P INT1 Pump out to shoe 6097' - Pump at drilling rate 11 :30 - 12:30 1.00 DRILL P INT1 CBU 1 X at shoe - GPM 375 - 90 RPM -TO 9K - PP 1810 12:30 - 13:30 1.00 DRILL P INT1 RIH to 8197' - Precautionary wash from 8197' to 8292' 13:30 - 00:00 10.50 DRILL P INT1 Directional Drill from 8992' to 8800' - WOB 13K - RPM 90 - TO on 10 - off 7 - GPM 530 - PP on 3600 - off 3350 - PU 190 - SO 130 - ROT 155 6/17/2004 00:00 - 02:00 2.00 DRILL P INT1 Directional Drill from 8800' to 8963' - TD 8 3/4" hole - WOB 12K - RPM 90 - TO on 10 - off 7 - GPM 530 - PP on 3620 - off 3360 - PU 190 - SO 130 - ROT 156 02:00 - 04:30 2.50 CASE P INT1 CBU 3 X - RPM 100 - TO 10 - GPM 530 - PP 3350 04:30 - 05:00 0.50 CASE P INT1 Pump from 8963' to 8200' at drilling rate 05:00 - 05:30 0.50 CASE P INT1 Flow check - RIH from 8200' to 8963' 05:30 - 07:00 1.50 CASE P INT1 CBU 2 X - GPM 530 - PP 3400 - RPM 100 - TO 9 07:00 - 09:30 2.50 CASE P INT1 Pump out to shoe @ 6097' - Pump out at drilling rate 09:30 - 10:30 1.00 CASE P INT1 CBU 1 X at shoe - 50 RPM - Tq 5K - GPM 530 - PP 2960 - Flow check - well stable - Pump dry job 10:30 - 12:00 1.50 CASE P INT1 POOH to BHA @ 718' 12:00-14:00 2.00 CASE P INT1 Lay down BHA - 5" HWT - Stand back one stand 5" HWT Printed: 6/29/2004 10: 15:53 AM Spud Date: 1/6/2004 End: Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: MPL-43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 9 of 14 BP Operations Summary Report ( (' (' ( BP Operations Summary Report Page 10 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL -43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From - To HoUrs Task Code NPT Phase Description· of Operations 6/17/2004 14:00 - 15:00 1.00 CASE P INT1 Pull wear ring - Install test plug - Change rams to 7" - Test door seals to 2500 15:00 - 16:30 1.50 CASE P INT1 Rig up Franks fill up tool - 7" casg equipment 16:30 - 22:30 6.00 CASE P INT1 PJSM - Run shoe tract joints - Check floats - Pick up and run 147 joints of 7" L-80 26# BTC-M casing to 6042' 22:30 - 23:00 0.50 CASE P INT1 Circulate one casing volume - 233 bbls @ 250 GPM - PP 750 psi - PU 170 - SO 115 23:00 - 00:00 1.00 CASE P INT1 Con't Running 7" casing - From 6042' to 7300' 6/18/2004 00:00 - 01 :00 1.00 CASE P INT1 Con't RIH with 7" L-80 26# BTC-M casing from 7300' to 8874 - Break circulation wash down to 8915' 01 :00 - 02:00 1.00 CASE P INT1 Make up Hanger I Landing joint - RIH from 8915 to 8953' - Land casg - Break and lay down Franks fill up tool - Make up Schlumberger Cementing head and lines - Break Circulation @ 2 bpm @ 850 psi - stage up to 6 bpm 770 psi - PU 250 - SO 140 - Work string 20' strokes while circutating 02:00 - 04:00 2.00 CASE P INT1 Circulate I condition mud for cement job - 2 casing volumes 684 bbls - 6 bpm @ 770psi 04:00 - 05:30 1.50 CEMT P INT1 Schlumberger - Pump 5 bbls water - Test lines to 4000 psi - Pump 10 bbls CW-100 @ 5 bpm 550 psi - Pump 15 bbls Mud Push @ 10.7 ppg @ 5 bpm 550 psi - Drop bottom plug - Pump 22 bbls of 15.8 ppg Class "G" cement with .3% D065 + .4% D167 + >2% D046 + >07% B155 - Yield 1.16 cu ftlsx @ 6 bpm 480 psi - Drop top plug - Kick out plug with 10 bbls water - Give to Rig for displacement - Displace with 9.7 ppg mud @ 6 bpm 600 psi - 327 bbls - Bump plug with 1500 psi - 1000 psi over pumping pressure - Hold for 2 mins - Bleed off - Floats holding - CIP @ 05:30 05:30 - 06:30 1.00 CASE P INT1 Flush stack with fresh water - Lay down Schlumberger cementing head / lines - Back out landing joint - 06:30 - 07:00 0.50 CASE P INT1 Clear rig floor of all casing / cementing tools - Change bails 07:00 - 08:00 1.00 CASE P INT1 Install 9 5/8" X 7" pack-off - RILDS - Test to 5K for 10 mins 08:00 - 09:00 1.00 CASE P INT1 Change top rams from 7" to 2 7/8" X 5" 09:00 - 09:30 0.50 CASE P INT1 Test BOP body test to 250 low - 4000 high psi 09:30 - 10:00 0.50 CASE P INT1 Pull test plug - Install wear ring 10:00 - 12:00 2.00 CASE P INT1 Make up BHA - Surface test MWD - 60 SPM @ 800 psi 12:00 - 14:30 2.50 CASE P INT1 RIH to 8808 - Fill pipe every 25 stands 14:30 - 16:00 1.50 CASE P INT1 PJSM - Cut drlg line - Rig service - Top Drive service 16:00 - 17:00 1.00 CASE P INT1 Rig up to test casg - Test casg to 4000 psi for 30 mins - Rig down test equipment 17:00 - 19:30 2.50 DRILL P INT1 Drill float collar @ 8868' - shoe tract to float shoe @ 8951' - RPM 50 - TO 10K - GPM 250 - PP 2000 19:30 - 21 :00 1.50 CASE P INT1 Pump 20 bbl sweep - Displace to 12.5 ppg LSND mud 21 :00 - 21 :30 0.50 CASE P INT1 Obtain Clean hole ECD Base - Non-rotating 250 GPM 13.85 ECD - Rotating 250 GPM 14.05 - Non-rotating 270 GPM 14.0 - Rotating 270 GPM 14.2 21 :30 - 22:00 0.50 DRILL P INT1 Drill float shoe - Clean out to 8963' - Drill 20' new hole from 8963' to 8983' 22:00 - 23:00 1.00 CASE P INT1 CBU - Balance mud weight to 12.4 23:00 - 00:00 1.00 EVAL P INT1 Rig up testing equipment - Preform FIT to 13.5 ppg - MD 8954' - TVD 6809' - Mud weight 12.4 ppg - Pressure 390 psi = EMW 13.5 - Rig down testing equipment 6/19/2004 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 8983' to 9268' - WOB 20 to 30 - RPM 100 - TO on 5 - off 4 - GPM 250 - PP on 3400 - off 3050 - PU - SO- Printed: 6/29/2004 10: 15:53 AM (: (' BP Operations Summary Report Page 11 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PL -43 MPL -43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From- To Hours Task Code NPT Phase Description of Operations 6/19/2004 00:00 - 00:00 24.00 DRilL P PROD1 ROT Freeze protect outter annulus 9 5/8" X 7" - 57 bbls diesel - Pump rate 1.8 bpm @ 1650 psi - Annulus presure after injection 1200 psi 6/20/2004 00:00 - 04:00 4.00 DRill P PROD1 Directional Drill from 9268' to 9287' - Trip due to very slow Rap 04:00 - 04:30 0.50 DRill N DPRB PROD1 Flow Check - Pump out to shoe - Packing off at 9020' - Work twice - Back-ream from 9287' to 8940' 04:30 - 05:30 1.00 DRill N DPRB PROD1 CBU 3 X - RPM 100 - TO 4K - GPM 250 psi 05:30 - 08:30 3.00 DRill N DPRB PROD1 Flow check 10 min - POH to BHA @ 272' 08:30 - 09:00 0.50 DRill N DPRB PROD1 Stand back BHA - Break bit 09:00 - 09:30 0.50 DRill N DPRB PROD1 Download MWD 09:30 - 10:00 0.50 DRill N DPRB PROD1 Service Top Drive 10:00 - 10:30 0.50 DRill., N DPRB PROD1 Make up bit - BHA - Surface test MWD - GPM 250 - @ 1250 psi 10:30 - 14:30 4.00 DRill N DPRB PROD1 RIH from 272' to 9192- Run at reduced speed to control surge pressures - Fill pipe @ 5066' - 7466' 14:30 - 15:30 1.00 DRill N DPRB PROD1 Precauctionary wash from 9192' to 9287' - CBU for trip gas - RPM 100 - TO 4.5 - GPM 250 @ 2700 psi - Max Trip gas 2200 units 15:30 - 22:00 6.50 DRill P PROD1 Directional Drill From 9287' - 9540' - WOB 8 - RPM 100 - TO on 6 - off 5 - GPM 250 - PP on 2930 - off 2800 - PU 155 - SO 120 - ROT 130 - ECD 14.48 PPG - BG gas units 45 to 70 - @ 9405' / 877 units - 9430' / 659 units - 9464 450 units - BG gas units 55 to 65 @ 9505 BG units dropped to 20 22:00 - 22:30 0.50 DRill P PROD1 Circulate to lower ECD - Initial ECD 14.48 - Final ECD 14.21 22:30 - 00:00 1.50 DRilL P PROD1 Directional Drill from 9540' to 9585' - WOB 8 - RPM 100 - TO on 6 - off 4 - GPM -250 PP 2930 on - off 2750 - PU 155 - SO 120 - ROT - 130 6/21/2004 00:00 - 02:30 2.50 DRilL P PROD1 Directional Drill from 9585' to 9645' - TD 6 1/8" hole - WOB 8 - RPM 100 - TO on 6 - off 4 - GPM 250 - PP on 2930- off 2750 - PU 155 - SO 120 - ROT 130 02:30 - 07:00 4.50 CASE P PROD1 CBU 3 X - Flow check well - well flowing - CBU - Gas back ground 20 units while circulating - On bottoms up gas 240 units - Pit gain of 2 bbls - Shut down - Flow check well - Well flowing - CBU - Gas units circulating 18 units - On bottoms max gas 48 units 07:00 - 08:00 1.00 CASE P PROD1 CBU 1.5 X - Max gas 50 units 08:00 - 08:30 0.50 CASE P PROD1 Pump out to shoe @ drilling rate - Hole in good shape - No problems 08:30 - 09:30 1.00 CASE P PROD1 Flow Check - Slight flow appears to be decreasing over the hour 09:30 - 10:00 0.50 CASE P PROD1 RIH - No problems - Precauctionary wash to bottom 10:00 - 10:30 0.50 CASE P PROD1 CBU 1 X - RPM 120 - GPM 250 - Max gas 300 units 10:30 - 13:30 3.00 CASE P PROD1 Weight up mud from 12.5 to 12.6 - RPM 120 - TO 5 K - GPM 254 - @ 2700 - Flow check - Hole static 13:30 - 14:00 0.50 CASE P PROD1 Pump out to shoe @ pump rate - GPM 250 14:00 - 14:30 0.50 CASE P PROD1 Flow check - 30 mins - No flow - Well static 14:30 - 15:30 1.00 CASE P PROD1 CBU from shoe - @ 8902' - RPM 120 - TO 4.5 - Stage up pump up to 246 GPM - Keeping ECD's below 14.4 15:30 - 16:30 1.00 CASE P PROD1 Pump out from 8902' to 7466' - Flow check - well static 16:30 - 17:00 0.50 CASE P PROD1 Monitor well - Well static 17:00 - 20:00 3.00 CASE P PROD1 POH from 7466' to BHA @ 217' - Pull at reduced speed to Printed: 6/29/2004 10: 15:53 AM ( ( BP Operations Summary Report Page 12 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From- To Hours Task Code NPT Phase Description of Operations 6/21/2004 17:00 - 20:00 3.00 CASE P PROD1 minimize swabbing 20:00 - 21 :00 1.00 CASE P PROD1 Stand back 31/2" HWT - 4 3/4" Flex DC's - Lay down MWD - XO subs - Break bit - Sperry Mud motor 21 :00 - 21 :30 0.50 CASE P PROD1 Lay down short BHA down beaver slide - Clear floor of all 21 :30 - 22:00 0.50 CASE P PROD1 Rig up liner running tools 22:00 - 00:00 2.00 CASE P PROD1 PJSM - Pick up 41/2" L-80 12.6# BTC-M liner - Fill liner @ 420' - Change out liner handling tools - Make up Baker Hanger / Top packer - Circ liner vol - 170 GPM @ 260 psi 6/22/2004 00:00 - 06:00 6.00 CASE P PROD1 RIH with 4 1/2" liner from 920' to 8950' (casing shoe 8953'). 06:00 - 07:00 1.00 CASE P PROD1 CBU with 50 spm at 350 psi. Maximum gas 500 units. Pick up weight 162 Slack off weight 115. Made up Baker plug dropping head on skate. 07:00 - 07:30 0.50 CASE P PROD1 RIH with 4-1/2" liner from 8950' to 9622'. No problems 07:30 - 08:00 0.50 CASE P PROD1 Made up liner plug dropping head with cement line and washout line. 08:00 - 11 :00 3.00 CASE P PROD1 Broke circulation at 2 bpm at 840 psi and slowly increase rate to 5 bpm at 1450 psi. Reciprocate liner with 20' strokes. PU weight 165 SO weight 115. Maximum gas with bottoms up 280 units. 11 :00 - 11 :30 0.50 CEMT P PROD1 Held PJSM on cementing operations. Batch mixed spacers and cement. Pumped 5 bbls of CW100 Chemical Wash - test lines to 4000 psi - 5 bbls of CW1 00 Chemical Wash - 15 bbls of Mudpush II weighted to 13.0 ppg - 120 sxs (26 bbls) Class G cement + 3.0% D174 Expanding CE + .4% D065 Dispersant + .13% D800 Retarder + 2 gal/sk D600G Gasblok + .2 gal/sk D047 Antifoam mixed in a 15.8 ppg slurry with a yield of 1.2 cfVsx. Shut down and washed lines. 11 :30 - 12:00 0.50 CEMT P PROD1 Attempted to kick up plug with 12.6 ppg mud. Pumped 1.5 bbls and dart did not leave head. Shut down and checked plug dropper and flag sub. Attempted to kick out dart again and pumped another 1.5 bbls before dart left head. Approximately 3 bbls of displacement fluid was pumped past dart before dart left head. Displace cement at 5 bpm at 1200 psi. Observed pressure increase as cement exited shoe and started up annulus. Continued working pipe with 20' strokes. Slowed the pump down to 2 bpm at 700 psi before latching the dart in the liner wiper plug. Latched dart into wiper plus and pressure increased to 1200 psi and sheared. Pumped an additional 8 bbls and shut down displacement (liner volume 11 bbls). 12:00 - 12:30 0.50 CASE P PROD1 Set liner on bottom at 9645'. Slacked off to 100K. Rotated to the right 20 turns. Picked up to free pipe weight of 165K plus 6'. Slacked off and string set down 4' high (indicates released from liner). Slacked off to and saw packer set with 100K down. Slacked off additional 25K to set packer. Picked up and rotated down to 50K weight on liner. 12:30 - 14:30 2.00 CASE P PROD1 Circulate cement to surface the long way at 212 gpm at 1400 psi. Circulated out spacer and cement contaminated mud. 14:30 - 16:00 1.50 CASE P PROD1 Lay down 27 jts of drill pipe to pipe shed 16:00 - 17:00 1.00 CASE P PROD1 Slip and cut Drilling line, service top drive 17:00 - 20:30 3.50 CASE P PROD1 Tripping out with running tool, lots of cement on last stand and running tool, lay down same 20:30 - 22:30 2.00 CASE P PROD1 Clear floor, Picking up BHA #12,6 1/8 bit and csg scraper, Float sub,3 jts HWDP, jars, 6 jts HWDP Printed: 6/29/2004 10: 15:53 AM f \- ( BP Operations Summary Report Page 13 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL -43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: Spud Date: 1/6/2004 End: Date From"" To Hours Task Code NPT Phase Description of Operations 6/22/2004 22:30 - 00:00 1.50 CASE P PROD1 Tripping in to 3286 6/23/2004 00:00 - 02:30 2.50 CASE P PROD1 Trip in with bit and scraper to 8570, fill pipe ever 20 sds. 02:30 - 03:00 0.50 CASE P PROD1 Wash from 8570 to 8,828 ( top of liner) with 170 gals min. 1500 psi, Didn't rotate csg scraper 03:00 - 04:00 1.00 CASE P PROD1 Circ and reciprocate for one bottoms up 04:00 - 07:30 3.50 CASE P PROD1 Slug pipe and tripping out for liner clean out assy. 07:30 - 08:30 1.00 CASE P PROD1 Lay down BHA 08:30 - 10:00 1.50 CASE P PROD1 Rig up and picking up liner clean out BHA. 10:00 - 12:00 2.00 CASE N HMAN PROD1 Wait on new mill with blades, not flat bottom 12:00 - 15:00 3.00 CASE P PROD1 Finish picking up 3.75 mill, motor, 3 1/8 dc, 2718 drill pipe 15:00 - 18:00 3.00 CASE P PROD1 Tripping in with clean out assy. to 8677' fill pipe ever 20 stands 18:00 - 19:00 1.00 CASE P PROD1 Rih slow past liner top @ 8828 to 8858 took wt., slowly stage pump up to 131 gals min. 2230 psi, motor stalling out when we put any wt on it. and had 15k over pull to pull free, tryed sitting down without pump and took 25k over pull to pull free acts like we are trying to push it in to out of gauge pipe, or mill is not proper size 19:00 - 22:30 3.50 CASE N DPRB PROD1 Pull out of hole,strapping pipe 22:30 - 00:00 1.50 CASE N DPRB PROD1 Laying down 27/8 pipe and 3118 dcs 6/24/2004 00:00 - 01 :30 1.50 CASE N DPRB PROD1 Laying down BHA 01 :30 - 02:00 0.50 CASE N DPRB PROD1 Change out mill, mill was wrong size 4", pick up 3.625 mill 02:00 - 03:30 1.50 CASE N DPRB PROD1 Picking up BHA 3.625 mill, motor,3 1/8 dc, jars, 2718 drill pipe 03:30 - 07:00 3.50 CASE N DPRB PROD1 Tripping in with 4" pipe, to 9408 fill pipe ever 20 stands 07:00 - 07:30 0.50 CASE P PROD1 Washed and mill plug to 9439, 155 gals min. 2600 psi, turn pump off push plug to 9558, PIU 180 k, Slo 110 k 07:30 - 08:00 0.50 CASE P PROD1 Drop ball to open circ sub, stacked to much wt. on 2 7/8 drill string, 60 K 08:00 - 09:00 1.00 CASE P PROD1 Test CSG and liner top to 4,000 psi for 30 min. 09:00 - 13:00 4.00 CASE N HMAN PROD1 Poh to BHA, Tripping out to check 2 7/8 string 13:00 - 15:30 2.50 CASE N HMAN PROD1 Laying down 2718 pipe and DCs 15:30 - 17:30 2.00 CASE N HMAN PROD1 Picking up mule shoe 3118 dcs, 2718 drill pipe 17:30 - 20:00 2.50 CASE N HMAN PROD1 Tripping in to 8753 20:00 - 21 :30 1.50 CASE N HMAN PROD1 slip and cut drilling line, service top drive 21 :30 - 22:00 0.50 CASE N HMAN PROD1 Tripping in to 9558 22:00 - 00:00 2.00 CASE P PROD1 Broke circ, rig up and reverse circ with 5 to 8 bbls min 3400 psi, displace hole with 700 bbls seawater 6/25/2004 00:00 - 00:30 0.50 CASE P PROD1 Circ, long way and spot corrosion inhibitor 9 bbls min. 3660 psi 00:30 - 08:00 7.50 CASE P PROD1 Pull out of liner with 9 stands, laying down 4" drill pipe 08:00 - 10:00 2.00 CASE P PROD1 Laying down BHA and 2 7/8 pipe 10:00 - 11 :00 1.00 RUNCOMP RUNCMP Pull wear ring, rig up to run tubing 11 :00 - 19:00 8.00 RUNCOMP RUNCMP PJSM with crews, picking up 4.5 12.6# L-80 I BT -M tubing 210 jts total run,Spaced out WLEG 8837, XN nipple 8825, Baker S-3 packer 8801, XD sliding sleeve 8777, GLM 2043 P/U wt 150k, S/o wt 105k, Block wt 50K 19:00 - 20:00 1.00 RUNCOMP RUNCMP Land tubing and test TWC to 1000 psi 20:00 - 21 :00 1.00 RUNCOMP RUNCMP Nipple down BOPS 21 :00 - 23:30 2.50 RUNCOMP RUNCMP Nipple up 4 1/16 CIW 5,000 tree and adapter, test adapter flange to 5000 psi, Tree to 4,000psi for 10 min. 23:30 - 00:00 0.50 RUNCOMP RUNCMP Rig up test equipment 6/26/2004 00:00 - 01 :30 1.50 RUNCOMP RUNCMP Drop ball, Pressure up on tubing and set packer with 4,000 psi for 30 min., bleed pressure to 3000 psi on tubing and pressure test annulus to 4500 psi for 30 min., bleed pressure off tubing and shear DCK valve to freeze protect Printed: 6/29/2004 10: 15:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( f BP Operations Summary Report MPL-43 MPL-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 6/26/2004 Rig Number: 6/26/2004 01 :30 - 02:30 Frorn-To Hours Task Code NPT Phase 02:30 - 03:00 1.00 RUNCOMP 0.50 RUNCOMP Page 14 of 14 Spud Date: 1/6/2004 End: Description of Operations RUNCMP Freeze protect well with 68 bbls diesel with First energy, let u-tube RUNCMP Install BPV, test to 1000 psi, secure well, Rig release @ 0:300 6/26/2004 Printed: 6/29/2004 10: 15:53 AM (' ( WELL: FIELD: API: PERMIT: MPL-43 MILNE PT. UNIT I KUPARUK RIVER SANDS 50-029-231900-00-00 203-224 POST DOYON 14- RIG WORK 06/27/04 PULLED BALL & ROD. PULLED RHC PLUG. PULLED 1" RP SHEAR VALVE, SET 1" DGLV, AND prr IA TO 1000 PSI. GOOD PfT, BLED BACK TO 0 PSI. RAN 10' X 3.70" BAR BELL ASSEMBLY & TAGGED TD @ 9553' MD USING CORRECTION OFF XN. THIS IS 89' BELOW THE PLANNED LOWER PERF SHOT (9464') AND 6' ABOVE THE LINER LANDING COLLAR (PBTD). 06/29/04 LOGGED PDC GR/CCL FROM O'-TD 9562' AND 9562'-0' WITH JEWELRY LOG. THE JEWELRY LOG SHOWED DEPTHS AT THE PROPOSED PERFORATION INTERVALS TO BE 5' DEEPER THAN THE SPERRY MWD ROP/EWR/DGR LOG DATED 14-JUN-2004. 06/30/04 PERFORATED 9449'-9469' AND 9415'-9435' MD (REF. SCHLUMBERGER PDC GR/CCL LOG DATED 29-JUNE-04) IN TWO RUNS OF 'BIG HOLE' CHARGES. GOT SBHP READINGS BETWEEN THE FIRST AND SECOND GUN RUNS, AND THEN AFTER THE SECOND GUN RUN. AFTER FIRING THE FIRST GUNS (9449'-94691) WE RAN IN HOLE WITH THE SBHP GAUGES AND GOT A BHP OF 3092 PSI. DECIDED TO PUMP 10 BBLS OF DIESEL TO BREAK DOWN PERFS TO ASSURE WE ARE COMMUNICATED WITH THE FORMATION. AFTER PUMPING THE DIESEL THE GAUGES WERE LEFT AT MID-PERF FOR ANOTHER 2 HOURS. AFTER THE SECOND GUN RUN (9415'- 9435') A SBHP GAUGE WAS RUN AND LEFT ON BOTTOM FOR 2 HOURS. NO PROBLEMS RIH OR POOH. TAGGED TD ON FIRST RIH AT 9562' MD. (VERIFY PERFORATIONS ARE OPEN) PUMPED 6.4 BBLS DIESEL DOWN TUBING AT 3000 PSI (MAX PRESSURE) AND 0.25 BPM 07/01/04 (PRE-FRAC MIT-IA) MITIA TO 3500 PSI PASSED. PUMPED 2.8 BBLS DIESEL DOWN IA TO PRESSURE TEST TO 3500 PSI. FOR 30 MINUTES. LOST A TOTAL OF 25 PSI IN 30 MINUTES. ./ ./ 07/02/04 (PRE-FRAC MIT-IA) PUMPED 2.9 BBLS DIESEL DOWN THE IA TO PRESSURE TEST TO 4000 PSI. LOST 25 PSI IN 30 MINUTES. 07/05/04 MIRU DS FRAC EQUIPMENT. DATAFRAC WI 150 BBLS YF130LG AT 10 BPM, FOLLOWED BY 154 BBLS WF120 AT 25 BPM. ISIP 1625 PSI. REDESIGN FRAC TREATMENT. PUMP FRAC AT 25 BPM AS FOLLOWS: 175 BBLS PAD, 21 BBLS 1#, 22 BBLS 2#,23 BBLS 3#,24 BBLS 4#,25 BBLS 5#,95 BBLS 6#,98 BBLS 7#,135 BBLS 8#,140 BBLS 9#,178 BBLS 10# DISPLACE WITH 138 BBLS SLlCKWATER (SLlPSTREAMED 30 BBLS DIESEL IN FLUSH). UNDERDISPLACED BY 5 BBLS. 170,500#'S 16/20 CL BEHIND PIPE. MAX TREATING PSI OF 4332 PSI, MAX RATE OF 25 BPM, AND MAX SAND CONCENTRATION OF 10.2 #/GAL. (FRACTURING) PUMPED 3.8 BBLS DIESEL DOWN IA TO HOLD BACKSIDE PRESSURE AT 3600 PSI DURING FRAC. 07/06/04 TAGGED FILL IN LINER AT 9360' CORR MD, 55' OF FILL ABOVE TOP PERF PERFORMED SBHP AT 8950' MD, AND 9350' MD. STATIC PRESSURES WERE SLIGHTLY DECREASING DURING THE TEST. M PL -43 Page 2 f ( 07/08/04 SET (BP-1109, 11A) JET PUMP. (FP TBG} ATTEMPTED TO PUMP 15 BBLS OF DEAD CRUDE DOWN TBG AFTER SLlCKLlNE REPORTED THAT THEIR TOOLS CAME OUT OF THE HOLE WITH SLUSH. COULD ONLY PUMP ABOUT 8 BBLS BEFORE THE WELL LOCKED UP. THE LOCK UP IS MOST LIKELY DUE TO A BLOCKAGE FROM THE FRAC SAND THAT COVERS THE PERFS. IW H P=0/1 00. FW H P=2000/2000 07/29/04 PUMP 10 BBLS CRUDE DOWN lA, 40 BBLS DIESEL DOWN TUBING TO FREEZE PROTECT WELL. 08/01/04 COME OFF WEATHER/WIND RESTRICTIONS. RAISE MAST AND MU WEATHERFORD FISHING STRING W/4-1/2" GS AND RIH. LATCHED JET PUMP AT 8765' CTM WITHOUT PROBLEM AND MADE 15 JAR LICKS WITH 5K UP TO 18K OVER, RELEASED, RELATCHED AND MADE 15 MORE LICKS AT 22K TO 24K OVER FOLLOWED BY STRATIGHT PULLS, RELEASED AND RE-LATCHED AND MADE 20 MORE JAR LICKS AT 24K OVER AND FISH DID NOT COME FREE. PIPE CYCLED OUT AT 50 LICKS, RELEASED WITHOUT PROBLEM AND POOH, CUT 157' OF PIPE. 08/02104 MU WFRD FISHING STRING W/ADDL WT BAR AND 4-1/2" GS AND RIH. TAG JET PUMP AT 8765' CTM AND MAKE 50 JAR LICKS AT 21-22K OVER. JET PUMP DID NOT COME FREE. POOH. SURFACE, CUT 2001 OF PIPE, MAKE UP NEW CTC, SWAP OUT JARS AND ACCELERATOR, ADD 3 RD WEIGHT BAR ANDRIH WITH 41/2" GS. PUMP 15 BBLS DIESEL/XYLENE DID NOT ESTABLISH INJECTION RATE, CIRCULATE IN 1 BBL EP MUD LUBE MIXED WITH 30 BBLS 1% XSLK KCL.MAKE 12 JARS LICKS MAX STRAIGHT PULLS 22K OVER LATCH. POOH. RECOVERED JET PUMP. FISHING NECK SHOWED SIGNS OF HEAVY JARRING. KEYS WERE COMPLETELY LOCKED UP. PROFILE MAY BE TOAST. LOST THREE FIBER PACKING RINGS OFF OF BOTTOM SEAL SECTION. MU 2.3" OD BDJSN W/O CHECKS AND RIH. TAG CARBOLlTE/SAND TOP AT 9273' CTM. START TO REVERSE OUT AND PICKING UP A LOT OF CARBOLlTE BUT CAN NOT MAKE HOLE. MADE TWO TRIPS TO 92701, COULD NOT REVERSE OFF, AND PUH REVERSING. JET PUMP CONDITION REPORT: FINE METAL SHAVINGS (STEEL WOOL CONSISTENCY) FOUND INSIDE PUMP AND AROUND KEYS OF THE LOCK. ALL BUT TWO PIECES OF PACKING MISSING FROM LOWER SET OF PACKING, THE LOWER COUPLE OF PIECES OF PACKING ON THE UPPER SET OF PACKING ARE DAMAGED, LOCK IS STUCK IN THE UP POSITION (INDICATING SAND OR PROPPANT IN THE HOUSING EXPANDER MANDREL AREA), SMALL AMOUNT OF RESIDUAL PROPPANT SEEN INSIDE THE DISASSEMBLED PUMP, ROCK SCREEN WAS CLEAN AND OPEN BORE THROUGH PUMP, NOZZLE AND NOZZLE HOUSING FLOW CUT, VISUAL INSPECTION OF THROAT INDICATES IT IS IN GOOD CONDITION. 08/03/04 MU 2.25" JDN W/CHECKS AND RIH. DISCUSS W/OPS SPVSR AT MPU AND GPB DECIDE TO LEAVE WELL IN ITS CURRENT STATUS AND POOH WHILE CHASING OUT AT 80%. FREEZE PROTECT TUBING TO 3000' WITH 50/50 METHANOL. DRIFTED TUBING WI 3.5" CENT, 2' X 1.875" STEM, 3.60" GAUGE RING TO 9244' WLM. BEAT DOWN. PRETTY SOLlD.POOH WHILE FLUSHING COIL. 08/05/04 CUT 4.5" TUBING AT 8799.51 WHICH WAS 21 ABOVE PACKER. WHP/IA = 0/0. BOTTOM NOT TAGGED. WELL LEFT SHUT IN. ( ( Page ·1.· of 3 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 M PL -43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code f\JPT Phase 8/9/2004 00:00 - 03:00 3.00 RIGU P PRE 03:00 - 06:00 3.00 KILL P DECaMP 06:00 - 08:00 2.00 KILL P DECaMP 08:00 - 08:30 0.50 KILL P DECaMP 08:30 - 09:00 0.50 KILL P DECaMP 09:00 - 13:00 4.00 KILL P DECaMP 13:00 - 16:00 3.00 WHSUR P DECaMP 16:00 - 20:00 4.00 WHSUR P DECaMP 20:00 - 21 :30 1.50 WHSUR P DECaMP 21 :30 - 22:30 1.00 PULL P DECaMP 22:30 - 23:30 1.00 PULL P DECaMP 23:30 - 00:00 0.50 PULL P DECaMP 8/10/2004 00:00 - 07:30 0.00 PULL P DECaMP 07:30 - 09:00 1.50 FISH P DECaMP 09:00 - 10:00 1.00 FISH P DECaMP 10:00 - 16:00 6.00 FISH P DECaMP 16:00 - 16:30 0.50 FISH P DECaMP 16:30 - 00:00 7.50 FISH P DECaMP 8/11/2004 00:00 - 01 :30 1.50 FISH P DECaMP 01 :30 - 04:30 3.00 FISH P DECaMP 04:30 - 06:00 1.50 FISH P DECaMP 06:00 - 06:30 0.50 FISH P DECaMP 06:30 - 07:30 1.00 CLEAN P DECaMP Start: 8/10/2004 Rig Release: 8/14/2004 Rig Number: Spud Date: 1/6/2004 End: 8/14/2004 De~criptiön of Operation~ RDMO MPU-L40; move to MPU-L43 and re-assemble sub base, Pipe Shed, Mud Pits. Accept rig @ 0600 hrs. R/U lines to tree and Tiger Tank. Install HCR valve on IA. Take on 140 F seawater to pits. Rig-Up Lines to tree and Tiger Tank. Finish off-Loading Sea Water. Pressure test Lines at 3,500 psi. Good. Pick-up Lubricator. Pull BPV. Lay down same. TP = 40 psi. CP - 0 psi. PJSM with All. Circulate Well with 120 deg Sea Water at 4 bpm/575 psi. Clean returns. Monitor Well. Slight flow from both sides. SI Well for 30 minutes. No pressure. Open Well and monitor...Well dead. NO Production Tree. N/U BOPE. Pressure test BOPE 250 psi low, 3500 psi high per BP/AOGCC requirements. State's right to witness waived by John Crisp. PIU lubricator, install Well Support XO, pull TWC, and LID same. Fluid level stayed at surface while preparing to P/U Idg jt. No loss or gain. P/U and install landing joint in tubing hanger. Tubing pulled free @ 97K. Pulled hanger to floor. Break out and LID hanger and floor valve from landing joint. Circulate annulus volume of 170 Bbls at 6 BPM, 500 psi and shutdown to monitor well. No gain or loss of fluid during circulation or while shutdown. During circulation, the returns to the pits were clean. POH and LID 4.5", 12.6#, L-80, IBT-M tubing. POOH with Frac String. Lay down 41/2",12.6#, L-80, IBT-M Tubing. Recovered 210 Jts, 1 GLM wlPup Jts, SS w/Pup Jts, and a Chemical Cut Pup Jt Stump. Rig down 4 1/2" Handling Equipment. Clear Floor. Pump out Stack. Install Wear Bushing. Bring Tools to Floor. Rig up for 3 1/2" Drill Pipe. Pick-up BHA #1 as follows: PRT and Extentions, Packer Mill, XO, 3 ea Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, 9 ea Drill Collars. RIH with BHA #1. Single in with 265 Jts 3 1/2" Drill Pipe from Pipe shed. Tag up on packer @ 8794'. PIU kelly & 23.83' pup jt. Break circulation & re-tag up on packer. @ 8794'. Mill packerfrom 8794 to 8799'. PIU 127K, SIO 90K, Rot 105K. Pump 3 BPM @ 600 psi. Torq 6K. 60-80 RPMs. WOB 6-10K. PIU wI 10K over, wt dropped off. Could not go down. Con't to POOH 40'+ & had 5K additional drag thru connection. Appear to have packer drag. Circulate bottoms up at 4 BPM @ 1000 psi. Monitor well, well dead. Prep to POOH. Set back kelly. POOH & stand back DP & DCs. LID BHA & fish. Recovered; cut off jt, packer, 2-10' pups, "XN" nipple, 10' pup & WLEG. Lay down 4 3/4" Drill Collars. Clear and Clean Floor. Rig up to handle BHA #2 and 2 7/8" PAC Drill Pipe for Liner Clean-Out. Printed: 8/14/2004 10:44:09 AM ( (' Page 20f 3 BP Operations Summary Report MPL-43 MPL-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Spud Date: 1/6/2004 End: 8/14/2004 Start: 8/10/2004 Rig Release: 8/14/2004 Rig Number: Description of Operations From - To Hours Task Code NPT Phase DECOMP Make up BHA #2 as Follows: 3" Mule Shoe, 24 Jts 2 7/8" PAC Drill Pipe, XO, Xo, 7" Casing Scraper, Bit sub, Bumper Sub, Oil Jar. DECOMP Run in hole with BHA #2 and 3 1/2" Drill Pipe. Tagged top of Fill at 9,244' (-170 ft above top Perf). DECaMP Begin to wash and reverse Carbolite at 4 bpm/500 psi down to top perf with bbl for bbl returns. Once started washing through Perfs losses went to 1 3/4 bom. Wash and reverse through Perfs. Continue down to 9,531' (62-ft below bottom Perf). Reverse 20 bbls sweep at 4 bpm/500 psi...losses were from 2.2 bpm to 2.6 bpm... however we were able to get sweep back to surface and the returns were clean after the sweep was recovered. DECOMP POOH & LID 3 1/2" DP to TaL. R/U to circulate. DECaMP Displace well wI 300 bbls of clean seawater. 3 BPM @ 1000 psi. DECOMP POOH & LID 31/2" DP. DECaMP LID BHA #2. Clean out assy. DECaMP Clear & clean rig floor. RID handling tools. Pull wear ring. OTHCMP Hold PJSM wI all hands for perforating. R/U wireline equipment. OTHCMP MIU 20' of perf gun. RIH, log & correlate depths. Attempt to perf 9394 to 9414' did not get indication @ surface. POOH. WAIT OTHCMP Safe out Perforating Gun. Gun did not fire. Lay down Gun. SWS trouble shoot electrical systen on Logging Unit. WAIT OTHCMP Repairs completed with Cable Head. Pick-up Gun #1...38/8" x 20' HSC, 6 spf, 60 deg phasing with 3406 PJ charges. OTHCMP (FL = 712')...RIH with Gun #1. Log tie-in pass. Position Gun #1 on depth with top shot at 9,394 - 9,414'. Fire Gun and log off. POOH (FL = 676') all shots fired. Pick-up Gun #2...3 3/8" x 20' HSC, 6 spf, 60 deg phasing, with 3406 PJ charges. Log tie-in pass. Log Gun #2 into position with top shot at 9,312' - 9,332'. Fire Gun and log off. POOH (FL = 680') all shots fired. Rig down SWS. RUNCMP Rig up to handle 27/8" Tbg and ESP equipment. RUNCMP Pick-up and service ESP Assembly. Plug in Moter Lead. Initial Cable check. RUNCMP RIH with ESP Assembly and new 27/8" 6.5 Ib/ft, L-80 Tbg. Ran 248 jts. Pump thru ESP & meg cable every 2000'. 1 BPM @ 1300 psi. RUNCMP Change out reels. Make reel to reel splice in ESP cable. RUNCMP Con't to make reel to reel splice. test same. Cut & slip 84' of drilling line. adjust brakes. RUNCMP Finish PIU & RIH w/2 7/8" tbg. Ran a total of 276 jts. Bottom of string @ 8771'. Pump intake @ 8729'. "XN" Nipple @ 8666'. GLM wI dummy @ 8555'. GLM wI DSOV @ 138'. Used 146 LaSalle Clamps, 5 Protectolizers, 3 Flat guards. PIU Wt 72K, S/O Wt 44K. RUNCMP M/U tbg hanger & PIU landing jt. Install penetrator. Make field splice. DFAL RUNCMP While attempting to connect the Field Connector to the Penetrator is was discovered that the ESP Cable was slipping throught the LaSalle Clamp on the Pup Jt below the Tbg 0.50 CLEAN P 8/11/2004 07:30 - 08:00 3.50 CLEAN P 08:00 - 11 :30 5.50 CLEAN P 11 :30 - 17:00 17:00 - 18:00 18:00 - 19:30 1.00 1.50 CLEAN P 4.00 CLEAN P 0.50 CLEAN P 1.00 CLEAN P 2.00 PERFOB P 19:30 - 23:30 23:30 - 00:00 8/12/2004 00:00 - 01 :00 01 :00 - 03:00 3.00 PERFOB P 03:00 - 06:00 0.50 PERFOB N 06:00 - 06:30 1.50 PERFOB N 06:30 - 08:00 3.50 PERFOB P 08:00 - 11 :30 0.50 RUNCOMP 3.50 RUNCOrvP 11 :30 - 12:00 12:00 - 15:30 8.00 RUNCOI\.IP 15:30 - 23:30 0.50 RUNCOMP 2.00 RUNCOMP 23:30 - 00:00 8/13/2004 00:00 - 02:00 1.00 RUNCOI\.IP 02:00 - 03:00 3.00 RUNCOMP 03:00 - 06:00 5.00 RUNCOMN 06:00 - 11 :00 Printed: 8/14/2004 10:44:09 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: (' ( Page 3 öf3 BP Operations Summary Report MPL-43 MPL-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 8/13/2004 06:00 - 11 :00 From... To Hours Task Code·NPT 5.00 RUNCOIVN Date 11 :00 - 14:00 Start: 8/10/2004 Rig Release: 8/14/2004 Rig Number: Spud Date: 1/6/2004 End: 8/14/2004 DescriptionÓfOperations DFAL RUNCMP Hanger. One Stand of Tbg was pulled and it was discovered that the next two LaSalle Clamps also let the ESP Cable slid through. After measuring several "new style clamps" the clamps were found to be 10 -13/1000 oversized. Discussed problem with Centrilift in Anch, MPU Well Ops Super, Anch Eng. Decission was made to POOH to were the change from the old style to the new style was made (132 Jts) and run back in hole using old style LaSalle to surface. Rig back up to pull ESP Cable and 2 7/8" Tbg. WO half of a load of Sea Water for displacement fluid...as Pits were already cleaned for the Rig move. DFAL RUNCMP Take on Sea Water in Pits. Start POOH with 27/8" Tbg and ESP Cable. Remove "new style" Clamps. Pulled 43 Stands to the "change" from new style clamps to old style. ESP Cable was kinked and twisted from the slack sliding down hole. Pulled 5 more stands to make sure that Old style LaSalle Clamps were holding properly...good. Cut ESP Cable. Load new Reel in Spooling Unit. Make Reel to Reel splice. Test splice. RIH wI 48 stands of 27/8" tbg. Pump thru pump & meg cable every 2000'. M/U hanger & landing jt. Install penetrator in hanger. Make field connection. Plug into penetrator & test connection. Land completion. RILDS. LID landing jt. Set TWC. Check ESP cable. N/D BOPE. Finish N/D BOPE. N/U & test tree. & void. Make final check on ESP. M/U lubricator. Pull TWC. Install & test BPV. LID lubricator. Secure tree & cellar. Release Rig @ 0300 hrs. RDMO to MPF-61. 3.00 RUNCOI\.IN 14:00 - 18:00 4.00 RUNCOIVN DFAL RUNCMP 18:00 - 21 :00 3.00 RUNCOI\.IN DFAL RUNCMP 21 :00 - 21 :30 0.50 RUNCOI\IN DFAL RUNCMP 21 :30 - 23:00 1.50 RUNCOI\If\J DFAL RUNCMP 23:00 - 23:30 0.50 RUNCOI\.IN DFAL RUNCMP 23:30 - 00:00 0.50 BOPSUR P RUNCMP 8/14/2004 00:00 - 00:30 0.50 BOPSUR P RUNCMP 00:30 - 02:00 1.50 WHSUR P RUNCMP 02:00 - 03:00 1.00 WHSUR P RUNCMP 03:00 - 06:00 3.00 RIGD P POST Printed: 8/14/2004 1044:09 AM ( ( 16-Jul-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPL-43 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,047.03' MD Window / Kickoff Survey: 6,097.00' MD (if applicable) Projected Survey: 9,645.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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')~K ~:518 1/ I ¡J ¡ 1 Date ! (I) '" ~~"J rI.J¡'tJy Signed Jj.ft'lf1v-t~ UlZU.N} Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ ~~- 2:1 '- ( Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPL MPL-43 Job No. AKZZ0002851292, Surveyed: 21 June, 2004 Surtley Report 13 July, 2004 'µ ) c ~ Your Ref: API 500292319000 Surface Coordinates: 6031825.26 N, 544837.72 E (70029' 52.1387" N, 149037'59.9824" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ y -l Surface Coordinates relative to Project H Reference: 1031825.26 N, 44837.72 E (Grid) Surface Coordinates relative to Structure Reference: 2024.08 N, 320.39 E (True) Kelly Bushing Elevation: 50.80ft above Mean Sea Level Kelly Bushing Elevation: 50.80ft above Project V Reference Kelly Bushing Elevation: 50. 80ft above Structure Reference SpE!!ï'I'Y-!5UI'1 cAILLING SERViCes A Halliburton Company JEF'N'--:VE '-- '-.-' Survey Ref: svy1429 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43 Your Ref: AP/500292319000 Job No. AKZZ0002851292, Surveyed: 21 June, 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) 6047.03 49.750 350.560 4355.72 4406.52 3682.80 N 436.51 W 6035505.36 N 544379.01 E 3708.50 Tie On Point MWD+IIFR+MS 6097.00 49.570 350.410 4388.07 4438.87 3720.37 N 442.80 W 6035542.89 N 544372.48 E 0.427 3746.53 Window Point 6112.24 48.930 350.580 4398.01 4448.81 3731.76 N 444.71 W 6035554.26 N 544370.51 E 4.284 3758.06 6208.04 44.370 353.720 4463.77 4514.57 3800.72 N 454.29 W 6035623.17 N 544360.51 E 5.322 3827.66 6303.16 39.600 352.730 4534.45 4585.25 3863.89 N 461.77 W 6035686.29 N 544352.65 E 5.063 3891.27 ~ 6400.08 36.790 352.870 4610.62 4661.42 3923.34 N 469.28 W 6035745.70 N 544344.78 E 2.901 3951.19 6495.30 36.410 352.450 4687.06 4737.86 3979.65 N 476.53 W 6035801.96 N 544337.19 E 0.478 4007.95 6591.67 36.000 352.140 4764.82 4815.62 4036.06 N 484.16 W 6035858.32 N 544329.22 E 0.466 4064.86 6688.05 35.550 354.490 4843.02 4893.82 4092.01 N 490.73 W 6035914.23 N 544322.32 E 1.500 4121.19 6783.22 37.280 356.770 4919.61 4970.41 4148.33 N 495.01 W 6035970.53 N 544317.69 E 2.308 4177.64 6879.14 36.750 355.840 4996.20 5047.00 4205.95 N 498.73 W 6036028.13 N 544313.63 E 0.804 4235.33 6975.54 35.950 355.620 5073.84 5124.64 4262.93 N 502.98 W 6036085.08 N 544309.03 E 0.841 4292.42 7070.94 36.270 356.280 5150.91 5201.71 4319.01 N 506.95 W 6036141.14 N 544304.72 E 0.528 4348.60 7164.98 35.440 355.540 5227.13 5277.93 4373.96 N 510.88 W 6036196.05 N 544300.47 E 0.996 4403.64 7264.41 35.000 356.630 5308.36 5359.16 4431 .16 N 514.79 W 6036253.24 N 544296.20 E 0.772 4460.92 7359.97 36.390 353.750 5385.97 5436.77 4486.71 N 519.49 W 6036308.75 N 544291.17 E 2.282 4516.65 7456.77 37.330 354.730 5463.42 5514.22 4544.48 N 525.31 W 6036366.49 N 544285.00 E 1.145 4574.71 7553.07 36.810 353.680 5540.26 5591.06 4602.23 N 531.17 W 6036424.20 N 544278.80 E 0.851 4632.75 7649.01 36.160 353.670 5617.40 5668.20 4658.93 N 537.46 W 6036480.86 N 544272.17 E 0.678 4689.80 7745.55 35.740 353.830 5695.55 5746.35 4715.27 N 543.63 W 6036537.16 N 544265.66 E 0.446 4746.47 7841.62 35.290 354.160 5773.75 5824.55 4770.77 N 549.47 W 6036592.63 N 544259.48 E 0.509 4802.28 7937.90 35.580 353.610 5852.19 5902.99 4826.27 N 555.41 W 6036648.09 N 544253.20 E 0.448 4858.1 0 --- 8033.54 35.030 354.460 5930.24 5981.04 4881.24 N 561.16W 6036703.03 N 544247.12 E 0.771 4913.37 8129.87 32.840 355.120 6010.16 6060.96 4934.79 N 566.05 W 6036756.55 N 544241.91 E 2.305 4967.13 8224.34 30.950 356.600 6090.36 6141.16 4984.57 N 569.67 W 6036806.30 N 544237.99 E 2.165 5017.00 8320.79 29.370 356.880 6173.76 6224.56 5032.95 N 572.43 W 6036854.66 N 544234.94 E 1.645 5065.39 8417.36 28.110 357.420 6258.43 6309.23 5079.32 N 574.74 W 6036901.02 N 544232.35 E 1.332 5111.73 8513.15 27.510 356.880 6343.15 6393.95 5123.96 N 576.96 W 6036945.64 N 544229.86 E 0.679 5156.34 8609.59 22.720 356.540 6430.45 6481.25 5164.81 N 579.30 W 6036986.48 N 544227.27 E 4.969 5197.20 8705.03 21.760 355.890 6518.79 6569.59 5200.86 N 581.68 W 6037022.51 N 544224.68 E 1.038 5233.28 13 July, 2004 - 10:36 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43 Your Ref: AP/S00292319000 Job No. AKZZ0002851292, Surveyed: 21 June, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth (ncl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8801.68 19.890 358.160 6609.12 6659.92 5235.16 N 583.49 W 6037056.80 N 544222.66 E 2.107 5267.58 8892.31 19.380 357.780 6694.48 6745.28 5265.59 N 584.57 W 6037087.23 N 544221.40 E 0.580 5297.94 8965.69 19.500 356.510 6763.68 6814.48 5289.99 N 585.79 W 6037111.62 N 544220.03 E 0.599 5322.32 9031.82 14.890 355.370 6826.84 6877.64 5309.48 N 587.15 W 6037131.10 N 544218.56 E 6.989 5341.84 9126.39 11.860 353.730 6918.83 6969.63 5331.26 N 589.19 W 6037152.87 N 544216.38 E 3.229 5363.71 9224.25 9.630 350.800 7014.97 7065.77 5349.34 N 591.60 W 6037170.93 N 544213.87 E 2.345 5381.95 '.-..-/ 9320.83 7.350 343.040 7110.49 7161.29 5363.22 N 594.69 W 6037184.80 N 544210.69 E 2.637 5396.09 9416.98 5.800 347.050 7206.00 7256.80 5373.84 N 597.57 W 6037195.40 N 544207.74 E 1.680 5406.96 9512.21 5.200 351.400 7300.80 7351.60 5382.80 N 599.30 W 6037204.34 N 544205.96 E 0.767 5416.05 9581.07 5.280 353.730 7369.37 7420.17 5389.03 N 600.11 W 6037210.57 N 544205.11 E 0.330 5422.34 9645.00 5.280 353.730 7433.03 7483.83 5394.88 N 600.75 W 6037216.42 N 544204.43 E 0.000 5428.22 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 No,things 2nd E2sUngs are relative to NÞ-.o27 A!aska 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 353.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9645.00ft., The Bottom Hole Displacement is 5428.22ft., in the Direction of 353.646° (True). "~ 13 July, 2004 - 10:36 Page 3 of4 DrillQuest 3.03.06.002 Milne Point Unit Comments Measured Depth (ft) 6047.03 6097.00 9645.00 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43 Your Ref: AP/500292319000 Job No. AKZZ0002851292, Surveyed: 21 June, 2004 BPXA Station Coordinates TVD Northings Eastings ~) ~) ~ij 4406.52 4438.87 7483.83 Comment 3682.80 N 3720.37 N 5394.88 N 436.51 W 442.80 W 600.75 W Tie On Point Window Point Projected Survey ~ Survey tool program for MPL-43 Fro m Measured Vertical Depth Depth (H) (ft) 0.00 6047.03 13 July, 2004 - 10:36 0.00 4406.52 To Measured Vertical Depth Depth Survey Too! Description (ft) (ft) 6047.03 9645.00 4406.52 Tolerable Gyro (MPL-43PBI) 7483.83 MWD+IIFR+MS (MPL-43) c___ Page 4 of4 DrillQuest 3.03.06.002 ) AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPL-43 MWD ') 16-Jul-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,047.03' MD Window / Kickoff Survey: 6,097.00' MD (if applicable) Projected Survey: 9,645.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 I b J v~ 2.tü ''-1 1W ð /¡~I Signed Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) ~.u1 7À ~.,/J.- Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPL MPL-43 MWD --~ Job No. AKMW0002851292, Surveyed: 21 June, 2004 Survey Report 13 July, 2004 ~-J CJ ~ \ Your Ref: API 500292319000 Surface Coordinates: 6031825.26 N, 544837.72 E (70029' 52.1387" N, 149037' 59.9824" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 .----- ?-J ~ ( Surface Coordinates relative to Project H Reference: 1031825.26 N, 44837.72 E (Grid) Surface Coordinates relative to Structure Reference: 2024.08 N, 320.39 E (True) Kelly Bushing Elevation: 50. 80ft above Mean Sea Level Kelly Bushing Elevation: 50.80ft above Project V Reference Kelly Bushing Elevation: 50. 80ft above Structure Reference sper-aI'Y-SUI'1 DRILLING seAVIc:es A Halliburton Company Survey Ref: svy1433 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43 MWD Your Ref: API 500292319000 Job No. AKMW0002851292, Surveyed: 21 June, 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) 6047.03 49.750 350.870 4355.74 4406.54 3686.52 N 393.71 W 6035509.34 N 544421.78 E 3707A4 Tie On Point 6097.00 49.570 350.410 4388.08 4438.88 3724.10 N 399.90 W 6035546.88 N 544415.36 E 0.789 3745A7 Window Point 6112.24 48.930 351.130 4398.03 4448.83 3735.49 N 401.76 W 6035558.26 N 544413A4 E 5.518 3757.00 6208.04 44.370 354.040 4463.78 4514.58 3804.53 N 410.81 W 6035627.25 N 544403.97 E 5.247 3826.62 6303.16 39.600 353.050 4534A7 4585.27 3867.74 N 417.93 W 6035690.41 N 544396A6 E 5.063 3890.23 6400.08 36.790 355.330 4610.64 4661.44 3927.35 N 424.04 W 6035749.98 N 544390.00 E 3.243 3950.14 .~ 6495.30 36.410 354.500 4687.08 4737.88 3983.89 N 429.07 W 6035806.49 N 544384.63 E 0.655 4006.90 6591.67 36.000 353.440 4764.84 4815.64 4040.50 N 435.04 W 6035863.06 N 544378.31 E 0.777 4063.82 6688.05 35.550 355.350 4843.04 4893.84 4096.57 N 440.55 W 6035919.10 N 544372A 7 E 1.249 4120.15 6783.22 37.280 357.350 4919.63 4970.43 4152.94 N 444.13 W 6035975.45 N 544368.55 E 2.204 4176.57 6879.14 36.750 355.870 4996.22 5047.02 4210.58 N 447.54 W 6036033.07 N 544364.79 E 1.081 4234.24 6975.54 35.950 356.020 5073.86 5124.66 4267.58 N 451.58 W 6036090.04 N 544360A 1 E 0.835 4291.33 7070.94 36.270 356.360 5150.93 5201.73 4323.68 N 455.31 W 6036146.11 N 544356.33 E 0.396 4347 A9 7164.98 35.440 355.560 5227.15 5277.95 4378.62 N 459.19 W 6036201.03 N 544352.13 E 1.014 4402.53 7264.41 35.000 356.930 5308.38 5359.18 4435.84 N 462.95 W 6036258.22 N 544348.02 E 0.910 4459.81 7359.97 36.390 354.010 5385.99 5436.79 4491.40 N 467.37 W 6036313.76 N 544343.26 E 2.301 4515.52 7456.77 37.330 354.990 5463.44 5514.24 4549.20 N 472.93 W 6036371.52 N 544337.35 E 1.145 4573.58 7553.07 36.810 354.580 5540.28 5591.08 4607.01 N 478.21 W 6036429.30 N 544331.73 E 0.598 4631.62 7649.01 36.160 354.250 5617.42 5668.22 4663.78 N 483.76 W 6036486.04 N 544325.84 E 0.708 4688.66 7745.55 35.740 354.220 5695.57 5746.37 4720.17 N 489.45 W 6036542.40 N 544319.80 E 0.435 4745.33 7841.62 35.290 355.230 5773.77 5824.57 4775.74 N 494.59 W 6036597.93 N 544314.33 E 0.770 4801.13 7937.90 35.580 354.400 5852.21 5903.01 4831.34 N 499.63 W 6036653.49 N 544308.95 E 0.584 4856.93 8033.54 35.030 355.000 5930.26 5981.06 4886.37 N 504.74 W 6036708.50 N 544303.51 E 0.680 4912.20 ~' 8129.87 32.840 355.140 6010.18 6060.98 4939.95 N 509.36 W 6036762.04 N 544298.57 E 2.275 4965.95 8224.34 30.950 357.080 6090.39 6141.19 4989.74 N 512.77 W 6036811.81 N 544294.86 E 2.276 5015.81 8320.79 29.370 357.290 6173.78 6224.58 5038.13 N 515.15 W 6036860.19 N 544292.18 E 1.642 5064.18 8417.36 28.110 357.930 6258.45 6309.25 5084.53 N 517.09 W 6036906.57 N 544289.96 E 1.343 5110.50 8513.15 27.510 357.100 6343.18 6393.98 5129.17 N 519.03 W 6036951.21 N 544287.76 E 0.745 5155.08 8609.59 22.720 356.590 6430.47 6481.27 5170.03 N 521.26 W 6036992.05 N 544285.28 E 4.972 5195.94 8705.03 21.760 356.100 6518.81 6569.61 5206.08 N 523.56 W 6037028.09 N 544282.76 E 1.024 5232.02 8801.68 19.890 358.720 6609.14 6659.94 5240.39 N 525.15 W 6037062.39 N 544280.97 E 2.161 5266.30 8892.31 19.380 358.290 6694.50 6745.30 5270.84 N 525.94 W 6037092.83 N 544279.99 E 0.585 5296.64 8965.69 19.500 1.290 6763.70 6814.50 5295.25 N 526.03 W 6037117.24 N 544279.76 E 1.370 5320.91 9031.82 14.890 2.070 6826.86 6877.66 5314.79 N 525.4 7 W 6037136.78 N 544280.19 E 6.980 5340.26 9126.39 11.860 358.000 6918.86 6969.66 5336.65 N 525.37 W 6037158.64 N 544280.16 E 3.353 5361.98 13 July, 2004 - 10:37 Page 20f4 DrillQuest 3.03.06.002 Milne Point Unit Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9224.25 9.630 351.050 7015.00 7065.80 9320.83 7.350 343.520 7110.52 7161.32 9416.98 5.800 347.350 7206.03 7256.83 9512.21 5.200 351.730 7300.82 7351.62 9581.07 5.280 354.080 7369.40 7420.20 9645.00 5.280 354.080 7433.05 7483.85 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43 MWD Your Ref: API 500292319000 Job No. AKMW0002851292, Surveyed: 21 June, 2004 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 5354.79 N 527.00 W 6037176.77 N 544278.43 E 2.632 5380.19 5368.69 N 530.01 W 6037190.66 N 544275.33 E 2.622 5394.34 5379.33 N 532.82 W 6037201.28 N 544272.46 E 1.674 5405.22 5388.30 N 534.49 W 6037210.24 N 544270.73 E 0.769 5414.32 5394.54 N 535.27 W 6037216.47 N 544269.92 E 0.333 5420.61 5400.39 N 535.87 W 6037222.32 N 544269.28 E 0.000 5426.49 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 353.620° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9645.00ft., The Bottom Hole Displacement is 5426.91ft., in the Direction of 354.333° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6047.03 6097.00 9645.00 4406.54 4438.88 7483.85 393.71 W 399.90 W 535.87 W 3686.52 N 3724.10 N 5400.39 N 13 July, 2004 - 10:37 Comment Tie On Point Window Point Projected Survey "~ Page 3 0'4 DrillQuest 3.03.06.002 Milne Point Unit Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43 MWD Your Ref: API 500292319000 Job No. AKMW0002851292, Surveyed: 21 June, 2004 BPXA Survey tool program for MPL-43 MWD Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 182.00 0.00 181.99 13 July, 2004 - 10:37 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 182.00 9645.00 181.99 Tolerable Gyro (MPL-43PB1 MWD) 7483.85 MWD Magnetic (MPL-43PB1 MWD) ~ ~ Page 4 of4 DrillQuest 3.03.06.002 ) ) 16-J u 1-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPL-43 PB1 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 9,306.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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, At< 99518 ? / I Date I~ ~JJ) ~ ~ Signed '¡µ ~/JvJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager "~" \ -, - ).Á 4 . I (j.> ¿/ . Attachment(s) i' Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPL MPL-43PB1 Job No. AKZZ0002851292. Surveyed: 12 January. 2004 Survey Report 13 July, 2004 >u c- vJ ! Y ,..., -l Your Ref: API 500292319070 Surface Coordinates: 6031825.26 N. 544837.72 E (70029' 52.1387" N. 149037'59.9824" W) Grid Coordinate System: NAD27 Alaska State Planes. Zone 4 Surface Coordinates relative to Project H Reference: 1031825.26 N. 44837.72 E (Grid) Surface Coordinates relative to Structure Reference: 2024.08 N. 320.39 E (True) Kelly Bushing Elevation: 50.80ft above Mean Sea Level Kelly Bushing Elevation: 50. 80ft above Project V Reference Kelly Bushing Elevation: 50.80ft above Structure Reference SpE!.l'r-'y-sul'1 DFtlL LINGSe A: vices A Halliburton Company )=F.I\ --- , 1, ¡ Vè _/ ...~ Survey Ref: svy1401 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 Your Ref: API 500292319070 Job No. AKZZ0002851292, Surveyed: 12 January, 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 -50.80 0.00 0.00 N 0.00 E 6031825.26 N 544837.72 E 0.00 Tolerable Gyro 182.00 0.900 34.000 131.19 181.99 1.19 N 0.80 E 6031826.45 N 544838.51 E 0.495 1.07 MWD+IIFR+MS 387.70 2.500 51.210 336.80 387.60 5.34 N 5.20 E 6031830.63 N 544842.89 E 0.808 4.59 478.26 3.160 52.750 427.25 478.05 8.08 N 8.73 E 6031833.40 N 544846.40 E 0.734 6.83 570.92 5.260 49.380 519.65 570.45 12.39 N 13.98 E 6031837.74 N 544851.63 E 2.281 10.40 661.84 7.890 39.330 609.97 660.77 19.94 N 21.10 E 6031845.32 N 544858.70 E 3.147 16.91 - 756.46 11.410 28.880 703.24 754.04 33.16 N 29.74 E 6031858.60 N 544867.26 E 4.141 28.85 848.98 14.330 26.950 793.43 844.23 51.38 N 39.35 E 6031876.88 N 544876.76 E 3.190 45.62 943.77 16.460 17.620 884.82 935.62 74.65 N 48.74 E 6031900.20 N 544886.01 E 3.440 67.40 1039.50 20.100 12.350 975.71 1026.51 103.65 N 56.37 E 6031929.25 N 544893.46 E 4.172 95.12 1134.83 25.320 8.330 1063.63 1114.43 139.85 N 62.83 E 6031965.49 N 544899.70 E 5.710 130.12 1228.16 26.4 70 8.430 1147.59 1198.39 180.17 N 68.77 E 6032005.85 N 544905.40 E 1.233 169.27 1323.13 31.300 6.550 1230.72 1281.52 225.65 N 74.69 E 6032051.35 N 544911.05 E 5.174 213.53 1415.27 34.030 7.130 1308.28 1359.08 275.02 N 80.62 E 6032100.76 N 544916.68 E 2.982 261.65 1510.34 34.200 5.300 1386.99 1437.79 328.02 N 86.39 E 6032153.80 N 544922.13 E 1.094 313.40 1605.32 34.070 3.240 1465.61 1516.41 381.16 N 90.36 E 6032206.96 N 544925.78 E 1.225 365.52 1700.59 34.480 2.960 1544.34 1595.14 434.74 N 93.26 E 6032260.55 N 544928.36 E 0.461 418.22 1793.93 35.590 0.840 1620.76 1671.56 488.28 N 95.02 E 6032314.11 N 544929.80 E 1.765 471.04 1888.45 36.350 0.480 1697.26 1748.06 543.80 N 95.66 E 6032369.62 N 544930.10 E 0.835 525.96 1982.24 37.560 359.530 1772.21 1823.01 600.18 N 95.66 E 6032426.01 N 544929.76 E 1 .427 581.83 2077.24 39.800 358.850 1846.37 1897.17 659.54 N 94.81 E 6032485.36 N 544928.55 E 2.400 640.76 2171.72 42.120 357.080 1917.71 1968.51 721.43 N 92.59 E 6032547.23 N 544925.96 E 2.745 702.38 2264.78 44.700 356.300 1985.31 2036.11 785.27 N 88.89 E 6032611.05 N 544921.87 E 2.832 766.14 --' 2359.80 47.750 354.490 2051.04 2101.84 853.64 N 83.35 E 6032679.39 N 544915.92 E 3.492 834.64 2454.76 50.300 351.690 2113.31 2164.11 924.79 N 74.70 E 6032750.48 N 544906.84 E 3.488 906.30 2549.60 51.340 350.120 2173.23 2224.03 997.37 N 63.07 E 6032823.00 N 544894.77 E 1.688 979.79 2645.14 51.480 350.220 2232.82 2283.62 1070.96 N 50.32 E 6032896.50 N 544881.58 E 0.168 1054.42 2738.35 51.500 350.230 2290.86 2341.66 1142.83 N 37.94 E 6032968.30 N 544868.76 E 0.023 1127.31 2830.66 51.480 348.710 2348.34 2399.14 1213.85 N 24.74 E 6033039.23 N 544855.13 E 1 .289 1199.46 2925.20 51.250 349.100 2407.37 2458.17 1286.31 N 10.52 E 6033111.61 N 544840.48 E 0.404 1273.18 3016.52 50.700 349.360 2464.87 2515.67 1356.01 N 2.73W 6033181.23 N 544826.81 E 0.642 1344.02 3111.81 50.710 349.450 2525.21 2576.01 1428.49 N 16.29 W 6033253.63 N 544812.81 E 0.074 1417.67 3205.77 50.250 349.530 2585.01 2635.81 1499.76 N 29.51 W 6033324.81 N 544799.16 E 0.494 1490.07 3300.47 50.200 349.910 2645.59 2696.39 1571.37 N 42.50 W 6033396.35 N 544785.74 E 0.313 1562.78 3393.47 50.380 350.390 2705.01 2755.81 1641.86 N 54.74 W 6033466.76 N 544773.08 E 0.442 1634.28 13 July, 2004 - 10:46 Page 2 of5 DrillQuest 3.03.06.002 Halliburlon Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 Your Ref: API 500292319070 Job No. AKZZ0002851292, Surveyed: 12 January, 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) (°/1 DOft) 3488.00 51.470 350.700 2764.60 2815.40 1714.25N 66.79 W 6033539.08 N 544760.59 E 1.181 1707.63 3582.82 52.190 350.940 2823.19 2873.99 1787.84 N 78.69 W 6033612.59 N 544748.25 E 0.785 1782.15 3677.20 52.290 351.390 2880.99 2931.79 1861.57 N 90.15 W 6033686.25 N 544736.35 E 0.392 1856.75 3771.51 51.650 352.200 2939.09 2989.89 1935.10 N 100.75 W 6033759.71 N 544725.30 E 0.958 1931.03 3865.49 51.880 349.450 2997.26 3048.06 2007.96 N 112.52 W 6033832.50 N 544713.09 E 2.311 2004.82 3960.04 51.920 349.300 3055.60 3106.40 2081.09 N 126.24 W 6033905.55 N 544698.93 E 0.132 2079.13 - 4052.92 51.500 349.470 3113.15 3163.95 2152.74 N 139.67 W 6033977.12 N 544685.07 E 0.474 2151.94 4146.90 50.600 350.250 3172.23 3223.03 2224.68 N 152.54 W 6034048.98 N 544671.76 E 1.155 2224.96 4240.54 51.570 348.770 3231.06 3281.86 2296.32 N 165.81 W 6034120.54 N 544658.06 E 1.608 2297.73 4333.68 52.400 349.290 3288.42 3339.22 2368.36 N 179.77 W 6034192.49 N 544643.66 E 0.994 2370.99 4425.01 52.950 349.360 3343.79 3394.59 2439.73 N 193.22 W 6034263.78 N 544629.78 E 0.605 2443.52 4519.72 52.750 349.340 3400.99 3451.79 2513.92 N 207.18 W 6034337.88 N 544615.38 E 0.212 2518.91 4615.00 54.190 349.100 3457.70 3508.50 2589.12 N 221.50 W 6034413.00 N 544600.61 E 1.525 2595.37 4710.21 54.110 349.120 3513.46 3564.26 2664.91 N 236.08 W 6034488.69 N 544585.57 E 0.086 2672.42 4802.88 53.080 348.900 3568.46 3619.26 2738.12 N 250.29 W 6034561.82 N 544570.91 E 1.128 2746.89 4898.07 51.570 347.850 3626.64 3677.44 2811.92 N 265.4 7 W 6034635.52 N 544555.29 E 1.811 2822.05 4992.84 52.570 347.560 3684.89 3735.69 2884.95 N 281.39 W 6034708.46 N 544538.93 E 1.082 2896.56 5087.98 51.160 348.420 3743.64 3794.44 2958.14 N 296.96 W 6034781.56 N 544522.92 E 1.644 2971.19 5182.62 51.180 347.920 3802.98 3853.78 3030.30 N 312.08 W 6034853.62 N 544507.37 E 0.412 3044.72 5277.18 51.910 348.4 70 3861 .79 3912.59 3102.78 N 327.22 W 6034926.01 N 544491.78 E 0.896 3118.59 5372.53 52.500 348.330 3920.22 3971.02 3176.59 N 342.38 W 6034999.73 N 544476.19 E 0.630 3193.76 5466.62 50.970 348.730 3978.49 4029.29 3248.99 N 357.07 W 6035072.04 N 544461.06 E 1.660 3267.48 5559.91 49.890 349.090 4037.92 4088.72 3319.56 N 370.90 W 6035142.52 N 544446.80 E 1.195 3339.27 5655.81 49.290 349.570 4100.09 4150.89 3391.31 N 384.42 W 6035214.19 N 544432.85 E 0.733 3412.19 ~ 5749.49 48.770 349.580 4161.51 4212.31 3460.88 N 397.22 W 6035283.68 N 544419.63 E 0.555 3482.85 5842.91 47.990 350.080 4223.56 4274.36 3529.62 N 409.56 W 6035352.34 N 544406.88 E 0.926 3552.62 5937.81 50.360 349.710 4285.59 4336.39 3600.31 N 422.16 W 6035422.96 N 544393.85 E 2.515 3624.36 6047.03 49.750 350.560 4355.72 4406.52 3682.80 N 436.51 W 6035505.36 N 544379.01 E 0.817 3708.04 6136.93 49.420 350.290 4414.00 4464.80 3750.30 N 447.89 W 6035572.79 N 544367.21 E 0.432 3776.45 6228.27 51.130 349.650 4472.38 4523.18 3819.47 N 460.13 W 6035641.89 N 544354.56 E 1.948 3846.64 6322.83 51.270 350.230 4531.63 4582.43 3892.03 N 473.00 W 6035714.37 N 544341.25 E 0.500 3920.28 6415.90 50.920 350.000 4590.08 4640.88 3963.38 N 485.44 W 6035785.64 N 544328.38 E 0.422 3992.65 6510.98 50.270 349.420 4650.44 4701 .24 4035.67 N 498.56 W 6035857.85 N 544314.83 E 0.830 4066.04 6604.48 51.830 349.850 4709.21 4760.01 4107.19 N 511.64 W 6035929.29 N 544301.32 E 1.706 4138.68 6697.96 52.900 349.670 4766.29 4817.09 4180.04 N 524.80 W 6036002.06 N 544287.72 E 1.155 4212.64 13 July, 2004 - 10:46 Page 3 of5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 Your Ref: API 500292319070 Job No. AKZZ0002851292, Surveyed: 12 January, 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) 6792.43 52.260 349.330 4823.70 4874.50 4253.81 N 538.4 7 W 6036075.75 N 544273.60 E 0.735 4287.58 6884.73 51.530 348.360 4880.66 4931.46 4325.07 N 552.52 W 6036146.92 N 544259.12 E 1.144 4360.08 6978.88 50.470 348.670 4939.91 4990.71 4396.77 N 567.09 W 6036218.53 N 544244.12 E 1.155 4433.09 7071.08 49.540 348.560 4999.17 5049.97 4466.01 N 581.03 W 6036287.69 N 544229.76 E 1.013 4503.58 7165.59 50.550 350.400 5059.86 5110.66 4537.24 N 594.25 W 6036358.83 N 544216.11 E 1.835 4575.93 7260.22 50.300 350.640 5120.15 5170.95 4609.18 N 606.26 W 6036430.70 N 544203.67 E 0.329 4648.84 -" 7356.00 46.780 350.600 5183.55 5234.35 4679.99 N 617.96 W 6036501.44 N 544191.54 E 3.675 4720.58 7447.81 45.850 349.880 5246.97 5297.77 4745.42 N 629.21 W 6036566.80 N 544179.90 E 1.161 4786.93 7541.08 43.390 350.010 5313.35 5364.15 4809.92 N 640.65 W 6036631.23 N 544168.07 E 2.639 4852.38 7635.55 40.980 350.360 5383.35 5434.15 4872.43 N 651.47 W 6036693.67 N 544156.87 E 2.563 4915.77 7729.24 38.040 349.560 5455.62 5506.42 4931.12 N 661.84 W 6036752.29 N 544146.14 E 3.185 4975.33 7825.86 35.240 349.650 5533.14 5583.94 4987.82 N 672.25 W 6036808.94 N 544135.40 E 2.898 5032.92 7921.91 33.480 350.130 5612.43 5663.23 5041 .19 N 681.77 W 6036862.24 N 544125.55 E 1.854 5087.08 8013.39 30.520 350.540 5690.00 5740.80 5088.97 N 689.91 W 6036909.98 N 544117.12 E 3.244 5135.52 8108.58 26.590 350.850 5773.59 5824.39 5133.86 N 697.28 W 6036954.82 N 544109.49 E 4.132 5181.00 8201.54 24.060 348.010 5857.62 5908.42 5172.95 N 704.52 W 6036993.86 N 544102.00 E 3.018 5220.70 8294.49 20.530 351.270 5943.61 5994.41 5207.60 N 710.93 W 6037028.48 N 544095.38 E 4.023 5255.91 8387.79 17.950 349.620 6031.69 6082.49 5237.92 N 716.01 W 6037058.77 N 544090.13 E 2.826 5286.63 8483.42 14.560 348.740 6123.48 6174.28 5264.21 N 721.01 W 6037085.03 N 544084.96 E 3.554 5313.36 8577.37 13.170 346.450 6214.69 6265.49 5286.20 N 725.83 W 6037106.99 N 544080.02 E 1.590 5335.79 8672.07 11 .160 348.950 6307.26 6358.06 5305.69 N 730.11 W 6037126.44 N 544075.62 E 2.194 5355.68 8765.50 9.030 352.720 6399.24 6450.04 5321.83 N 732.77 W 6037142.58 N 544072.86 E 2.386 5372.04 8859.89 6.300 350.920 6492.78 6543.58 5334.30 N 734.53 W 6037155.03 N 544071.02 E 2.903 5384.62 _'"' 8953.97 3.600 334.960 6586.51 6637.31 5342.07 N 736.59 W 6037162.79 N 544068.91 E 3.195 5392.61 9047.94 1.050 337.360 6680.39 6731.19 5345.54 N 738.18 W 6037166.25 N 544067.31 E 2.715 5396.26 9142.69 1.550 110.200 6775.13 6825.93 5345.90 N 737.31 W 6037166.62 N 544068.18 E 2.524 5396.49 9306.00 1.550 110.200 6938.38 6989.18 5344.37 N 733.16 W 6037165.11 N 544072.33 E 0.000 5394.43 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 352.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9306.00f1., The Bottom Hole Displacement is 5394.43ft., in the Direction of 352.189° (True). 13 July, 2004 - 10:46 Page 4 of5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 Your Ref: AP/500292319070 Job No. AKZZ0002851292, Surveyed: 12 January, 2004 Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 9306.00 6989.18 5344.37 N 733.16 W Projected Survey ~.'" Survey tool program for MPL-43PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 182.00 0.00 181.99 182.00 9306.00 181.99 Tolerable Gyro 6989.18 MWD+IIFR+MS c~ 13 July, 2004 - 10:46 Page 50f5 DrillQuest 3.03.06.002 ) ) 16-Jul-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPL-43 PB1 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 9,306.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 L'~/¿ / V? /..i D1h A Date ¡ (f\ ~L~ ~\"\ Signed I:kv zJ¿ ~ ' Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ;{ (j ~-2).. Y Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPL MPL-43PB1 MWD ~ Job No. AKMW0002851292, Surveyed: 12 January, 2004 Survey Report 13 July, 2004 ~ Your Ref: API 500292319070 Surface Coordinates: 6031825.26 N, 544837.72 E (70029'52.1387" N, 149037' 59.9824" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ c:.. \.../V ; )-J ~ ( "'- Surface Coordinates relative to Project H Reference: 1031825.26 N, 44837.72 E (Grid) Surface Coordinates relative to Structure Reference: 2024.08 N, 320.39 E (True) Kelly Bushing Elevation: 50.80ft above Mean Sea Level Kelly Bushing Elevation: 50.80ft above Project V Reference Kelly Bushing Elevation: 50.80ft above Structure Reference !5f't:=tr''-'Y-SUf1 DRIL.LING SERVices A Halliburton Company Survey Ref: svy1402 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 MWD Your Ref: API 500292319070 Job No. AKMW0002851292, Surveyed: 12 January, 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 -50.80 0.00 0.00 N 0.00 E 6031825.26 N 544837.72 E 0.00 Tolerable Gyro 182.00 0.900 34.000 131.19 181.99 1.19 N 0.80 E 6031826.45 N 544838.51 E 0.495 1.07 MWD Magnetic 387.70 2.500 51.720 336.80 387.60 5.30 N 5.22 E 6031830.60 N 544842.91 E 0.810 4.55 478.26 3.160 52.750 427.25 478.05 8.04 N 8.76 E 6031833.35 N 544846.43 E 0.731 6.79 570.92 5.260 50.000 519.65 570.45 12.31 N 14.05 E 6031837.66 N 544851.69 E 2.276 10.31 661.84 7.890 44.650 609.97 660.77 19.43 N 21.63 E 6031844.82 N 544859.23 E 2.967 16.34 ~ 756.46 11.410 29.280 703.25 754.05 32.22 N 30.77 E 6031857.67 N 544868.30 E 4.579 27.79 848.98 14.330 27.010 793.43 844.23 50.41 N 40.45 E 6031875.91 N 544877.87 E 3.202 44.50 943.77 16.460 18.210 884.83 935.63 73.62 N 49.98 E 6031899.19 N 544887.25 E 3.329 66.22 1039.50 20.100 13.100 975.72 1026.52 102.54 N 57.95 E 6031928.15 N 544895.05 E 4.151 93.80 1134.83 25.320 8.580 1063.63 1114.43 138.68 N 64.71 E 6031964.33 N 544901.59 E 5.770 128.70 1228.16 26.4 70 8.970 1147.59 1198.39 178.96 N 70.93 E 6032004.65 N 544907.57 E 1.246 167.78 1323.13 31.300 6.870 1230.72 1281.52 224.39 N 77.18 E 6032050.11 N 544913.55 E 5.196 211.95 1415.27 34.030 7.360 1308.28 1359.08 273.73 N 83.35 E 6032099.49 N 544919.42 E 2.977 260.01 1510.34 34.200 5.630 1387.00 1437.80 326.70 N 89.38 E 6032152.50 N 544925.13 E 1.036 311.69 1605.32 34.070 3.720 1465.62 1516.42 379.82 N 93.72 E 6032205.64 N 544929.15 E 1.137 363.73 1700.59 34.480 3.240 1544.34 1595.14 433.37 N 96.98 E 6032259.21 N 544932.08 E 0.515 416.36 1793.93 35.590 1.840 1620.77 1671.57 486.90 N 99.34 E 6032312.75 N 544934.13 E 1 .468 469.08 1888.45 36.350 0.970 1697.27 1748.07 542.40 N 100.70 E 6032368.26 N 544935.15 E 0.969 523.89 1982.24 37.560 1.040 1772.21 1823.01 598.77 N 101.69 E 6032424.64 N 544935.80 E 1.291 579.62 2077.24 39.800 0.790 1846.37 1897.17 658.13 N 102.64 E 6032484.00 N 544936.38 E 2.364 638.32 2171.72 42.120 358.730 1917.72 1968.52 720.06 N 102.35 E 6032545.92 N 544935.73 E 2.841 699.71 2264.78 44.700 358.430 1985.31 2036.11 783.98 N 100.76 E 6032609.84 N 544933.75 E 2.781 763.27 2359.80 47.750 356.580 2051.05 2101.85 852.51 N 97.75 E 6032678.35 N 544930.32 E 3.504 831.58 ~ 2454.76 50.300 353.590 2113.32 2164.12 923.92 N 91.57 E 6032749.72 N 544923.72 E 3.586 903.17 2549.60 51.340 351.910 2173.24 2224.04 996.84 N 82.29 E 6032822.58 N 544913.99 E 1.757 976.68 2645.14 51.480 350.030 2232.83 2283.63 1070.59 N 70.57 E 6032896.25 N 544901.83 E 1.545 1051.33 2738.35 51.500 351.390 2290.87 2341.67 1142.57 N 58.79 E 6032968.16 N 544889.62 E 1.142 1124.24 2830.66 51.480 349.600 2348.35 2399.15 1213.80 N 46.86 E 6033039.32 N 544877.26 E 1.517 1196.43 2925.20 51.250 348.210 2407.38 2458.18 1286.27 N 32.66 E 6033111.70 N 544862.62 E 1.174 1270.15 3016.52 50.700 350.330 2464.88 2515.68 1355.96 N 19.44 E 6033181.31 N 544848.98 E 1.901 1340.99 3111.81 50.710 350.040 2525.23 2576.03 1428.63 N 6.87 E 6033253.90 N 544835.97 E 0.236 1414.69 3205.77 50.250 350.230 2585.02 2635.82 1500.04 N 5.55W 6033325.23 N 544823.13 E 0.514 1487.12 3300.47 50.200 350.420 2645.61 2696.41 1571.78N 17.78 W 6033396.91 N 544810.46 E 0.163 1559.86 3393.47 50.380 350.800 2705.03 2755.83 1642.37 N 29.45 W 6033467.42 N 544798.36 E 0.369 1631.37 13 July, 2004 - 10:37 Page 20f5 DrillQuest 3.03.06.002 Halli/;Jurlon Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 MWD Your Ref: AP/500292319070 Job No. AKMW0002851292, Surveyed: 12 January, 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) 3488.00 51.470 351.270 2764.61 2815.41 1714.86 N 40.88 W 6033539.84 N 544786.49 E 1.216 1704.74 3582.82 52.190 351.400 2823.21 2874.01 1788.55 N 52.11 W 6033613.46 N 544774.82 E 0.767 1779.27 3677.20 52.290 351.830 2881.00 2931.80 1862.37 N 62.99 W 6033687.21 N 544763.49 E 0.375 1853.88 3771.51 51.650 352.760 2939.11 2989.91 1935.98 N 72.96 W 6033760.77 N 544753.09 E 1.031 1 928.17 3865.49 51.880 349.920 2997.28 3048.08 2008.95 N 84.07 W 6033833.66 N 544741.53 E 2.386 2001.97 3960.04 51.920 349.770 3055.62 3106.42 2082.19 N 97.19 W 6033906.82 N 544727.97 E 0.132 2076.30 "--.-Y' 4052.92 51.500 349.970 3113.17 3163.97 2153.95 N 110.01 W 6033978.51 N 544714.72 E 0.483 2149.14 4146.90 50.600 350.740 3172.25 3223.05 2226.00 N 122.26 W 6034050.48 N 544702.03 E 1.150 2222.19 4240.54 51.570 349.200 3231.07 3281.87 2297.74 N 134.96 W 6034122.14 N 544688.91 E 1.646 2294.98 4333.68 52.400 349.670 3288.43 3339.23 2369.88 N 148.41 W 6034194.20 N 544675.02 E 0.976 2368.27 4425.01 52.950 349.830 3343.81 3394.61 2441.34 N 161.33 W 6034265.59 N 544661.66 E 0.618 2440.83 4519.72 52.750 349.440 3401.01 3451.81 2515.60 N 174.91 W 6034339.76 N 544647.64 E 0.390 2516.24 4615.00 54.190 349.660 3457.72 3508.52 2590.89 N 188.80 W 6034414.96 N 544633.30 E 1.523 2592.71 4710.21 54.110 349.600 3513.48 3564.28 2666.80 N 202.69 W 6034490.79 N 544618.95 E 0.098 2669.80 4802.88 53.080 349.300 3568.48 3619.28 2740.13 N 216.34 W 6034564.03 N 544604.85 E 1.142 2744.30 4898.07 51.570 348.400 3626.66 3677.46 2814.04 N 230.91 W 6034637.86 N 544589.84 E 1.754 2819.50 4992.84 52.570 3L~8.0.o;.O 3684.91 373571 2887.22 N 246.17 W 6034710.94 N 544574.14 E Î .097 2894.07 5087.98 51 . 1 60 348.840 3743.66 3794.46 2960.53 N 261.17 W 6034784.16 N 544558.70 E 1.623 2968.73 5182.62 51 . 1 80 348.420 3803.00 3853.80 3032.81 N 275.70 W 6034856.35 N 544543.73 E 0.346 3042.31 5277.18 51.910 349.130 3861.81 3912.61 3105.44 N 290.12 W 6034928.89 N 544528.88 E 0.970 3116.22 5372.53 52.500 349.170 3920.24 3971.04 3179.44 N 304.30 W 6035002.81 N 544514.25 E 0.620 3191.46 5466.62 50.970 349.370 3978.51 4029.31 3252.02 N 318.05 W 6035075.30 N 544500.05 E 1.635 3265.23 5559.91 49.890 349.880 4037.94 4088.74 3322.76 N 331.01 W 6035145.96 N 544486.68 E 1.232 3337.06 5655.81 49.290 350.120 4100.10 4150.90 3394.67 N 343.69 W 6035217.79 N 544473.56 E 0.654 3410.03 --" 5749.49 48.770 350.110 4161.53 4212.33 3464.35 N 355.83 W 6035287.40 N 544461.00 E 0.555 3480.71 5842.91 47.990 350.550 4223.58 4274.38 3533.19 N 367.56 W 6035356.17 N 544448.85 E 0.906 3550.51 5937.81 50.360 349.930 4285.61 4336.41 3603.96 N 379.74 W 6035426.86 N 544436.24 E 2.546 3622.27 6047.03 49.750 350.870 4355.74 4406.54 3686.52 N 393.71 W 6035509.34 N 544421.78 E 0.864 3705.96 6136.93 49.420 350.900 4414.02 4464.82 3754.10 N 404.55 W 6035576.85 N 544410.53 E 0.368 3774.38 6228.27 51.130 350.140 4472.40 4523.20 3823.39 N 416.13 W 6035646.07 N 544398.54 E 1.978 3844.60 6322.83 51.270 350.280 4531.65 4582.45 3896.01 N 428.66 W 6035718.61 N 544385.57 E 0.188 3918.25 6415.90 50.920 351.050 4590.10 4640.90 3967.48 N 440.41 W 6035790.01 N 544373.39 E 0.746 3990.64 6510.98 50.270 349.590 4650.46 4701.26 4039.89 N 452.76 W 6035862.35 N 544360.60 E 1.369 4064.06 6604.48 51.830 349.830 4709.23 4760.03 4111.44 N 465.74 W 6035933.81 N 544347.18 E 1.680 4136.70 6697.96 52.900 348.910 4766.31 4817.11 4184.19 N 479.40 W 6036006.48 N 544333.09 E 1.385 4210.63 13 July, 2004 - 10:37 Page 30'5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 MWD Your Ref: API 500292319070 Job No. AKMW0002851292, Surveyed: 12 January, 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) (0/1 OOft) 6792.43 52.260 349.610 4823.72 4874.52 4257.90 N 493.39 W 6036080.11 N 544318.66 E 0.897 4285.56 6884.73 51.530 349.370 4880.68 4931 .48 4329.31 N 506.63 W 6036151.44 N 544304.98 E 0.817 4358.10 6978.88 50.470 349.540 4939.93 4990.73 4401.24 N 520.02 W 6036223.29 N 544291.16 E 1.135 4431.18 7071.08 49.540 349.120 4999.19 5049.99 4470.66 N 533.10 W 6036292.62 N 544277.66 E 1.067 4501.72 7165.59 50.550 351.220 5059.88 5110.68 4542.03 N 545.46 W 6036363.92 N 544264.87 E 2.011 4574.11 7260.22 50.300 351.270 5120.17 5170.97 4614.12 N 556.56 W 6036435.94 N 544253.34 E 0.267 4647.04 ~ 7356.00 46.780 351 .240 5183.58 5234.38 4685.06 N 567.47 W 6036506.81 N 544242.00 E 3.675 4718.80 7447.81 45.850 350.480 5246.99 5297.79 4750.60 N 578.01 W 6036572.29 N 544231.06 E 1.177 4785.17 7541.08 43.390 350.460 5313.37 5364.17 4815.21 N 588.86 W 6036636.83 N 544219.83 E 2.638 4850.65 7635.55 40.980 350.650 5383.37 5434.17 4877.78 N 599.27 W 6036699.34 N 544209.04 E 2.555 4914.05 7729.24 38.040 349.910 5455.64 5506.44 4936.53 N 609.32 W 6036758.02 N 544198.63 E 3.178 4973.62 7825.86 35.240 349.950 5533.16 5583.96 4993.30 N 619.40 W 6036814.73 N 544188.21 E 2.898 5031.22 7921.91 33.480 350.530 5612.45 5663.25 5046.72 N 628.60 W 6036868.09 N 544178.69 E 1.864 5085.40 8013.39 30.520 350.660 5690.02 5740.82 5094.54 N 636.52 W 6036915.86 N 544170.48 E 3.237 5133.85 8108.58 26.590 351.180 5773.61 5824.41 5139.46 N 643.71 W 6036960.74 N 544163.02 E 4.137 5179.33 8201.54 24.060 348.430 5857.64 5908.44 5178.59 N 650.70 W 6036999.83 N 544155.79 E 3.001 5219.04 ()"- ("'\ ,\ ."-- 20.530 351.740 5943.83 5994.43 5213.29 N 656.85 W 6037034.49 N 544149.43 E 4.029 5254.26 C;L~'-, .-<_' 8387.79 17.950 350.100 6031.71 6082.51 5243.65 N 661.67 W 6037064.82 N 544144.43 E 2.825 5284.99 8483.42 14.560 349.560 6123.50 6174.30 5270.00 N 666.38 W 6037091.14 N 544139.56 E 3.548 5311.73 8577.37 13.170 346.870 6214.71 6265.51 5292.03 N 670.96 W 6037113.15N 544134.85 E 1.630 5334.18 8672.07 11 .160 349.520 6307.28 6358.08 5311.55 N 675.07 W 6037132.65 N 544130.62 E 2.202 5354.08 8765.50 9.030 353.070 6399.26 6450.06 5327.73 N 677.60 W 6037148.80 N 544127.99 E 2.374 5370.45 8859.89 6.300 351.100 6492.80 6543.60 5340.20 N 679.30 W 6037161.26 N 544126.22 E 2.905 5383.03 8953.97 3.600 334.820 6586.53 6637.33 5347.97 N 681.36 W 6037169.02 N 544124.12 E 3.207 5391.01 ----- 9047.94 1.050 337.810 6680.41 6731.21 5351.44 N 682.94 W 6037172.48 N 544122.51 E 2.716 5394.66 9142.69 1.550 110.640 6775.15 6825.95 5351.79 N 682.06 W 6037172.84 N 544123.38 E 2.524 5394.89 9306.00 1.550 110.640 6938.40 6989.20 5350.24 N 677.93 W 6037171.31 N 544127.53 E 0.000 5392.79 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 352.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9306.00ft., The Bottom Hole Displacement is 5393.01ft., in the Direction of 352.779° (True). 13 July, 2004 - 10:37 Page 4 of5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPL - MPL-43PB1 MWD Your Ref: AP/500292319070 Job No. AKMW0002851292, Surveyed: 12 January, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 9306.00 6989.20 5350.24 N 677.93 W Projected Survey ~ Survey tool program for MPL-43PB1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 182.00 0.00 181.99 182.00 9306.00 181.99 Tolerable Gyro 6989.20 MWD Magnetic ~ 13 July, 2004 - 10:37 Page 50f5 DrillQuest 3.03.06.002 RE: MPL-43 ') ) ;¿a3~···~ Subject: RE: MPL-43 From: "Quay, Walter (Natchiq)" <QuayWD@BP.com> Date: Fri, 14 May 2004 14:05:48 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Archey, Pat" <ArcheyPJ@BP.com> Tom, The 7" will be cemented to 500' above the shoe. With the projected shoe depth of 8952', the TOC would be 8452'MD. Cement Planned: 22Bbls (105 sxs) of 15.8 ppg G @ 1.16 ft3/sx. This is based on 40% OH excess. The 4-1/2" will be cemented entirely to the liner top. Cement Planned: 27Bbls (127sxs) of 15.8 ppg G @ 1.20 ft3/sx. This is based on 40 OH excess. On timing for L-43, I estimate that 4 days should reach the end of intermediate section and additional 3 days to end of the liner section. We are still employing the 2-7/8" x 5 and 3-1/2" x 6" rams. Only the replaced rams are tested. Walter Quay quaywd@bp.com (907)564-4178 (907)440-8632 - Cell -----Original Message----- From: Thomas Maunder [~~.!.~?:.~~l to: tom rn.a\.m.de:r.@adrnin. ~:;t::ate. a},:. 'U.s] Sent: Thursday, May 13, 2004 4:20 PM To: Quay, Walter (Natchiq) Subject: MPL-43 Walter, I am looking at the sundry for MPL-43. What are the cement specifics for the 7" and 4-1/2" jobs?? I note that you are requesting a 14 day BOP test. Are you still employing the 2-7/8" x 5 and 3-1/2" x 6" rams?? What sort of timing do you see for intermediate and then the liner section?? Since the variable rams will be re-installed after running the 7" casing, is a full BOP test done then or only the replaced rams?? Thanks, Tom 1 of 1 5/18/2004 1:11 PM 1. Type of Request: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): ) STATE OF ALASKA ) RECEIVED J( ALASKA OIL AND GAS CONSERVATION COMrvllSSION MAY. ~ APPLICATION FOR SUNDRY APPROVAL 13 2004 ,i~' 20 MC 25.280 Alaska Oil & Gas Cons. Ç.Qm~sigp/ Anr.hnra.gp. ø~ :ý ~ y o Other · o Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate o Plug Perforations D Stimulate o Perforate New Pool a Re-Enter Suspended Well 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service D Waiver o Time Extension D Annular Disposal 5. Permit To Drill Number 203-224 6. API Number: 50- 029-23190-00 99519-6612 KBE = 50.80' 9. Well Name and Number: MPL-43 8. Property Designation: ADL 025509 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands Total Depth MD (ft): 9306' Casing' , Structural Conductor Surface Intermediate Production Liner Total Depth TVD 6989' Length Effective Depth MD (ft): Effective Depth TVD (ft): 6077' I 4426' 'Size " MD I TXlD· Plugs (measured): 6077' Bµrsf. Junk (measured): N/A ,coHaþse,' ., 112' 6097' 20" 9-5/8" 112' 6097' 112' 4391' 1530 5750 520 3090 Perforation Depth MD (ft): N/A Packers and SSSV Type: N/A Perforation Depth TVD (ft): N/A Tubing Size: N/A Tubing Grade: N/A Packers and SSSV MD (ft): N/A Tubing MD (ft): N/A 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Signature P..:t S (l-.-.cL1 CO:;i~~~on Use::I~803 Date >/ÍYtN 13. Well Class after proposed work: o Exploratory 181 Development 0 Service June 1, 2004 Date: 15. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Walter Quay, 564-4178 Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance w~'"" ....... ~~L~<...~ C:~ri.Ð"L...o'-- ('O'~ \Ù~'-i.'"--_ ::\. \.......\c~, o..ODm.:d. Other: ~__~S"",\",\·-,.....)\'"\..D.J1('··~.:>~., ~--'-,'" \' ~ " ,~ ,1 4D ~~<- d-:-S , C) ~ '5 \.. ~ '\ '-., ) Sundry Number: .3o.i./-1 g 3 / ORIGINAL ØJlS Bi";l ~~ 1 " 'hiU"f Date Är~c.t MA1 ¡~~IIÌ~licate COMMISSIONER ~8fL BY ORDER OF THE COMMISSION bp j ) To: Tom Maunder - AOGCC Date: May 11, 2004 From: Walter Quay - Milne Point Rotary Drilling Subject: Reference: MPL-43 Application for Sundry Approval - Reenter to Drill and Complete Suspended Well (Sundry 304-024) API # 50-029-23190-00 Approval is requested to reenter the suspended well, well MPL-43. The well was suspended after encountering unexpected overpressure preventing the continuation of this well with the original well plan. This well was suspended on January 19, 2004 with 3 cement plugs and an EZSV set at 6077'. The plan is to drill and set the 7" casing above the abnormal pressure encountered in the lower Kalubik. With this casing set, the mud weight will be raised to - 12.5 ppg to drill the pressured zone and though the Kuparuk as per the original well plan. This will be completed with a 4-1/2" production liner and a 4-1/2" completion string. For this well, approval is sought to change the BOP testing interval from 7 days to 14 days. Scope Notify the field AOGCC representative with intent to reenter well. Pre-RiQ Operations: RiQ Operations: 1 . M I I RU Doyon 14 2. Pull BPV. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 4,OOOpsi. Pull TWC. 4. R/U. Pull Hanger. 5. PU 4" drill pipe. Pressure-test casing to 2000 psi. POH. 6. M/U 83/4" bit, BHA. RIH and tag the EZSV. 7. Displace the well to 9.7ppg LSND based drilling fluid. Drill EZSV and cement to bottom of casing +20' of open hole. 8. Pull up into 9 5/8" casing and conduct an FIT to 12.5ppg EMW. POOH. 9. Kickoff from previous wellbore and drill to intermediate casing point (near the top of the Kalubik). 10. Run and set and cement 7" casing. 11. M/U 6-1/8" bit and BHA. RIH, tag and drill shoe track. Displace to 12.5 ppg mud. 12. Drill 20' of new hole. Pull up into 7" casing and conduct an FIT to 13.5ppg EMW. 13. Drill ahead to section TD per directional proposal. 14. Circulate well bore clean, short trip to the 7" shoe. Circulate. POOH. 15. Run and cement a 4 Y2", 12.6#, L-80 solid production liner. POOH. 16. R/U and run a 4 1/2" frac string completion. 17. Set the packer. Individually test the tubing and annulus to 4,OOOpsi for 30 minutes. Record each test. 18. Install a TWC. 19. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC. 20. Freeze protect the well with diesel. Install BPV. Secure the well. 21. Rig down and move off. Post-Ria Operations: 1. MI I RU slick line. Pull the BPV & ball and rod I RHC plug from landing nipple below the production packer. 2. Perforate. Estimated Pre-rig Start Date: 06/01/04 Estimated Spud Date: 06/01/04 Walter Quay Operations Drilling Engineer 564-4178 MPL-43 Application for Sundry Base Permafrost 2,010' 1,850' Surface Casing 9.625-in 40.0-lb/ft Already Set L-80, BTC-M Ca~lng;Þolrit 6,097' 4,439', 8.835-lh ID MWD/GR/RES NONE I FR/Cas Top Tail Cement 8,830' Intermediate Casing 7.000-in 26.0-lb/ft L-80, BTC-M Base HRZ 8,904' 6,776' 8.750-in Casing Point 8,952' 6,820' 6.276-in ID MW = 9.9 MWD/GR/RES NONE I FR/Cas KLGM 8,979' 6,847' Top Kup D-sand 9,161' 7,021' Top Kup C-sand 9,318' 7,176' r~ r Tail Cement Top Kup A3-sand 9,408' 7,266' Volume 11 .0 bbl Production 50 sx Liner 4.500-in TMLV 9,509' 7,366' 6.125-in 12.6 ~ L-80, BTC-M Total Depth 9,738' 7,596' 3.958-in ID MW = 12.5 ) BP EXPLORATION MPL-43 Field: Milne Point Pad: L-Pad KUPARUK GRASSROOTS Frac Producer DIR I LWD MWD OH LOGS FORM DEPTH MD I TVD NONE NONE Permafrost 112' 12' NONE 5/11/2004 ) ENG: M. Green, W. Quay RIG: Doyon 14 RKB: 51.2-ft HOLE SIZE CASING SPECS MUD INFO PIT INFO INFO 42 20.000-in 91.1-lblft H-40 Welded,lnsul Wellhead FMC Gen 5 20" x 11" 5K MPL-43 Well Plan Schematic.xls Iœß.;. 4-1/16" - 5M FMC ') MPL 43 P d Wellhead: 11" x 4.5" 5M Gen 6 - ropose w/4.5" TCII T&B Tubing Hanger CIW "H" BPV profile 20" 91.1-lb/ft H-40 1112' f 9.625-in 40-lb/ft L-80 BTRC casing I *6097' I ~ Sidetrack on Whipstock at 9340' * Already Set 7.0-in 26-lb/ft L-80 IBT-M casing ( drift ID = 6.151 ", cap = 0.0383-bbl/ft ) 4.5" 12.6# L-80 IBT-M tubing "Reverse Circulation' Jet Pump Conflguratlon 1 ~__ 1 :21 - - I ~I ~ æl ~I ~I ~I 0..1 , 0..1 1 I I I I 1 I -~ ~..~ I .............. , L-.:-..................;.~J I I ,,~- ,~ DATE 06 April 04 fl1Æ f1liI Top ZXP Liner Top Packer 8802' 4-1/2" Flexlock Liner Hanger 7.0-in Casing Shoe 8952' ~ 4.5.-in Casing Shoe 9739' ~ REV. BY COMMENTS WDQ Proposed Completion -) DF alav. = 51.20' 014) urig. GL. alav.= 16.3' ~ KOP @ SOD' Max hole angle in tubing = 51 degree o degrees at sleeve Camco 4.5" x 1" GLM I 2000' I ~ 4.5" CMD sliding sleeve 18,715' I 4.5" HES X-Nipple 18,735' 1 18,745' I 7.0" x 4.5" Baker Premier Packer 4.5" HES XN-Nipple 18,775'1 18,805' I WLEG ~ Perforated and frac Kuparuk A-sands Est. Top TKA3 - 9410' MD .. MILNE POINT UNIT WELL MPL-43 API NO: - BP EXPLORATION (AK) SURVEY PROGRAM Plan: MPL-43 wpJ2 (MPL-43/Plan MPL-43 Depth Fm Depth To SurveyIPIao Tool Created By: Ken Allen Date: 3/1 8/2004 6097.00 9738.77 PIanœd: MPL-43 "p12 VI2 MWD+IFR+MS Checked: Date: Reviewed: Date: WELL DETAILS Name +N'-S +FJ-W Northing Easting LatRude Longitude Slot MPL-43 202430 32033 6031825.26 544837.72 70"29'52.J39N 149"3759.982W N'A TARGET DETAILS Narœ 1VD +N'-S +FJ-W Northing Easting Shape MPL-43 Fank #1 4830.80 5412.76 -230.10 6037236.00 544575.00 Pnlygon MPL-43 Fauk 112 6960.80 4610.62 -1052.03 6036429.00 543758.00 Polygon MPL-43 Fauk toJ 7240.80 6674.07 -1584.65 6038489.00 543213.00 Polygon MPL-43 Tla 7245.80 5333.96 -596.62 6037155.00 544209.00 Point MPL-43 G<o Poly 7245.80 5333.96 -596.62 6037155.00 544209.00 Polygon MPL-43 Fank #5 7290.80 6188.09 -143156 6038004.00 543369.00 Polygon MPL-43 Fauk #4 7300.80 5598.18 -1291.10 6037415.00 543513.00 Polygon MPL-43 T2a 7595.80 5333.96 -5%.62 6037155.00 544209.00 Point SECTION DErAILS Sec MD Inc Azi TVD +N/-S +FJ- W DLeg TFace VSec Target 1 6097.00 49.57 350.41 4438.87 3720.14 -442.95 0.00 0.00 3746.33 2 6447.00 35.90 354.93 4695.41 3954.86 -474.38 4.00 169.00 3983.08 3 8047.00 35.90 354.93 5991.50 4889.35 -557.36 0.00 0.00 4921.00 4 8467.48 19.08 354.75 6363.17 5081.95 -574.67 4.00 -179.80 5114.34 5 9011.15 19.08 354.75 6876.98 5258.92 -590.94 0.00 0.00 5292.01 6 9388.66 4.00 0.00 7245.80 5333.96 -596.62 4.00 178.60 5367.22 MPL-43 Tla 7 9509.52 0.83 180.00 7366.57 5337.29 -596.62 4.00 180.00 5370.54 8 9738.77 0.83 180.00 7595.80 5333.96 -596.62 0.00 0.00 5367.22 MPL-43 T2a CASING DErAILS FORMATION TOP DErAll..S No. TVD MD Name Size No. TVDPath MDPath Formation 1 6820.80 8951.71 7" 7.000 1 4442.80 6103.05 SBA5 (Base OB) 2 7595.63 9738.60 41/2" 4.500 2 6718.80 8843.78 THRZ (if present 3 6775.80 8904.09 BHRZ 4 6846.80 8979.22 KLGM spE!r'll'""'y-s;u, 5 7020.80 9160.90 TKUD 6 7175.80 9318.35 TKUC u.. >.... DRILLING SERVICES 7 7185.80 9328.41 TKUB A. R-\U.lßl!RTO.... CO\!PA......... 8 7255.80 9398.69 TKUA .om<___ 9 7265.80 9408.70 TKA3 10 7280.80 9423.72 TKA2 11 7310.80 9453.74 TKAl 12 7365.80 9508.75 1MLV m..,'''. -_.....- um<___ .....,---- ø II I ;I .I 'F:m fIP -,- .I -I I ¡P 6000 6600 REFERENCE INFORMATION Co-ordinate (NIE) Reference: Wen Centre: MPL-43, True North Vertical (IVD) Reteren:e: MPL-43: 50.80 Se<tion (VS) Reference: Slot - (O.OON,O.OOE) M~~~~~= ~~ !D, -14 .1«. 8 7'11'- 'D r MD. 4t.<JS.'~]· rVD .; JC , 1i~~/ ~ ----- . L..... ~.~ "v -~ ~ /1- rllIPl-4 ~ "'Jl12 I I I I I I I I I I 4200 4800 5400 Vertical Section at 353.62° [600ft/in] COMPANY DET AJI.S BP Amoco ea1cu\atioo, Method: Minimum Curvature Error System: ¡SCWSA S=I Method: Trav Cylinder North Error Surface: Elliptical' Casing Warning MeIhod: Rules Based 4200 4800 5400 E ¢: o o ~ ~ P.. Ö "§ 6000 t -> .. :3 ¡:: 3600 6600 7200 7800 SURVEY PROGRAM Plan: MPL-43 wp12 (MPL-431PIan MPL-43 Depth Fro Depth To Swveyil'1ao Tool Created By: Troy Jakabosky Date: 311 812004 6097 .00 9738.77 PJamed: MPL-43 ...p12 VI2 MWD+IFR+MS Checked: Date: WElL DETAll.S Name +W-5 "'f'j-W NoI1hing Easting Latitude Longitude Slot MPL-43 202430 32033 6031825.26 544837.72 70"29'52.139N 149"'3159.982W WA SECITON DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFaee VSee Target 1 6097.00 49.57 350.41 4438.87 3720.14 -442.95 0.00 0.00 3746.33 2 6447.00 35.90 354.93 4695.41 3954.86 -474.38 4.00 169.00 3983.08 3 8047.00 35.90 354.93 5991.50 4889.35 -557.36 0.00 0.00 4921.00 4 8467.48 19.08 354.75 6363.17 5081.95 -574.67 4.00 -179.80 5114.34 5 9011.15 19.08 354.75 6876.98 5258.92 -590.94 0.00 0.00 5292.01 6 9388.66 4.00 0.00 7245.80 5333.96 -596.62 4.00 178.60 5367.22 MPL-43 Tla 7 9509.52 0.83 180.00 7366.57 5337.29 -596.62 4.00 180.00 5370.54 8 9738.77 0.83 180.00 7595.80 5333.96 -596.62 0.00 0.00 5367.22 MPL-43 T2a REFERENCE INFORMATION Co-onIinate (NIE) Reference: Well Centre: MPL-43, True North Vertical (IVD) Reference: MPL-43: 50.80 Section (VS) Reli:œnce: Slot - (01lON,0.OOE) Measured Deplh Reference: MPL-43: 50.80 Calculation Method: Minimum Curwture COMPANY DETAILS CalculaJion MetOOd: Minimwn Curvature ~;:: ~=: ~~v~;~inder North Error Surface: Elliptical + Casing Warning M.tb:xI: Rules Based 114 6000 CASING DETAILS No. TVD MD Name Size 1 6820.80 8951.71 7" 7.000 -- 2 7595.63 9738.60 41/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 4442.80 6103.05 SBA5 (Base OB) 2 6718.80 8843.78 THRZ (if present) 3 6775.80 8904.09 BHRZ 4 6846.80 8979.22 KLGM 5 7020.80 9160.90 TKUD 6 7175.80 9318.35 TKUC 7 7185.80 9328.41 TKUB 8 7255.80 9398.69 TKUA 9 7265.80 9408.70 TKA3 10 7280.80 9423.72 TKA2 11 7310.80 9453.74 TICAl 12 7365.80 9508.75 TMLV .,-,l:tf"T"Iy-c::I .., Q R I ~.LJ.!\I G se.RVIc:e~ A HALUIlL'RTOr.~ co..\IP'A.''''\~ - TARGETDETAll.S Namo 1VD -tW-S ~EI·W Northing Easting Shape MPL-43 Faull #1 4830.80 5412.76 -230.10 6037236.00 544575.00 Polygon MPL-43 Fault #2 6960.80 4610.62 -1052.03 6036429.00 543758110 Polygon MPL-43 Faull !13 7240.80 6674.07 -1584.65 6038489.00 543213.00 Polygon MPL-43 Tla 7245.80 5333.96 -596.62 6037155.00 544209.00 Point MPL-43 Goo Poly 7245.80 5333.96 -596.62 6037155.00 544209.00 Polygon MPL-43 Faull #5 7290.80 6188.09 -143156 6038004.00 543369.00 Polygon MPL-43 Faull !i4 7300.80 5598.18 -1291.10 6037415.00 543513.00 Polygon MPL-43 T2a 7595.80 5333.96 -596.62 6037155.00 544209.00 Pnint · . · · · · · ¡.nnn . .hh. .nn [:=~ · · · 800 " I I I I I I I -400 0 400 W est( - )/East( +) [400ft/in] MD. I '. ~~ / - ---~~ i _, . 4'-~;;; 7~~9~. t'" MD; -~ ~- 00'-: úO"I7' End- DÎI Start D¡r 4U 45/ / I / I I I / / , I -8uU I 1200 5600 5200 4800 4400 4000 3600 'C ::â o o :!. +' .J:' 1:: ~ .c '5 o VJ Comp~ny: Field: SI,te: ': Well:. Wellp'åt~:. BP Amoco Milne Point ,'M ptt.: Pad MPL-43 Plan MPL43 ) ) Sperry-Sun - Draft Copy Sperry-Sun Date: 3/18/2004; Time: 08:46:26 rag!:'; ~ Cõ"or~inate(NE)~eferel1ce:' "Wèll:MPL-43, True Nt:jrth" Yertl~al&'fVD)R,eferel1ce: MPL4~: 50.8, ~ec~lon<YS) R,~teren~e: ,Well (q.OQN 0;00E ~53J~2Azil ,Suryey Calcula~ion M:ethod: Minlmumpurvature Db: Plan: MPL-43 wp12 Changed to add pump Tangent and Drill out, Principal: Yes Date Composed: Version: Tied-to: Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: M pt L Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: MPL-43 6029799.28 ft 544529.55 ft Latitude: Longitude: North Reference: Grid Convergence: Slot Name: WelI Position: +N/-S 2024.30 ft Northing: 6031825.26 ft +E/-W 320.33 ft Easting: 544837.72 ft Position Uncertainty: 0.00 ft Latitude: Longitude: WelIpath: Plan MPL-43 Current Datum: Magnetic Data: Field Strength: Vertical Section: Casing Points MD ft 8951.71 9738.60 Formations _~·~~·_.Y'__._--..w 6103.05 8843.78 8904.09 8979.22 9160.90 9318.35 9328.41 9398.69 9408.70 9423.72 9453.74 9508.75 MPL-43: 2/20/2004 57552 nT Depth From (TVD) ft 34.50 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 50.80 ft +N/-S ft 0.00 ¡VD : Diameter Hõle Size Name ft ·in in 6820.80 7.000 8.500 7" 7595.63 4.500 6.125 41/2" MD ft TVD ft, 0.00 0.00 0.00 4442.80 6718.80 6775.80 6846.80 7020.80 7175.80 7185.80 7255.80 7265.80 7280.80 7310.80 7365.80 . Formations Lithology:' ---....--..-.--- BPRF TUZC SBF2-NA SBA5 (Base OB) THRZ (if present) BHRZ KLGM TKUD TKUC TKUB TKUA TKA3 TKA2 TKA1 TMLV 3/16/2004 12 From: Definitive Path Alaska, Zone 4 Well Centre bggm2003 70 29 32.230 N 149 38 9.412 W True 0.34 deg 70 29 52.139 N 149 37 59.982 W MPL-43PB1 6097.00 ft Mean Sea Level 24.96 deg 80.88 deg Direction deg 353.62 1 . 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 Direction dèg' 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 ) ) Sperry-Sun - Draft Copy Sperry-Sun C~'mpany: BP Amoco Field: .' MUnepoint ,S,ite::;.. MPt L Pad WéU:';:MPL~,~ , ..... ' ",èllpa.th:, 'Plari MPL43 Dåtë: . 3/18/2004:< Time: 08:46:26 Påge:', Co':ordinátë(NE) Referénce: 'Wêll:MpL.;;.43,' True Nõrth' Yert,cal (TVD)iReferénce:>: MPL~43>50.8·/i('; ...........:: Se~tlonœS).I{efer:~nce::: Well (Q.OON;O;QOE 35~.62AZi) .... ':" '.; SurveyÇalcùlati~n Method: MinimuÎn CurVature ,. . Db:Cracle' Targets Ma.p, ,:"Map .. '<~-;';', Latittide;:'~-> <......Lon~itlld~~-> TVO +N/-S" . +EI-W Northing , Easting Deg l\1in . S~c Deg:~i!Ì" Se't ft: ft ','ft ft Jti MPL-43 Fault #1 4830.80 5412.76 -230.10 6037236.00 544575.00 70 30 45.372 N 149 38 6.761 W -Polygon 1 4830.80 5412.76 -230.10 6037236.00 544575.00 70 30 45.372 N 149 38 6.761 W -Polygon 2 4830.80 3054.08 -827.39 6034874.00 543992.00 70 30 22.174 N 149 38 24.348 W -Plan out by 1383.59 at 4830.80 4052.48 -483.05 6035874.36 544330.29 70 30 31.994 N 149 38 14.209 W MPL-43 Fault #2 6960.80 4610.62 -1052.03 6036429.00 543758.00 70 30 37.482 N 149 38 30.970 W -Polygon 1 6960.80 4610.62 -1052.03 6036429.00 543758.00 70 30 37.482 N 149 38 30.970 W -Polygon 2 6960.80 4267.90 222.05 6036094.00 545034.00 70 30 34.112 N 149 37 53.442 W -Plan out by 815.60 at 6960.80 5284.96 -593.26 6037106.03 544212.65 70 30 44.114 N 149 38 17.459 W MPL-43 Fault #3 7240.80 6674.07 -1584.65 6038489.00 543213.00 70 30 57.775 N 149 38 46.671 W -Polygon 1 7240.80 6674.07 -1584.65 6038489.00 543213.00 70 30 57.775 N 149 38 46.671 W -Polygon 2 7240.80 4588.39 -1014.16 6036407.00 543796.00 70 30 37.264 N 149 38 29.854 W -Plan out by 1665.26 at 7240.80 5333.60 -596.61 6037154.64 544209.00 70 30 44.593 N 149 38 17.557 W MPL-43 T1a 7245.80 5333.96 -596.62 6037155.00 544209.00 70 30 44.596 N 149 38 17.557 W -Plan hit target MPL-43 Geo Poly 7245.80 5333.96 -596.62 6037155.00 544209.00 70 30 44.596 N 149 38 17.557 W -Polygon 1 7245.80 5580.96 -924.16 6037400.00 543880.00 70 30 47.025 N 149 38 27.207 W -Polygon 2 7245.80 5085.92 -927.15 6036905.00 543880.00 70 30 42.157 N 149 38 27.293 W -Polygon 3 7245.80 5082.97 -437.11 6036905.00 544370.00 70 30 42.128 N 149 38 12.858 W -Polygon 4 7245.80 5578.97 -594.14 6037400.00 544210.00 70 30 47.006 N 149 38 17.485 W -Plan hit target MPL-43 Fault #5 7290.80 6188.09 -1431.56 6038004.00 543369.00 70 30 52.995 N 149 38 42.158 W -Polygon 1 7290.80 6188.09 -1431.56 6038004.00 543369.00 70 30 52.995 N 149 38 42.158 W -Polygon 2 7290.80 6205.89 -71.29 6038030.00 544729.00 70 30 53.172 N 149 38 2.083 W -Plan out by 1192.70 at 7290.80 5336.39 -596.62 6037157.44 544208.99 70 30 44.620 N 149 38 17.557 W MPL-43 Fault #4 7300.80 5598.18 -1291.10 6037415.00 543513.00 70 30 47.194 N 149 38 38.017 W -Polygon 1 7300.80 5598.18 -1291.10 6037415.00 543513.00 70 30 47.194 N 149 38 38.017 W -Polygon 2 7300.80 5621.89 -414.86 6037444.00 544389.00 70 30 47.428 N 149 38 12.204 W -Plan out by 742.06 at 7300.80 5336.74 -596.62 6037157.78 544208.98 70 30 44.624 N 149 38 17.557 W MPL-43 T2a 7595.80 5333.96 -596.62 6037155.00 544209.00 70 30 44.596 N 149 38 17.557 W -Plan hit target Plan Section Information MD Incl AZini TVD +N/-S +E/..W DLS Build Turn .TFO ft deg deg ft ft 'ft dEig/100ft:deg/100ft deg/100ft deg 6097.00 49.57 350.41 4438.87 3720.14 -442.95 0.00 0.00 0.00 0.00 6447.00 35.90 354.93 4695.41 3954.86 -474.38 4.00 -3.91 1.29 169.00 8047.00 35.90 354.93 5991.50 4889.35 -557.36 0.00 0.00 0.00 0.00 8467.48 19.08 354.75 6363.17 5081.95 -574.67 4.00 -4.00 -0.04 -179.80 9011.15 19.08 354.75 6876.98 5258.92 -590.94 0.00 0.00 0.00 0.00 9388.66 4.00 0.00 7245.80 5333.96 -596.62 4.00 -3.99 1.39 178.60 9509.52 0.83 180.00 7366.57 5337.29 -596.62 4.00 -2.62 148.94 180.00 9738.77 0.83 180.00 7595.80 5333.96 -596.62 0.00 0.00 0.00 0.00 Target MPL-43 T1a MPL-43 T2a Survey MD Incl Åzim TYO MâpN MapE VS DLS TFO Comment ft deg deg ft ft ft ft deg/100ft deg 6097.00 49.57 350.41 4438.87 4388.07 6035542.30 544372.38 3746.33 0.00 0.00 MWD+IFR+MS 6100.00 49.45 350.44 4440.82 4390.02 6035544.55 544371.98 3748.60 4.00 169.00 MWD+IFR+MS 6103.05 49.33 350.4 7 4442.80 4392.00 6035546.82 544371.59 3750.91 4.00 168.98 SBA5 (Base SBA5(Ba 6200.00 45.53 351.51 4508.38 4457.58 6035617.25 544359.97 3822.22 4.00 168.96 MWD+IFR+MS 6300.00 41.62 352.74 4580.82 4530.02 6035685.44 544350.09 3891.11 4.00 168.26 MWD+IFR+MS 6400.00 37.72 354.16 4657.78 4606.98 6035748.79 544342.39 3954.93 4.00 167.37 MWD+IFR+MS 6447.00 35.90 354.93 4695.41 4644.61 6035776.80 544339.54 3983.08 4.00 166.27 MWD+IFR+MS 6500.00 35.90 354.93 4738.34 4687.54 6035807.74 544336.61 4014.15 0.00 0.00 MWD+IFR+MS 6600.00 35.90 354.93 4819.34 4768.54 6035866.10 544331.07 4072.77 0.00 0.00 MWD+IFR+MS 6614.14 35.90 354.93 4830.80 4780.00 6035874.36 544330.29 4081.06 0.00 0.00 MPL-43 Fau MPL43 F 6700.00 35.90 354.93 4900.35 4849.55 6035924.47 544325.53 4131.39 0.00 0.00 MWD+IFR+MS 6800.00 35.90 354.93 4981.36 4930.56 6035982.84 544319.99 4190.01 0.00 0.00 MWD+IFR+MS 6900.00 35.90 354.93 5062.36 5011.56 6036041.21 544314.46 4248.63 0.00 0.00 MWD+IFR+MS ) ) Sperry-Sun - Draft Copy Sperry-Sun Cömpany: BP Amoco ,Date: /3/18/2004 Tim~:)~08:46:26 - Pagê: I}ield: Milne Point · Co-o~~inate(NErRefereiu:e: Well: MPLio43, :True' North.' Site:'. M;Pt LPad ' V~r.lcal ()l;YDliRe(e'rence: MPL-43: 60.8/>'" " Well:'- MÞL~43' Sèc,tlori <y:S)~efer,~n(:e: ' ""',~II·_(q.ºON,0.OOE.353.62~!) Wellpiath: Plari'MPl-43 survey Calc~htti9n Metbodf ',Jy1inll11ul11 CurvatlJr~ 'Db: Survey MD loCi Azlm TVD ,SysTVD - l\1apN M~pE VS DLS TFO Tool Comment ;ft deg deg ft :;ft .: '1t 'ft ft ;':dËig/10OO <deg 7000.00 35.90 354.93 5143.37 5092.57 6036099.57 544308.92 4307.25 0.00 0.00 MWD+IFR+MS 7100.00 35.90 354.93 5224.37 5173.57 6036157.94 544303.38 4365.87 0.00 0.00 MWD+IFR+MS 7200.00 35.90 354.93 5305.38 5254.58 6036216.31 544297.84 4424.49 0.00 0.00 MWD+IFR+MS 7300.00 35.90 354.93 5386.39 5335.59 6036274.67 544292.30 4483.11 0.00 0.00 MWD+IFR+MS 7400.00 35.90 354.93 5467,39 5416.59 6036333.04 544286.77 4541.73 0.00 0.00 MWD+IFR+MS 7500.00 35.90 354.93 5548.40 5497.60 6036391.41 544281.23 4600.35 0.00 0.00 MWD+IFR+MS 7600.00 35.90 354.93 5629.40 5578.60 6036449.78 544275.69 4658.97 0.00 0.00 MWD+IFR+MS 7700,00 35.90 354.93 5710.41 5659.61 6036508.14 544270.15 4717.59 0.00 0.00 MWD+IFR+MS 7800.00 35.90 354.93 5791.41 5740.61 6036566.51 544264.61 4776.21 0.00 0.00 MWD+IFR+MS 7900.00 35.90 354.93 5872.42 5821.62 6036624.88 544259.08 4834.83 0.00 0.00 MWD+IFR+MS 8000.00 35.90 354.93 5953.43 5902.63 6036683.24 544253.54 4893.45 0.00 0.00 MWD+IFR+MS 8047.00 35.90 354.93 5991.50 5940.70 6036710.68 544250.94 4921.00 0.00 0.00 MWD+IFR+MS 8100.00 33.78 354.91 6035.00 5984.20 6036740.81 544248.07 4951.27 4.00 180.20 MWD+IFR+MS 8200.00 29.78 354.88 6119.99 6069.19 6036793.22 544243.07 5003.91 4.00 180.21 MWD+IFR+MS 8300.00 25.78 354.85 6208.45 6157.65 6036839.60 544238.63 5050.49 4.00 180.23 MWD+IFR+MS 8400,00 21.78 354.79 6299.94 6249.14 6036879.72 544234.75 5090,79 4.00 180.27 MWD+IFR+MS 8467.48 19.08 354.75 6363.17 6312.37 6036903.16 544232.46 5114.34 4.00 180.31 MWD+IFR+MS 8500.00 19.08 354.75 6393.90 6343.10 6036913.74 544231.42 5124.97 0.00 0.00 MWD+IFR+MS 8600.00 19.08 354,75 6488.41 6437.61 6036946.26 544228.24 5157.65 0.00 0.00 MWD+IFR+MS 8700.00 19.08 354.75 6582,92 6532.12 6036978.79 544225.05 5190.33 0.00 0.00 MWD+IFR+MS 8800.00 19.08 354.75 6677.42 6626,62 6037011.32 544221.86 5223.01 0.00 0.00 MWD+IFR+MS 8843.78 19.08 354.75 6718.80 6668.00 6037025.56 544220.47 5237.31 0.00 0.00 THRZ (if p THRZ (if 8900.00 19.08 354.75 6771.93 6721.13 6037043.85 544218.67 5255.69 0.00 0.00 MWD+IFR+MS 8904,09 19.08 354.75 6775.80 6725.00 6037045.18 544218.54 5257.03 0.00 0.00 BHRZ BHRZ 8951.71 19.08 354.75 6820.80 6770.00 6037060.67 544217.03 5272.59 0.00 0.00 7" 7" 8979.22 19.08 354.75 6846.80 6796,00 6037069.62 544216.15 5281.58 0.00 0.00 KLGM KLGM 9000.00 19.08 354.75 6866.44 6815.64 6037076.37 544215.49 5288.37 0.00 0.00 MWD+IFR+MS 9011.15 19.08 354.75 6876.98 6826.18 6037080.00 544215.13 5292.01 0.00 0.00 MWD+IFR+MS 9098.97 15.57 355.07 6960.80 6910.00 6037106.03 544212.65 5318.15 4.00 178.60 MPL-43 Fau MPL-43 F 9100.00 15.53 355.07 6961.79 6910.99 6037106.30 544212.62 5318.43 4.00 178.29 MWD+IFR+MS 9160.90 13.09 355.40 7020.80 6970.00 6037121.29 544211.28 5333.47 4.00 178.29 TKUD TKUD 9200.00 11.53 355,67 7059.00 7008.20 6037129.59 544210.58 5341.80 4.00 177.97 MWD+IFR+MS 9300.00 7.53 356.89 7157.60 7106.80 6037146.10 544209.37 5358,34 4.00 177.70 MWD+IFR+MS 9318.35 6.80 357.27 7175.80 7125.00 6037148.39 544209.24 5360.62 4.00 176.50 TKUC TKUC 9328.41 6.40 357.52 7185.80 7135.00 6037149.54 544209.18 5361.78 4.00 176.12 TKUB TKUB 9383.65 4.20 359.69 7240.80 7190.00 6037154.64 544209.00 5366.86 4.00 175.88 MPL-43 Fau MPL-43 F 9388.66 4.00 0.00 7245.80 7195.00 6037155.00 544209.00 5367.22 4.00 173.72 MPL-43 T1a MPL-43 - 9398.69 3.60 0.00 7255.80 7205.00 6037155.66 544209.00 5367.88 4.00 180.00 TKUA TKUA 9400.00 3.55 0.00 7257.11 7206.31 6037155.75 544209.00 5367.96 4.00 180.00 MWD+IFR+MS 9408.70 3.20 0.00 7265.80 7215.00 6037156.26 544208.99 5368.47 4.00 180.00 TKA3 TKA3 9423.72 2.60 0.00 7280.80 7230.00 6037157.02 544208.99 5369.22 4.00 180.00 TKA2 TKA2 9433.73 2.20 0.00 7290.80 7240.00 6037157.44 544208.99 5369.64 4.00 180.00 MPL-43 Fau MPL-43 F 9443.74 1.80 0.00 7300.80 7250.00 6037157.78 544208.98 5369.99 4.00 180.00 MPL-43 Fau MPL-43 F 9453.74 1.40 0.00 7310.80 7260.00 6037158.06 544208.98 5370.26 4.00 180.00 TKA1 TKA1 9508.75 0.80 180.00 7365.80 7315.00 6037158.35 544208.98 5370.55 4.00 180.00 TMLV TMLV 9509.52 0.83 180,00 7366.57 7315.77 6037158.34 544208.98 5370.54 4.00 0.00 MWD+IFR+MS 9600.00 0.83 180.00 7457.04 7406.24 6037157.02 544208.99 5369.23 0.00 180.00 MWD+IFR+MS 9700.00 0.83 180.00 7557.03 7506.23 6037155.56 544209.00 5367.78 0.00 180.00 MWD+IFR+MS 9738.60 0.83 180.00 7595.63 7544.83 6037155.00 544209.00 5367.22 0.00 180.00 41/2" 4 1/2" 9738.77 0.83 180.00 7595.80 7545.00 6037155.00 544209.00 5367.22 0.00 180.00 MPL-43 T2a MPL-43 - WELL DETAll.S Nome +NI-S +E/-W Northing Easting Latitude Longitude SloI MP1A3 202430 3203 603182526 544837.12 70"29'52.139N 149"J7"59.982W NlA -320 -300 -250 -200 -150 -100 -50 -0 270 --50 -100 -150 -200 -250 -300 -320 SECITON DETAILS See MD Inc Azi 1VD ~-S +Fl-W DLeg TFace vSee Target I 6097.00 4957 350.41 4438.87 3nO.14 -442.95 0.00 0.00 374633 2 6447.00 35.90 354.93 4695.41 3954.86 -47438 4.00 169.00 39&3.08 3 8047.00 35.90 354.93 599150 483935 -55736 0.00 0.00 4921.00 4 8467.48 19.08 354.75 6363.17 5081.95 -574.fiI 4.00 -179.80 51\434 5 9011.15 19.08 354.75 6876.98 5258.92 -590.94 0.00 0.00 5292.01 6 9388.66 4.00 0.00 n45.80 5333.96 -596.62 4.00 178.60 536722 MPL-43 Tla 7 950952 0.83 lSO.OO 736657 533729 -596.62 4.00 180.00 5370.54 8 9738.77 0.83 ISO.OO 7595.80 5333.96 -596.62 0.00 0.00 536722 MPL-43 123 From o o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 o 6500 7500 8500 9500 90 - ANTI-COLLISION SE1TINGS Intetpolation MethodMD Interval: 25.00 Depth Range From: 6097.00 To: 9738.77 Maximum Range: II 70.43 Reference: Plan: MPL-43 wp12 roMPANY DETAILS BP Amoco CalcuJatioo Method: Minimum Curvature Enor System: ISCWSA Scan Method: Trav <)1inder North Error Surlàce: Elliptical + Casing Warning Method: RuJ.. Based Colour Depth Fm Depth To 6097.00 9738.77 ToMD o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10500 WEIl.PA rn DETAILS Plan MPL-43 Parent Wellpath: MP1A3PBI Tæ on MD; 6097.00 RiB' MPL-43: 50.8011 Ref Datum: V -Section Origin Origin Starting Angle +NI-S +Fl-W From 1VD 353.62· 0.00 0.00 '50 LEGEND - MPL-05 (MPL-05), Major Risk - MPL-15 (MPL-I5), Major Risk - MPL-24 (MPL-24), Major Risk - MPL-43 (MPL-43PBI), NOERRORS - PJan MPL-43 - MPL-43 wp12 ~ - SURVEY PROGRAM Survey",1an PIanœd: MPL-43 wpI2 V12 Tool MWD-"-IFR+MS ,ç~J11pany: BP Amoco 'F'~I~:;:;; '. . :Mlln~;P()iÏ1t Rèf~r~pce~ite: Ml?t L Pad Rete~~pce '\y~ll: MPL43 R¿fer,ence WèUpatb: ''Plan'MPG43 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 ofreference Interpolation Method: MD Interval: 25.00 ft Depth Range: 6097.00 to 9738.77 ft Maximum Radius: 1170.43 ft Casing Points 'l\ID' ft· 8951.71 9738.60 TVD f1' 6820.80 7595.63 ) ') Sperry-Sun - Draft Copy Anticollision Report Date:>: 3/18/2004 Thne: 08:44:58 'Co.;.or ;U~åte{NE) Réf~Hmce:;,' , .Well:MPL~43,Trµe North Vertiçal(TVI» J{eference:, ; MPb43:;50.8,' Reference: Error Model: Scan Method: Error Surface: Diameter in 7.000 4.500 Name: Hòle Size in 8.500 6.125 7" 41/2" Plan: MPL-43 wp12 Changed to add pump Tangent and Drill out, Principal: Yes Summary <' Site Db: Plan: MPL-43 wp12 & NOT PLANNED PROGRt ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Date Composed: Version: Tied-to: 3/16/2004 12 From: Definitive Path M Pt L Pad M Pt L Pad M pt L Pad M Pt L Pad Site: M pt L Pad Well: MPL-05 Wellpath: MPL-05 V1 .'. . R~teren~e MD' ::TYD ',ft ;ft 6116.43 4451.57 6183.27 4496.73 6249.92 4543.96 6316.09 4592.90 6381.49 4643.21 MPL-05 MPL-15 MPL-24 MPL-43 Offset .~. ';ftc" 7850.00 6700.00 6325.00 6100.00 çtr-Ctr?:No-Gò Distance' Area . ft' ft 1051.50 196.72 783.30 206.35 509.39 245.57 0.00 0.00 Allowable" ' Deviation ',' :Warning 'ft ' 854.78 Pass: Major Risk 576.95 Pass: Major Risk 263.82 Pass: Major Risk 0.00 Pass: NOERRORS Major Risk 0.00 ft , Allowa)ble, 'Deviattoni~ar~ipg , . . ft ' . 908.19 909.45 909.75 909.15 907.82 Pass Pass Pass Pass Pass 6445.89 4694.51 6750.00 5128.33 19.87 29.92 128.24 133.34 1064.03 158.40 905.63 Pass 6470.36 4714.33 6775.00 5143.71 19.94 30.05 127.84 132.91 1062.48 159.33 903.15 Pass 6494.14 4733.59 6800.00 5159.11 20.00 30.19 127.43 132.51 1060.91 160.26 900.65 Pass 6517.96 4752.89 6825.00 5174.56 20.07 30.28 127.03 132.10 1059.38 161.06 898.32 Pass 6541.81 4772.21 6850.00 5190.14 20.14 30.38 126.63 131.71 1057.98 161.86 896.12 Pass 6565.71 4791.57 6875.00 5205.83 20.21 30.47 126.24 131.31 1056.70 162.66 894.04 Pass 6589.65 4810.96 6900.00 5221.63 20.28 30.56 125.86 130.93 1055.53 163.46 892.08 Pass 6613.61 4830.37 6925.00 5237.48 20.35 30.69 125.4 7 130.55 1054.43 164.34 890.09 Pass 6637.56 4849.77 6950.00 5253.30 20.42 30.81 125.09 130.16 1053.35 165.23 888.12 Pass 6661.50 4869.16 6975.00 5269.10 20.49 30.93 124.70 129.77 1052.29 166.12 886.17 Pass 6685.43 4888.55 7000.00 5284.87 20.56 31.05 124.31 129.38 1051.26 167.02 884.24 Pass 6709.38 4907.95 7025.00 5300.66 20.64 31.18 123.92 129.00 1050.27 167.91 882.35 Pass 6733.35 4927.37 7050.00 5316.53 20.71 31.30 123.54 128.61 1049.34 168.81 880.54 Pass 6757.35 4946.81 7075.00 5332.4 7 20.78 31.42 123.16 128.23 1048.49 169.70 878.79 Pass 6781.38 4966.28 7100.00 5348.49 20.85 31.55 122.78 127.86 1047.70 170.59 877 .12 Pass 6805.43 4985.75 7125.00 5364.55 20.92 31.63 122.41 127.49 1046.97 171.33 875.64 Pass 6829.48 5005.24 7150.00 5380.62 21.00 31.71 122.04 127.11 1046.29 172.08 874.21 Pass 6853.53 5024.72 7175.00 5396.70 21.07 31.79 121.67 126.74 1045.65 172.82 872.82 Pass 6877.59 5044.21 7200.00 5412.79 21.14 31.87 121.30 126.37 1045.05 173.57 871 .48 Pass 6901 .67 5063.71 7225.00 5428.95 21.21 31.95 120.93 126.00 1044.55 174.32 870.23 Pass 6925.79 5083.25 7250.00 5445.24 21.29 32.03 120.57 125.64 1044.18 175.06 869.11 Pass 6949.95 5102.83 7275.00 5461.67 21.36 32.11 120.22 125.29 1043.93 175.80 868.13 Pass 6974.15 5122.43 7300.00 5478.23 21.43 32.19 119.87 124.95 1043.82 176.53 867.29 Pass 6998.37 5142.04 7325.00 5494.82 21.51 32.32 119.53 124.61 1043.77 177.40 866.37 Pass 7022.56 5161.65 7350.00 5511.37 21.58 32.44 119.19 124.26 1043.72 178.27 865.45 Pass -,-----_._-._--_._._~_.---,_._--~'"-----------,-----"~-.------ ,~---- __.____ .__._______._,____~,_.___.._.__,_________'.._._,______ - _..___0·'.-.__------------.-.-. MPL-05 V1 MPL-15 V1 MPL-24 V1 MPL-43PB1 V5 7506.67 6100.00 6107.00 6100.00 Qffset MD TV» ,ft ft 6625.00 5051.31 6650.00 5066.78 6675.00 5082.20 6700.00 5097.58 6725.00 5112.95 Rule Assigned: Inter·Site Error: Se~i;;MaJ~.rAxi~ ... . .... ....' ..' ....... '. . ...Ç~;;Çtr.No"Çò ª~f ()ffset'. .. TFO+ A~l. TF9~HSÇ~sipØJ;~lstapçe Ar~a : ft ft cjeg d~g in' ft~ ' ft ' 18.89 28.99 128.83 138.22 1059.62 151.43 19.11 29.20 128.78 137.46 1062.48 153.03 19.32 29.40 128.70 136.60 1064.33 154.58 19.52 29.60 128.58 135.63 1065.19 156.04 19.70 29.76 128.43 134.55 1065.09 157.27 ,) ) Sperry-Sun - Draft Copy Anticollision Report Company: BPAmoco Dåte: 3/18/2004 Tilne: 08:44:58 >riel~: " " Milne Point Rèfereiice Site: M,Pt L Pad ; Co.,()rdinat~(NE)~efefe~~ë: R:~re~~l1c'e,".."\¥~II: MPL~43, ' Vertical (1'VQ) ;Referen~,e: ,<Reference Wellpjttb: Plarì'MPL~43 ,·Db:'·' Oracle, ',' Site: M pt L Pad Well: MPL-05 Rule Assigned: Major Risk Wellpath: MPL-05 V1 Inter-Site Error: 0.00 ft ,Reference Offset Semi-,l\1ajºf Axis,:' Ctr-Ctr' 'Nó~Go Allowable 'MD ;TVD MD TVD Ref Offset ,TIfP+~ZI T:f()~HSCashlgIHSJi~tå.nceArea;> Deyiation ' Warning ft' ft ft 'ft 'ft ,>, ,ff" deg deg in ft ft; .ft 7046.75 5181.24 7375.00 5527.87 21.66 32.57 118.84 123.91 1043.68 179.15 864.53 Pass 7070.92 5200.81 7400.00 5544.32 21.73 32.69 118.49 123.56 1043.65 180.02 863.62 Pass 7095.07 5220.38 7425.00 5560.73 21.81 32.86 118.13 123.21 1043.63 181.04 862.58 Pass 7119.22 5239.94 7450.00 5577.11 21.88 33.03 117.78 122.85 1043.63 182.07 861.57 Pass 7143.35 5259.49 7475.00 5593.45 21.95 33.20 117.42 122.50 1043.67 183.09 860.58 Pass 7167.48 5279.04 7500.00 5609.76 22.03 33.37 117.06 122.14 1043.73 184.12 859.61 Pass 7191.62 5298.59 7525.00 5626.14 22.10 33.50 116.70 121.78 1043.86 185.00 858.86 Pass 7215.81 5318.19 7550.00 5642.67 22.18 33.62 116.36 121.43 1044.13 185.87 858.26 Pass 7240.05 5337.82 7575.00 5659.36 22.25 33.75 116.02 121.10 1044.53 186.74 857.79 Pass 7264.33 5357.49 7600.00 5676.21 22.33 33.88 115.70 120.77 1045.05 187.59 857.46 Pass 7288.63 5377.18 7625.00 5693.11 22.41 34.00 115.38 120.45 1045.63 188.44 857.19 Pass 7312.91 5396.84 7650.00 5709.94 22.48 34.13 115.05 120.13 1046.21 189.29 856.92 Pass 7337.17 5416.49 7675.00 5726.71 22.56 34.25 114.72 119.80 1046.79 190.14 856.64 Pass 7361.41 5436.13 7700.00 5743.41 22.63 34.38 114.39 119.46 1047.36 191.00 856.36 Pass 7385.64 5455.75 7725.00 5760.06 22.71 34.55 114.05 119.13 1047.95 192.00 855.95 Pass 7409.85 5475.37 7750.00 5776.67 22.79 34.72 113.72 118.79 1048.58 193.00 855.58 Pass 7434.05 5494.97 7775.00 5793.25 22.86 34.89 113.37 118.45 1049.23 194.00 855.23 Pass 7458.23 5514.56 7800.00 5809.78 22.94 35.06 113.03 118.11 1049.91 195.00 854.91 Pass 7482.43 5534.17 7825.00 5826.36 23.01 35.18 112.69 117.77 1050.66 195.86 854.79 Pass 7506.67 5553.80 7850.00 5843.08 23.09 35.31 112.36 117.44 1051.50 196.72 854.78 Pass 7530.95 5573.47 7875.00 5859.92 23.17 35.44 112.04 117.11 1052.42 197.56 854.86 Pass 7555.26 5593.16 7900.00 5876.89 23.24 35.56 111.73 116.80 1053.44 198.40 855.04 Pass 7579.60 5612.88 7925.00 5893.95 23.32 35.65 111.42 116.50 1054.52 199.10 855.42 Pass 7603.96 5632.61 7950.00 5911.06 23.40 35.73 111.12 116.20 1055.63 199.79 855.84 Pass 7628.33 5652.35 7975.00 5928.23 23.48 35.81 110.83 115.90 1056.78 200.48 856.29 Pass 7652.72 5672.11 8000.00 5945.45 23.55 35.90 110.54 115.61 1057.95 201.17 856.78 Pass 7677.11 5691.87 8025.00 5962.67 23.63 36.02 110.25 115.32 1059.15 201.98 857.16 Pass 7701.49 5711.61 8050.00 5979.85 23.71 36.15 109.95 115.03 1060.35 202.80 857.55 Pass 7725.85 5731.35 8075.00 5996.99 23.79 36.28 109.66 114.73 1061.56 203.62 857.94 Pass 7750.21 5751.08 8100.00 6014.08 23.87 36.40 109.36 114.44 1062.79 204.44 858.34 Pass 7774.55 5770.80 8125.00 6031.13 23.94 36.57 109.06 114.14 1064.02 205.39 858.63 Pass 7798.89 5790.51 8150.00 6048.14 24.02 36.74 108.76 113.84 1065.27 206.34 858.93 Pass 7823.21 5810.22 8175.00 6065.12 24.10 36.91 108.46 113.53 1066.53 207.29 859.24 Pass 7847.53 5829.92 8200.00 6082.07 24.18 37.08 108.16 113.23 1067.80 208.23 859.56 Pass 7871.84 5849.61 8225.00 6098.98 24.26 37.25 107.85 112.92 1069.09 209.19 859.90 Pass 7896.14 5869.30 8250.00 6115.88 24.34 37.42 107.54 112.62 1070.40 210.14 860.26 Pass 7920.44 5888.98 8275.00 6132.76 24.41 37.58 107.24 112.31 1071.73 211.08 860.65 Pass 7944.73 5908.66 8300.00 6149.62 24.49 37.75 106.93 112.01 1073.08 212.03 861.05 Pass 7969.03 5928.34 8325.00 6166.49 24.57 37.88 106.63 111.70 1074.47 212.85 861.62 Pass 7993.34 5948.03 8350.00 6183.41 24.65 38.01 106.32 111.40 1075.91 213.67 862.24 Pass 8017.67 5967.74 8375.00 6200.38 24.73 38.14 106.03 111.10 1077.40 214.48 862.92 Pass 8042.00 5987.45 8400.00 6217.39 24.81 38.27 105.73 110.81 1078.93 215.29 863.64 Pass 8073.20 6012.86 8425.00 6234.41 24.89 38.40 105.43 110.51 1080.43 216.13 864.30 Pass 8105.86 6039.87 8450.00 6251.38 24.97 38.54 105.10 110.19 1081.78 216.98 864.80 Pass 8138.15 6066.99 8475.00 6268.30 25.02 38.67 104.74 109.84 1082.98 217.78 865.20 Pass 8170.04 6094.14 8500.00 6285.18 25.08 38.81 104.35 109.46 1084.05 218.58 865.46 Pass 8201.50 6121.29 8525.00 6302.01 25.13 38.99 103.93 109.05 1084.98 219.52 865.46 Pass 8232.51 6148.38 8550.00 6318.80 25.17 39.16 103.48 108.61 1085.78 220.45 865.33 Pass 8263.04 6175.37 8575.00 6335.55 25.22 39.34 103.01 108.15 1086.46 221.38 865.08 Pass 8293.08 6202.22 8600.00 6352.26 25.26 39.51 102.51 107.66 1087.04 222.32 864.72 Pass ----.--------.--.--------- ,,------"-..------.-,..,---..-. - --_._-_.~_._-~ "--'--"'.-..... -..----------- .-.,-------- --" ~- ----_._.,_._--_..~._- --.-_._-_.-._- ----- -'-'---'~'-------~ -..-.-.--- ) ) Sperry-Sun - Draft Copy Anticollision Report Co~p.ny: BP Amoco Time: 08:44:58 ,Page: , F~¢ld:',' Milne Point t":":::):'~::.. ' ftefertnce Sit!: MPt L Pád Co-ordlnate(NE);Ref~~ence:,;, Well: MPL:':43;True North R~(~~~*~~,'Ý ëÌl'; '. .'; MPb43 Vertical (1!m)~efer~nce: < MPL43: 50.8 '. . .. Rdertrice Wellpath: Plan' MPL-43'; Db: Oracle Site: M pt L Pad Well: MPL-05 Rule Assigned: Major Risk Wellpath: MPL-05 V1 Inter-Site Error: 0.00 ft ;R~ferel1ç,ê' Offset S~ml-Major,~is 'Ctr~CtrNo"Go Allowable >l\1D . tVD MD TVD >.Ref ...······'··.O(fset TFÒ+AZI.······TFh-HS; ca$lng/BIDlst~nce<.'Arel\;;' .,; D~ybttton. .' . ft ' ff ft ft ff 'ft ,geg . deg 'in . , ft . ft 'ft' 8322.62 6228.89 8625.00 6368.94 25.30 39.67 101.98 107.15 1087.48 223.19 864.29 Pass 8351.65 6255.35 8650.00 6385.62 25.33 39.82 101.43 106.61 1087.77 224.06 863.71 Pass 8380.18 6281.58 8675.00 6402.28 25.36 39.98 100.86 106.06 1087.91 224.93 862.98 Pass 8408.18 6307.54 8700.00 6418.93 25.39 40.13 100.27 105.48 1087.93 225.79 862.13 Pass 8435.63 6333.18 8725.00 6435.55 25.42 40.29 99.65 104.88 1087.88 226.66 861.23 Pass 8462.48 6358.45 8750.00 6452.11 25.45 40.45 99.01 104.26 1087.86 227.51 860.35 Pass 8485.05 6379.77 8775.00 6468.61 25.47 40.61 98.35 103.60 1087.90 228.36 859.54 Pass 8506.66 6400.20 8800.00 6485.05 25.50 40.76 97.69 102.94 1088.08 229.21 858.87 Pass 8528.23 6420.58 8825.00 6501.43 25.54 40.94 97.03 102.28 1088.40 230.11 858.28 Pass 8549.75 6440.92 8850.00 6517.74 25.57 41.12 96.36 101.61 1088.85 231.00 857.84 Pass 8571.23 6461.22 8875.00 6533.98 25.61 41.30 95.69 100.94 1089.44 231.88 857.56 Pass 8592.66 6481.48 8900.00 6550.15 25.64 41.47 95.01 100.26 1090.17 232.73 857.44 Pass 8614.09 6501.73 8925.00 6566.31 25.67 41.61 94.33 99.59 1091.04 233.45 857.60 Pass 8635.56 6522.01 8950.00 6582.53 25.71 41.75 93.66 98.91 1092.05 234.14 857.91 Pass 8657.06 6542.34 8975.00 6598.80 25.74 41.88 93.00 98.25 1093.19 234.82 858.37 Pass 8678.60 6562.69 9000.00 6615.13 25.78 42.02 92.34 97.59 1094.45 235.47 858.98 Pass 8700.16 6583.07 9025.00 6631.48 25.81 42.13 91.68 96.93 1095.83 236.04 859.79 Pass 8721.73 6603.45 9050.00 6647.84 25.85 42.25 91.02 96.27 1097.31 236.59 860.72 Pass 8743.30 6623.83 9075.00 6664.20 25.88 42.36 90.37 95.62 1098.88 237.12 861.77 Pass 8764.87 6644.23 9100.00 6680.57 25.92 42.48 89.72 94.97 1100.55 237.63 862.92 Pass 8786.45 6664.62 9125.00 6696.94 25.95 42.61 89.07 94.32 1102.29 238.18 864.11 Pass 8808.04 6685.02 9150.00 6713.31 25.99 42.75 88.42 93.67 1104.06 238.71 865.35 Pass 8829.64 6705.43 9175.00 6729.69 26.02 42.88 87.77 93.02 1105.87 239.23 866.64 Pass 8851.24 6725.85 9200.00 6746.06 26.06 43.02 87.13 92.38 1107.71 239.72 867.99 Pass 8872.82 6746.24 9225.00 6762.41 26.09 43.18 86.48 91.73 1109.64 240.27 869;37 Pass 8894.36 6766.60 9250.00 6778.70 26.13 43.33 85.84 91.09 1111.70 240.80 870.90 Pass 8915.86 6786.92 9275.00 6794.92 26.16 43.49 85.19 90.44 1113.90 241.30 872.59 Pass 8937.32 6807.20 9300.00 6811.08 26.20 43.65 84.54 89.79 1116.23 241.79 874.44 Pass 8958.76 6827.46 9325.00 6827.21 26.23 43.81 83.89 89.15 1118.73 242.28 876.45 Pass 8980.19 6847.71 9350.00 6843.32 26.27 43.98 83.25 88.50 1121.41 242.75 878.67 Pass 9001.61 6867.96 9375.00 6859.43 26.30 44.14 82.61 87.86 1124.28 243.00 881.28 Pass 9022.80 6888.00 9400.00 6875.53 26.33 44.31 81.97 87.19 1127.32 243.41 883.92 Pass 9043.53 6907.69 9425.00 6891.63 26.36 44.46 81.32 86.47 1130.58 243.72 886.86 Pass 9063.89 6927.12 9450.00 6907.73 26.38 44.61 80.66 85.74 1134.08 244.03 890.05 Pass 9083.88 6946.29 9475.00 6923.82 26.40 44.76 80.00 84.99 1137.84 244.33 893.51 Pass 9103.51 6965.18 9500.00 6939.92 26.42 44.90 79.32 84.23 1141.85 244.59 897.26 Pass 9122.78 6983.79 9525.00 6956.01 26.43 45.06 78.63 83.45 1146.11 244.81 901.30 Pass 9141.67 7002.10 9550.00 6972.08 26.44 45.21 77.94 82.66 1150.60 245.01 905.59 Pass 9160.21 7020.12 9575.00 6988.13 26.45 45.36 77.24 81.85 1155.33 245.17 910.16 Pass 9178.38 7037.84 9600.00 7004.17 26.46 45.52 76.53 81.02 1160.31 245.30 915.01 Pass 9200.00 7059.00 9625.00 7020.17 26.47 45.69 75.81 80.14 1165.54 245.42 920.12 Pass Site: M pt L Pad Well: MPL-15 Rule Assigned: Major Risk Wellpath: MPL-15 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr· No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Caslng/HIDlstance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 6100.00 4440.82 6700.00 4009.43 18.83 64.78 306.71 316.27 783.30 206.35 576.95 Pass 6117.56 4452.32 6725.00 4018.95 18.89 65.12 306.90 316.28 792.17 206.61 585.55 Pass 6133.37 4462.80 6750.00 4028.46 18.95 65.45 307.09 316.31 801.25 206.84 594.41 Pass 6149.04 4473.32 6775.00 4037.91 19.00 65.79 307.30 316.35 810.51 207.00 603.51 Pass -,_..-----~---_._-" ,---------,---,~._- ".. - .._, -'--.-,"....._" ----_._----_.._------,--,--- ._,---_..,_._---~_..._- _.._---~~---,----~--- _,.,,'"-.______.". "...______ ____·____"._._H__.. .~.__.~___, ~__. ~. _ .'- -.-------.-,..- ) ) Sperry-Sun - Draft Copy Anticollision Report Compâny: BPAmoco Date:' 3/18/2004> Time:'08~44:5á ,FIeld: ' Milne Point '" Re(ererlce:Slte: :M,f:lt~Pød 'Có-o~,dl,n;tte(NElR~feren~e::, ' ; Well: JvJÞt.43, :rrÚ~North ' R~fe~:e~ce \V~R: MPL-43 Vef;,tJc,al {TVDlJieference::,,:" MPL43: qO.8 . " Refeiepce.Wel1patl1: Plan MPL-43 Db: Oracle Site: M pt L Pad Well: MPL-15 Rule Assigned: Major Risk Wellpath: MPL-15 V1 Inter-Site Error: 0.00 ft Reféhnce ." Offset> Seml';MajotAxls :.",< 'i;; .'. '. :>/ . .... .Çt~~C~:.;No7Go 'ij Allowable. N.(D TVD Mp TVD Ref . Off$"t;:TFO+~ZI FO-:J:lS ,Caslng/~S>lst~lßceAre~;: Deviation Warning;;' ft 'ft ff; ft ft ff'd~g, deg in ft ft; ft 6164.58 4483.87 6800.00 4047.30 19.05 66.13 307.52 316.41 819.94 207.10 612.85 Pass 6179.98 4494.45 6825.00 4056.63 19.10 66.46 307.77 316.48 829.55 207.13 622.42 Pass 6200.00 4508.38 6850.00 4065.97 19.17 66.80 308.02 316.51 839.48 207.16 632.32 Pass 6200.00 4508.38 6875.00 4075.34 19.17 67.15 308.18 316.67 849.82 207.25 642.57 Pass 6225.24 4526.22 6900.00 4084.76 19.25 67.48 308.43 316.62 860.35 207.28 653.07 Pass 6240.00 4536.79 6925.00 4094.20 19.29 67.82 308.62 316.64 871.29 207.37 663.92 Pass 6254.62 4547.36 6950.00 4103.65 19.34 68.15 308.82 316.66 882.42 207.42 675.00 Pass 6269.10 4557.93 6975.00 4113.10 19.38 68.49 309.02 316.68 893.72 207.45 686.28 Pass 6300.00 4580.82 7000.00 4122.55 19.48 68.81 309.28 316.54 905.41 207.38 698.03 Pass 6300.00 4580.82 7025.00 4132.00 19.48 69.16 309.45 316.71 916.85 207.39 709.46 Pass 6300.00 4580.82 7050.00 4141.42 19.48 69.50 309.60 316.86 928.95 207.44 721.51 Pass 6325.49 4600.02 7075.00 4150.83 19.55 69.83 309.83 316.75 941.17 207.32 733.84 Pass 6339.14 4610.42 7100.00 4160.21 19.59 70.17 310.01 316.74 953.82 207.32 746.50 Pass 6352.63 4620.78 7125.00 4169.61 19.62 70.50 310.18 316.73 966.72 207.31 759.41 Pass 6365.99 4631.12 7150.00 4179.11 19.66 70.84 310.35 316.70 979.78 207.31 772.47 Pass 6379.22 4641.43 7175.00 4188.68 19.70 71.17 310.51 316.66 993.00 207.32 785.68 Pass 6400.00 4657.78 7200.00 4198.34 19.75 71.50 310.69 316.52 1006.42 207.28 799.14 Pass 6400.00 4657.78 7225.00 4208.00 19.75 71.84 310.81 316.64 1019.90 207.38 812.52 Pass 6418.12 4672.18 7250.00 4217.64 19.80 72.17 310.99 316.54 1033.50 207.24 826.25 Pass 6430.81 4682.35 7275.00 4227.24 19.83 72.50 311.17 316.52 1047.24 207.13 840.11 Pass 6447.00 4695.41 7300.00 4236.80 19.87 72.84 311.37 316.45 1061.13 206.93 854.20 Pass 6461 .45 4707.11 7325.00 4246.27 19.91 73.18 311.51 316.58 1075.31 207.02 868.28 Pass 6481.73 4723.54 7350.00 4255.63 19.97 73.53 311.63 316.70 1089.75 207.20 882.55 Pass 6501 .86 4739.85 7375.00 4264.88 20.02 73.88 311.73 316.81 1104.44 207.44 897.00 Pass 6521.88 4756.06 7400.00 4274.04 20.08 74.22 311.82 316.89 1119.32 207.72 911.60 Pass 6541.91 4772.29 7425.00 4283.22 20.14 74.56 311.91 316.98 1134.18 207.99 926.19 Pass 6561.97 4788.54 7450.00 4292.44 20.20 74.90 311.99 317.07 1148.99 208.26 940.73 Pass 6582.07 4804.82 7475.00 4301.69 20.26 75.24 312.08 317.15 1163.76 208.54 955.23 Pass Site: M pt L Pad Well: MPL-24 Rule Assigned: Major Risk Wellpath: MPL·24 V1 Inter-Site Error: 0.00 ft " Reference Offset Semi-Major Axis Ctr..ctr ..... . No,.Go Allowable' MD TVD MD TVD Ref Offset· TFO+AZI· TFO-HS CaslngIHS>lstance" Area Deviation Warning 'ft ft ft ft ft ft deg, deg in ft ft ft 6107.00 4445.38 6325.00 4373.71 18.86 53.46 271.00 280.49 4.500 509.39 245.57 263.82 Pass 6128.31 4459.43 6350.00 4384.74 18.93 53.78 271.78 281.05 4.500 511.13 246.14 264.98 Pass 6149.43 4473.58 6375.00 4395.75 19.00 54.09 272.59 281.64 4.500 513.19 246.65 266.54 Pass 6170.37 4487.84 6400.00 4406.77 19.07 54.40 273.43 282.25 4.500 515.49 247.06 268.44 Pass 6191.15 4502.20 6425.00 4417.85 19.14 54.71 274.29 282.88 4.500 517.98 247.40 270.58 Pass 6211.75 4516.65 6450.00 4428.99 19.21 55.02 275.16 283.52 4.500 520.65 247.66 272.99 Pass 6232.17 4531.17 6475.00 4440.17 19.27 55.33 276.06 284.18 4.500 523.51 247.81 275.70 Pass 6252.40 4545.75 6500.00 4451.38 19.33 55.63 276.98 284.85 4.500 526.61 247.89 278.72 Pass 6272.43 4560.38 6525.00 4462.61 19.39 55.93 277.92 285.54 4.500 529.94 247.88 282.06 Pass 6292.27 4575.05 6550.00 4473.87 19.45 56.23 278.88 286.24 4.500 533.52 247.79 285.73 Pass 6311.89 4589.74 6575.00 4485.14 19.51 56.54 279.85 286.95 4.500 537.35 247.59 289.76 Pass 6331.32 4604.45 6600.00 4496.44 19.56 56.84 280.83 287.67 4.500 541.44 247.29 294.15 Pass 6350.53 4619.16 6625.00 4507.78 19.62 57.14 281.82 288.39 4.500 545.79 246.92 298.87 Pass 6369.54 4633.88 6650.00 4519.15 19.67 57.44 282.82 289.12 4.500 550.39 246.46 303.93 Pass 6388.35 4648.59 6675.00 4530.58 19.72 57.75 283.83 289.85 4.500 555.26 245.92 309.34 Pass 6406.95 4663.29 6700.00 4542.04 19.77 58.05 284.85 290.57 4.500 560.39 245.29 315.10 Pass , ,,_ ,,_'"__·__.__.._w__.'_·____,__.._._,..~,_ _".._.".___ ...__,,_,_______~_._____~.,.___....__" .__.___'''' _"___. _._"",__,.__,,__,___,,_~.,._ _____.......___,..____..___..___ ·_'___._·__h__.___._·.._ ._..._...._...._..~___.__.__,__._.__.__ ) ) Sperry-Sun - Draft Copy Anticollision Report ,Conipany: BP'Amoco ,Fiëld:, ., ty1i1nøPoint ReferencèSlte: M pfLPad Refèr~ncewéi1: MPL43 :Refèr¢ùce Wellpåth: Plän MPL;;43, ,Wøll:MPb43; True: North " ty1PL:743: 50.8" Db: Oracle Site: M pt L Pad Well: MPL-24 Wellpath: MPL-24 V1 " Reference:,· MD'" , "TVri' ft' :ft 6425.33 4677.94 6447.00 4695.41 6464.88 4709.89 6487.11 4727.90 'rime:: oð:44:58 Page: 5' " Offset, MD,: TVD 'ft it 6725.00 4553.52 6750.00 4564.98 6775.00 4576.44 6800.00 4587.89 Rule Assigned: Inter-Site Error: Se~i7M:aJor,Axis ....... " :: ....:;;...)} qr.;C~ ~o-Go;,: :R.d·, '. Offset1:FQ+AZI JFQ-HSqas~nglHs).stagçe>.r\rea:::::·: it ft d,eg' ~eg< in ' ',ft', 'ft; 19.82 58.35 285.86 291.29 4.500 565.90 244.55 19.87 58.65 286.89 291.96 4.500 571.85 243.75 19.92 58.96 287.83 292.91 4.500 578.14 243.01 19.98 59.28 288.75 293.83 4.500 584.70 242.29 Major Risk 0.00 ft Allowable Deviation·':: Wa,rning ::. fi ". 321.35 Pass 328.10 Pass 335.13 Pass 342.41 Pass 6509.29 4745.86 6825.00 4599.23 20.04 6531.40 4763.78 6850.00 4610.45 20.11 6553.45 4781.64 6875.00 4621.55 20.17 6575.47 4799.47 6900.00 4632.58 20.24 6597.50 4817.32 6925.00 4643.65 20.30 6619.56 4835.19 6950.00 4654.77 20.37 6641.64 4853.08 6975.00 4665.93 20.43 6663.75 4870.98 7000.00 4677.14 20.50 6685.87 4888.90 7025.00 4688.39 20.57 6708.00 4906.83 7050.00 4699.68 20.63 6730.15 4924.78 7075.00 4711.02 20.70 6752.27 4942.69 7100.00 4722.28 20.76 6774.30 4960.54 7125.00 4733.36 20.83 6796.25 4978.32 7150.00 4744.24 20.90 6818.11 4996.03 7175.00 4754.95 20.96 6839.90 5013.68 7200.00 4765.51 21.03 6861.63 5031.28 7225.00 4775.96 21.09 6883.30 5048.83 7250.00 4786.29 21.16 6904.91 5066.34 7275.00 4796.52 21.22 6926.55 5083.87 7300.00 4806.80 21.29 6948.24 6969.96 6991.72 7013.54 7035.39 7057.30 7079.23 7101.17 7123.11 7145.05 7166.98 7188.86 7210.70 7232.49 7254.31 7276.17 7298.06 7319.99 7341.95 7363.94 7385.94 7407.97 7429.97 7451.96 7473.93 5101.44 7325.00 4817.17 21.36 5119.03 7350.00 4827.62 21.42 5136.66 7375.00 4838.15 21.49 5154.33 7400.00 4848.77 21.56 5172.04 7425.00 4859.49 21.62 5189.78 7450.00 4870.31 21.69 5207.55 7475.00 4881.18 21.76 5225.32 7500.00 4892.09 21.82 5243.09 7525.00 4903.01 21.89 5260.87 7550.00 4913.97 21.96 5278.63 7575.00 4924.88 22.03 5296.35 7600.00 4935.72 22.10 5314.04 7625.00 4946.48 22.16 5331.70 7650.00 4957.16 22.23 5349.37 7675.00 4967.87 22.30 5367.08 7700.00 4978.66 22.37 5384.82 7725.00 4989.53 22.43 5402.58 7750.00 5000.48 22.50 5420.37 7775.00 5011.48 22.57 5438.18 7800.00 5022.54 22.64 5456.00 7825.00 5033.66 22.71 5473.84 7850.00 5044.81 22.78 5491.67 7875.00 5055.96 22.85 5509.48 7900.00 5067.09 22.92 5527.28 7925.00 5078.20 22.99 59.60 289.66 294.74 59.92 290.56 295.64 60.25 291.45 296.52 60.57 292.31 297.39 60.89 293.16 298.23 61.21 293.98 299.05 61.53 294.78 299.85 61.84 295.55 300.63 62.14 296.30 301.37 62.45 297.02 302.09 62.75 297.71 302.79 63.06 298.40 303.48 63.38 299.09 304.17 63.69 299.79 304.86 64.01 300.49 305.57 64.34 301.19 306.26 64.67 301.88 306.95 65.00 302.56 307.63 65.32 303.23 308.31 65.64 303.88 308.96 65.96 304.51 309.58 66.28 305.11 310.18 66.58 305.69 310.76 66.89 306.24 311.32 67.19 306.78 311.86 67.50 307.30 312.37 67.81 307.79 312.87 68.11 308.27 313.34 68.42 308.72 313.80 68.74 309.16 314.24 69.06 309.59 314.66 69.39 310.01 315.08 69.71 310.42 315.50 70.04 310.83 315.90 70.36 311.22 316.30 70.68 311.61 316.68 71.00 311.98 317.05 71.32 312.33 317.41 71.63 312.68 317.75 71.94 313.01 318.08 72.25 313.33 318.40 72.57 313.63 318.71 72.88 313.93 319.00 73.20 314.21 319.29 73.52 314.49 319.56 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 591.48 241.55 598.50 240.79 605.73 239.99 613.16 239.16 620.70 238.32 628.33 237.48 636.06 236.64 643.92 235.76 651.94 234.90 660.12 234.06 668.44 233.24 676.86 232.43 685.34 231.56 693.88 230.64 702.49 229.68 711.22 228.73 720.09 227.76 729.10 226.77 738.25 225.75 747.51 224.75 756.87 223.78 766.31 222.85 775.83 221.94 785.40 221.04 795.01 220.19 804.67 219.38 814.41 218.61 824.29 217.88 834.29 217.19 844.41 216.55 854.63 215.94 864.96 215.34 875.38 214.74 885.90 214.14 896.44 213.56 906.98 213.01 917.51 212.48 928.04 211.97 938.59 211.48 949.18 211.03 959.79 210.60 970.45 210.22 981.19 209.86 992.03 209.53 1002.96 209.22 349.93 357.71 365.74 374.00 382.37 390.85 399.42 408.16 417.04 426.06 435.20 444.43 453.78 463.24 472.80 482.49 492.33 502.34 512.50 522.77 533.09 543.46 553.89 564.35 574.82 585.29 595.81 606.41 617.10 627.86 638.69 649.62 660.64 671.76 682.88 693.97 705.03 716.06 727.11 738.15 749.19 760.23 771.34 782.51 793.74 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass 7495.93 5545.10 7950.00 5089.34 23.06 73.84 314.76 319.83 4.500 1013.84 208.93 804.92 Pass 7517.98 5562.96 7975.00 5100.56 23.13 74.16 315.03 320.10 4.500 1024.59 208.63 815.97 Pass - ,-----_...._._-"~---,-- -' ~'---...,-_._------,,-----,-_._._,-,--,--._,.,_.__.__.-.--.--.. ---_.~----~-_._----,-_._-------_. ------,-"'.~._.,_.,----------_.'------~_._,-_._- '-"---~'-'-~'- --'-"-" ,) ) Sperry-Sun - Draft Copy Anticollision Report çq~pany: ,BPAmoco, Timer" 08:44:58 Field:" ..........',., Miln,ePoint ,. "".'. Reference Site: tyhPt L Pad Có!"ordin~te(NJ$}Rerert~~ce: W~II:·MPL~43. True North " 'JÏ~ferehc~)Ve~,I~,.. ..;MPL~43 ..' Vert!pal(TVD) Reference: MPL";4~: 59~8,,: Reference,Wenpath:Plan MPL~43 Site: M Pt L Pad Well: MPL-24 Rule Assigned: Major Risk Wellpath: MPL-24 V1 Inter-Site Error: 0.00 ft ~ "Reference pffset Semt~Mäjqr ~,~i~::'. '. ......>' '. ' .,,:,:,Ctr~qtr;,N~Go< , AlIoyvable MD' 'TVD' MD TW' Ref. , Offset TFO"':Az,;I T~O~~S, (:~sing¡HS:)(~~ance A~ea,' ,:Devlatlon ..', 'ft ft ft ft ft' ' ft deg , qeg:c' in .,ft ' ft ft 7540.09 5580.87 8000.00 5111.85 23.20 74.48 315.30 320.37 4.500 1035.20 208.31 826.89 Pass 7562.24 5598.81 8025.00 5123.21 23.27 74.80 315.57 320.65 4.500 1045.67 207.98 837.69 Pass 7584.39 5616.76 8050.00 5134.56 23.34 75.13 315.84 320.92 4.500 1056.15 207.67 848.48 Pass 7606.52 5634.68 8075.00 5145.87 23.41 75.45 316.11 321.18 4.500 1066.71 207.37 859.34 Pass 7628.62 5652.58 8100.00 5157.12 23.48 75.78 316.37 321.44 4.500 1077.33 207.07 870.26 Pass 7650.69 5670.46 8125.00 5168.33 23.55 76.10 316.62 321.70 4.500 1088.04 206.78 881.25 Pass 7672.76 5688.34 8150.00 5179.56 23.62 76.42 316.86 321.94 4.500 1098.83 206.53 892.30 Pass 7694.84 5706.23 8175.00 5190.84 23.69 76.75 317.09 322.16 4.500 1109.71 206.32 903.39 Pass 7716.92 5724.12 8200.00 5202.16 23.76 77.07 317.30 322.38 4.500 1120.69 206.17 914.52 Pass 7739.00 5742.00 8225.00 5213.51 23.83 77.40 317.50 322.57 4.500 1131.75 206.05 925.70 Pass 7761.04 5759.85 8250.00 5224.80 23.90 77.73 317.69 322.77 4.500 1142.91 205.95 936.96 Pass 7783.03 5777.67 8275.00 5235.99 23.97 78.05 317.88 322.96 4.500 1154.17 205.84 948.33 Pass 7804.97 5795.44 8300.00 5247.10 24.04 78.38 318.07 323.15 4.500 1165.53 205.74 959.79 Pass Site: M pt L Pad Well: MPL~43 Rule Assigned: NOERRORS Wellpath: MPL-43PB 1 V5 Inter-Site Error: 0.00 ft .. Reference Offset Semi~MajórAxls , ... Ctro;Ctr'''No.;Gó Allchvabl~: MD TVD MD Tvp Ref Offset TF'O"':AZI ." TFQo;HS'CaSlng/llS>,lstance" Area' Deviation ..' Warning' , Jt .ft ft ft ft ,ft dElg deg, in ,., ' ft; , ft ft 6100.00 4440.82 6100.00 4440.82 18.83 18.84 350.44 0.00 7.000 0.00 0.00 0.00 Pass 6125.00 4457.23 6125.00 4457.05 18.92 18.93 334.94 344.24 7.000 0.25 0.00 0.25 Pass 6149.98 4473.95 6150.00 4473.29 19.00 19.02 335.29 344.33 7.000 0.94 0.00 0.94 Pass 6174.92 4490.96 6175.00 4489.39 19.09 19.12 336.05 344.82 7.000 2.24 0.00 2.24 Pass 6199.78 4508.23 6200.00 4505.34 19.17 19.21 336.58 345.07 7.000 4.19 0.00 4.19 Pass 6224.55 4525.73 6225.00 4521.13 19.25 19.31 336.94 345.15 7.000 6.79 0.00 6.78 Pass 6249.21 4543.44 6250.00 4536.81 19.32 19.42 337.35 345.26 7.000 9.94 0.00 9.94 Pass 6273.75 4561.35 6275.00 4552.48 19.40 19.52 337.91 345.51 7.000 13.52 0.00 13.52 Pass 6298.16 4579.45 6300.00 4568.14 19.47 19.63 338.49 345.78 7.000 17.53 0.00 17.53 Pass 6322.43 4597.70 6325.00 4583.79 19.54 19.73 339.05 346.01 7.000 21.97 0.00 21.97 Pass 6346.55 4616.10 6350.00 4599.45 19.61 19.82 339.47 346.10 7.000 26.80 0.00 26.80 Pass 6370.51 4634.63 6375.00 4615.14 19.67 19.91 339.74 346.03 7.000 32.01 0.00 32.01 Pass 6394.30 4653.28 6400.00 4630.86 19.74 19.99 339.92 345.85 7.000 37.59 0.00 37.59 Pass 6417.92 4672.02 6425.00 4646.62 19.80 20.08 340.04 345.59 7.000 43.54 0.00 43.54 Pass 6441.35 4690.83 6450.00 4662.43 19.86 20.16 340.08 345.25 7.000 49.83 0.00 49.83 Pass 6465.29 4710.22 6475.00 4678.30 19.92 20.24 340.01 345.08 7.000 56.34 0.00 56.33 Pass 6489.44 4729.78 6500.00 4694.23 19.99 20.32 339.88 344.95 7.000 62.79 0.00 62.79 Pass 6513.59 4749.35 6525.00 4710.18 20.06 20.41 339.74 344.81 7.000 69.23 0.00 69.23 Pass 6537.71 4768.89 6550.00 4726.01 20.13 20.51 339.66 344.74 7.000 75.81 0.00 75.81 Pass 6561.79 4788.39 6575.00 4741.70 20.20 20.60 339.66 344.73 7.000 82.55 0.00 82.55 Pass 6585.81 4807.85 6600.00 4757.24 20.27 20.70 339.70 344.77 7.000 89.45 0.00 89.45 Pass 6609.80 4827.28 6625.00 4772.66 20.34 20.81 339.76 344.84 7.000 96.51 0.00 96.51 Pass 6633.75 4846.68 6650.00 4787.98 20.41 20.92 339.82 344.90 7.000 103.69 0.00 103.69 Pass 6657.66 4866.05 6675.00 4803.20 20.48 21.03 339.88 344.95 7.000 110.99 0.00 110.98 Pass 6681.53 4885.39 6700.00 4818.33 20.55 21.15 339.93 345.01 7.000 118.40 0.00 118.40 Pass 6705.40 4904.72 6725.00 4833.44 20.62 21.25 339.97 345.05 7.000 125.83 0.00 125.83 Pass 6729.29 4924.08 6750.00 4848.61 20.69 21.35 339.99 345.06 7.000 133.20 0.00 133.20 Pass 6753.20 4943.44 6775.00 4863.85 20.77 21.45 339.98 345.06 7.000 140.50 0.00 140.50 Pass 6777.13 4962.83 6800.00 4879.14 20.84 21.55 339.96 345.03 7.000 147.75 0.00 147.74 Pass 6801.08 4982.23 6825.00 4894.49 20.91 21.63 339.90 344.98 7.000 154.92 0.00 154.92 Pass 6825.04 5001.64 6850.00 4909.92 20.98 21.72 339.82 344.89 7.000 162.03 0.00 162.03 Pass 6849.03 5021.07 6875.00 4925.41 21.05 21.81 339.70 344.78 7.000 169.08 0.00 169.07 Pass __ _._.._"______.__"..__"_ _.~,..__ ___""___._.__._..., __ ______._.__~_..._____.__...,_______ ___ _'___'_ ___."_.._n_____.___'___.._.__.. -.----"'--------.----- .__,_______,_·,_·_._.·~_,_·R_____..___,·_________ __ ) ) Sperry-Sun - Draft Copy Anticollision Report ~ompany:: BP Amoco thne: 08:44:58 Page; ". ,'7 Fi~'~£,. '.' Milne point:: Wiéll: MPL~43;'+~¿Ndrth' Reference Site: M Pt LPad (;;o.(>rdlnate(NE) I~ef~~eöce: #efe!:~~ce,,,,ell: MPL~43 V ertlcal(T'\!I:) ~èfçrencer MPL::43: 50.8. OracÎe 'Refer',erice Wel1patb: Plah MPL-43 . Db: Site: M pt L Pad Well: MPL-43 Rule Assigned: NOERRORS Wellpath: MPL-43PB1 V5 Inter-Site Error: 0.00 ft Reference ' Offset ,S~ml~Majqr~1S ........ .... ........ ........ . '.".. '. .......>Ct!.Ctr No~Go, ." ~lIqwable 'v,,· Mn .......~ . TVD MD' TV» ..Ref ,,' Offset !FQ+AZI ·:rFQ-H~.< CaslnglHSJ~~~~n.ce\~re~. .' Deviation Warning "ft ft ft it ft' ft;' d~g deg . in; . ft" > '; ff ft< 6873.03 5040.52 6900.00 4940.98 21.13 21.89 339.57 344.64 7.000 176.05 0.00 176.04 Pass 6897.07 5059.99 6925.00 4956.64 21.20 21.98 339.44 344.52 7.000 182.90 0.00 182.90 Pass 6921.14 5079.49 6950.00 4972.39 21.27 22.07 339.33 344.41 7.000 189.63 0.00 189.63 Pass 6945.25 5099.02 6975.00 4988.24 21.35 22.16 339.23 344.30 7.000 196.25 0.00 196.25 Pass 6969.39 5118.57 7000.00 5004.18 21.42 22.25 339.12 344.20 7.000 202.75 0.00 202.75 Pass 6993.55 5138.15 7025.00 5020.21 21.49 22.34 339.02 344.10 7.000 209.14 0.00 209.14 Pass 7017.74 5157.74 7050.00 5036.32 21.57 22.44 338.92 343.99 7.000 215.44 0.00 215.44 Pass 7041.96 5177.36 7075.00 5052.51 21.64 22.53 338.81 343.88 7.000 221.63 0.00 221.63 Pass 7066.18 5196.97 7100.00 5068.68 21.72 22.62 338.73 343.81 7.000 227.84 0.00 227.84 Pass 7090.37 5216.57 7125.00 5084.75 21.79 22.71 338.71 343.78 7.000 234.13 0.00 234.13 Pass 7114.55 5236.16 7150.00 5100.74 21.87 22.80 338.73 343.80 7.000 240.50 0.00 240.50 Pass 7138.70 5255.73 7175.00 5116.64 21.94 22.90 338.79 343.86 7.000 246.93 0.00 246.93 Pass 7162.86 5275.30 7200.00 5132.55 22.01 22.99 338.85 343.93 7.000 253.35 0.00 253.35 Pass 7187.03 5294.87 7225.00 5148.48 22.09 23.09 338.92 344.00 7.000 259.75 0.00 259.74 Pass 7211.21 5314.46 7250.00 5164.42 22.16 23.19 338.99 344.06 7.000 266.11 0.00 266.10 Pass 7235.41 5334.06 7275.00 5180.45 22.24 23.28 339.05 344.12 7.000 272.37 0.00 272.37 Pass 7259.69 5353.73 7300.00 5196.75 22.32 23.37 339.09 344.17 7.000 278.29 0.00 278.29 Pass 7284.07 5373.48 7325.00 5213.35 22.39 23.46 339.11 344.19 7.000 283.83 0.00 283.83 Pass 7308.53 5393.30 7350.00 5230.26 22.47 23.55 339.12 344.19 7.000 288.99 0.00 288.99 Pass 7333.06 5413.16 7375.00 5247.39 22.54 23.63 339.10 344.18 7.000 293.85 0.00 293.85 Pass 7357.60 5433.04 7400.00 5264.61 22.62 23.72 339.08 344.15 7.000 298.61 0.00 298.61 Pass 7382.16 5452.94 7425.00 5281.91 22.70 23.80 339.03 344.11 7.000 303.27 0.00 303.27 Pass 7406.74 5472.85 7450.00 5299.29 22.78 23.88 338.97 344.05 7.000 307.84 0.00 307.84 Pass 7431.35 5492.78 7475.00 5316.83 22.85 23.96 338.90 343.98 7.000 312.21 0.00 312.21 Pass 7456.01 5512.76 7500.00 5334.57 22.93 24.05 338.83 343.90 7.000 316.30 0.00 316.30 Pass 7480.71 5532.77 7525.00 5352.51 23.01 24.13 338.74 343.82 7.000 320.12 0.00 320.11 Pass 7505.45 5552.81 7550.00 5370.65 23.09 24.21 338.65 343.73 7.000 323.65 0.00 323.65 Pass 7530.23 5572.89 7575.00 5388.98 23.16 24.29 338.56 343.63 7.000 326.90 0.00 326.90 Pass 7555.05 5592.99 7600.00 5407.49 23.24 24.37 338.46 343.53 7.000 329.89 0.00 329.89 Pass 7579.90 5613.12 7625.00 5426.20 23.32 24.45 338.36 343.43 7.000 332.60 0.00 332.59 Pass 7604.77 5633.27 7650.00 5445.09 23.40 24.52 338.24 343.32 7.000 335.02 0.00 335.02 Pass 7629.67 5653.43 7675.00 5464.21 23.48 24.60 338.11 343.19 7.000 337.13 0.00 337.13 Pass 7654.59 5673.62 7700.00 5483.54 23.56 24.67 337.96 343.04 7.000 338.93 0.00 338.93 Pass 7679.52 5693.82 7725.00 5503.09 23.64 24.75 337.79 342.86 7.000 340.40 0.00 340.40 Pass 7704.47 5714.03 7750.00 5522.84 23.72 24.82 337.60 342.67 7.000 341.57 0.00 341.57 Pass 7729.42 5734.24 7775.00 5542.78 23.80 24.89 337.40 342.47 7.000 342.43 0.00 342.43 Pass 7754.39 5754.46 7800.00 5562.92 23.88 24.96 337.18 342.26 7.000 342.98 0.00 342.98 Pass 7779.35 5774.69 7825.00 5583.24 23.96 25.03 336.96 342.04 7.000 343.24 0.00 343.23 Pass 7804.31 5794.91 7850.00 5603.71 24.04 25.09 336.73 341.81 7.000 343.23 0.00 343.23 Pass 7829.27 5815.13 7875.00 5624.30 24.12 25.16 336.50 341.57 7.000 343.03 0.00 343.03 Pass 7854.23 5835.34 7900.00 5645.00 24.20 25.22 336.26 341.34 7.000 342.64 0.00 342.64 Pass 7879.18 5855.55 7925.00 5665.81 24.28 25.29 336.02 341.10 7.000 342.05 0.00 342.05 Pass 7904.12 5875.76 7950.00 5686.78 24.36 25.35 335.77 340.85 7.000 341.18 0.00 341.18 Pass 7929.04 5895.95 7975.00 5707.94 24.44 25.41 335.51 340.59 7.000 339.96 0.00 339.96 Pass 7953.94 5916.11 8000.00 5729.29 24.52 25.47 335.23 340.31 7.000 338.41 0.00 338.41 Pass 7978.81 5936.26 8025.00 5750.83 24.60 25.53 334.94 340.02 7.000 336.51 0.00 336.51 Pass 8003.63 5956.37 8050.00 5772.58 24.68 25.58 334.63 339.70 7.000 334.19 0.00 334.19 Pass 8028.40 5976.43 8075.00 5794.55 24.76 25.63 334.29 339.37 7.000 331 .46 0.00 331 .46 Pass 8052.04 5995.59 8100.00 5816.73 24.84 25.69 333.93 339.00 7.000 328.31 0.00 328.31 Pass 8072.40 6012.21 8125.00 5839.11 24.89 25.74 333.55 338.63 7.000 325.03 0.00 325.02 Pass 8092.81 6029.03 8150.00 5861.62 24.94 25.78 333.15 338.23 7.000 321.83 0.00 321.83 Pass '--'~--'-- ---,------~--_.._--,- --,--~~---_.. ~--_._-, -,,--~.- -- -- ----".-.--.-.---.""--,-....--..-,---. ----,--- ------,------~._-~--- "-_.__.~--_.._--,.._----_.~-------------". -- -.--'.-.---..- - -.- .._---. -.. ------ ) ) Sperry-SUD - Draft Copy Anticollision Report Company: BPAmoco Date: 3/18/2004 Time:······.····08:44:58· Page:.' 8 FI~ld: , Milne Point ' "', ",':. . '"".' ,," " .::.... ........ :'.:: :..:.... . . ..... ., Refe~enceSite: ,Mpt L Pad C::;o..ordlnate(NE)R~f~rence::> '.'Nên;MPL~43. Truå"Ñorth 'Jlefe~enfe'Yen: .'MPL-43 y ertlc~1 (TVD)R~f~rence: MPL~43: 50.8 .. V' ',' , Refer~nce Wenpath: Plan MPL;.43 Db: ..Or.åcle Site: M pt L Pad Well: MPL-43 Rule Assigned: NOERRORS Wellpath: MPL-43PB1 V5 Inter~Site Error: 0.00 ft . ~eference, Offset Seml.-I\iI!Jor;µis .' .... ..' .' ....... ...... .. qr~ç~~>{,)So~~ó ·..·Ano~~~I~;, MIl" TVD MD':" 'TvD Ref . Offsét Tl\Ø+A.~I.·...TFQ..HS .C~sll1gIBSJìsta~çe ··.·..Are,~ Devlat1()n/ ;f't ' ft 'ft ' ft' ft "tF :deg d~g in' ft ff ft 8113.27 6046.06 8175.00 5884.25 24.98 25.83 332.72 337.81 7.000 318.74 0.00 318.74 Pass 8133.78 6063.29 8200.00 5907.01 25.01 25.88 332.27 337.37 7.000 315.75 0.00 315.75 Pass 8154.33 6080.72 8225.00 5929.91 25.05 25.92 331.82 336.92 7.000 312.79 0.00 312.79 Pass 8174.92 6098.33 8250.00 5952.98 25.08 25.96 331.38 336.49 7.000 309.74 0.00 309.73 Pass 8200.00 6119.99 8275.00 5976.20 25.13 26.00 330.96 336.08 7.000 306.63 0.00 306.63 Pass 8216.25 6134.14 8300.00 5999.57 25.15 26.04 330.57 335.69 7.000 303.35 0.00 303.35 Pass 8236.99 6152.33 8325.00 6023.06 25.18 26.07 330.17 335.30 7.000 300.14 0.00 300.14 Pass 8257.78 6170.70 8350.00 6046.65 25.21 26.10 329.76 334.89 7.000 297.02 0.00 297.02 Pass 8278.62 6189.26 8375.00 6070.34 25.24 26.14 329.33 334.48 7.000 293.98 0.00 293.97 Pass 8300.00 6208.45 8400.00 6094.12 25.27 26.17 328.90 334.06 7.000 291.01 0.00 291.01 Pass 8320.44 6226.92 8425.00 6118.02 25.29 26.20 328.46 333.62 7.000 288.05 0.00 288.04 Pass 8341 .42 6246.00 8450.00 6142.03 25.32 26.22 328.01 333.18 7.000 285.08 0.00 285.08 Pass 8362.44 6265.25 8475.00 6166.14 25.34 26.25 327.55 332.73 7.000 282.10 0.00 282.10 Pass 8383.51 6284.66 8500.00 6190.34 25.37 26.28 327.08 332.28 7.000 279.17 0.00 279.17 Pass 8400.00 6299.94 8525.00 6214.58 25.39 26.30 326.61 331.82 7.000 276.48 0.00 276.48 Pass 8425.85 6324.03 8550.00 6238.87 25.41 26.32 326.15 331.37 7.000 273.92 0.00 273.92 Pass 8447.11 6343.97 8575.00 6263.19 25.43 26.34 325.69 330.93 7.000 271.62 0.00 271.62 Pass 8468.59 6364.22 8600.00 6287.55 25.45 26.36 325.25 330.50 7.000 269.49 0.00 269.48 Pass 8493.41 6387.67 8625.00 6311.97 25.48 26.38 324.81 330.06 7.000 267.28 0.00 267.28 Pass 8518.20 6411.10 8650.00 6336.43 25.52 26.40 324.35 329.60 7.000 264.85 0.00 264.85 Pass 8542.96 6434.50 8675.00 6360.94 25.56 26.42 323.88 329.13 7.000 262.21 0.00 262.20 Pass 8567.69 6457.88 8700.00 6385.50 25.60 26.44 323.39 328.64 7.000 259.33 0.00 259.33 Pass 8592.39 6481.22 8725.00 6410.10 25.64 26.45 322.87 328.12 7.000 256.23 0.00 256.22 Pass 8617.05 6504.53 8750.00 6434.74 25.68 26.47 322.34 327.59 7.000 252.89 0.00 252.89 Pass 8641.67 6527.79 8775.00 6459.43 25.72 26.49 321.77 327.02 7.000 249.32 0.00 249.32 Pass 8666.24 6551.01 8800.00 6484.16 25.76 26.50 321.15 326.40 7.000 245.52 0.00 245.52 Pass 8690.74 6574.17 8825.00 6508.94 25.80 26.51 320.47 325.72 7.000 241.51 0.00 241.51 Pass 8715.18 6597.27 8850.00 6533.75 25.84 26.52 319.72 324.97 7.000 237.28 0.00 237.28 Pass 8739.55 6620.30 8875.00 6558.61 25.88 26.53 318.89 324.15 7.000 232.86 0.00 232.86 Pass 8763.85 6643.26 8900.00 6583.49 25.92 26.54 317.97 323.22 7.000 228.27 0.00 228.27 Pass 8788.06 6666.14 8925.00 6608.41 25.96 26.54 316.94 322.19 7.000 223.55 0.00 223.55 Pass 8812.18 6688.93 8950.00 6633.34 25.99 26.55 315.79 321.04 7.000 218.71 0.00 218.71 Pass 8836.22 6711.65 8975.00 6658.30 26.03 26.56 314.53 319.78 7.000 213.75 0.00 213.75 Pass 8860.18 6734.30 9000.00 6683.27 26.07 26.56 313.19 318.44 7.000 208.62 0.00 208.62 Pass 8884.06 6756.87 9025.00 6708.26 26.11 26.56 311.75 317.00 7.000 203.35 0.00 203.35 Pass 8907.86 6779.36 9050.00 6733.25 26.15 26.57 310.20 315.45 7.000 197.96 0.00 197.96 Pass 8931.59 6801.79 9075.00 6758.25 26.19 26.57 308.55 313.80 7.000 192.45 0.00 192.45 Pass 8955.26 6824.16 9100.00 6783.25 26.23 26.57 306.81 312.06 7.000 186.84 0.00 186.84 Pass 8978.87 6846.47 9125.00 6808.25 26.27 26.57 304.95 310.20 7.000 181.15 0.00 181.15 Pass 9002.41 6868.71 9150.00 6833.24 26.30 26.57 302.98 308.23 7.000 175.40 0.00 175.40 Pass 9024.94 6890.03 9175.00 6858.23 26.33 26.58 300.89 306.10 7.000 169.86 0.00 169.86 Pass 9047.07 6911.06 9200.00 6883.22 26.36 26.58 298.76 303.89 7.000 164.75 0.00 164.75 Pass 9069.42 6932.42 9225.00 6908.21 26.38 26.59 296.60 301.66 7.000 160.08 0.00 160.08 Pass 9092.01 6954.09 9250.00 6933.20 26.41 26.59 294.44 299.40 7.000 155.85 0.00 155.85 Pass 9114.80 6976.07 9275.00 6958.19 26.43 26.60 292.29 297.15 7.000 152.04 0.00 152.04 Pass 9137.80 6998.34 9300.00 6983.18 26.44 26.60 290.16 294.90 7.000 148.63 0.00 148.63 Pass 9143.35 7003.72 9306.00 6989.18 26.44 26.60 289.66 294.36 7.000 147.86 0.00 147.86 Pass \ STATE OF ALASKA \. ... .. ,. .... r'" ALASKA .t AND GAS CONSERVATION COM!\-. ~ION ri~, t:::"(~; ,: WELL COMPLETION OR RECOMPLETION REPORT AND LÒG ~AR () 4: 2004 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned B Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3636' NSL, 5040' WEL, SEC. 08, T13N, R10E, UM Top of Productive Horizon: N/A Total Depth: 3700' NSL, 474' WEL, SEC. 06, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 544838' y- 6031825' Zone- ASP4 TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 544072. y- 6037165' Zone- ASP4 18. Directional Survey BYes 0 No 21. Logs Run: MWD , GR , IFR/CASANDRA , RES, PWD One Other 5. Date Comp., Susp., or Aband. 1/16/2004 ,"'- 6. Date Spudded 1/612004 ' 7. Date T.D. Reached 1/12/2004 .. 8. KB Elevation (ft): KBE = 50.80' 9. Plug Back Depth (MD+ TVD) 6077' + 4426' 10. Total Depth (MD+TVD) ~ 9306' + 6989" 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1",~Þ:J(wéil ðlå~~:~ B Develoßfn~rnr\\'~\;: 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-224 304-024 13. API Number 50- 029-23190-00 14. Well Name and Number: M PL-43 15. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands Ft Ft 16. Property Designation: ADL 025509 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) CASING, LINER AND CEMENTING RECORD !'·S:§J:i(J~G',I'[¡)gATIIi:'MQ,:',:S~~IN~I:~,t;~'T~','ŒÞ ,,~'!I'I,:O~:I!ili'I::, ,:,~b1;reM;:! '",:;,I:,,:¡I,I,Ø~':""::, ItsomoM' 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 35' 6097' 35' 4391' 12-1/4" 250 sx Class 'L', 225 sx Class 'G' I"I~MQLJ,~~::::¡:: :,¡I'I~::~&'iligEH':'I~ 22. i: I: ';il,::'I':,' :;;:: CA~I'~G:;,:~::!",; I:;·, ¡ :,':' ,il:';1 ':,::': ,",'~;",. ,il'::,:~"I,i':,:/; :;'!':i,:":,I"II,:.i::':':,,I¡:¡,:,I:::' 'I,.:,:. ,: :',1,:\ :,!:',"'ßI?E',,"':I: ,,'::' 1"I,I!,'W:1í;,;llpeRI,E:l1~I'::I 20" 92# 9-5/8" 40# H-40 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): N/A MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested SIZE N/A TVD DEPTH SET (MD) PACKER SET (MD) ::2S{'I',,··, .",.' '1'1 I', :"''''';''11'1 ,,:,,',1',','·'1";,,",' "'1,1, ',,',:,;1,': ,I", ",1,',.':"" ,1"',";'.' 1'1,:",,1 ,'/1",,,,,,1 ;, 'II ,:1,."11,,,,:,1,,: ," I ' , I' :::":"','.,~Slp¡,'~~q~q~E¡"I'~~~I~~m':~9~~E2:9';EJP;'!',':: ,'~ 1,'::.: ,,'11."'): ..:1'::1," DEPTH INTERVAL (MD) 8784' 8187' 6077' AMOUNT & KIND OF MATERIAL USED P&A with 48 Bbls Class 'G' (1st Cement Plug) Set 2nd Cement Plug with 48 Bbls Class 'G' Set EZSV retainer with 47 Bbls Cement PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-Bsl Press. 24-HoUR RATE GAs-MCF W A TER-BSl CHOKE SIZE GAS-Oil RATIO GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". :-.....~.,~.:t ç~""",;;' è,---z-. __) Ù r·\":'¡;~!t: ":~~l"¡ \ c¡ . Z-l., v,':: ; i,'.:' ',I, ..,,!" ) ,,~~~~~Q;- !:~:~, 27. None tBWSBFl .:082OM CONTINUED o~~s~ GE\ N A L Form 10-407 Revised 12/2003 (yç 28. GEOLOGIC MARKERS ') 29. lRMA TION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD THRZ 9036' 6719' None TKLB KLGM 9092' 9164' 6775' 6847' MAR 0 4 2004 fH 30. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true a~rrect to the best of my knowledge. Signed Sondra ~< O~e Technical Assistant Date ()3 -t)</-M MPL-43 203-224 304-024 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Walter Quay, 564-4178 Permit No.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 OPJG\NÞ,L .) BP QperatiónsSljmmary d~eport . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Date. From- To Hours Task Code NPT . Phase 1/5/2004 00:00 - 00:30 0.50 MOB P PRE 00:30 - 01 :00 0.50 MOB P PRE 01 :00 - 02:00 1.00 MOB P PRE 02:00 - 03:30 1.50 MOB P PRE 03:30 - 04:00 0.50 MOB P PRE 04:00 - 07:00 3.00 RIGU P PRE 07:00 - 10:30 3.50 RIGU P PRE 10:30 - 00:00 13.50 DRILL P SURF 1/6/2004 00:00 - 01 :30 1.50 DRILL P SURF 01 :30 - 02:00 0.50 DRILL P SURF 02:00 - 04:00 2.00 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 05:30 1.00 BOPSURP SURF 05:30 - 06:00 0.50 DRILL P SURF 06:00 - 06:30 0.50 DRILL P SURF 06:30 - 08:00 1.50 DRILL P SURF 08:00 - 00:00 16.00 DRILL P SURF 00:00 - 05:30 5.50 DRILL P SURF 05:00 - 07:00 2.00 DRILL P SURF 07:00 - 09:00 2.00 DRILL P SURF 09:00 - 10:00 1.00 DRILL P SURF 10:00 - 11 :30 1.50 DRILL P SURF 11 :30 - 12:30 1.00 DRILL P SURF 12:30 - 21 :30 9.00 DRILL P SURF 21 :30 - 23:30 2.00 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 00:00 - 02:30 2.50 DRILL P SURF 02:30 - 04:00 1.50 DRILL P SURF 04:00 - 17:00 13.00 DRILL P SURF 17:00 - 19:00 2.00 CASE P SURF 19:00 - 23:30 4.50 CASE P SURF 23:30 - 00:00 0.50 CASE P SURF 00:00 - 01 :30 1.50 CASE P SURF 01 :30 - 03:30 2.00 CASE P SURF 03:30 - 09:30 6.00 CASE P SURF 09:30 - 10:30 1.00 CASE P SURF 10:30 - 17:30 7.00 CASE P SURF 17:30 - 18:00 0.50 CASE P SURF 1/7/2004 1/8/2004 1/9/2004 Pélge tof ~ Start: 1/5/2004 Rig Release: 1/19/2004 Rig Number: Spud Date: 1/6/2004 End: Dèscriþtion of Operations Skid rig floor from drlg position to move position Move rig off MPF-88 Move rig from MPF-Pad to MPL-Pad Move rig onto MPL-43 - Shim rig Skid rig floor from move position to drlg position - Spot and berm rockwasher - Rig up service lines to rig floor - Connect Top Drive electrical lines - Prepare pipe shed to recieve drill pipe (Accept rig at 07:00 hrs) Nipple up divertor - Riser - Flowline - Hole fill lines - Load 5" Drill pipe in pipe shed Pick up 5" drill pipe from pipe shed - make up in mouse hole - Due to ice plug in conductor pipe at 45' deep which caused more time picking up - stand back in derrick - Total 94 stands - (MPU went to phase 3 driving conditions @ 21: 15 hrs) Pick up 5" HWT - Stand back in derrick Clear rig floor Change out saver sub from 4" HT-38 to 4 1/2" IF Pre Spud meeting with all personnel - Function test Divertor I Accumulator test, the right to witness test was wavier by Lou Grimaldi AOOGC Pick up motor - make up bit - fill stack check for leaks, R/U wire line unit Spud well @ 06:00 1/6/2004, Drilling from 112 to 131' .~ Picking up MWD,Flex des. Directional drill 131 to 2,229' run gyro @ 182', 80 rpms 500 gals per min 1650 psi, AST 6.25, ART 4.08 Directional drill 2,229' to 3050' 80 rpms 500 gals per min 1650 psi, Circ, Three bottoms up Pump out to HWDP with full drilling rate Stand back BHA Pickup new bit, reset bend on motor to 1.22, trip in with Bha Trip to bottom, washed 60 ft to bottom Directional drill 3050' to 4549' 120 rpms 500 gals per min 2000 psi, AST.5 ART 6.08 Circ, three bottoms up, 500 gals min. 1800 psi, 120 rpms Pumping out to HWDP with full drilling rate Finish pumping out to HWDP, no problems Trip to bottom, wash 60 ft to bottom Directional drill 4549' to 6106' TD 120 rpms 500 gals per min 2080 psi AST 1.75 ART 6 Circ Two bottoms up with 120 rpms 500 gals min, 1700 psi Pump out to HWP, with full drilling rate, no problems Trip to bottom Finish trip to bottom washed 60 ft. Circ two bottoms up with 120 rpms, 500 gals per min., 1700 psi Slug pipe, Tripping out Rig up to run 9 5/8 csg PJSM, picking up 9 5/8 40# L-80 Btc csg 147 jts 6052' , shoe @ 6097', float collar 6052', landing collar 6010, ES cementer 1927' SO wt 150K Rig down Franks tool, Rig up cement head Printed: 1/26/2004 10:29:42 AM ',) ) BP Op.eratiorls.. SUmmary<Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Date From -To HOurs Task Code NPT Phase 1/9/2004 18:00 - 20:30 2.50 CASE P SURF 20:30 - 23:00 2.50 CEMT P SURF 23:00 - 00:00 1.00 CEMT P SURF 1/10/2004 00:00 - 01 :30 1.50 CEMT P SURF 01 :30 - 03:00 1.50 CEMT P SURF 03:00 - 05:30 2.50 CEMT P SURF 05:30 - 07:00 1.50 CEMT P SURF 07:00 - 08:30 1.50 CASE P SURF 08:30 - 10:30 2.00 CASE P SURF 10:30 - 16:00 5.50 CASE P SURF 16:00 - 19:00 3.00 CASE P SURF 19:00 - 19:30 0.50 CASE P SURF 19:30 - 20:30 1.00 CEMT P SURF 20:30 - 22:00 1.50 CASE P SURF 22:00 - 23:30 1.50 CASE P SURF 23:30 - 00:00 0.50 CASE P SURF 1/11/2004 00:00 - 01 :00 1.00 CASE P SURF 01 :00 - 02:00 1.00 CEMT P SURF 02:00 - 03:00 1.00 CASE P SURF 03:00 - 03:30 0.50 CASE P SURF 03:30 - 10:30 7.00 DRILL P INT1 10:30 - 11 :00 0.50 DRILL P INT1 11 :00 - 14:30 3.50 DRILL P INT1 Start: 1/5/2004 Rig Release: 1/19/2004 Rig Number: Spud Date: 1/6/2004 End: Descri ptiÖnof Operations Circ. and thin mud for cement job 9 bbls min 370 psi, no losses Cement with Schlumberger, with 10bbls water,test lines to 4,000,15 bbls CW 100, mixed and pumped 40 bbls mud push mixed @ 10.2, drop bottom plug, load top plug, mixed and pumped 250 sxs. Artie set light, yield 4.45, 198 bbls mixed @ 10.7,tailed wI 225 sxs Class G yield 1.16 46 bbls mixed @ 15.8, kicked out top plug with 30 bbls water, swap over to rig displace with 274 bbls mud,75 bbls water,follow with 72 bbls mud, displace @ 9 bbls min. 800 psi, bump plug with 1800 psi, float held, mudlcement interface @ surface last ten bbls of displacement Load closing plug in head, open ES cementer with 2,300 psi, circ contaminated mud and cement out, 70 bbls good cement to surface Circ and condition mud for cement stage 2 Cement with Schlumberger with 10 bbls water,test lines to 4000psi, 15 bbls CW 100, 45 bbls Mud push mixed @ 10.2, with 2 gals dye in spacer, mixed and pumped 215 sxs, 170 bbls Arctic set light mixed @ 10.7 6 bbls min 300 psi, Dye @ surface, kicked out closing plug with 30 bbls water, displace with rig with 116 bbls mud 6 bbls min 350 psi, close ES cementer with 1500 psi, checked for flow back tool closed, 100 bbls good cement to surface Flush diverter system with water,Lay down landing jt, Nipple down diverter M/U Speed head, Energize metal to metal seal, Test to 1,000 psi f/1 0 min. Nipple up BOPS Rig up and test BOPS and manifold to 250-3500 psi for 5 min. per test, hydrill 250-2500 psi for 5 min. per test, the test was witness by Jeff Jones wI AOOGC, install wear ring Change Elevators and bails, Picking up BHA # 3, bit 8 3/4 Hem 605 PDC with 5 14 jets, 7" sperry drill 1.22 bend,stab,float sub, 6 3/4 GRlRES/PWD, 6 3/4 DM, hang off sub,6 3/4 ACAL,stab,3 flex DC,stab,12 HWDP, jars,5 HWDP, 15 dril pipe, Ghost reamer Trip in to 1927 Drill ES cemnter @ 1927 with 400 gals min 500 psi, 60 rps, 5-8K bit wt. Trip in to 5924 Cut and slip drilling line, service top drive Test csg to 2500 psi for 30 min. good test Finish Csg test 2500 psi for 30 min. Drill landing collar, float and shoe, drill new hole to 6126' Circ and displace hole with 8.4 new LSND mud FIT test with 8.4 mud, 830 psi, 4438 TVD, = EMW 12.0, good test Directional drill 6126' to 7190" 120 rpms 625 gals per min 2000 psi, Circ change shaker screens, losing to much mud Directional drill 7190' to 7705' 120 rpms 625 gals per min 2000 psi" losing mud over shakers, start angle drop from 50 degrees Printed: 1/26/2004 10:29:42 AM ') ) BP OperationsSurnmary.'Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 1/19/2004 Rig Number: Spud Date: 1/6/2004 End: Date From - Tb Hours Task Code NPT Phase Description of Operations 1/11/2004 14:30 - 15:30 1.00 DRILL P INT1 Circ change shaker screens, from 180 to 80s, losing to much mud 15:30 - 17:30 2.00 DRILL P INT1 Directional drill 7705' to 7990' 120 rpms 625 gals per min 2000 psi" losing mud over shakers 17:30 - 18:30 1.00 DRILL P INT1 Circ change shaker screens, from 80s to 200s, losing to much mud, change screens down to 100s 18:30 - 20:00 1.50 DRILL P INT1 Directional drill 7990' to 8270' 120 rpms 500 gals per min 1800 psi, next to no lost over shaker. 20:00 - 21 :30 1.50 DRILL P INT1 Screen up shakers from 100 to 230s with 400 gals min. near total lost to rock washer, screen down to 100s 21 :30 - 00:00 2.50 DRILL P INT1 Directional drill 8270' to 8540' 120 rpms 550 gals per min 2050 psi, AST 3.25 ART 6.25 ECD 10.4 1/12/2004 00:00 - 10:30 10.50 DRILL P INT1 Directional drill 8540' to 9306' 120 rpms 550- 625 gals per min 2300-3000 psi, at 8,700' raised mud wt to 9.8 as planned, ECD 10.6 to 11.0 ppg- With stand down at 9306', Check flow before connection - slight flow 10:30 - 11 :00 0.50 DRILL P INT1 Put pump back on and Circulate bottoms up at 625 gpms, 2750 psi, pit volume increase 8 bbls as circulation bottoms up - initial ECD 11.06 final ECD 10.6, - shut well in at 11 :08 am - Monitor well. - SIDP 60 psi, SICP 100 psi - SPR at 9023 560 psi at 40 spm 11 :00 - 12:30 1.50 DRILL N DPRB INT1 Circ. thru choke with drillers method holding 650 psi, shut in pressure were 60 SIDPP 100 SICP slow pump rate 560-40 spm 12:30 - 15:30 3.00 DRILL N DPRB INT1 Begin Circ on choke kill wt mud 10.0, SIDPP 100, ICP 650 wI 40 spm, mud wt returns 9.8, 15:30 - 16:00 0.50 DRILL N DPRB INT1 Pump down well shut in SIDPP 100 psi, SICP 180 psi 16:00 - 19:00 3.00 DRILL N DPRB INT1 Begin Circ.,on choke, 10.5 kill wt. mud ICP 650 wI 40spm with 9.8 returns, 19:00 - 19:30 0.50 DRILL N DPRB INT1 Shut well in, check pressure, SIDPP 70, SICP 180 (lots of oil in mud 8%) 19:30 - 22:30 3.00 DRILL N DPRB INT1 Circ on choke, raise mud wt to 10.7 ICP 725 psi full circ mud returns 10.1, 22:30 - 23:30 1.00 DRILL N DPRB INT1 Circ on choke, raise mud wt to 10.8 ICP 700 psi, with choke wide open, started to lose mud. 23:30 - 00:00 0.50 DRILL N DPRB INT1 Open Hydrill and worked pipe, Circ with 700 psi 40 spm losing about 20 bbls hr. 1/13/2004 00:00 - 03:00 3.00 DRILL N DPRB INT1 Circ slow, rotate 50 rpms and reciprocate pipe, starting circ @ 40 spm with 700psi, hole taking mud up to 60 bbls per hr. slowed to 3 bbls per hr., increase circ rate up to 300 gpm 1040 psi mud wt return cut from 10.8 to 9.2, 8 % oil in mud ECD 11.4 with 300 gpm, lost total 1 00 bbls to hole 03:00 - 05:00 2.00 DRILL N DPRB INT1 Displace well with 580 bbls, new 10.8 LSNO mud with 300 gals per min. - Gas breaking out in bell nipple, looks like boiling water. Oil in returns. 05:00 - 11 :30 6.50 DRILL N DPRB INT1 Circulate down flow line, increase mud wt from 10.8 to 11.0 - increase pump rate 300 to 338 gpm, ECO 11.4 - 11.6 ppg - lot of Gas and oil in returns. Initial loss rate 60-bbllhr. Average loss rate 75-bbllhr. Slow pump rate to 84-gpm. Rotate and reciprocate - 50-rpm, 20K torque. 11 :30 -12:00 0.50 DRILL N DPRB INT1 Observe well. Flow observed. Pull out of hole one stand to 9,213-ft. Gained 5-bbl while standing OP in derrick. 12:00 - 17:30 5.50 DRILL N DPRB INT1 Circulate 11.1-lb/gal mud @ 84-gpm, 320-psi, 50-rpm, Printed: 1/26/2004 10:29:42 AM ) Page4of8 SP Operations. Summary Rèport . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 1/19/2004. Rig Number: Spud Date: 1/6/2004 End: . Date From..; To Hours Task Code NPT Phase Description of Qperåtions 1/13/2004 12:00 - 17:30 5.50 DRILL N 17:30 - 18:00 0.50 DRILL N 18:00 - 19:00 1.00 DRILL N 19:00 - 21 :00 2.00 DRILL N 21 :00 - 22:00 1.00 DRILL N 22:00 - 23:30 1.50 DRILL N 23:30 - 00:00 0.50 DRILL N 1/14/2004 00:00 - 01 :00 1.00 DRILL N 01 :00 - 02:00 1.00 DRILL N 02:00 - 03:00 1.00 DRILL N 03:00 - 03:30 0.50 DRILL N 03:30 - 04:00 0.50 DRILL N 04:00 - 04:30 0.50 DRILL N 04:30 - 05:00 0.50 DRILL N 05:00 - 07:00 2.00 DRILL N 07:00 - 07:30 0.50 DRILL N 07:30 - 09:00 1.50 DRILL N 09:00 - 11 :30 2.50 DRILL N 11 :30 - 13:00 1.50 DRILL N 13:00 - 13:30 0.50 DRILL N 13:30 -14:30 1.00 DRILL N 14:30 - 15:00 0.50 DRILL N DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 DPRB INT1 reciprocate pipe. MW In 11.3-lb/gal, MW Out 9.9-lb/gal (non-pressure balance), 11.3-lb/gal (pressurised balance). Increased flowrate to 244-gpm, 880-psi, 50-rpm, ECD 11.73-lb/gal, 80-bbl/hr losses. Flow check: 5-bbl gain in 8-min. Circulate 11.3-lb/gal mud @ 120-gpm, 410-psi, 50-rpm, reciprocate pipe. MW Out 9.8 to 10.5-lb/gal Circulate 11.3-lb/gal mud @ 250-gpm, 890-psi, 80-rpm. ECD climbed from 11.75 to 11.86-lb/gal. Losing 120-bbl/hr Slow pump to 140-gpm @ 500-psi Oil content 10%., Circ. 2 bbls min 240 psi, monitor well gain two bbls Circ. 2 bbls min with no returns, shut down and monitor well Flow check: 2-bbl gain in 12-min. Monitor well, no gains or losses Poh 9213 to 8365 filling through DP 10 bbls gain taken pulling pipe Monitor well no gains no loss Close annular, dead head 50 bbls 11.5 down back side with 3 bbls min. 220 psi, shut down pressure 40 psi, trying to get back side to take mud Open annular, slight flow, close annular,dead head 50 bbls 11.5 down back side with 3 bbls min. 230 psi, shut down press 50 psi Open annular, flow more flow back 8 bbls, close Annular,dead head 50 bbls 11.5 down back side with 3 bbls min. 250 psi, shut down press 80 psi Open annular, well flowing, close annular,dead head 50 bbls 11.5 down back side with 3 bbls min. 260 psi, shut down press 90 psi, well flow 45 bbls Circ 11.5-lb/gal mud @ 2-bpm. 270 psi loss started @ 30 bbl/hr. going up to 60 bbl/hr. Working and rotate pipe. Full losses. Shut down, blow down top drive, monitor well - reciprocate pipe, no rotation. Continue to monitor well. Slow gas bubbles to surface. Average gain 1-bbI/3-min (20-bbl/hr). Flow increased, increased gas bubbling out. Circulate at 30-spm, 50-rpm. Increased gas to surface. Circulate at 20-spm. Losses 24-bbl/hr. Continue to circulate at 20-spm. Losses cease, slight gain. Gas continued to boil out in the bell nipple. Continue to circulate at 20-spm. Slight losses. Stop circulation after 5,600-stk of 11.5-lb/gal mud. MW with pressurised balance In 11.8, Out 11.3-lb/gal. MW with un-pressurised balance In 11.6, Out 10.0-lb/gal. MU TIW valve, blow down top-drive, Close TIW valve, Close annular. Net 6-bbl gain from time of shut-down (15-min). Connect cement line to pump-in sub. Monitor pressures. Initial: SIDPP O-psi, SICP 60-psi (pressures are all re-calibrated based on low pressure gauges). Start pump and pump 5.5-bbl before float opens. SIDPP 40-psi, SICP 70-psi. Stop pump and monitor pressures every 15-min. Initial: SIDPP 20-psi, SICP 70-psi. Continue to monitor well. SIDPP O-psi. SICP 90-psi. Printed: 1/26/2004 10:29:42 AM ') ') BP Operéltion!; Summary Réport Page 5 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 1/19/2004 Rig Number: Spud Date: 1/6/2004 End: Date . From ..-' To Hours Task Code N PT Phase Descriptiol'1bf Oþerations 1/14/2004 15:00 - 16:00 1.00 DRILL N DPRB INT1 Continue to monitor well. SIDPP O-psi. SICP 120-psi. Conference call with office. 16:00 - 16:30 0.50 DRILL N DPRB INT1 PJSM. 16:30 - 17:00 0.50 DRILL N DPRB INT1 RU to pump out of hole. When annular was opened, a substantial transient flow was observed with a high oil content - the highest yet. Gas boiling in the bell nipple to the same extent as previously. 17:00 - 21 :30 4.50 DRILL N DPRB INT1 Start to pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 to 12 bbls per stand. 21 :30 - 22:00 0.50 DRILL N DPRB INT1 Monitor well with trip tank, loss 30 bbl hr. @ 5718' 22:00 - 22:30 0.50 DRILL N DPRB INT1 Pooh with out pump for 5 stands, well swabbing, took improper fill- 3 bbls 22:30 - 00:00 1.50 DRILL N DPRB INT1 Cont. pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 to 12 bbls per stand. to 4,414' 1/15/2004 00:00 - 04:30 4.50 DRILL N DPRB INT1 4414 to 1850' pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 to 12 bbls per stand. returns mud wt. 7.7 nearly all oil., 3 pulls 10,000 # over pull in csg as we were tripping out 04:30 - 05:00 0.50 DRILL N DPRB INT1 1850 getting good mud back, Monitor well no flow no loss, attempt to pull stand pull 30 ft. well swab, shut down. pump out with 11.5-lb/gal mud at 15-bbl/std (twice open hole volume), pulling at 4-min/std for an overall rate of 6 to 7-min/std. Losses of...7 bbls stand for one stand, pull one more stand gain one bbl, pull one more gain 10 bbls( total mud pumped poh 998 bbls total, left in well 661 bbls) 05:00 - 07:00 2.00 DRILL N DPRB INT1 Shut well in, @ 1573, Monitor pressures, blow down top drive, rig to circ thru choke 70 psi SIDPP 100 SICP( before we shut in got 45 bbl gain) 07:00 - 08:00 1.00 DRILL N DPRB INT1 Dump contaminated mud from pits, replace with clean 11.5-lb/gal mud. Prepare pits for well control operations. SIDPP 75psi, SICP 130-psi. 08:00 - 09:00 1.00 DRILL N DPRB INT1 Kill well using drillers method. Bring pump up to 20-stk/min holding casing pressure at 130-psi, DP pressure rose to 250-psi, then hold DP pressure at 250-psi, opening choke as required. Circulated 110-bbl through choke. Lost 31-bbl to well. Mud cut with moderate amount of oil. MW Out unpressurised scale 8.9 to 9.8-lb/gal, pressurised scale 10.8-lb/gal. Final DP pressure 240-psi, final casing pressure 50-psi. 09:00 - 09:30 0.50 DRILL N DPRB INT1 Shut down pump. Well flowing 1 to 2-bbl/min. Shut well in, open float. SIDPP 90-psi, SICP 100-psi. 09:30 - 10:00 0.50 DRILL N DPRB INT1 SIDPP 80-psi, SICP 110-psi. 10:00 - 10:30 0.50 DRILL N DPRB INT1 Fully open choke to bleed off 50-bbl to determine whether well is breathing. Record time every 5-bbl. 10-bbl 2.5-bbl/min, 20-bbl 3.4-bbl/min, 30-bbl, 5.7-bbl/min, 40-bbl, 3.8-bbl/min, 50-bbl 3.8-bbl/min. Shut in well - 50-bbl gain in 15-min. SIDPP 90-psi, SICP 190-psi. Monitor well. 10:30 - 13:30 3.00 DRILL N DPRB INT1 Monitor SIDPP and Casing pressure. Initial SIDPP-50 psi SICP-150 psi. Final SIDPP-160 psi and SICP-240 psi. Increase mud weight in pit 5 to 13.0 ppg. 13:30 - 15:00 1.50 DRILL N DPRB INT1 Displaced drill string to 1573' with 13.0 ppg mud. Pumped Printed: 1/26/2004 10:29:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) BP Operations Summary Report 1.50 DRILL N DPRB INT1 MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 1/19/2004 Rig Number: Spud Date: 1/6/2004 End: 1/15/2004 13:30 - 15:00 From -To Hours Task Code NPT Phase .. Description of Operations 15:00 -16:00 16:00 - 20:00 1.00 DRILL N DPRB INT1 4.00 DRILL N DPRB INT1 20:00 - 22:00 2.00 DRILL N DPRB INT1 22:00 - 22:30 0.50 DRILL N DPRB INT1 22:30 - 23:00 0.50 DRILL N DPRB INT1 23:00 - 00:00 1.00 DRILL N DPRB INT1 1/16/2004 00:00 - 00:30 0.50 DRILL N DPRB INT1 00:30 - 02:00 1.50 DRILL N DPRB INT1 02:00 - 03:30 1.50 DRILL N DPRB INT1 03:30 - 04:00 0.50 CEMT N DPRB INT1 04:00 - 04:30 0.50 DRILL N DPRB INT1 04:30 - 06:00 1.50 DRILL N DPRB INT1 06:00 - 15:00 9.00 DRILL N DPRB INT1 15:00 - 17:00 17:00 - 17:30 17:30 - 19:00 2.00 DRILL N DPRB INT1 0.50 DRILL N DPRB INT1 1.50 DRILL N DPRB INT1 down kill line and displaced 9-5/8" casing with 13.0 ppg mud. Displaced well with at 5 bpm. Initial pressure 350 psi and final pump pressure 80 psi. Pumped a total of 464 bbls. Shut down pump. No pressure on well. Open choke. No flow. Opened annular preventer and could not see mud in annulus. Pumped 50 bbls of 11.5 ppg mud in annulus. Still unable to see mud in annulus. Continued pumping 1 bpm into annulus. Pulled out of hole with BHA and stood in derrick. Had returns to surface just as BHA is racked back in derrick. Monitor well and well appeared to be taking 60 bbls per hour. Made up 5" mule shoe on stand of 5" drill pipe and float sub on top of first stand. Ran in hole with 5" drill pipe filling drill pipe every 5 stands. Hole standing full while running in hole. Hole taking displacement. Mule shoe @ 9294 Well flowing, shut in on Hydrill, shut in with 80# build to 150 in 15 min. 150# drill pipe pressure final 170# SIDPP, 190# SICP Bleed back 60 bbls thru choke, flow 5bbls per 3 min., getting back 7.7 oily mud Secure well, monitor well SIDPP 120# SICP 170# Bleed back 75 bbls thru choke, flowing 5 bbls every 2.5 min., getting back 7.7 oily mud Bleed back 35 more bbls, flowing slow to 6-7 min per 5 bbls, getting back 8.7 oily mud Shut in, SIDPP started and stayed 100#, SICP started 40# build to 170# Pumped down kill line and displaced 9-5/8" casing with 13.0 ppg mud. Displaced well with at 5 bpm. Initial pressure 350 psi and final pump pressure 80 psi. Pumped a total of 350 bbls. Shut down pump. No pressure on well. Pump cement plug with Schlumberger, with 5 bbls water, test lines to 2,000 psi,1 0 water, 48 bbls of 15.8 Class G with gas block, 5 bbls water, pumped @ 7bbls min., displace with rig with 148 bbls 11.5 mud, no returns to surface, cement plug should be from 9293 to 8683 Pull 8 stands slow, pick up top drive pumped 30 bbls to clear pipe, no returns to surface, could not see mud in well bore Pull in to csg to 6000 ft, filling with 1 bbl per stand, hole filled up with 24 bbls, but was dropping in well bore, shut well in on hydrill and monitor pressure. 0 @ 6.00 While waiting on cement, made up floor valve and cement line to monitor pressure on drill string. Fluid was at surface at 07:40 hrs. Pressure slowly increased from zero to SIDPP-O psi and SICP-250 psi. Opened choke and bled pressure off of annulus. Recovered approximately 10 bbls mud and 40 bbls of crude oil. Well stopped flowing through choke manifold. Opened annular preventer and flow check well. Hole standing full with gas bubbles working out of mud. Pumped 15 bbls of 11.5 ppg mud down drill string attempting to circulate out crude oil. Returns consist of 70% mud and 30% crude oil. Closed annular and opened kill line. Bullheaded 350 bbls of 13.0 ppg mud down annulus at 4-5 bpm. Initial pumping Printed: 1/26/2004 10:29:42 AM ) ~) ) Bp· O;peratiol1s> Summary Reporf . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Date From .;.To Hours Task Codè N PT Phase 1/16/2004 17:30 - 19:00 1.50 DRILL N DPRB INT1 19:00 - 20:30 1.50 DRILL N DPRB INT1 20:30 - 22:00 1.50 CEMT N DPRB INT1 22:00 - 23:30 1.50 DRILL N DPRB INT1 23:30 - 23:00 23.50 DRILL N DPRB INT1 23:00 - 00:00 1.00 DRILL N DPRB INT1 1/17/2004 00:00 - 10:30 10.50 DRILL N DPRB INT1 10:30 - 12:00 1.50 DRILL N DPRB INT1 12:00 - 14:00 2.00 DRILL N DPRB INT1 14:00 - 16:30 2.50 DRILL N DPRB INT1 16:30 - 17:30 1.00 DRILL N DPRB INT1 17:30 - 20:00 2.50 DRILL N DPRB INT1 20:00 - 22:00 2.00 DRILL N DPRB INT1 22:00 - 23:00 1.00 DRILL N DPRB INT1 23:00 - 23:30 0.50 DRILL N DPRB INT1 23:30 - 00:00 0.50 DRILL N DPRB INT1 1/18/2004 00:00 - 02:30 2.50 DRILL N DPRB INT1 02:30 - 03:30 1.00 DRILL N DPRB INT1 03:30 - 04:30 1.00 CEMT N DPRB INT1 04:30 - 06:30 2.00 CEMT N DPRB INT1 06:30 - 08:00 1.50 DRILL N DPRB INT1 08:00 - 09:00 1.00 DRILL N DPRB INT1 09:00 - 11 :30 2.50 DRILL N DPRB INT1 Start: 1/5/2004 Rig Release: 1/19/2004 Rig Number: Spud Date: 1/6/2004 End: Dèscriptionof Operations pressure 270 psi and final pump pressure 50 psi. Opened annular and well on vacuum. Trip in to 8784 tag top of cement with 5,000 set down,tag was witness by John Spalding AOOGC Cement with Schlumberger with 5 bbls water, test lines to 2000 v psi,10 bbls water, 48 bbls of Class G mixed @ 15.8# mixed on fly, 5 bbls water, mixed and pumped 5 bbls min., displace with rig pump 98 bbls min 600 psi, no return to surface bottom cement plug 8760 top 8150 Pull to 7974, pump 30 bbls mud to clear pipe Trip out to 6000 ft., fill hole with 1 bbl per stand well filled up after 23 bbls but was falling Monitor well 0 pressure at midnight Monitor well with trip tank on top of hole. Hole taking 5 bbls per hour. Ran back in hole with cementing string to 7950'. Filled drill pipe and continued pumping 1.5 bpm. Washed down and tagged top of cement at 8187' (Calculated top of cement 8150'). Pumped 20 bbls of 13.0 ppg mud down drill pipe for a slug. Started out of hole. Hole swabbing. Started pumping out of hole at 25 spm to 6000'. Pulled out of hole wet fl 6000' to BHA. Reduced pulled speed to reduce swabbling. Hole began taking fluid at 3000'. Laid down mule shoe. Broke out bit from motor in derrick. Picked up HWDP, Jars, float sub, bit sub casing scrapper and re-run 8-3/4" bit. Run in hole at reduced speed for surge presure to 6077'. No returns while running in hole. Pulled out of hole to BHA at reduced rate to reduce swabbing. Laid down HWDP, Jars and scrapper assembly. Picked up a 9-5/8" EZSV cement retainer and float sub and made up on 5" drill pipe Tripping hole with EZSV cement retainer at a reduced rate to reduce surge. Finished running in hole with 9-5/8" EZSV cement retainer to 6077'. Rigged up cement lines. Circulated through retainer. Set retainer at 6077'. Test casing to 2000 psi. Pulled out of retainer. Stung back into retainer with 30K weight. Established injection rate of 5 bpm at 610 psi. PJSM-Pump 5 bbls water-test lines to 4000 psi-pump 47 bbls (225 sxs) 15.8 ppg cement-5 bbls water behind. Displaced cement with rig pumps with 102 bbls of 10 ppg mud at 4 bpm. Left one bbl of cement in pipe. Final pressure 500 psi. Shut down pressure 270 psi. Pull out of retainer. Pulled one stand of pipe. Slug pipe with 13 ppg mud. Pulled out of hole to 3700'. Pipe started pulling wet. Mud aired up and having trouble mixing slug. Slip and cut drill line. Service top drive. Mix and pump dry job. Finish pulling out of hole with cementing string and laid down setting tool. Run in hole with BHA from derrick. Laid down flex collars. Download MWD. Lay down MWD and motor. Printed: 1/26/2004 10:29:42 AM ) ) ·BP O,peratio nSSun'u11aryReport Þage8Qf e· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/18/2004 1/19/2004 MPL-43 MPL-43 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/5/2004 Rig Release: 1/19/2004 Rig Number: Spud Date: 1/6/2004 End: From- To Höurs Task Code NPT Phase Description of Operations 11 :30 - 14:00 2.50 DRILL N DPRB INT1 Picked up rerun 8-3/4" bit, bit sub and float sub and tripped in hole with 5" drill pipe to 6036'. Filled drill pipe at 30 stands. 14:00 - 15:00 1.00 DRILL N DPRB INT1 PJSM-Filled drill pipe and washed and rotated from 6036' to EZSV retainer at 6077'. 15:00 - 15:30 0.50 DRILL N DPRB INT1 Displace mud in hole with new 9.6 ppg mud at 9.5 bpm. Rotated and reciprocated pipe during displacement. 15:30 - 17:30 2.00 DRILL N DPRB INT1 Laid down 99 jts of 5" drill pipe 17:30 - 18:30 1.00 DRILL N DPRB INT1 Rih with pipe from derrick to 6077 18:30 - 19:00 0.50 DRILL N DPRB INT1 Circ remainder of 10# mud from pit to flush drill pipe 90 bbls 19:00 - 00:00 5.00 DRILL N DPRB INT1 Clean pits and drip pans, solids equipment,suction lines of oil contamiation, with hot water from hot oil truck 00:00 - 04:00 4.00 DRILL N DPRB INT1 Finish Cleaning pits and drip pans, solids equipment,suction lines of oil contamiation, Taking on Sea water to pits 04:00 - 06:00 2.00 DRILL N DPRB INT1 Displace mud in hole WI Sea water at 9.5 bpm., Displace Sea water WI 9.8 Brine at 9.5 bpm. Rotated and reciprocated pipe during displacement. 06:00 - 10:00 4.00 DRILL N DPRB INT1 Laying down Drill pipe 10:00 - 11 :00 1.00 DRILL N DPRB INT1 Pull wear ring, install hanger with TWC, test to 1000 psi 11 :00 - 12:30 1.50 DRILL N DPRB INT1 Nipple down BOPS 12:30 - 14:00 1.50 DRILL N DPRB INT1 Nipple up dry hole tree, Test tree 4000 psi, install BPV, clean out cellar, rig release for move 1/19/2004 1600 hrs Printed: 1/26/2004 10:29:42 AM Legal Name: Common Name: Test Date 1/10/2004 1/11/2004 FIT FIT SF> l..eak~O'f·"Fe$t···$l..Il'Tlmêl..y MPL-43 MPL-43 Test Type TestDépth (IMP) (ft) 6,097.0 (ft) Tøst[)~ptljltvP) (ft) 4,438.0 (ft) (ppg) 8.40 (ppg) Surface Pressure (psi) 830 (psi) l..¢a{(·PffpresstJfê{Bfil?:) (psi) 2,767 (psi) 12.06 (ppg) 12.00 (ppg) ~ ~ Printed: 1/26/2004 10:29:35 AM ) ) dQ3- é)é) L- 09-Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPL-43 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 O'MD 9,306.00' MD (if Applicalble) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager attachments J lr Ýv '"' J - j I ) . l1\ P , ..'- {eC ~ I~ RECEIVED F- :.~~p ? 6 ?n04 ._U '- ....1.; .f..\jÐ3ka on & Gas Cons. Commisston A~_e ~~~~'J\~ ) ) ~3 ddL' 09-Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPL-43 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' MD 9,306.00' MD (if Applicalble) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager attachments \ u Vv ~!\ J~ /Í j ( ~ ) . '1)!.~ c.. { t.~_ '- '-- fk RECE\VED FCI3 2. 6 2004 .Ala~~a 01\ & Gas Cons. CommilS\On Anchorage ~~~,\f\~ ) &03- é) d-~I ) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 12, 2004 RE: MWD Fonnation Evaluation Logs MPL-43 , AK-MW-2851290 1 LIS fonnatted Disc with verification listing. API#: 50-029-23190-00 ) éJ ~I J \ 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: "'-~ f"'. ~ Signed: ~~Q~ ~ -\_ )'-~.J'-t,",,- RECEIVED F r~;) 1 G :"004 ._.u <' 1... \; Alaska OH & Gas Cons. Commission Anchorage ~'n~{'1\-~ ) STATE OF ALASKA ) ALASKA OILAND GAS CONSERVATION COMI\1II3SION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 kiG A- '12..'l (¿()() tf- ID'~ 1/29/9- 1. Type of Request: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): /1 181 Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate o Plug Perforations 0 Stimulate o Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: 1m Development D Stratigraphic Test o Waiver o Time Extension o Annular Disposal 5. Permit T~rill Number D Explorator) 203-224 D Service 6. API Number: / 50- 029-23190-00 o Other 99519-6612 Planned KBE = 46' 9. Well Name and Number: MPL·43 /' 8. Property Designation: ADL 025509 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands Total Depth MD (ft): 9306' . ~åsing. Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 6989' 6077' 4437' 6077' ',.~ength .:.Siié'MP,"tVO," .... . , '::.aùtst', Junk (measured): N/A .,,·,',CØllapše .'., 112' 6097' 20" 9-5/8" 112' 6097' 112' 4391' 1530 5750 520 3090 Perforation Depth MD (ft): N/A Packers and SSSV Type: N/A Perforation Depth TVD (ft): N/A Tubing Size: N/A Tubing Grade: N/A Packers and SSSV MD (ft): N/A Tubing MD (ft): N/A 12. Attachments: 1m Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for """,~ Commencing Operations: Jan}JEfry .1~004 16. Verbal Approval: ~: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Prepared By Name/Number: f3~ cò:~~~~øriUSè5:~I~03 Date ¡ /2 7/t> '( Sondra Stewman, 564-4750 13. Well Class after proposed work: D Exploratory 1m Development 0 Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ /. 1m Plugged DWINJ D Abandoned D WDSPL Contact Walter Quay, 564-4178 Si9nature Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 30L/ - O;;2.r D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance RECEIVE,D Other: Pe ( ¿o ÄA-C [5. Subseque . G) I 6.-1+~","lV--h "",,- tl pl~1irlí pro litkt~lI¡~ ~þ~~4¡fecL Alaska Oil & Gas Cons. CommiSSion ,,1 '7 Anchorage OQIGINAL COMMISSIONER BY ORDER OF THE COMMISSION Date ~~~f ~~ ~\rih,. 'fEb ~0) bp ') ) ... .,-\,.t". ~~~ ~~.. .~~ ~~. .",.,\\.. ". To: From: Tom Maunder- AOGCC Pat Archey- BPXA ACT Drilling & Wells Date: January 20, 2004 Subject: MPL-43 - Application for Sundry Approval to Suspend Well Reference: // Sundry approval is sought for the suspension of MPL-43. This suspension is due to the encountering of unexpected overpressure preventing the continuation of this well with the present well plan. As per the previously submitted plan (email: 1/14/04), the bottom section of the well and the open ~,/ hole just below the surface casing shoe will both be isolated with cement plugs. The casing shoe will also be isolated with an EZSV cementing retainer (Telecon 1/17/04). Planned Rig Operations - Suspension 1. Kill Well and POH with BHA 2. Notify AOGCC State Inspector to witness spotting of plug 3. TIH with cementing sub to TD or as deep as possible and lay balanced cement plug from 9306 to 8,9001 4. WOC 12 hours. Tag plug if required by AOGCC 5. TIH with cementing sub to +/- 6,800' and spot Form-a-Set Plug to 6400' 6. POH to shoe and W.O. plug to set. 7. Spot cement plug from 6,400 to 5,950 8. POH and lay down stinger. WOC 12 hrs. 9. Rih with bit. Dress off cement plug. Circ barite from casing 10. TIH with drilling BHA and re-drill hole to original target. Actual Rig Operations - Suspension 1. Kill Well and POH with BHA 2. TIH and set 48 bbl¡:23@1.17ft/SX)Plugfrom9293't08683"/' 3. Tag top of plug @ ~ /'" 4. Set second deep 4 }~!>.~ (230 sx @ 1 .17 ft/sx) plug from 8760' to 8150'. 5. Tag top of plug @¡8'1ß~:. / 6. Set EZSV @ 607~~g Shoe @ 6097'). 7. Pump 48 Bbls (230 sx @ 1.17 ft/sx) of 15.8 ppg for a plug from 6077' to 6530'. The plan is to return to this well with the drilling rig at the scheduled near the end of April 2004. /' j j ) ) MPL-43 Plugback(PROPOSED) ~ 9.625-in, 40#, L-80, BTC-M @ 6097'MD/4438' TVD 1 -5950' 450' Cement Plug -6400' 400'Form-Ä-Plug Base -6800' -8900' 400' Cement Plug Silts 9216 - 9297 MD 8-3/4" Hole TD @ 9306' MD, Est.6989' TVD j r--"'I ~L L..---.I ') ) -'~ ./ MPL-43 Plugback{Actual) ~ 9.625-in, 40#, L-80, BTC-M @ 6097'MO/4438' TVI ----- -450' Cement Plug /-- -6530' Cement Plug / 8760' - 8150' Calculated Tagged @ 8187' / Cement Plug 9293' - 8683' Calculated C (0 Tagged @ 8784'/ Silts 9216 - 9297 MO 8-3/4" Hole TO @ 9306' MO, Est.6989' TVO ) ) Quay, Walter (Natchiq) From: Sent: To: Subject: Archey, Pat Thursday, January 15, 2004 1 :59 PM Quay, Walter (Natchiq) FW: L-43 Plans Here is what Tom has. Pat Archey Sr. Drilling Engr. Wk.-564-5803 Cell 240-8035 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, January 14, 2004 3:08 PM To: Archey, Pat Cc: AOGCC North Slope Office; Jim Regg; Winton G Aubert; Steve Davies Subject: Re: L-43 Plans Pat, I can appreciate the mud stability problems, but the goal of the plugging operation is to isolate a source of higher than expected pressure above the intended target zone. Getting that pressure source isolated with a plug placed as close as you can get to the identified formation is important to prevent pressure migrating higher in the geologic column and creating other drilling problems in the area. As we discussed, I believe that BP needs to attempt to get the plugging string as deep in the well as possible with the goal of getting as near TD as practical. If getting deep in the well does not prove possible, then that situation can be addressed then. It is probable that we will want the Inspector out there to witness the plug placement if possible. I will forward this message to them and you can have the Company Man get in touch with him as the operations get closer to happening. Good luck with the operations. Tom Maunder, PE AOGCC Archey, Pat wrote: >Tom, > > We are closer to getting out of the hole with the BHA and wanted to run our plan forward by you. With all of the barite we are leaving in the hole due to sag, we aren't going to plan to run casing, but to redrill this section. We have not penetrated the reservoir yet so we believe the flow is coming from the below mentioned pressurized silts. > We are concerned about getting back into the open hole due to the >losses and barite strung throughout the open hole. The proposal is to >set a cement plug at the casing shoe and redrill from there. We would >then set intermediate casing above the suspect pressurized silts. > > >MD TVD >6,097' >9,000' >9,216' >9,297' >9,330' 9-5/8" Casing Shoe 6,6701 Top HRZ 6,8861 Top Highest Pressurized silt 6,967' Bottom Highest Pressurized silt 7,000' Top of Kuparuk D > > > 1. Kill Well and POH with BHA 1 > > > > > > > 2. 3. 4. 5. 6. 7. TIH wi th cementi1'~) sub to + / - 6,400' and spot Fork l-set Plug w.o. Plug to set. PU to 6,200 Spot cement plug from 6,200 to 5,900 POH and lay down stinger Rih with bit. Dress off cement plug. Circ barite from casing TIH with drilling BHA and re-drill hole to original target. > Illl be back in after lunch to discuss at you convenience. > >Pat Archey >Sr. Drilling Engr. >Wk.-564-5803 Cell 240-8035 > «MPL-43 Well Control v2.0.cnv» > > 2 ) ') MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg /'7 .\\1D\cA < v (lLJ6l', P.I. Supervisor ~ t DATE: January 16 & 17,2004 From: John Spaulding Petroleum Inspector SUBJECT: Plug and Abandonment BPXA / MPU / L-43 PTD 203~ dd''-\ January 16 & 17, 2004: I traveled to BPXA's Milne Point well L-34 to witness the formation plugging operation prior to suspending the well for further diagnostics. Earlier in the week while drilling the rig had an influx of gas and oil. They attempted to circulate the influx out without a lot of success. The decision was made to abandon the bottom portion of the hole. One plug was laid in about 80' off bottom (td 9309'md) this plug was approximately 500" in length and was tagged (8k) with open ended drill pipe to verify the depth of top of plug (8784' md). A second plug was set directly on top of the first. The top of cement was tagged with 10k on open ended drill pipe (8187' md) It is my understanding that a bridge plug will be set approximately 20' inside the shoe and 40 bbls. of cement will be down squeezed through the bridge plug. Also another surface plug will be set, neither of these plugs will be tagged to verify depth. SUMMARY; I witnessed the successful top of cement tags on well L-43. NON-CONFIDENTIAL p&a mpu 1-43 1-18-04 jhs.doc ) " FRANK H. MURKOWSKI, GOVERNOR AI~A.SKA. OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH 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: Milne Point Unit IvIPL-43 BP Exploration (Alaska), Inc. Permit No: 203-224 Surface Location: 3636' NSL, 5040' WEL, Sec. 08, T13N, R10E, UM Bottomhole Location: 3695' NSL, 467 WEL, Sec. 06, T13N, R10E, UM 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 to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). S incer:!I' . (-) (.7 . ß-~ i ¡J/'/ ,,\i\ ',_ Iii \'-.._ ''-.-- ,/ /' I../f-"----" - \..-- ,,,, '-' '.------- / ~ Sarah Palin Chair BY ORDER OF THE COMMISSION DATED thisli day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) STATE OF ALASKA ) ALASKA 01.... AND GAS CONSERVATION COMl\lh~SION PERMIT TO DRILL 20 MC 25.005 4t Id'? II Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3636' NSL, 5040' WEL, SEC. 08, T13N, R10E, UM Top of Productive Horizon: 3695' NSL, 467 WEL, SEC. 06, T13N, R10E, UM Total Depth: 3695' NSL, 467 WEL, SEC. 06, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-544838" y-6031825 ~ Zone-ASP4 16. Deviated Wells: Kickoff Depth ,1',':~, ' "I;,:,',!C,. "å,' ',S, 'i,mg'i::,a~,O,',', 'g",',r"a,",.,','R1, :,,;1 I ",",i' ,,", l,rl":"I"':':'I,"I¡S'"'''~'':'''''''''''''""11"",1 ,I' : 1':"'1 ", :1,1111 ',1,1, .1" 1'1'1:: 'IZt::::, ,0,;' :1:, ,1,,1,,1 ',I~,~,~"I!'I'I I ,,":', .; ,I Hole Casing 42" 20" 12-1/4" 9-518" 8-3/4" 7" 1 b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: III Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 9925' TVD 7595' 7. Property Designation: ADL 025509 II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: MPL·43 12. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 8. Land Use Permit: 13. Approximate Spud Date: 01/07/<Ý.f· 14. Distance to Nearest Property: 11750' 9. Acres in Property: 2560 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL): KBE = 46' feet 1400' away from MPL-05 o 17. Anticipated pressure (see 20 AA9 25.035) / 51 Max. Downhole Pressure: 3542 psig. Max. Surface Pressure: 2818 psig ,:,""I(,I,I"il,::i:,¡II';:i:liil:il¡,I:~,ga"~i~~I'ióf.lefjm!e~t:I,'li:I:'lllil,ii!i:'· I".,I",:!II::¡,'::! ,III i", ,,'I. , ,,',1"',"11," 'I :::'il !,I"'IIII:::!',(""c",'il: ~':":'o' "~;;s"::a"'" "'¡;':;&Js'" ':'\',':I":lli:~I:,:,;:,,,I""'I",':I,'I'',i:'::I;111 11.1" I," ",.",1,1"",1,.,111,',.:1,1 1"; ",¡ I I,'l" I','!: 1,1,11",1" ..11'.,1,. ,~I'II., ,,.,,;,,1:\: 111"'1 .'I~,III';', 'I' ,I'L 1:'1,111",,:';,1 ,I:!,I,: ,I (including stage data) 260 sx Arctic Set (Approx.) 788 sx Class 'L', 218 sx Class 'G' 218 sx Class 'G' TVD 112' 4450' 7595' 500' ft Maximum Hole Angle Weight 92# 40# 26# Grade H-40 L-80 L-80 Coupling Length MD TVD MD Weld 112' Surface Surface 112' BTC-M 6122' Surface Surface 6122' BTC-M 9925' Surface Surface 9925' 'I \",,' : ,',': I," b'R!1:8ENJi y¡..lÈI !'Ù' ~Ò~I [)'';'I'''''~I:''S''' "'I,IIP;IIII'r.~'A!""~:(''''''~''''.''b'' 'I:"",V:':""'""", ," ,:," ".' ""." '1~"':i";;:"';'i,CI """;;:'¡~;I:I"',:I,I,~':ti:I¡:~':"'o ,,:1,',"': "" ·"f "';'·"hii'" ""." ,I," """,~" ',",:,,, '"" ':',': ",' i':I"'!",.,'.,I'" ;1: .'" .11,''''':'''' ;.'!',II,"""",,:.'! ",,";",,1',. ',,,',' I,!!,,' "'," " '.:""R,,,, .~."" """ " ': ,,'I'"~ "" L" "':'''''''.",,!l~ '",I,''' ",Y"I,~"" '~'~ll~'~~"[:'!"Y":,~,','CQmp!e:~t: J~IJpr'l~EI:~,,'I..,~1'~Y'I~I"p~ :',~n~fYi,lyp~rª,~IQh,ßJ"":' 1";"I,'I,,,,'::!,'I::"!"''''''i,.' ':;',,:::1"":"':' " Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): , Casing' Structural Conductor Surface Intermediate Production Liner L:ength ,," . Size , :, ' çernehtVol(J 'r1e" 'MD 'TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments 1m Filing Fee 0 BOP Sketch III Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Property Plat 0 Diverter Sketch 0 Seabed Report III Drilling Fluid Program 11I20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Walter Quay, 564-4178 Printed Name Pat Archey Title Senior Drilling Engineer J Prepared By Name/Number: Signature f~<; O..l'-f'ÞI Phone XÇøo'3 Date /-¿III /&5 Sondra Stewman, 564-4750 Commission" Use Only Permit To Drill ., / API N"umber: -7 '7, ¡CO .~ Number: :2L>3-227 50-[)7£j- ~ ~ ·--C-é; Conditions of Approval: Samples Required 0 Yes ~o Hydrogen Sulfide Measures .~es . 0 No Other: 3S(X:)~c;\ \31J\)~\- ¡&1\IB BFL Permit Approval /' ~. ~, See cover letter f" or Date: Ill" IJ ,Q!~Y&r \q lmts Mud Log Required IJId: ·eslf .~ Directional Survey RequiÕEC' šeiò[tf0 OEe S J 103 \, 0"' & Gas Cons. \...urnt1\l.5sion A'as~a , Anchorage , BY ORDER OF ' '7J / O !7 ~~.) 1~I'oAE" t THE COMMISSION Date '''t- Z iJ Ó '7 . \ J l.J I ~ \J M Submit In Duplicate Approved Bv: Form 10-401 Revised 3/2003 Originai Signed By Sarah Palin ') Mi¡ )pOint MPL-43 Well Permit IWell Name: I MPL-43 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer Kuparuk A Suñace Location: 36361 FSL,"- 240' FWL;SEC. 8, T13N, R10E ,. E=544837.72 ·"N=6031825.26"- 1584' FNL, 467' FEL, SEC.6 , T13N, R10E E=544080 N=6037160 Z=7195' TVD SS 1584' FNL{467' FEL/ SEC.6 , T13N, R10E ' E=544080 N=6037160 Z= 7545' TVD SS 11,750' 1400' from MPL-05 ' Target Location: TOP Kuparuk A3 Target Location: BHL Well TD Distance to Property line Distance to nearest pool I AFE Number: I I RiQ: 1 Doyon 14 I Estimated Start Date: 1 07 Jan 04 f I I Operating days to complete: 120 1 MD: 19,925' 1/ I TVD: 17595' 1/ I Max Inc: 151 I I KOP: 1500' "I I KBE:146' 1 1 1 I Well DesiQn (conventional, slimhole, etc.): 1 Ultra Slim hole Grass Roots Frac Producer 1-' I Kuparuk A Sand v I Objective: 1 Mud Program: 12 1fi¡" surface hole (0-6122'): Fresh Water Surface hole mud Density Viscosity Yield Point API FL (ppg) (sec/qt.) (Lb/100ft) cc/30min 8.5-9.2 250-300 45-70 NC 9.0-9.5 150-200 35-45 <8 Rtl Initial Base PF-top SV SV-TD 9.0-9.5 9.0-9.5 9.5 max 75-150 25-30 <8 9.0-9.5 8 %" Production Hole (6122- 9925'): Density PV Yield Point (ppg) (Lb/100ft) 9.2-9.8 10-15 25-30 9.8-9.9 10-15 25-30 Upper interval Top HRZ to TD LSND APIFL Rtl cc/30min 6-8 9.0-9.5 4-6 9.0-9.5 LCM Restrictions: Use caC03 as LCM Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to D8-4 disposal site ,/ Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 1 Cement Program: ) Mi.. )point MPL-43 Well Permit CasinQ Siz~ 19-5/8" 40-lb/ft L-80 BTC Surface Casing Basis 1200% excess over gauge hole in permafrost interval 40% excess over gauge hole below permafrost Total Cement Volume: 645-bbl Wash 20-bbl water Spacer Lead Tail 50-bb11 0.2-lb/Qal Alpha Spacer 600-bbl, 788-sx 10.7 Ib/gal Class L - 4.27 fe/sx (cement to surface) 45-bbl, 218-sx 15.8 Ib/gal Prem G - 1.17 ft;j/sx (top of tail at 5,622-ft MD Casinç Size 17" 26-lb/ft L-80 BTC Intermediate Casing Basis 40% excess over gauge hole. Lead 500-ft MD above top of Kuparuk Total Cement Volume: 45-bbl Wash 5-bbl water Spacer Lead Temp Evaluation Program: .30-bbl 1 O~2-lb/qaIAlpha Spacer (Alpha) 45-bbl, 218-sx 15.8 Ib/gal Prem G - 1.16 ft;j/sx (top of lead at 8800-ft MD) BHST ~175°F from SOR 12-1/4" Section Open Hole: MWD/GR IFRlCASANDRA Photo Gyro as required. Sperry InSite Cased Hole: N/A 8-3/4" Section Open Hole: MWD/GRlRES, PWD IFRlCASANDRA Cased Hole: N/A v 2 ) Mil, )POint MPL-43 Well Permit Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (1t) (psi) (Ib/gal)* BPRF 2010 1850 782 8.35 TUZC 4678 3550 1520 8.35 SBF2-NA 5580 4112 1764 8.35 SBA5(Base OB) 6023 4338 1884 8.35 THRZ 9000 6670 2874 8.35 BHRZ 9085 6755 2911 8.35 KLGM 6830 2944 8.35 TKUD 9330 7000 3018 8.35 / TKUC 9485 7155 3508 9.48 ~ TKUB 9495 7165 3507 9.48 TKUA 9565 7235 3542 9.48 TKA3 9575 7245 3547 9.48 TKA2 9592 7262 3555 9.48 TKA1 9620 7290 3569 9.48 TMLV 9675 7345 3596 9.48 ¡/ Casing/Tubing Program: Hole Csg WtJ Grade Conn Burst Collapse Length Top Bottom Size Diam Ft MD/TVDrkb MD/TVDrkb 20-in 92 H-40 Weld 1530 520 112-ft 0 112-ft / 112-ft 12.25-in 9.625-in 40 L-80 BTC-M 5750 3090 6122-ft 0 6,122-ft / 4,450-ft 8.75-in 7.0-in 26 L-80 BTC-M 7240 5410 9925 0 9,925-ft / 7,595-ft 4.5-in 12.6 L-80 BTC 9400 Recommended Bit Program: 1 2 3 12.25-in 12.25-in 8.75-in Depth (MD) o - 2500' 2500' - 6122' 6122 - 9925' Bit Type Nozzle/Flow rate BHA Hole Size Mill Tooth M ill Tooth PDC 3 ) MiL'.:ÞOint MPL-43 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. Intermediate and Production Intervals I · Maximum anticipated BHP: 3,542-psi @ 7,235-ft TVOss - Top of Kuparuk A-sand · Maximum surface pressure: 2,818-psi"@ surface (Based on BHP and a full column of gas from TO @ 0.1-psi/ft) · Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 3,500-psi high. An FIT to 12.0-lb/gal will be made at the 9.625-in casing shoe. 59-bbl with 10.0 Ib/gal mud and FIT of 12.0-lb/gal @ 9.625-in · Integrity test: · Kick tolerance: shoe · Planned completion fluid: 9.9-lb/gal Brine / 6.8-lb/gal Diesel Drilling Hazards & Contingencies: Lost Circulation · Breathing/losses are a possibility in this area. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). v' · The Kuparuk Pressure is expected to be 9.48 ppg EMW ¿/ Pad Data Sheet · Please read the L-Pad Data Sheet thoroughly. Breathing · Wellbore breathing is a possibility with the mud density used. Good operating practices to minimize ECO and surge/swab pressures should be employed. Hydrocarbons . Hydrocarbons will be encountered in the Kuparuk sands. The Schrader Bluff will be behind the v' existing surface casing and will not be exposed. Faults . There is a possible fault crossing in the Colville at -4830' tvd, 6732' md, in the 8-3/4" interval. 4 ) Hydrogen Sulfide ML )POint MPL-43 Well Permit MPL-Pad is not designated as an H2S Pad, however Standard Operating Procedure for H2S precautions should be followed at all times. Highest Level of H2S on L-Pad . Anti-collision Issues / 11.5 ppm on MPL-2, Sept 2003 11 ppm on MPL-03, Sept 2003 3.5 ppm on MPL-05, Sept 2003 2.4 ppm on MPL-29, Sept 2003 . MPL-43 does not have anti-collision close approach issues as it passes the 1/200 minor risk criteria. This closest well MPL-17 is within 25' center to center distance at 649' MD 5 ) DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. Install starting head on 20-in conductor. Procedure Mi. )Point MPL-43 Well Permit 1. MIRU. NU diverter on 20-in conductor and function test. 2. Drill 12-1/4" surface hole as per directional plan. 3. Case and cement 9-5/8" surface casing. 4. NO diverter, NU BOPE and test. 5. Perform FIT. 6. Drill 8-3/4" hole to land in top of the Kuparuk-sand as per directional plan. 7. Case and cement 7" intermediate casing. Displace cement with brine. 8. Freeze protect 7" x 9-5/8" annulus. 9. Run 4-1/2" completion as per schematic. 1 O. Land tubing hanger and test. 11. Set B PV. 12. NO BOP. 13. Install and test tree. 14. Pull BPV. 15. Freeze protect thru GLM. 16. Install BPV and secure well. 17. RD/MO. 6 ~ 4-1/16"-5M FMC \ftIlPL 43 P d Wellhead: 11" x 4.5" 5M Gen 6 'JJVI - ropose wI 4.5" TCII T&B Tubing Hanger CIW "H" BPV profile 20" 91.1-lb/ft H-40 ~ I 112' I 9.625-in 40-lb/ft L -80 BTRC casing I 6122' I ~ Sidetrack on Whipstock at 9340' 7.0-in 26-lb/ft L-80 IBT-M casing ( drift ID = 6.151", cap = 0.0383-bbl/ft ) 4.5" 12.6# L-80 IBT-M tubing Perforated and frac Kuparuk A-sands Est. Top TKA3 - 9575' MD ~ ~ 7.0-in Casing Shoe 9925' DATE REV. BY COMMENTS 01-Dec-03 WDQ Proposed Completion E,' ~F alav.:::: 51.20: 014) C bL. alav.:::: 16.3 ~ KOP @ 500' Max hole angle in tubing = 51 degree o degrees at sleeve Camco 4.5" x 1" GLM I 2000' I ~ 4.5" CMD sliding sleeve 19,405' I 4.5" HES X-Nipple 19,445" 19,455' 1 7.0" X 4.5" Baker Premier Packer 4.5" HES XN-Nipple 19,475'1 19,525' I WLEG I ... MILNE POINT UNIT WELL MPL-43 API NO: - BP EXPLORATION (AK) Plan: MPL-43 wp09 (plan MPL-43/Plan MPL-43 Created By: Bart Goff SURVEY PROORAM Depth Fm Depth To SurveyIPJan Tool 34.00 1000.00 Planned: MPL43 wp09 VB CB-GYRO-SS 1000.00 9923.70 P1aooed: MPlAJ wp09 VB MWJ};.ŒR+MS REFERENCE INFORMATION Co-oniioare (NIE) Refereoœ: Wen Centre: Plan MPlAJ. Troe North Vel1ica1 (IVD) Refereoœ: 5030 S030 Sectioo (VS) Relèreoce: Use< Defmed (O.OON,O.OOE) Measured Depth Reference: S030 50.30 Calculation Method: Minimum Curv.IIuIe COMPANY DET All.S BP Amoco Minimum Curvature ISCWSA T ",v Cylinder North Elliptical + Casing Rules Based Dale: Date: WELL DETAILS Name +NJ-S +FJ·W Northing Eastiog Latitude Loogitude Slot Plan MPL43 202430 32033 603182526 544837.72 70"29'52.139N 149"37'59982W N/A TARGETDETAll.S Name 1VD +N/-S +FJ-W Northing Easting Shape MPL-43 Vert Poly 724530 5339.74 .725.60 6037160.00 S44080.00 Polygoo SECTION DETAILS See MD Ine Azi TVD +N/-S +PJ-W DLeg TFaee VSee Target I 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 433.33 2.00 45.00 433.31 1.65 1.65 1.50 45.00 1.41 4 1511.29 34.00 12.00 1445.82 318.20 79.69 3.00 325.30 304.57 5 1889.99 37.00 0.00 1754.46 536.04 101.74 2.00 288.32 517.46 6 2009.62 37.00 0.00 1850.00 608.03 101.74 0.00 0.00 588.80 7 2410.85 51.44 349.83 2137.16 884.98 73.85 4.00 -29.97 866.98 8 7279.14 51.44 349.83 5171.94 4631.75 -598.54 0.00 0.00 4670.16 9 8993.70 0.00 0.00 6665.30 5339.74 -725.60 3.00 180.00 5388.81 10 9573.70 0.00 0.00 7245.30 5339.74 -725.60 0.00 0.00 5388.81 MPL-43 Vert Poly II 9673.70 0.00 0.00 7345.30 5339.74 -725.60 0.00 0.00 5388.81 _3 12 9923.70 0.00 0.00 7595.30 5339.74 -725.60 0.00 0.00 5388.81 ----~. Start Dir 4°1l 00' : 2009.62' MD, 1850'TVD ~1~End Dir : 1889.99' MD, 1754.46' TVD -¡--Start Dir 2°1l00' : 1511.29' MD, 1445.82'TVD l;¡ _ t+ Start Dir 3°/100' : 433.33' MD, 433.31 'TVD I :1fI()...L Start Dir 1.5°/100' : 300' MD, 300'TVD ,..". I I I I I I I I I o 856 1713 " /. , ~'" I " , '-', J . "',...., ""'.~".::::;~ """">«'~ "'" - //" "'" Ó/)/') "" / VU-¿ /;;<"""", BPRF TUZC SBF2-NA SBA5 (Base OB) THRZ BHRZ TKUD TKUC TKUB TKUA TKA3 TKA2 TKA1 TMLV FORMATION TOP DETAILS TVDPath Fonnation MDPath 2009.99 4677.76 5579.30 6022.05 8998.70 9083.70 9328.70 9483.70 9493.70 9563.70 9573.70 9590.70 9618.70 9673.70 1850.30 3550.30 4II2.30 4388.30 6670.30 6755.30 7000.30 7155.30 7165.30 7235.30 7245.30 7262.30 7290.30 7345.30 No. I 2 3 4 5 6 7 8 9 10 11 12 13 14 Checked: Reviewed: CASING DETAILS No. TVD MD Name Size 1 4450.30 6121.51 95/8' 9.625 2 7595.30 9923.70 7" 7.000 Calculalioo Method: Error System: Scan Method: Error SurraC'c: Wam~ Method: I -2569 TVD 6665.3' TVD 5171.94'TVD 2137.16' TVD MD, 2410.85' 7595.3' MD, 8993.7' 7279.14' MD, MD, Dir 9923.7' Depth West(-)lEast(+) [ft] All TVD depths are ssTVD plus 50.30'jor RKBE. 5138 4282 5 ~ 1:: ! -g 2569 o (/) 3425 856 713 o ) Sperry-Sun Planning Report - Geographic ;J,,~~~~f~y:····· l:!~;¡i:!;;, ,:" ::WeIJpa(h: : 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 ) ,:?])~~e:. /:l~~5àdÖ~ .d·,·t¡~~~::f··tå:5Ô:&Kr.."'" .........' .'., 'r:C9~órdi~~tê(NE)'R:~fer~ncei ~\fI.Ì~Î!ÚPlanM~~-~3. TtìJe Nórth ";<: yertical(TVI»:Referenee: 50.~.95~t3:X:i1j:' X> ....>.. i,: .... ..; ,+;j'r~eçtton (,VS)~e,(ei~ºc~:i' '.. Use~f(Ò;QQN:,9;9º1:;3?2;,:?6Azi),:}. ;:~I~~,L. ; f:> \;,,,: ',.", MPS~.3,rWpp~;iŠ\~' > ','i. ,'. Map Zone: Coordinate System: Geomagnetic Model: Site: M pt L Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: Plan MPL-43 6029799.28 ft 544529.55 ft Alaska, Zone 4 Well Centre bggm2003 Latitude: Longitude: North Reference: Grid Convergence: 70 29 32.230 N 149 38 9.412 W True 0.34 deg Slot Name: Surface Position: +N/-S 2024.30 ft Northing: 6031825.26 ft Latitude: 70 29 52.139 N +E/-W 320.33 ft Easting : 544837.72 ft Longitude: 149 37 59.982 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 2024.30 ft Northing: 6031825.26 ft Latitude: 70 29 52.139 N +E/-W 320.33 ft Easting : 544837.72 ft Longitude: 149 37 59.982 W Measured Depth: 34.00 ft Inclination: 0.00 deg Vertical Depth: 34.00 ft Azimuth: 0.00 deg Wellpath: Plan MPL-43 Current Datum: Magnetic Data: Field Strength: Vertical Section: 50.30 09/08/2003 57539 nT Depth From (TVD) ft 34.00 Principal: Yes Plan: MPL-43 wp09 Plan Section Information Height 50.30 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Date Composed: Version: Tied-to: 34.00 300.00 433.33 1511.29 1889.99 2009.62 2410.85 7279.14 8993.70 9573.70 9673.70 9923.70 0.00 0.00 2.00 34.00 37.00 37.00 51.44 51.44 0.00 0.00 0.00 0.00 0.00 0.00 45.00 12.00 0.00 0.00 349.83 349.83 0.00 0.00 0.00 0.00 34.00 300.00 433.31 1445.82 1754.46 1850.00 2137.16 5171.94 6665.30 7245.30 7345.30 7595.30 Well Ref. Point 34.00 ft Mean Sea Level 25.16 deg 80.87 deg Direction deg 352.26 11/11/2003 8 From Well Ref. Point 0.00 0.00 1.65 318.20 536.04 608.03 884.98 4631.75 5339.74 5339.74 5339.74 5339.74 ··::~~tt"',': .····.····:'Jd~~~ô6J:i:d1~~~~Oft ~t~~OOft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.65 1.50 1.50 0.00 79.69 3.00 2.97 -3.06 101.74 2.00 0.79 -3.17 101.74 0.00 0.00 0.00 73.85 4.00 3.60 -2.54 -598.54 0.00 0.00 0.00 -725.60 3.00 -3.00 0.00 -725.60 0.00 0.00 0.00 -725.60 0.00 0.00 0.00 -725.60 0.00 0.00 0.00 ,;TFO t:ët~ 0.00 0.00 45.00 325.30 288.32 0.00 -29.97 0.00 180.00 0.00 0.00 0.00 MPL-43 Vert Poly Section 1 : Start Hold MD,·. Incl Azim TVD +N/-S ,····+EI- W VS DLS,> .... Build Turn TFO ft deg deg ft ft ft ft, døg/10Oftdegl'1 00ftdegl1 000 '. deg 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ') ') Sperry-Sun Planning Report - Geographic Qa~~: 12J05/2Òå~:. .!',Ti~e:';i~1 O;~0:54 . ..... ..' ,'/',1'J~i~è:::)::' 2 ~;(i~~~~~Ÿ~~~~:~:~~~~~.\ ~~~~Fs~.~:i~,P¡it~i.~rur:.~o~~:;. ,........',:,':::;..,:::,. " . .... ..Se~t~on ,~Vs>-:Jlefe~~~ff,~: .....j;' UsertP;pq~,0,~pE!'~~?'f6Azi~$i: . ':' , ,.,.ê ", . . flam i·i::' ,,\>(.>., ::~: MI?L~3,.:wpO~<¡'~P;:41;iL<;t:'J.f.: . ¡, ,',. Section 2: Start Build 1.50 400.00 433.33 1.50 2.00 45.00 45.00 399.99 433.31 Section 3: Start DLS 3.00 TFO 325.30 0.93 1.65 0.93 1.65 499.89 599.45 698.41 796.50 893.43 988.96 1082.81 1174.74 1264.48 1351.79 1436.43 1445.82 ·;····:!:~:~ifJ.·(ïFtw;lr~?~J:f~.j':,: 4.43 3.50 12.90 7.05 26.49 11.52 45.15 16.90 68.84 23.17 97.50 30.31 131.05 38.31 169.39 47.14 212.41 56.78 260.01 67.21 312.05 78.38 318.20 79.69 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1511.29 3.82 6.74 9.71 12.69 15.68 18.68 21.67 24.67 27.67 30.66 33.66 34.00 27.64 19.99 16.98 15.37 14.37 13.68 13.18 12.79 12.48 12.23 12.02 12.00 4 : Start DLS 2.00 TFO 288.32 1,. ~iÍÔ.'; . :t.:X?:LTW Z';':~e9I:¡::;nTt, ~. '~.' 9.03 1519.10 5.80 1601.06 2.69 1682.20 0.00 1754.46 Section 1600.00 1700.00 1800.00 1889.99 34.59 35.35 36.18 37.00 Section 5: Start Hold MD'>: ft' . 1900.00 37.00 2009.62 37.00 '~~i~~)¡t~'~::~·:J~!1~~0~f'~~~j~~;..d~\~~ol·( ..:{1J:.:',' 0.79 1.50 1.50 0.00 0.00 1.41 1.50 1.50 0.00 0.00 ;> ;. A) 'i)',., 367.34 424.16 482.42 536.04 88.80 96.18 100.49 101.74 ;))~~<::'~;~;~i*d~~fqþijl~:~t~~o6tJtd~~~iÒOft'" . 3.92 3.00 2.73 -26.04 11.83 3.00 2.92 -7.65 24.69 3.00 2.97 -3.01 42.46 3.00 2.98 -1.61 65.10 3.00 2.99 -1.00 92.53 3.00 2.99 -0.69 124.70 3.00 2.99 -0.50 161.50 3.00 3.00 -0.39 202.83 3.00 3.00 -0.31 248.60 3.00 3.00 -0.25 298.66 3.00 3.00 -0.21 304.57 3.00 3.00 -0.19 -34.70 -17.36 -9.75 -6.77 -5.19 -4.21 -3.56 -3.08 -2.73 -2.45 -2.23 -2.05 352.03 407.34 464.50 517.46 :dþLS:':. ". ,.... ~~ild:,:, .::i:IU~1:i2;'t~:LW;íFØ ~~gI.1 OOO..d~QI1 Op~t g~~t:1Pp,,~j;jJ;<%'t9~ 2.00 0.67 -3.35 -71.68 2.00 0.75 -3.23 -69.23 2.00 0.84 -3.11 -66.58 2.00 0.91 -2.99 -64.05 0.00 0.00 ft 1762.46 1850.00 Section ;<~D ;,·{t:,.· 2100.00 2200.00 2300.00 2400.00 2410.85 6 : Start DLS 4.00 TFO -29.97 :···.~~.)·:,;i'1::..·'·'~ì~l,;. ':'f:,,;', .;~..;.: 40.17 357.20 1920.65 43.74 354.50 1995.01 47.37 352.14 2065.03 51.04 350.04 2130.37 51.44 349.83 2137.16 542.06 608.03 ;+N/¿S ..' , ft', 664.36 731.01 801.89 876.65 884.98 101.74 101.74 :J)LS '}'. '.'. JJuild, "', . ''J:'urn.i;j;<:t .'.:....·.'··1'~O ~~g/1 000 d~g/1 qÇ>ft~té,gltÒ~~~;,;^:{ji:deg 523.43 0.00 0.00 0.00 180.00 588.80 0.00 0.00 0.00 180.00 {;::;±:EI~W!~:h:;:.' VS · ·.i<. DLS:\;m,BuUd ...;, ~;TÜ'ríl" .., :'.<;::: ,rt,;;-";.:i;/,,,;· "ft· ." . ;:';degltP®~eg~;1.ogtt~;d~gI1gpft. ' 100.31 644.81 4.00 3.50 -3.10 95.43 711.51 4.00 3.57 -2.70 87.08 782.86 4.00 3.63 -2.36 75.33 858.53 4.00 3.67 -2.10 73.85 866.98 4.00 3.69 -1.98 ,'T:F1();L', ·····,q~X~, -29.97 -27.78 -25.78 -24.12 -22.75 Section 7 : Start Hold 'MD Incl ' Azho TVD " +N/-S +E/';'W VS DLS . . Build . . Turn' TFO ft deg deg ,ft ,ft ft ft deg/10OO 'deg/10Oftdegl1QOO 'dég~ 2500.00 51.44 349.83 2192.73 953.59 61.53 936.62 0.00 0.00 0.00 0.00 2600.00 51.44 349.83 2255.07 1030.56 47.72 1014.75 0.00 0.00 0.00 0.00 2700.00 51.44 349.83 2317.41 1107.52 33.91 1092.87 0.00 0.00 0.00 0.00 2800.00 51.44 349.83 2379.75 1184.48 20.10 1170.99 0.00 0.00 0.00 0.00 2900.00 51.44 349.83 2442.08 1261.44 6.29 1249.11 0.00 0.00 0.00 0.00 3000.00 51.44 349.83 2504.42 1338.41 -7.52 1327.23 0.00 0.00 0.00 0.00 3100.00 51.44 349.83 2566.76 1415.37 -21.33 1405.35 0.00 0.00 0.00 0.00 3200.00 51.44 349.83 2629.10 1492.33 -35.15 1483.47 0.00 0.00 0.00 0.00 3300.00 51.44 349.83 2691.44 1569.29 -48.96 1561.60 0.00 0.00 0.00 0.00 3400.00 51.44 349.83 2753.77 1646.26 -62.77 1639.72 0.00 0.00 0.00 0.00 3500.00 51.44 349.83 2816.11 1723.22 -76.58 1717.84 0.00 0.00 0.00 0.00 3600.00 51.44 349.83 2878.45 1800.18 -90.39 1795.96 0.00 0.00 0.00 0.00 3700.00 51.44 349.83 2940.79 1877.15 -104.20 1874.08 0.00 0.00 0.00 0.00 3800.00 51.44 349.83 3003.12 1954.11 -118.02 1952.20 0.00 0.00 0.00 0.00 J ) Sperry-Sun Planning Report - Geographic Section 7 : Start Hold S ,;,,'¡d~!l~~~r:~~11~~,::ø~~~td~~.··;..':'Î:~ :, ftZ'" >' ·y:·....·v· 3900.00 51.44 349.83 3065.46 2031.07 -131.83 2030.33 0.00 0.00 0.00 0.00 4000.00 51.44 349.83 3127.80 2108.03 -145.64 2108.45 0.00 0.00 0.00 0.00 4100.00 51.44 349.83 3190.14 2185.00 -159.45 2186.57 0.00 0.00 0.00 0.00 4200.00 51.44 349.83 3252.47 2261.96 -173.26 2264.69 0.00 0.00 0.00 0.00 4300.00 51.44 349.83 3314.81 2338.92 -187.07 2342.81 0.00 0.00 0.00 0.00 4400.00 51.44 349.83 3377.15 2415.88 -200.89 2420.93 0.00 0.00 0.00 0.00 4500.00 51.44 349.83 3439.49 2492.85 -214.70 2499.05 0.00 0.00 0.00 0.00 4600.00 51.44 349.83 3501.83 2569.81 -228.51 2577.18 0.00 0.00 0.00 0.00 4700.00 51.44 349.83 3564.16 2646.77 -242.32 2655.30 0.00 0.00 0.00 0.00 4800.00 51.44 349.83 3626.50 2723.74 -256.13 2733.42 0.00 0.00 0.00 0.00 4900.00 51.44 349.83 3688.84 2800.70 -269.94 2811.54 0.00 0.00 0.00 0.00 5000.00 51.44 349.83 3751.18 2877.66 -283.76 2889.66 0.00 0.00 0.00 0.00 5100.00 51.44 349.83 3813.51 2954.62 -297.57 2967.78 0.00 0.00 0.00 0.00 5200.00 51.44 349.83 3875.85 3031.59 -311.38 3045.91 0.00 0.00 0.00 0.00 5300.00 51.44 349.83 3938.19 3108.55 -325.19 3124.03 0.00 0.00 0.00 0.00 5400.00 51.44 349.83 4000.53 3185.51 -339.00 3202.15 0.00 0.00 0.00 0.00 5500.00 51.44 349.83 4062.86 3262.47 -352.81 3280.27 0.00 0.00 0.00 0.00 5600.00 51.44 349.83 4125.20 3339.44 -366.62 3358.39 0.00 0.00 0.00 0.00 5700.00 51.44 349.83 4187.54 3416.40 -380.44 3436.51 0.00 0.00 0.00 0.00 5800.00 51.44 349.83 4249.88 3493.36 -394.25 3514.63 0.00 0.00 0.00 0.00 5900.00 51.44 349.83 4312.22 3570.32 -408.06 3592.76 0.00 0.00 0.00 0.00 6000.00 51.44 349.83 4374.55 3647.29 -421.87 3670.88 0.00 0.00 0.00 0.00 6100.00 51.44 349.83 4436.89 3724.25 -435.68 3749.00 0.00 0.00 0.00 0.00 6200.00 51.44 349.83 4499.23 3801.21 -449.49 3827.12 0.00 0.00 0.00 0.00 6300.00 51.44 349.83 4561.57 3878.18 -463.31 3905.24 0.00 0.00 0.00 0.00 6400.00 51.44 349.83 4623.90 3955.14 -477.12 3983.36 0.00 0.00 0.00 0.00 6500.00 51.44 349.83 4686.24 4032.10 -490.93 4061.48 0.00 0.00 0.00 0.00 6600.00 51.44 349.83 4748.58 4109.06 -504.74 4139.61 0.00 0.00 0.00 0.00 6700.00 51.44 349.83 4810.92 4186.03 -518.55 4217.73 0.00 0.00 0.00 0.00 6800.00 51.44 349.83 4873.25 4262.99 -532.36 4295.85 0.00 0.00 0.00 0.00 6900.00 51.44 349.83 4935.59 4339.95 -546.18 4373.97 0.00 0.00 0.00 0.00 7000.00 51.44 349.83 4997.93 4416.91 -559.99 4452.09 0.00 0.00 0.00 0.00 7100.00 51.44 349.83 5060.27 4493.88 -573.80 4530.21 0.00 0.00 0.00 0.00 7200.00 51.44 349.83 5122.60 4570.84 -587.61 4608.34 0.00 0.00 0.00 0.00 7279.14 51.44 349.83 5171.94 4631.75 -598.54 4670.16 0.00 0.00 0.00 0.00 Section 8 : Start Drop -3.00 '.}.... ':.~~~~~~>...; }.;: !':;'..~~;,.: '. ,...- '. ^ 7300.00 50.81 7400.00 47.81 7500.00 44.81 7600.00 41.81 7700.00 38.81 7800.00 35.81 7900.00 32.81 8000.00 29.81 8100.00 26.81 8200.00 23.81 8300.00 20.81 8400.00 17.81 8500.00 14.81 8600.00 11.81 8700.00 8.81 8800.00 5.81 8900.00 2.81 8993.70 0.00 ,"~1",:;1;~~:'¡···j¡::·:l:;,f",)j\,~y;;:/ /r~:::~~~~;}.,··...,:,.",j};ht~/it~'~,t\1t.~;·.J~·,:.'~fjj·'i, ,. 349.83 5185.03 4647.73 -601.41 4686.39 349.83 5250.22 4722.36 -614.80 4762.13 349.83 5319.29 4793.52 -627.57 4834.37 349.83 5392.04 4861.03 -639.69 4902.90 349.83 5468.29 4924.70 -651.11 4967.53 349.83 5547.81 4984.36 -661.82 5028.08 349.83 5630.40 5039.83 -671.77 5084.39 349.83 5715.83 5090.98 -680.95 5136.30 349.83 5803.86 5137.65 -689.33 5183.68 349.83 5894.25 5179.73 -696.88 5226.39 349.83 5986.75 5217.09 -703.59 5264.32 349.83 6081.11 5249.64 -709.43 5297.35 349.83 6177.08 5277.28 -714.39 5325.41 349.83 6274.38 5299.94 -718.45 5348.41 349.83 6372.75 5317.55 -721.61 5366.29 349.83 6471.93 5330.08 -723.86 5379.00 349.83 6571.63 5337.47 -725.19 5386.51 0.00 6665.30 5339.74 -725.60 5388.81 d~~~~··..·~~~~~~~;'~~t ¿º~·¡~~:>ý;t~.,;;~~~~.~';,·.,1;. 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 3.00 -3.00 0.00 180.00 ) ) Sperry-Sun Planning Report - Geographic :~iç~~~#n~:"~PAmoC9, " {?::Fiel~:;")\:: Mlh1ef?oint ' !: ~1~r~~~¡[~!J .'. Section 9: Start Hold .', ;J)ate~;.0,1;2Iº5í200~ ";/;;;"0 Time: 1 10:$9:54 ::',:!^'.;;E!' ,:;:; .!;a,~,','"""e",',: · · '4' , ,«':C~O~dl~~t~(NE)Rèfêf~n~e:Well: Plàn ~P~~~iTI}Ì+'Nòk~,' ',", "", '.:, ,.: ··~>¡IJ~a.;1f··~i·~~i=~~iijfmi{'·~!:·¡·¡\:~': 9000.00 0.00 0.00 6671.60 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 9100.00 0.00 0.00 6771.60 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 9200.00 0.00 0.00 6871.60 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 9300.00 0.00 0.00 6971.60 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 9400.00 0.00 0.00 7071.60 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 9500.00 0.00 0.00 7171.60 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 9573.70 0.00 0.00 7245.30 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 Section 10: Start Hold ftc', +ÊZ w:'/'.'" ,~': 'vs ß" DtS, <Bûild . ,'Turn ~" '<~!ff'Ffõi'~:"" ',KRr"'¡':~ '1' 'äègÎ10dtf degl10Óft \Htfg/10 ,":'¡':';' ~.,;,,; . . '", ·x. . .':::::"%. .f:,.. < 'wWoo.;, 9600.00 9673.70 0.00 0.00 0.00 7271.60 0.00 7345.30 5339.74 -725.60 5388.81 5339.74 -725.60 5388.81 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Section 11 : Start Hold 9700.00 9800.00 9900.00 9923.70 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 7371.60 7471.60 7571.60 7595.30 5339.74 5339.74 5339.74 5339.74 -725.60 -725.60 -725.60 -725.60 5388.81 5388.81 5388.81 5388.81 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 Survey 34.00 0.00 0.00 34.00 0.00 0.00 6031825.26 544837.72 70 29 52.139 N 149 37 59.982 W 100.00 0.00 0.00 100.00 0.00 0.00 6031825.26 544837.72 70 29 52.139 N 149 37 59.982 W 200.00 0.00 0.00 200.00 0.00 0.00 6031825.26 544837.72 70 29 52.139 N 149 37 59.982 W 300.00 0.00 0.00 300.00 0.00 0.00 6031825.26 544837.72 70 29 52.139 N 149 37 59.982 W 400.00 1.50 45.00 399.99 0.93 0.93 6031826.19 544838.64 70 29 52.148 N 149 37 59.955 W 433.33 2.00 45.00 433.31 1.65 1.65 6031826.92 544839.36 70 29 52.155 N 149 37 59.934 W 500.00 3.82 27.64 499.89 4.43 3.50 6031829.72 544841.19 70 29 52.182 N 149 37 59.879 W 600.00 6.74 19.99 599.45 12.90 7.05 6031838.20 544844.69 70 29 52.266 N 149 37 59.775 W 700.00 9.71 16.98 698.41 26.49 11.52 6031851.81 544849.08 70 29 52.399 N 149 37 59.643 W 800.00 12.69 15.37 796.50 45.15 16.90 6031870.51 544854.34 70 29 52.583 N 149 37 59.485 W 900.00 15.68 14.37 893.43 68.84 23.17 6031894.24 544860.47 70 29 52.816 N 149 37 59.300 W 1000.00 18.68 13.68 988.96 97.50 30.31 6031922.94 544867.44 70 29 53.098 N 149 37 59.090 W 1100.00 21.67 13.18 1082.81 131.05 38.31 6031956.52 544875.23 70 29 53.427 N 149 37 58.855 W 1200.00 24.67 12.79 1174.74 169.39 47.14 6031994.91 544883.83 70 29 53.805 N 149 37 58.595 W 1300.00 27.67 12.48 1264.48 212.41 56.78 6032037.99 544893.21 70 29 54.228 N 149 37 58.311 W 1400.00 30.66 12.23 1351.79 260.01 67.21 6032085.65 544903.35 70 29 54.696 N 149 37 58.004 W 1500.00 33.66 12.02 1436.43 312.05 78.38 6032137.75 544914.21 70 29 55.208 N 149 37 57.675 W 1511 .29 34.00 12.00 1445.82 318.20 79.69 6032143.91 544915.48 70 29 55.268 N 149 37 57.636 W 1600.00 34.59 9.03 1519.10 367.34 88.80 6032193.09 544924.30 70 29 55.751 N 149 37 57.368 W 1700.00 35.35 5.80 1601.06 424.16 96.18 6032249.95 544931.33 70 29 56.310 N 149 37 57.151 W 1800.00 36.18 2.69 1682.20 482.42 100.49 6032308.23 544935.29 70 29 56.883 N 149 37 57.024 W 1889.99 37.00 0.00 1754.46 536.04 101.74 6032361.85 544936.21 70 29 57.410 N 149 37 56.987 W 1900.00 37.00 0.00 1762.46 542.06 101.74 6032367.88 544936.18 70 29 57.470 N 149 37 56.987 W 2009.62 37.00 0.00 1850.00 608.03 101.74 6032433.84 544935.78 70 29 58.119 N 149 37 56.987 W 2100.00 40.17 357.20 1920.65 664.36 100.31 6032490.15 544934.02 70 29 58.673 N 149 37 57.029 W 2200.00 43.74 354.50 1995.01 731.01 95.43 6032556.76 544928.73 70 29 59.328 N 149 37 57.173 W 2300.00 47.37 352.14 2065.03 801.89 87.08 6032627.58 544919.96 70 30 0.025 N 149 37 57.419 W 2400.00 51.04 350.04 2130.37 876.65 75.33 6032702.26 544907.75 70 30 0.760 N 149 37 57.765 W 2410.85 51.44 349.83 2137.16 884.98 73.85 6032710.58 544906.22 70 30 0.842 N 149 37 57.808 W 2500.00 51.44 349.83 2192.73 953.59 61.53 6032779.11 544893.50 70 30 1.517 N 149 37 58.171 W ) ) Sperry-Sun Planning Report - Geographic ¡'íi:rifät~ifÎii;: Survey 2600.00 51.44 349.83 2255.07 1030.56 47.72 6032855.98 544879.22 70 30 2.274 N 149 37 58.577 W 2700.00 51.44 349.83 2317.41 1107.52 33.91 6032932.86 544864.95 70 30 3.031 N 149 37 58.984 W 2800.00 51.44 349.83 2379.75 1184.48 20.10 6033009.73 544850.67 70 30 3.788 N 149 37 59.391 W 2900.00 51.44 349.83 2442.08 1261.44 6.29 6033086.60 544836.40 70 30 4.545 N 149 37 59.797 W 3000.00 51.44 349.83 2504.42 1338.41 -7.52 6033163.47 544822.12 70 30 5.302 N 149 38 0.204 W 3100.00 51.44 349.83 2566.76 1415.37 -21.33 6033240.34 544807.85 7030 6.058 N 149 38 0.611 W 3200.00 51.44 349.83 2629.10 1492.33 -35.15 6033317.21 544793.58 70 30 6.815 N 149 38 1.017 W 3300.00 51.44 349.83 2691.44 1569.29 -48.96 6033394.08 544779.30 70 30 7.572 N 149 38 1.424 W 3400.00 51.44 349.83 2753.77 1646.26 -62.77 6033470.95 544765.03 70 30 8.329 N 149 38 1.831 W 3500.00 51.44 349.83 2816.11 1723.22 -76.58 6033547.82 544750.75 70 30 9.086 N 149 38 2.237 W 3600.00 51.44 349.83 2878.45 1800.18 -90.39 6033624.69 544736.48 70 30 9.843 N 149 38 2.644 W 3700.00 51.44 349.83 2940.79 1877.15 -104.20 6033701.56 544722.20 70 30 10.600 N 149 38 3.051 W 3800.00 51.44 349.83 3003.12 1954.11 -118.02 6033778.43 544707.93 70 30 11.357 N 149 38 3.457 W 3900.00 51.44 349.83 3065.46 2031.07 -131.83 6033855.30 544693.66 70 30 12.114 N 149 38 3.864 W 4000.00 51.44 349.83 3127.80 2108.03 -145.64 6033932.17 544679.38 70 30 12.871 N 149 38 4.271 W 4100.00 51.44 349.83 3190.14 2185.00 -159.45 6034009.04 544665.11 70 30 13.627 N 149 38 4.677 W 4200.00 51.44 349.83 3252.47 2261.96 -173.26 6034085.91 544650.83 70 30 14.384 N 149 38 5.084 W 4300.00 51.44 349.83 3314.81 2338.92 -187.07 6034162.78 544636.56 70 30 15.141 N 149 38 5.491 W 4400.00 51.44 349.83 3377.15 2415.88 -200.89 6034239.65 544622.29 70 30 15.898 N 149 38 5.898 W 4500.00 51.44 349.83 3439.49 2492.85 -214.70 6034316.52 544608.01 70 30 16.655 N 149 38 6.304 W 4600.00 51.44 349.83 3501.83 2569.81 -228.51 6034393.39 544593.74 70 30 17.412 N 149 38 6.711 W 4700.00 51.44 349.83 3564.16 2646.77 -242.32 6034470.26 544579.46 70 30 18.169 N 149 38 7.118 W 4800.00 51.44 349.83 3626.50 2723.74 -256.13 6034547.13 544565.19 70 30 18.926 N 149 38 7.525 W 4900.00 51.44 349.83 3688.84 2800.70 -269.94 6034624.00 544550.91 70 30 19.683 N 149 38 7.932 W 5000.00 51.44 349.83 3751.18 2877.66 -283.76 6034700.88 544536.64 70 30 20.440 N 149 38 8.338 W 5100.00 51.44 349.83 3813.51 2954.62 -297.57 6034777.75 544522.37 7030 21.197 N 149 38 8.745 W 5200.00 51.44 349.83 3875.85 3031.59 -311.38 6034854.62 544508.09 70 30 21.953 N 149 38 9.152 W 5300.00 51.44 349.83 3938.19 3108.55 -325.19 6034931.49 544493.82 70 30 22.710 N 149 38 9.559 W 5400.00 51.44 349.83 4000.53 3185.51 -339.00 6035008.36 544479.54 70 30 23.467 N 149 38 9.966 W 5500.00 51.44 349.83 4062.86 3262.47 -352.81 6035085.23 544465.27 70 30 24.224 N 149 38 10.373 W 5600.00 51.44 349.83 4125.20 3339.44 -366.62 6035162.10 544450.99 70 30 24.981 N 149 38 10.779 W 5700.00 51.44 349.83 4187.54 3416.40 -380.44 6035238.97 544436.72 70 30 25.738 N 149 38 11.186 W 5800.00 51.44 349.83 4249.88 3493.36 -394.25 6035315.84 544422.45 70 30 26.495 N 149 38 11.593 W 5900.00 51.44 349.83 4312.22 3570.32 -408.06 6035392.71 544408.17 70 30 27.252 N 149 38 12.000 W 6000.00 51.44 349.83 4374.55 3647.29 -421.87 6035469.58 544393.90 70 30 28.009 N 149 38 12.407 W 6100.00 51.44 349.83 4436.89 3724.25 -435.68 6035546.45 544379.62 70 30 28.765 N 149 38 12.814 W 6200.00 51.44 349.83 4499.23 3801.21 -449.49 6035623.32 544365.35 70 30 29.522 N 149 38 13.221 W 6300.00 51.44 349.83 4561.57 3878.18 -463.31 6035700.19 544351.07 70 30 30.279 N 149 38 13.628 W 6400.00 51.44 349.83 4623.90 3955.14 -477.12 6035777.06 544336.80 70 30 31.036 N 149 38 14.035 W 6500.00 51.44 349.83 4686.24 4032.10 -490.93 6035853.93 544322.53 70 30 31.793 N 149 38 14.442 W 6600.00 51.44 349.83 4748.58 4109.06 -504.74 6035930.80 544308.25 70 30 32.550 N 149 38 14.849 W 6700.00 51.44 349.83 4810.92 4186.03 -518.55 6036007.67 544293.98 70 30 33.307 N 149 38 15.255 W 6800.00 51.44 349.83 4873.25 4262.99 -532.36 6036084.54 544279.70 70 30 34.064 N 149 38 15.662 W 6900.00 51.44 349.83 4935.59 4339.95 -546.18 6036161.41 544265.43 70 30 34.821 N 149 38 16.069 W 7000.00 51.44 349.83 4997.93 4416.91 -559.99 6036238.28 544251.16 70 30 35.578 N 149 38 16.476 W 7100.00 51.44 349.83 5060.27 4493.88 -573.80 6036315.15 544236.88 70 30 36.334 N 149 38 16.883 W 7200.00 51.44 349.83 5122.60 4570.84 -587.61 6036392.03 544222.61 70 30 37.091 N 149 38 17.290 W 7279.14 51.44 349.83 5171.94 4631.75 -598.54 6036452.86 544211.31 70 30 37.690 N 149 38 17.612 W 7300.00 50.81 349.83 5185.03 4647.73 -601.41 6036468.83 544208.35 70 30 37.848 N 149 38 17.697 W 7400.00 47.81 349.83 5250.22 4722.36 -614.80 6036543.36 544194.50 70 30 38.581 N 149 38 18.092 W 7500.00 44.81 349.83 5319.29 4793.52 -627.57 6036614.44 544181.31 70 30 39.281 N 149 38 18.468 W 7600.00 41.81 349.83 5392.04 4861.03 -639.69 6036681.87 544168.78 70 30 39.945 N 149 38 18.825 W ) ') Sperry-Sun Planning Report - Geographic !ço~p~~y£'·a~A,~qcO" 1 Field:;;')" '~it Jv1iln~~òihtJ' :¡~i~~j·~{¡t~~~!î!i '!.," ..·.,p~t¢:Xt::..·1,~9'5/29º~·. ............',:~... ';;;Tjm~ir' ....·.·1Ö:~9~~4· ." ....... .... :'.,',t&J$;;}~;:':; .Pagè:' ::; .,ç?""or;~iiuitè(~E)R~fetèpceÙW~!(:: plan::MPL43;' T~~;N0Jiti. ."'. .:;"; '. ":::Y~rti~#Ü~m» R~f~re~c!::;::!?O;~P 50.~~ '::, .<.. " ·./i;'0:;;:~f'b,' .k ., . :':}·;·.·,~¡~~~~:n{~~,,~~f~jfrc'~:{~0'. ,.~(:'~éel~~~~g¡~~.;:~~.1~;;if~~i~æ ':; . Vi·" .(/::"/ Survey 'i¡~I~Î i':~ j ~~ :." ?i~.~·f·:~· ': ~ J;', ' .~ ~ ~'.'> ,", 7700.00 38.81 349.83 5468.29 4924.70 -651.11 6036745.46 544156.98 70 30 40.571 N 149 38 19.162 W 7800.00 35.81 349.83 5547.81 4984.36 -661.82 6036805.05 544145.91 70 30 41.158 N 149 38 19.477 W 7900.00 32.81 349.83 5630.40 5039.83 -671.77 6036860.45 544135.62 70 30 41.704 N 149 38 19.771 W 8000.00 29.81 349.83 5715.83 5090.98 -680.95 6036911.54 544126.14 70 30 42.207 N 149 38 20.041 W 8100.00 26.81 349.83 5803.86 5137.65 -689.33 6036958.16 544117.48 70 30 42.666 N 149 38 20.288 W 8200.00 23.81 349.83 5894.25 5179.73 -696.88 6037000.18 544109.68 70 30 43.080 N 149 38 20.511 W 8300.00 20.81 349.83 5986.75 5217.09 -703.59 6037037.50 544102.75 70 30 43.447 N 149 38 20.708 W 8400.00 17.81 349.83 6081.11 5249.64 -709.43 6037070.01 544096.71 70 30 43.767 N 149 38 20.880 W 8500.00 14.81 349.83 6177.08 5277.28 -714.39 6037097.62 544091.58 70 30 44.039 N 149 38 21.027 W 8600.00 11.81 349.83 6274.38 5299.94 -718.45 6037120.25 544087.38 70 30 44.262 N 149 38 21.146 W 8700.00 8.81 349.83 6372.75 5317.55 -721.61 6037137.84 544084.11 70 30 44.435 N 149 38 21.240 W 8800.00 5.81 349.83 6471.93 5330.08 -723.86 6037150.35 544081.79 70 30 44.558 N 149 38 21.306 W 8900.00 2.81 349.83 6571.63 5337.47 -725.19 6037157.74 544080.42 70 30 44.631 N 149 38 21.345 W 8993.70 0.00 0.00 6665.30 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9000.00 0.00 0.00 6671.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9100.00 0.00 0.00 6771.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9200.00 0.00 0.00 6871.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9300.00 0.00 0.00 6971.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9400.00 0.00 0.00 7071.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9500.00 0.00 0.00 7171.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9573.70 0.00 0.00 7245.30 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9600.00 0.00 0.00 7271.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9673.70 0.00 0.00 7345.30 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9700.00 0.00 0.00 7371.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9800.00 0.00 0.00 7471.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9900.00 0.00 0.00 7571.60 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W 9923.70 0.00 0.00 7595.30 5339.74 -725.60 6037160.00 544080.00 70 30 44.653 N 149 38 21.357 W z 12/23/03 TUE 11:48 FAX 907 564 4441 Id.J 001/005 ré:lge .1 U.l..!') ,) ) Ohms, Danielle H . , , ~ .... V/"'W'·'~"'''''''·fY V -," " . " . -. . _w, V"'frTlw-IItN."'--""""""-.-'-"',' 1', ...., . "VI ... '-w... ... r'."..." . . . '"' . 'yw~'\!'. To: steve_da vies @admin.state.ak.us Cc: Quay, Walter (Natchiq); Archey, Pat; Vendi, Larry J SUbject: FW: MPU L·43 Spacing Exception Steve, looked over 4328 which was applied for by Conoco Phillips. It only lists spacing exceptions listed in CO 182. There were also spacing exceptions listed in CO 205 for MPU (I have a hard copy, though it is not on the AOGCC website). It amends CO 173 to allow for 4 wells per government quarter section -except for those quarter sections adjacent to the MPU boundary. This is for the area described in CO 205 which pertains to the MPU Kuparuk River Oil Pool waterftood at the time: T1 SN, R10E (various sections - unfortunately does not include section 6 where L-43 is) and T13N, R11 E (various sections). This was not referenced in Conoco Phillip's CO 4328 - which primarily addressed changes to the Kuparuk River Unit not the Milne Point Unit_ Also in CO 205 is a provision: liThe Ala$ka Oil and Gas Conservatjon Commission may, by administrative action, make changes and approve operatiol1s that will enhance the efficiency of the MiJne Point Unit waterflood project". The reasoning for a spacing exception for L-43 i$ to increase waterflood and USWAG recovery from a partially faulted area. Sufficient ínjection support already exists to match voidage from new well L·43 in addition to other producers in MPU Hydraulic Unit 261. I'll be faxing a copy of CO 205 to you. Please check this and see if this sufficiently enables the AOGCC to make an exception for L-43 without having to go through the public notice process. Pat Archey will likely follow up with you tomorrow on this. Thanks. Danielle Ohms (564-5759) RECEIVED . -----Originai Message----- From: Quay, Walter (Natchiq) Sent: Monday, December 22,20033:20 PM To: Skillern, Randy L Cc: Archey, Pat; Ohms, Danielle H; U~ban, Dennis M; Vend], Larry J Subject: FW: MPU L-43 Spacing Exception Randy, Present Plans have uS drilling this well in early Jan. 2004. In the drilling permit process, Steve Davies has brought the spacing issue to light. Thís issue would require at least 30 days for a new CO is open for public comment and hearing... unless you have some other solution. So the sooner we can get the clock going the better. Can you help? DEC 2 :3 ¿tJU..~ -1 r .,ø.Caeo.ølielK>n ¡'ed'lIIt -u--Original Message----- From: Stephen Davies [mailto:5teve_davies@admin.state.ak,us] Sent: Monday, December 22, 2003 2:00 PM To: Quay, Walter (Natchiq) Cc: Tom Maunder Subject: MPU L-43 Spacing Exception Walter, It is Iny understanding that the MPU L-43 production well wiIl be drilled to the Kuparuk Formation at a bottom hole location in the NE/4 of Section 6, T13N, RIDE, UM. The Kuparuk River Oil Pool in this 12/23/2003 12/23/03 TUE 11:48 FAX 907 564 4441 ~~Q,2L<¿q~ ) ') area is goven1ed by Conservation Order (CO) 432B. Rule 3 of this order states: "Not more than one well ¡nay be drilled on any governlnentaI quarter section or govermnentallot corrcsponding to it nOr Inay any well be dri11ed on a govermnental quarter section or govemlnental1otcorresponding t9 it which contains less than J 25 acres7 nor lnay the pool be ope.ned in a well bore that is closer than 500 feet to any property line nor closer than 1,000 feet to the pool opened to the well bore in another well exccpt that in SectÍon~ 57 67 7, 8, 15, 16,21, and 22, TIIN, RIOE, U.M., an unrestricted number of wells nlay be driJJed.1I As proposed, L-43 meets the setback requirements froxn offset well bores and property lines~ but it will be the second well completed in the Kuparuk River FOl'luation in the NE/4 of Section 6 (the other bcing MPU L-04, a470+ BOPD Kuparuk production well). Consequently, a spacing exceptionis needed for MPU L-43. Because CO 432B has no ntle allowing administrative amendlllent, the spacing exception will take thè form of a new CO. Por this, the Commission must publish a public notice and provide opportunity for public CQrmnent and hearing. You can access and review CO 432B on the Commission's web site at: lllip:/lww'0£...~.t(-lt.e.·.~l~..!us/locallakpage~/ ADMIN/()gc/()rden~/.c9/ç()inQ~x.htrn. You can review the process and requirements for a spacing exception applièation in reguJation 20 AAC 25.055(d), which is also located on Qur web site at: hUI2/.Lwww.st.(lt.e.ak:.\1..s!loca]/akpagcs/^DMIN/ogçLR~gu ations/Reglnc1cx.hlIu. For your conveniencc, I have attached the full text of 20 ^AC 25.055 to the bot-tOln of this message. However, I urge you to review our regulations in their entirery. To help guide YOU7 1 have also attached a çopy of the checklist that the Commission staff uses to ensure spacing exception applications are complete. With your application, could you also please include a brief explanation as to why BP has chosen to drill L-43 În lhe same govenunental quartcr section as eXÎ~ting producer L-04'? If you have any additional questions, please feel free to call me, Sincerely, Steve Davies Petroleum Geologist. Alaska Oil and Gas Conservation Commission Telephone: (907) 793..1224 ------~~....__~~______________________________________--------1._.~~________ 20 AAC 25.055 DRILLING UNITS AND WELL SPACING. (d) The commission will -review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540, The applicant for an excepUon shall scnd notice of the applicatiun by cerlified mail tQ the owners, landowners! and operator~ described in (1) of this subsection and shall fUlilish the cOlrunisslon with a copy of the nOlÏce, the date of ¡nailing, and the addresses to which the nOliçe was sent. The application must include (1) the names of all owners, landowners, and operators of all properties within 1 ~OOO feet of a well drilJing for oil or within 3,000 feet of a well drilling for gas for which an exception is sought; (2) a plat drawn to a scale of one inch equaling 2,640 feet 01' larger, showing the location of the 12/23/2003 I4J 003/005 12/23/03 TUE 11:49 FAX 907 564 4441 ) ) STATE OF ALAS¥..A ALASKA OIL AND GAS CONSERVATION COt~!ISSION 3001 Porcupine Drive Anchorage. Alaska 99501-3192 Re: THE APPLICATION OF CONOCO ) Conserva~ion Order No. 205 INC. requesting an order ) approvin~ a waterflood ) Kuparuk River Field project or the Milne Point ) Kuparuk River Oil Pool Unit in the Kuparuk River ) Oil Pool and Field. ) October 9, 1984 IT APPEARING THAT: 1. Conoco Inc. I by letter and documents dated August 15 t 1984t and September 18, 1984, requested the Alaska Oil and Gas Conservation Commis$ion to approve the implemen- tation of a waterflood project for the Kuparuk River Oil Pool within the Milne Point Unit, a part of the Kuparuk River Field. 2. Notice of the application was published in the Anchorage Times on September 27t 198~. 3. There were no protests to the application. FINDINGS: 1. 2. 3. 4, 5. A waterflood project for the Kuparuk River Unit in the Kuparuk River Oil Pool and Fièld was approved on . June 14t 1984. The Kuparuk River Oil Pool and Field has been defined to include the area of the Milne Point Unir. - The application for additional recovery pertaining ~o the Milne Point Unit waterflood project filed by Canaco Inc. for the Kuparuk River Oil Pool contains all of the necessary data required by 20 AAC 25.400. Primary recovery from the Milne Point Unit portion of the Kuparuk River Oil Pool is estimated to be 10 percent of the original oil-in-place. Primary plus secondary oil recovery is expected to be 27 percent of the original oil-in-place or 53 ~illion barrels of stock tank oil. 12/23/03 TUE 11:49 FAX 907 564 4441 Conservation ( )er No. 205 Page 2 October 9, 1984 ~) Iß.J 004/005 '".,., .r..? f .j. 6. Rule 3 of Conservation Order No. 173 provides for one well per governmental quarter section. Increased well densit:y may be required to recover the ma.ximum amount of oil in areas 0: the Kuparuk River Oil Pool. 7. Areas of the Kuparuk River Oil Pool may require a production/injection well density of one well per 40 acres to provide the flexibility needed for a effective waterflood project. 8. Correlative rights will be protected And there will be no waste in a 40 acre spacing pattern for the Milne Point Unit. 9. The Alaska Oil and Gas Conservation Commission should have a.dministrative power to approve modifications to the Milne Point Unit waterflood project. CONCLUSION: The planned Milne Point Unit ~aterflood project will result in the recovery of significantly more oil, correlative rights will be protected and there will be no waste of hydrocar- bons . NOW, THEREFORE. IT IS ORDERED THAT the Milne Point Unit wa.ter- flood project is approved for the area described as follows: T13N, R10E, U.M. T13N, Rl1E, U.M. 5% Section 1. Sections 2. 3, 4, 9, 10, 11, 12, 13. 14, 15, N~, SE~ and E~ SWi Section 23, Sections 24 and 25, and E~ NE~ Section 26. S~ S~ Section 6, Section 7, SW~ and S% NW% Section S, SW~, S\ SE~. SW\ ~~, N~ NW~ and m~~ NE~ Section 18, Section 19, and NW~ NW~, S~ NW~. SW~, W% SE~ and SE~ SE~ Section 20. Rule 1. Well Spacing. Rule 3 of Conservation Order No. 173 is hereby amended by adding the following sentence; However, in the area des~ribed in Conservation Order No. 205, ex~epL for those govern~ental quarter sections adjacent to the Milne Point Unit boundarYJ four wells may be drilled per govern- mental quarter s@ction. 12/23(03 TUE 11:49 FAX 907 564 4441 Conservation C ~r No. 205 Page 3 October 9, 1984 141905/00",ª- ") RU~e ._~.. Administrati~~ __Action. The Alaska Oil and Gas ConsèrvatiùnCommission may, bv adcinistrative a.ction,. make cha.n~esand approve operations that- will enhance the efficiency of the Milnta Point Unit waterflood project. . RL~l~ } '. . Milne Point Unit ~vaterflood Surveillance Program. The Unit Operator will submit: an annual report: to the Commission on the Milne Point Unit waterflood. The report ~ill be submitted by April 1 of each year for the period ending December 31 and will contain the following information: (a) A tabulation of all pertinent reservoir pressure and injection pressure data on wells in che waterflood permits, (b) A tabulation of all production logs, injection well surveys, and injection well performance data. (c) Produced fluid volumes (oil, gas, and water) and water injection volumes reported by ~onth and On a cumulative bas is. Rule 4. Injectivity Profiles. An injection profile survey will be obtained on each injection well during the first nine months of sustainedinjec- tion using a quantitative method. Follow~up surveys will be performed on a rotating basis such that one-third of the total number of injection wells are surveyed during each cale-ndar year. The completed injection surveys will be filed with the Commission within 90 days after performing the survey. DONE at Anchorage, Æ1.'þ-. C! 1. -"'~ ~ · ~.v.o '?: .. ..,¡ " rf.r G' ~~~;~1~~ f~.',.,.!:.¡""_( . .~....\ -=t,,_.:.¡;,¡.<~...~ """ ~'?l..:"" r .,.....;~·~' -.'\. ..., i.,.: Ö . ;..-- --. -.. . ;-, \. ~.'-' :z ~~;:-~." .\WI~S 1JJ;~ ~ ..J~ .'l~ ~ ~.? "",,":h. ....'.'; .. lION Co·~· 9 I Conservation Commission " t:c), U~fLv ¿rry H. K gler, Commi sioner Alaska Oil and Gas Co servation Commission ~/ i)e . ,- h~--':" (~L Lorinie c. Smitb::- Commi"ssioner Alaska Oil and Gas Conservation Commission Re: MPL-43 Casing Program ) ) ~!~f:~~~:i~è'.M~I,~fq~si1t~¡ .~~~.i:J.....:...''''¡¡ ..·.,.........'.:...:..'·.·..·..(¡,·i..·..·.,·..··,·.·.·. ¡.. ,.... ~r9~:i~~~( ~ªW1d¢r~F~j~~7r@~~.~~~'a1<!~( t: ..' ,. .. ';tt~:'Tu~;:..~~:p~£:,2~QBl@:*1 :J4f~~()Ø ~ij,hi:iI .... 'it;{ Walter, Thanks for this information. I will place this note in the file. Nothing further is needed at this time. Tom Maunder, PE AOGCC Quay, Walter (Natchiq) wrote: Tom, As per our conversation, the following casing program changes are planned for MPL-43 (Permit is presently in review) : 1. 7" Longstring will be set at ....9230' (6902' TVD) and cemented to 500' above the shoe. Est. Cmt of 25 Bbls of 15.8 ppg G, ( 12 0 SX) 2. 4-1/2" Liner set at the same previous TD for the 7".. 9,925' MD (7595' TVD). Top of liner ....150' above 7" shoe @ 9,080' . Est. Cement Volume of 21 Bbls 15.8 ppg Latex G (100 Sx) Bottom Hole location is unchanged from the proposed permit plan. Walter Quay quaywd@bp.com (907)564-4178 (907)440-8632 - Cell 1 of 1 12/23/2003 1 :21 PM MPU L-43 Spacing Exception ) ') ~~~j~ç~;i~P~L~436pacihg'ß~~ep~ib#...·...... . .,............................. ..................................... ................... ~r?~.:··.'.$~~~~e,~i.··.g~y~.es.·...<stev~Ä~ay~~...~.~.a.~tpit1:.st~t~.~a~i u~.~.· ]4)~te:, ·ºn~.42P~()gp0:3J3,:~~:~Q 7090Ø Walter, It is my understanding that the MPU L-43 production well will be drilled to the Kuparuk Formation at a bottom hole location in the NE/4 of Section 6, TI3N, RI0E, UM. The Kuparuk River Oil Pool in this area is governed by Conservation Order (CO) 432B. Rule 3 of this order states: "Not more than one well may be drilled on any governmental quarter section or governmental lot corresponding to it nor may any well be drilled on a governmental quarter section or governmental lot corresponding to it which contains less than 125 acres, nor may the pool be opened in a well bore that is closer than 500 feet to any property line nor closer than 1,000 feet to the pool opened to the well bore in another well except that in Sections 5, 6, 7, 8, 15, 16, 21, and 22, TIIN, RI0E, U.M., an unrestricted number of wells may be drilled." As proposed, L-43 meets the setback requirements from offset well bores and property lines, but it will be the second well completed in the Kuparuk River Formation in the NE/4 of Section 6 (the other being MPU L-04, a 470+ BOPD Kuparuk production well). Consequently, a spacing exception is needed for MPU L-43. Because CO 432B has no rule allowing administrative amendment, the spacing exception will take the form of a new CO. For this, the Commission must publish a public notice and provide opportunity for public comment and hearing. You can access and review CO 432B on the Commission's web site at: http://www.state.~lk.lLs/local/akp~ges/ADMIN/ogc/ordcrs/cÒ/coindcx.htm. You can review the process and requirements for a spacing exception application in regulation 20 AAC 25.055(d), which is also located on our web site at: http://www.state.ak.us/local/akpages/ AD.MIN/ogc/Regulations/Reglndcx.htm. For your convenience, I have attached the full text of20 AAC 25.055 to the bottom of this message. However, I urge you to review our regulations in their entirety. To help guide you, I have also attached a copy of the checklist that the Commission staff uses to ensure spacing exception applications are complete. With your application, could you also please include a brief explanation as to why BP has chosen to drill L-43 in the same governmental quarter section as existing producer L-04 ? If you have any additional questions, please feel free to call me. Sincerely, Steve Davies 10f2 12/23/2003 1 :22 PM MPU L-43 Spacing Exception ) ) Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793-1224 ---------------------------------------------------------------------------- 20 AAC 25.055 DRILLING UNITS AND WELL SPACING. (d) The commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540. The applicant for an exception shall send notice of the application by certified mail to the owners, landowners, and operators described in (1) of this subsection and shall furnish the commission with a copy of the notice, the date of mailing, and the addresses to which the notice was sent. The application must include (1) the names of all owners, landowners, and operators of all properties within 1,000 feet of a well drilling for oil or within 3,000 feet of a well drilling for gas for which an exception is sought; (2) a plat drawn to a scale of one inch equaling 2,640 fe~t or larger, showing the location of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and we~ls; and (3) an affidavit by a person acquainted with the facts, verifying that all facts are true and that the plat correctly portrays pertinent and required data. ( e) Upon application by the operator, the commission will establish notice requirements different from those of (d) of this section if the operator demonstrates to the commission's satisfaction that compliance with the notice requirements in (d) of this section is not feasible because of the complexity of ownership within the notice area. History - Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152 Content-Type: application/msword Step3 Spacing Exception CHECKLIST.doc - - - Content-Encoding: base64 20f2 12/23/2003 1 :22 PM . p055196 DATE 11/25/2003 CHECK NO. 055196 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 11/25/2003 PR111803F PERMIT TO DRILL =EES H <~~ ~ ~ l. ..L\3 RECEIVED DEC 1 8 2003 Alaskc Oi\ & Gas Cons. l;Ù\ÍiiHI~sior; Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. P 0 5 51 9 6 CONSOLIDATED COMMERCIAL ACCOUNT - PAY: fj...............:......:.... P··· ). F;JJ' 1I'..·~mll tUh¡ .(.;.:.1' Ii f £ t f '.. I 'liP .hlt .pvr.- . -. - .t' . p' .::::1; !;t: U"I1:--- 1U~o DATE November 25,2003 AMOUNT *******$1 00.00******* TO THE ORDER OF: ALASKA OIL & GAS CONSERVATION COMMISSION 333W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 NOT~~~Dþ.IT~8 1~,o D~YS.;~~.;->~__-;. i;'~>.';"'-". h :.\~; ::.~..::::~.:::::~~:~:~:~.~. ::'::';';", ../~.::~;i:~:}~:::/:~<.'::: ~< '. .. 1"~-1f' :i:.~. .... ...... '''N' ..-" .............. ·~·>;:·~~··:··4:;í;~qA·· '. ::"~ ::"~ :·;~::!l:::··..:.·:. ¡ .1.. '-~......,..............,.. .¿~::~::~..:: {~:/::.;~.. :·(I~t~::~:rd:~,;:=~}~·::):~·::·::~.~j(J III 0 5 5 ~ Ii b III 8: 0 L. ~ 2 0 ~ a Ii 51: 0 ~ 2 7 a Ii b III ) '\ ) TRANSMJT AL LETTER CHECK'LIST CIRCLE APPROPRJA TE LETTER/P ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME IJ?pa ¿ - «3 2Ð3-2-2f PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dumber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellboresegment'of existing well ' Permit No, API No. Production, should continue to be reported as a function 'of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), al1 records, data and logs acquired for tbe pilot hole must be dearly differentiated In both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) / SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates The permit is approved subject ·to fuD compliance with 20 AAC 25.,055. Approval to perforate and produce is contingent upon issu~nce of ~ conse'¡&tion order 9)U:oving a spacing exception. ¡-y~ (Company Name) assumes tbe liability of any protest to tbe spacing ,exception tbat may occur. An dry ditcb sample sets submitted to the Commission must be in no greater tban 30' sample intervals from below the permafrost or from where samples are first caugbt and 10' sample intervals through target zones. .WELL ~~~I\'IITgl:i~è,KL~SI Field & Pool__.~~~~~~9~~!~'S~~~~~.~.~~YE.~_C?~~~ 525100 ____.__.__.____._..___....__.___.__._..__ Well Name: MJLNE_.eLU.NJLKR.L4.~__.____..__.___._ Program Ø_E\L____ ______._____._ Well bore seg [J PTD#: 2032240 Company _a.e_E~P-LQßAII.Qr~U8L8SIS8)JNC-.--------.--_-..--..---n ___.__________.___ Initial ClasslType __QE~..E.EJ~tD_ GeoArea _8_9_0______.___._.___._ Unit lJ.3.2JL_~___. On/Off Shore .Qo_.._._.__ Annular Disposal [] Administration 1 p~(lnit.fe~ attaçhed_ _ . . . _ . . _ _ . . . _ _ . . . . . _ _ . . . . . Y~s . _ . _ _ . . . _ . _ . . . . . _ _ _ . . . . _ _ . . . _ . .. . . _ . _ . . 2 .Leas~.numb~r .appropriate_ . . Y~s _ _ . . _ . 3 _U.niqµe well. n.arn~ .and OlU1)b.er . . . _ . . . . . . . . . . . . _ _ _ . _ . . . . . _ _ . . _ . . . . . . . Yes _ .. . . . _ _ _ . . . . . . _ _ . . . . . . . . . . _ . . . . . . . . . _ _ _ _ _ . _ _ _ . . . .. . . .. . _ _ _ _ .. . .. _ _ _ _ . . . .. _ . . . . _ _ 4 _W~II JQcat~d in.a. d.efine.d .pool. . . _ . . . . . _ .. . . . _ _ .. ... _ yes _ _ _ . _ _ . . _ . . . . . . .. _ . . _ _ . . . . . . . . . . 5 .W~JIJQcated pr.oper _di.stance. from driJling unitb_ound.ary_ _ . . . . . . . . . . . Y~s . . . . _ . . _ _ . _ . .. _ . _ . . _ _ . . . _ . . . . . . 6 .Well JQcpt~d pr.op~r .d ista nce_ from otb~r w~l!s.. . _ . _ _ _ . _ . Yes. . _ _ _ . . _ _ . . . . . _ _ _ _ .. _ . . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ . _ . . . _ . . . . . _ . 7 _S.uffiçient.açr~a9.e.available¡n.dJilJiogunjt... ~......... _ _..... _'. _ _ _ _... _. _. No... _ _.. .SPAGING_EXÇEI?TION.RE.QUJREO:.GQ432a.Rule3al!ows~w~lJp~rgov.ernme.ntalquar:t~r.sec;tipn... . 8 Jf.d~viated.js_weJlbQr~platincJu_ded. _. _ _. _ _ _ _ _ _... _ _.. _ _ _ _ _ _ _ _ _... _. _. Y~s... _.. .ThiswilJb~the~ecolJd.w~IUntheNE.1l4.oJSec;tioo6......... _ _.. _ _ _. _ _. ... _ _. 9 _O'p~r:.ator only affeçt~d party. .. . . . . . . . _ . . . _ . . . . _ . . . . . . . . . . _ . _ _ ...... Y~$ _ _ _ . . . . . . . . . . . _ _ _ . . . _ . . . . . _ . . . . . . . _ _ . . . . . . . . . _ _ _ _ _ _ _ _ . _ _ _ . . . _ _ _ _ _ _ . . _ . . . _ . _ 1 0 _O.p~r:.ator bas.appropriate_ b.ond in JQrç~ . _ . _ . . . . _ _ . . _ . . . . _ _ _ _ _ _ _ . . . . . . . .. _ _Y_e$ _ _ . . _ _ _ _ . . . . _ _ . . . . . _ _ _ _ . _ _ _ . _ . . _ _ _ _ _ _ . . . . _ . _ _ _ . . . . . . . . . _ _ _ _ _ . . _ _ . . . . . . . .. _ . _ 11 P~rmit c;an be issuerj witbQut co_n$erva.tion or(j~r.. . _ . _ _ _ . . . . . . . _ _ _ _ _ _ _ _ . _ _ _ _ _ No. . _ _ _ _ . . _ _ _ _ _ _ . . . . . . . . . . . _ . . . .. _ _ . _ _ . . . . _ . . _ . _ . . . .. _ _ . . . . . _ . . . . . .. _ . _ . _ . . Appr Date 12' P~rmitc;a(1 be iS$u.eçl witbQut administrative..approvaJ . .. . . . .. . _ . . . . . .. . .. _ ... . _ . . _ Y~$ _ . _ . _ . .. _ . _ . _ . . . _ . .. _ _ . . . . _ . . .. . _ _ . . _ . .. . . _ . . . . . . . . _ . _ . _ . . _ _ _ _ .. . . . _ . . _ SFD 12/22/2003 13 Can permit be approved before 15-day wait Yes 14 _W~JIJQcatedwithinareaal1d.strata_authorizedby.l(ljec;tiooOrd~r#(putlO#in.comm~(1t$).(For. NA _....... _. _ _ _ _ ... _ _ _ _... _ _ _...... _..... _.... _ _..... _. _.. _ _. _ _ _. _. _. _ _.... _ _ _ _._ 15 _AJlw~lJs_witDi_n.1l4_roile_ar~a_0f(eyi~wjd~otifi~d(Fo(~erv.ic~_w.ellonly>- _ _ _ _ _ _ _ _ _ _.... .NA _ _ _ _. _ _ _ _ _.... _ _ _ _.... _... _ _ _ _ _... _ _ _ _ _ _..... _ _........ _ _ _........ _ _ _ _ _ _ _.. ( 16 PJ~-produ.ced.i(1jeçtor; ,Òur.atio.n.ofpre-.pro'òuc;tiplJl~$s.tnan.~montlJs.(For.ser:.vi.cewellonJy)... _NA.... _. _..... _. _..... _ _ _ _.'. _..... _ _ _....... _ _. _.... _ _ _ _ _.... _ _ _ _ _ _.. _. _... __ 17 .A.cMP_ F.ind.ing .of CQn.si.st~(1çy. h.as bee_n .is.sued.for.tbis pr:.oiect. . . . . .. .. . . _ . _ . _ _ . _ . . . .NA _ _ . . . . . .. . _ . . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . .. _ . . . . . . _ _ .. _ _ _ _ .. _ . . _ _ . _ _ _ _ . . _ . . _ . 18 19 20 21 22 23 24 25 26 27 Date 28 12/23/2003 29 30 31 32 33 34 Engineering Appr TEM ¥t'~ -.---.--- h._.._____ .C.oodu.ct.or st(in.g.PJQvid~d _ _ _ . _ . _ . . _ . . '. . . . _ . . . . .. . . .. . . . _ . _ _ .. _ . . . . _ . . Y~$ . . . . . _ _ . . . . . .. . . _ _ . . .. . . _ . . .. . _ . . . . . . . . .. _ . . . . . .. _ _ _ . . . . _ . _ _ _ . . .. . . _ _ . _ _ _ . . _ . . . _ _ .Surjac~.cas.ing_PJQtec;ts. all.known. USOWs _ _ . . ... ......... _ _ . _ _ _ _ _ .. _ .. . . NA _ . . . . . . All. aq.uiJe.rs ex.empted,..4.o_G.FRH7::J02.(b)(3) _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ . . _ . _ _ .. . . . _ _ .. .. .. _ . . _ .CMT..v_ol..a.dequ.ate..to circ.ul..ate.o.n..cood_uçtor.&su..rf.C$g . . " . _ _ _ _ _ . . _ _ _ _ ..Y~s _ . . . . . . . . . _ _ _ . .. . . . . . . _ _ . . _ . . _ _ _ _ . _ .. . _ . _ _ . . _ _ . .. . . . . . _ _ _ _ .CMT.. v.ol. adequ.ate..to tie-i..nJong..string tÇ>.sud csg.. .. . . . . . . . . .. . . . .. . . . . . . _ _ . No. . . . . _ _ . Cement wUI çov.er. any _hyqrQc;arb.oos... .. . .. . _ . _ . .. .. . _ _ . . .. '.. . _ _ _ _ . .. . . .. _ . . . . . . . .CMTwil! coyer.aHklJown_pro_ductive bori;zon.s__ . . . . _ . . _ .. . . . . _ _ _ _ _ . . . . Y~s . _ _ .. . . . . . . . . . _ . .. . . . . .. _ _ _ _ _ _ _ . . _ . _ __ . _ _ _ _ _ _ _ _ . . . . . _ _ . .. . . _ _ _ . . _ _ . . . .G_asi[1g de.sig[1S aqequa.t~ f.or. C,,T, 6.&.permafr.ost... _. _ . _ . . . _ _ _ _ _ . . .. ..Y~s . . . . . . _ _ _ . . . . . . .. .. . _ .. . . . . _ . . _ . . . _ . .. . .. _ . . . . . . _ .. _ _ . . . _A'òequ.at.e_tan..kage.oJ re.serv~ pit. , _ _ _ _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . .. . . . _ . .. Yßs. . . .. . . . Rig js.e.quippe_d_witn $t~el_plts.. No rese.rve.p.itplanoe..d, All waste to.apprpve.d_dispos..al well(s).. . . _ . _ . . Jf..a..re-çlrilt, bas.a. 1..0:-403 fOJ abançlQnme.nt. be~o apPJoved . _ _ . . . . . .. . .. .. ._ . . _ _ _ _ NA.. . . _ . .. _ . . . . .. .. _ . . .. . . . . . . . . . . .. .. . . . . . . _ . _ _ _ _ . . _ _ _ . _ . _ _ _ . _ _ _ . . . . . _ . . _ _ .A'òequ~te_we!lbor~ ~eparÇltjo_n.pro'poseçl_ _ _ _ _ . _ . _ . _ _ . _ . . . . _ _ _ . _ . . _ . _ _ _ . . . .Y~s _ _ _ _ . _ . I?ro~imi..ty an~IY$i$ p~rf.o(rne_d, No .cI..O$~ ~pp(o~çh. iss.ue$ i'òen.tified.. .N!itjg.atiQn.m~a$lJres ~v~iJa..ble, . . _ . . . .. . . Jf..djv~r:t~r Jeq_uiJ~d, dQes jt ..me~t reguJatioos_ _ _ _ _ _ _ _ _ _ _ _ . _ .. . . . _ . . . _ _ . _ _ _ _ _ _ ..Y~s . . . . . _ . . . . . _ . _ . . . .. . . _ . . . _ . . . . . .. . . . . _ .. .. .. . . _ . _ . . _ .. . . . .. .. . ._ . . . . .. _ . .. . . .DJitliogflu.id.PJQgramsGhematic.&eq.uipJist..adequate_........... _ _. _..... _...... Yes. _.... ..MaximumBHl?in..Kupar.uk,.9.5.EMW.. Ptaoneçl.MW9._8-:9.9.atTO._..... _. _ _ _ _.... _ _ _ _.. _ _ _..... .B.oPEs,_d.o.they ..meetr~guJatiof') . . . . . . . _ . _ . . _ . .. .. . . . . .. . _ . .. Ye$ . _ _ _ _ . .. _ . _ _ . . . .. _ _ .. . .. . _ . _ _ _ _ . . . _ _ . . . . . . . _ . . . _ . _ _ _ . . . . _B.O..PE.p.r~s$ ra.tiog ~ppropriate;..test lo.(pu..t psig i.n.cpmmelJts). .. . .. _ _ _ _ _ _ . _ _ . _ _ _ . . . Yes _ . _ _ . . _ CalcuJa.ted_MASP.28.18 psi... 350Ppsi..test plan.nßd.. . . _ _ . _ . .. . .. _ . .. . . . _ _ . . . . _ ...... _ . . . . . . _C.hoke.manifQld cornpJies. w/Al?1.. RP-5~ (May 84).. . . . . . _ . . . . . _ . _ . . .. _ _ . . . .. . . . . ..Ye$ _ _ _ . . . . . _ _ . . . . . . . . . _ . . . .. . . . . . .. . _ _ _ . . .. . . . _ . . . . . . . . . . . _ . _ _ . . . .. _ _ _ _ . . _ _ _ . . .. .Work w.ill pçc.U( withpueoperptio.n .shutdown. . . . .. . . . . . . . .. _ _ _ .. ..Y~$ . .. ... ..... _ . . . . . _ _ _ .. . . . _ _ . .. .. . _ _ .. . .. . . . _ . . . . . . . . .. . . _ _ _ . .. . ..Is. pres.ence_ o.f H2S gas. prob.aÞI~. _ . . . . . . . . . . . . . . . . . . . _ _ . _ _ _ .. . . . . . . . No. _ . _ . _ . . _ . . _ _ _ . . . _ _ _ _ _ _ . . . .. . .. . . . . . . . _ _ . _ . .. . .. . _ . . .. .. . _ .. .. .. . .. .. . _ _ _ .. . _ . .. . . . _ . MeçlJa.ni.cal.coodJti.o[l.ot w~lIs within AOR ve.riJied. (Fpr:.s.ervice welJ QnJy).. _ . _ _ . _ . . . . .. . . NA.. _ _ . . . . . . . _ _ _ . . . .. . _ _ . . . . . . . . . . . . . . . .. . .. . . . _ _ . .. .. _ _ . . . . _ _ . . . .. _ _ . . . _ _ .. _ .. .. _ . _ . ( Geology --------,---,._--_.,_._._--~.._--_. --- -----.--------------.. Appr SFD 35 36 Date 37 12/22/2003 38 39 Geologic Commissioner: t:JYS --."---..----.-- .P~rrnit c_ao þe i..ssu.eçl w!o hyçlr:.ogen_ s.ul.fiçle lJ1eas.u(e~. _ _ . .. . . . . . . .. . .. .. . . _ . . .. .. . No. . . _ .. . . . l,-Pad. w~lI$nav.e_pro_dUGeçl.up to_ 1..1,5. p-pm. H2.S~ . . . _ . .. . _ . . . . . _ _ . . . . _ _ .. . . .. . _ _ . . . .. . . .. . . . . .D.ata.PJeseotecton.p-ote.nt.ialovemres.surß.zpne$................ -.. . -. _ _ _ _. Yes. _.... .Norm.a'-PJesSLln~gr:.a(jieoeexpeçte(jto..tOP~LlParuk..Re.servoir..pres_sure.e~pect~cJt.o.b~.9,5.ppg.EMW... _ _ _ _ _. .S~i$r:njc.analysjs.QfSbaJlowgas..z.ooes. . .. .. . .. . _ _ . .. . .. . . . _ . _ . . .. .. _ _ _ . . . . . . NA.. .. . . . .. . _ Res~(voir int.erv.atwill be_driHed.with.9.8.-.9,9.ppg.m.uçl._ _ . . . _ _ . . . _ . . _ _ . . . . . .Sßabe.çI.condjtioo survey.(if off-shore) _ . . . _ . . _ . .. .. _ . . . . . .. .. . .. . . . _ _ _ _ . NA. _ .. _ . . . .. . . . _ . . .. .. .. . _ _ _ _ _. _ _ _ _ . .. . _ _ . _ _ _ _ . . . . . . . . . . _ .. . _ . . . . . . . . . . .. . .. . . . .. .. CQnta.ct namelpDoneJor.weßkly prpgress.rep-o.rts [exploratory .only].. . .. .. . . . . . _ . . _ . _ . . NA. .. . . . . . . .. . . _ . . . . . . . . .. . .. . . _ . . . . . _ . . . . . . . . _ . . . . . . _ . . . .. .. . . . . . . _ . . .. . . . . . Date: Engineering Commissioner: "\ì./) Public / 2¿ 5?" J / r -" Commissioner:/ Date Date 2-/ <. c¡ /0 ) ) Well History File APPENDIX Infornlation of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. . To inlprove 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 c103-zzt I ~ 787 $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 23 15:11:02 2004 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/23 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. . . . . . . . . . . . . . . . . . . . .04/09/23 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 MPL-43 500292319000 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 23-SEP-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002851292 J. STRAHAN C. DIXON MWD RUN 2 MW0002851292 J. STRAHAN C. DIXON MWD RUN 4 MW0002851292 C.A. DEMOSKI D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002851292 C.A. DEMOSKI E. VAUGHN MWD RUN 6 MW0002851292 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 13N 10E RECE\VEO OCT 2 0 2004 O\t & Gas Cons. Comm\SS\Ofì A\_a Ancmøge 3636 5040 MSL 0) 50.80 16.30 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.750 9.625 6097.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS MPL-43 PBl AT ABOUT 6117'MD, 20' OUT OF THE 9 5/8" CASING SHOE AT 6097'MD. 4. MWD RUNS 1 AND 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 4 - 6 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 5 AND 6 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 6/29/2004. THESE LOG DATA WERE PROVIDED TO SSDS BY K. COONEY (SIS/BP) ON 9/15/04. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS I, 2, 4 - 6 REPRESENT WELL MPL-43 WITH API#: 50-029-23190-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9645'MD/7484'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name......... ... .STSLIB.OOl Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation...... .04/09/23 Maximum Physical Record..65535 File Type............... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ .5000 START DEPTH 67.5 111.5 6093.0 6093.0 6093.0 6093.0 6093.0 STOP DEPTH 9601.0 9651.0 9608.5 9608.5 9608.5 9608.5 9608.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -- BASELINE DEPTH 7.5 101.5 105.0 120.0 125.5 134.0 144.0 152.0 162.5 191.5 225.0 244.0 257.5 273.0 287.0 298.5 308.0 312.5 324.0 339.0 360.0 381.0 402.0 417.5 424.5 429.0 439.0 473.5 478.0 499.5 525.0 536.5 571.5 607.0 617.0 644.0 666.0 679.0 683.5 687.5 760.5 787.5 808.5 833.5 842.5 848.0 853.5 864.5 916.5 932.5 935.5 GR 67.5 102.5 107.5 121.0 127.0 134.5 143.5 150.0 158.5 193.0 228.0 246.5 261.0 276.0 289.5 299.5 307.5 311.0 324.0 338.5 359.0 379.5 406.5 419.5 424.5 428.0 435.5 469.5 478.0 496.5 520.5 532.5 568.0 605.0 616.0 640.0 664.5 677.0 681.0 685.0 758.0 786.5 809.0 831.0 840.0 847.5 853.5 862.5 918.0 932.0 935.0 985.0 996.0 1017.5 1041.0 1077.5 1092.0 1109.0 1136.0 1169.5 1179.0 1198.0 1206.5 1244.5 1293.5 1379.5 1402.5 1420.5 1436.5 1474.0 1515.0 1600.5 1669.5 1699.0 1710.5 1736.0 1770.5 1778.5 1790.5 1809.0 1876.5 1891.0 1899.0 1909.5 1915.0 1917.5 1930.0 1942.5 1951.5 1982.0 2010.5 2015.0 2056.5 2070.0 2080.0 2119.5 2146.5 2160.5 2171.0 2178.0 2197.5 2221.0 2229.5 2249.0 2261.0 2268.0 2275.5 2365.5 2372.5 2387.5 2396.5 2408.0 2413.5 2418.0 2422.5 2451.5 2457.0 2477.0 2497.0 985.0 996.5 1016.5 1041.0 1077.5 1089.0 1102.5 1129.5 1166.5 1178.5 1198.5 1209.0 1248.0 1294.5 1380.5 1403.5 1415.0 1432.0 1469.0 1506.0 1592.0 1660.5 1689.0 1703.0 1725.5 1762.5 1772.0 1782.5 1803.0 1875.0 1888.5 1897.0 1908.5 1914.5 1917.0 1930.0 1941.0 1948.0 1981.5 2011.5 2015.5 2057.0 2069.0 2080.0 2119.5 2149.5 2163.0 2172.5 2181.0 2200.5 2223.0 2231.5 2249.0 2259.5 2267.5 2275.0 2361.5 2369.5 2386.5 2394.0 2406.5 2411.0 2415.5 2421.0 2449.0 2455.5 2475.5 2497.0 2512.5 2520.5 2554.5 2573.5 2580.5 2592.5 2606.0 2633.0 2659.0 2680.0 2691.0 2702.0 2714.0 2720.0 2735.5 2757.0 2774.5 2779.0 2790.5 2797.5 2815.0 2822.5 2839.5 2852.5 2871.5 2884.5 2900.5 2906.0 2914.0 2917.0 2934.0 2937.5 2960.5 2963.0 2970.0 2979.0 2991.5 3018.0 3022.5 3026.5 3031.5 3068.0 3149 . 0 3177.0 3183.5 3201.0 3208.0 3220.0 3231.0 3235.0 3245.0 3249.0 3266.5 3280.0 3292.0 3307.5 3333.0 3348.0 3358.5 3379.5 3392.5 3397.5 3401.5 3459.0 3500.0 3505.5 3523.5 3544.5 2510.5 2520.5 2553.0 2570.0 2577.5 2587.0 2602.5 2630.5 2655.0 2677.5 2690.5 2699.5 2714.5 2720.0 2734.5 2754.0 2772.5 2778.0 2791.0 2797.0 2814.0 2822.5 2837.5 2856.5 2874.0 2883.5 2901.0 2905.5 2915.0 2919.0 2936.5 2939.0 2959.5 2962.0 2966.0 2976.5 2990.5 3016.0 3021.5 3026.0 3031.5 3066.5 3149.5 3175.0 3182.5 3200.0 3207.0 3218.5 3228.0 3231.0 3241.0 3245.0 3262.5 3279.5 3291.0 3303.0 3331.0 3346.5 3357.0 3381.0 3393.0 3396.5 3400.0 3461.5 3500.0 3506.5 3522.0 3544.0 3561.0 3570.0 3589.0 3610.0 3626.5 3639.5 3663.5 3746.0 3762.5 3770.5 3780.0 3801.5 3827.5 3843.5 3854.5 3895.0 3897.5 3909.0 3918.5 3927.5 3959.0 3966.5 3982.5 3991.5 4019.0 4028.0 4041.5 4064.0 4072.5 4075.0 4099.5 4111.0 4127.5 4164.0 4182.5 4203.5 4226.0 4235.5 4342.5 4372.5 4395.0 4411.0 4418.0 4442.0 4450.0 4468.5 4535.0 4548 .5 4560.0 4573.5 4606.0 4614.5 4626.0 4633.0 4642.5 4657.0 4678.0 4702.0 4717.0 4721.5 4733.5 4741.5 4772.5 4790.0 4804.0 4849.0 4858.0 4867.0 3562.0 3571.5 3588.5 3608.5 3623.5 3638.0 3658.5 3748.5 3762.0 3769.0 3780.0 3801.0 3826.5 3842.5 3855.0 3894.5 3897.0 3908.0 3920.5 3928.5 3957.5 3964.5 3979.5 3991.0 4017.5 4029.0 4045.0 4069.0 4075.5 4080.0 4100.0 4111.5 4129.0 4166.0 4183.0 4203.5 4225.5 4234.0 4344.0 4374.0 4393.5 4411.0 4416.0 4440.5 4448.5 4467.5 4535.0 4548.0 4561.0 4574.5 4607.0 4616.0 4626.0 4634.0 4642.5 4657.5 4679.0 4703.5 4717.0 4719.5 4733.0 4741.0 4773.0 4789.0 4805.0 4845.5 4856.5 4869.0 4886.5 4906.0 4911.0 4935.5 4955.5 4963.5 5002.0 5018.5 5035.5 5045.5 5067.0 5108.0 5115.5 5123.5 5126.5 5132.0 5168.5 5175.0 5188.5 5203.5 5233.5 5256.5 5268.5 5273.5 5287.0 5299.0 5301.0 5307.0 5313.5 5317.0 5328.0 5359.5 5364.0 5375.0 5379.0 5429.0 5451.5 5455.0 5499.5 5507.5 5520.5 5527.5 5550.5 5557.5 5570.0 5593.0 5599.0 5609.0 5617.5 5621.5 5648.0 5665.5 5694.0 5709.5 5725.5 5756.5 5771.0 5779.0 5823.0 5832.5 5836.0 5839.5 5845.5 5854.5 5866.0 5881.0 5917.0 5930.5 4888.5 4910.5 4917.0 4938.5 4955.5 4963.5 5002.5 5017.0 5032.5 5044.5 5063.5 5110.0 5115.0 5121.0 5125.5 5133.5 5166.5 5173.5 5186.5 5203.0 5235.0 5256.0 5271.0 5276.5 5292.0 5300.5 5303.5 5308.5 5313.5 5318.0 5331.0 5362.0 5366.5 5375.5 5380.0 5422.5 5443.0 5446.5 5495.5 5504.0 5520.5 5525.0 5552.0 5557.0 5571.5 5594.0 5601.5 5608.5 5618.5 5624.5 5644.0 5657.0 5689.5 5704.5 5719.5 5755.0 5769.5 5781.5 5824.5 5833.0 5835.5 5839.0 5845.0 5851.5 5864.5 5879.0 5915.0 5927.0 5946.0 5960.0 5985.0 5996.5 6006.5 6021.0 6037.0 6047.0 6060.0 6073.0 6082.0 6085.0 6098.5 6101.0 6111.0 6115.0 6169.0 6181.5 6203.5 6215.0 6221.0 6224.5 6375.0 6380.5 6389.5 6402.0 6419.0 6483.5 6496.0 6501.5 6512.0 6536.0 6573.5 6607.5 6743.0 6752.0 6776.5 6817.0 6918.0 6921.5 7075.0 7117.5 7221.5 7262.5 7281.5 7293.5 7298.0 7300.5 7320.5 7357.0 7362.5 7398.0 7438.5 7444.0 7478.0 7529.5 7532.5 7547.0 7564.0 7588.0 7590.5 7603.5 7612.0 7651.0 7673.5 7693.0 7698.0 7714.0 5943.0 5961.0 5985.0 5996.0 6004.5 6019.0 6037.5 6047.0 6060.5 6071.5 6080.0 6081.5 6098.0 6099.5 6107.5 6109.5 6165.0 6176.5 6200.0 6212.0 6214.5 6217.0 6370.5 6376.0 6384.5 6398.5 6415.5 6482.0 6493.5 6497.0 6506.0 6537.5 6576.0 6603.0 6739.5 6747.5 6771.0 6821.0 6916.5 6920.5 7074.5 7114.5 7216.5 7258.0 7279.5 7289.0 7292.0 7295.5 7315.0 7352.0 7356.0 7395.5 7435.0 7439.5 7475.0 7529.0 7531.0 7547.0 7566.0 7587.5 7588.5 7599.0 7610.0 7648.5 7671.0 7690.0 7693.0 7709.0 7727.5 7762.5 7780.5 7813.0 7937.0 7960.0 7984.5 8049.5 8195.0 8233.0 8239.0 8337.0 8352.0 8355.0 8366.0 8379.0 8383.5 8391.5 8396.5 8398.5 8401.0 8405.5 8408.5 8448.5 8474.5 8516.0 8542.5 8569.0 8747.0 8851.5 8857.5 8865.0 8869.0 8873.0 8881.0 8885.0 8891.5 8897.5 8900.5 8902.5 8905.5 8914.5 8972.0 8975.0 8986.5 8995.5 9012.0 9016.5 9041.5 9054.5 9057.0 9066.0 9098.5 9111.5 9113.0 9115.0 9130.5 9160.0 9165.0 9191.0 9199.5 9211.5 9227.0 9229.0 9238.0 9257.0 9265.5 9272.5 7720.5 7756.0 7772.0 7808.5 7932.0 7953.5 7980.0 8041.5 8191.0 8228.0 8233.0 8333.0 8346.0 8348.0 8358.5 8374.5 8379.5 8387.5 8392.5 8395.5 8397.5 8402.0 8404.0 8444.5 8469.5 8511.5 8539.0 8565.0 8740.5 8844.0 8852.0 8859.5 8863.0 8867.5 8875.5 8879.0 8884.5 8891.0 8895.5 8897.0 8899.5 8909.5 8968.5 8971.5 8982.0 8991.5 9007.0 9012.0 9038.0 9048.5 9052.5 9060.5 9096.5 9108.5 9110.0 9112.0 9126.5 9156.0 9160.5 9188.0 9196.0 9210.0 9224.5 9226.5 9236.0 9253.0 9261.0 9269.5 9283.0 9291.5 9302.5 9312.5 9318.0 9320.5 9331.5 9336.5 9348.0 9361.5 9374.5 9384.5 9395.5 9402.0 9413.5 9422.5 9425.0 9426.0 9431.0 9439.5 9448.0 9452.5 9459.0 9464.5 9469.0 9477.0 9482.5 9490 . 5 9497.0 9501.0 9503.0 9511.5 9523.0 9530.5 9535.0 9544.0 9549.5 9555.0 9651.0 $ 9279.5 9287.5 9298.0 9307.5 9314.0 9317.0 9327.5 9332.0 9344.0 9357.5 9370.5 9380.5 9391.0 9397.5 9409.0 9417.0 9420.0 9421.5 9425.5 9432.0 9443.5 9447.0 9454.0 9460.0 9464.5 9473.0 9477.5 9485.5 9492.5 9495.5 9498.0 9504.5 9516.5 9526.0 9531.0 9539.0 9544.5 9549.5 9645.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 4 5 6 MERGE TOP 67.5 3050.0 6097.0 8963.0 9288.0 MERGE BASE 3050.0 6097.0 8963.0 9288.0 9645.0 # 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 DEPT ROP MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 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 67.5 9651 4859.25 19168 67.5 9651 Rap MWD FT/H 0.22 1174.14 243.447 19080 111.5 9651 GR MWD API 17.64 257.99 80.8207 19068 67.5 9601 RPX MWD OHMM 0.89 944.57 3.24536 7032 6093 9608.5 RPS MWD OHMM 0.63 1532.5 3.86445 7032 6093 9608.5 RPM MWD OHMM 0.13 2000 22.2588 7032 6093 9608.5 RPD MWD OHMM 0.87 1930.74 6.31596 7032 6093 9608.5 FET MWD HOUR 0.18 47.08 2.103 7032 6093 9608.5 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .9651 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/23 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...... .04/09/23 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 67.5 113.5 STOP DEPTH 3004.0 3050.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 07-JAN-04 Insite 66.37 Memory 3050.0 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 DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 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 112.0 3050.0 .9 51.5 TOOL NUMBER 61497 12.250 112.0 Spud Mud 9.40 115.0 9.0 1650 12.6 .000 .000 .000 .000 Name Service Order DEPT ROP MWD010 GR MWD010 units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 .0 68.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3050 1558.75 5966 67.5 3050 ROP MWD010 FT/H 35.34 970.68 273.934 5874 113.5 3050 GR MWD010 API 18.2 126.08 63.0834 5874 67.5 3004 First Reading For Entire File......... .67.5 Last Reading For Entire File...... ... ..3050 File Trailer Service name.... ........ .STSLIB.002 service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/09/23 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...... .04/09/23 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. 2 .5000 START DEPTH 3004.5 3050.5 STOP DEPTH 6014.0 6097.0 # 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: 08-JAN-04 Insite 66.37 Memory 6097.0 3050.0 6097.0 48.0 54.2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER 61497 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Spud Mud 9.50 120.0 8.3 1000 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 .0 80.6 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3004.5 6097 4550.75 6186 3004.5 6097 ROP MWD020 FT/H 7.61 1174.14 327.158 6094 3050.5 6097 GR MWD020 API 17.64 122.45 71.1923 6020 3004.5 6014 First Reading For Entire File......... .3004.5 Last Reading For Entire File.. ........ .6097 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/23 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...... .04/09/23 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 RPS FET RPD RPX RPM ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 6014.5 6091.5 6091.5 6091.5 6091.5 6091.5 6097.5 STOP DEPTH 8925.0 8917.0 8917.0 8917.0 8917.0 8917.0 8963.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 17-JUN-04 Insite 66.37 Memory 8963.0 6097.0 8963.0 19.4 49.6 TOOL NUMBER 163686 157645 8.750 6097.0 LSND 9.20 57.0 9.0 2300 6.8 .850 .540 1.750 1.850 76.0 123.8 65.0 65.0 Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing................. ... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth 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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6014.5 8963 7488.75 5898 6014.5 8963 ROP MWD040 FT/H 0.22 638.43 167.799 5732 6097.5 8963 GR MWD040 API 33.72 257.99 102.923 5822 6014.5 8925 RPX MWD040 OHMM 1.15 465.97 2.6199 5652 6091.5 8917 RPS MWD040 OHMM 0.63 460.75 2.61249 5652 6091.5 8917 RPM MWD040 OHMM 0.13 1097.24 3.27258 5652 6091.5 8917 RPD MWD040 OHMM 0.99 1930.74 4.70497 5652 6091.5 8917 FET MWD040 HOUR 0.18 13.96 1.11178 5652 6091.5 8917 First Reading For Entire File........ ..6014.5 Last Reading For Entire File.......... .8963 File Trailer Service name............ .STSLIB.004 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .04/09/23 Maximum Physical Record. .65535 F i 1 e 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...... .04/09/23 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: 5 header data for each bit run in separate files. 5 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM FET RPD GR ROP $ .5000 START DEPTH 8917.5 8917.5 8917.5 8917.5 8917.5 8925.5 8963.5 STOP DEPTH 9245.5 9245.5 9245.5 9245.5 9245.5 9238.5 9288.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ..... .........0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.. ........ .Feet Data Reference Point... ......... ..Undefined Frame Spacing.................. ...60 .1IN 20-JUN-04 Insite 66.37 Memory 9288.0 8963.0 9288.0 9.7 19.5 TOOL NUMBER 129046 162742 6.125 8953.0 LSND 12.40 53.0 8.5 550 5.0 2.100 1.170 1.800 3.300 74.0 138.1 74.0 74.0 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 8917.5 9288 9102.75 742 8917.5 9288 ROP MWD050 FT/H 0.25 174.09 33.0634 650 8963.5 9288 GR MWD050 API 59.21 182.86 119.376 627 8925.5 9238.5 RPX MWD050 OHMM 0.89 1777.24 8.85656 657 8917.5 9245.5 RPS MWD050 OHMM 0.87 1851.1 15.8874 657 8917.5 9245.5 RPM MWD050 OHMM 0.84 2000 211.701 657 8917.5 9245.5 RPD MWD050 OHMM 0.87 1705.92 28.0018 657 8917.5 9245.5 FET MWD050 HOUR 0.67 47.08 9.7445 657 8917.5 9245.5 First Reading For Entire File......... .8917.5 Last Reading For Entire File.......... .9288 File Trailer Service name............ .STSLIB.005 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .04/09/23 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.. .... .04/09/23 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 GR RPD RPM 6 header data for each bit run in separate files. 6 .5000 START DEPTH 9239.0 9246.0 9246.0 STOP DEPTH 9595.5 9602.5 9602.5 RPS RPX FET ROP $ 9246.0 9246.0 9246.0 9288.5 9602.5 9602.5 9602.5 9645.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units........ ...Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ... . Undefined Absent value.......... ..... ...... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 21-JUN-04 Insite 66.37 Memory 9645.0 9288.0 9645.0 5.2 7.4 TOOL NUMBER 129046 162742 6.125 8953.0 LSND 12.50 52.0 .0 500 3.8 2.300 1.210 2.000 5.300 68.0 135.1 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9239 9645 9442 813 9239 9645 ROP MWD060 FT/H 0.8 161.86 66.8318 714 9288.5 9645 GR MWD060 API 28.5 134.13 95.0062 714 9239 9595.5 RPX MWD060 OHMM 1.47 70.48 5.55843 714 9246 9602.5 RPS MWD060 OHMM 1.45 71.39 5.35654 714 9246 9602.5 RPM MWD060 OHMM 1.39 63.94 5.0259 714 9246 9602.5 RPD MWD060 OHMM 1.45 55.65 4.90242 714 9246 9602.5 FET MWD060 HOUR 0.43 18.67 2.98244 714 9246 9602.5 First Reading For Entire File......... .9239 Last Reading For Entire File.......... .9645 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/23 Maximum Physical Record. .65535 File Type....... ........ .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/23 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. . . . . . . . . . . . . . . . . . . . .04/09/23 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 ) Sperry-Sun Dril~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 22 07:41:07 2004 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/22 Orig in. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Tape Header Service name.. . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/22 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name...... ......... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA ) :20 3 .. 2. 2. c.f RECEIVEr) SEP 2 8 2004 J .~ ~P- Alaska Oil & Gas Cons. CommiSSion Anchorage Scientific Technical Services Scientific Technical Services MPL-43 PB1 500292319070 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 21-SEP-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-285129 J. STRAHAN C. DIXON MWD RUN 2 AK-MW-285129 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 13N 10E 3636 5040 50.80 16.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.750 9.625 6097.0 # MWD RUN 3 AK-MW-285129 J. STRAHAN C. DIXON REMARKS: ) ) 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 3 COMPRISED DIRECTIONAL WITH DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); PRESSURE WHILE DRILLING (PWD); AND ACOUSTIC CALIPER (ACAL). 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 6/29/2004. THESE LOG DATA WERE PROVIDED TO SSDS BY K. COONEY (SIS/BP) ON 9/15/04. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3 REPRESENT WELL MPL-43 PB1 WITH API#: 50-029-23190-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9306'MD/6989'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/22 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 1 and clipped curves; all bit runs merged. .5000 START DEPTH 67.5 111.5 6088.5 6088.5 6088.5 6088.5 STOP DEPTH 9260.0 9311.5 9270.0 9270.0 9270.0 9270.0 67.5 102.5 107.5 121.0 127.0 134.5 143.5 150.0 158.5 193.0 228.0 246.5 261.0 276.0 289.5 299.5 307.5 311.0 324.0 338.5 359.0 379.5 406.5 419.5 424.5 428.0 435.5 469.5 478.0 496.5 520.5 532.5 568.0 605.0 616.0 640.0 664.5 677.0 681.0 685.0 758.0 786.5 809.0 831.0 840.0 847.5 853.5 862.5 918.0 932.0 935.0 985.0 996.5 1016.5 1041.0 1077.5 1089.0 1102.5 1129.5 1166.5 1178.5 GR BASELINE DEPTH 7.5 101.5 105.0 120.0 125.5 134.0 144.0 152.0 162.5 191.5 225.0 244.0 257.5 273.0 287.0 298.5 308.0 312.5 324.0 339.0 360.0 381.0 402.0 417.5 424.5 429.0 439.0 473.5 478.0 499.5 525.0 536.5 571.5 607.0 617.0 644.0 666.0 679.0 683.5 687.5 760.5 787.5 808.5 833.5 842.5 848.0 853.5 864.5 916.5 932.5 935.5 985.0 996.0 1017.5 1041.0 1077.5 1092.0 1109.0 1136.0 1169.5 1179.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -------- ) 9270.0 6088.5 ) RPX $ 1198.0 1198.5 ) ) 1206.5 1209.0 1244.5 1248.0 1293.5 1294 . 5 1379.5 1380.5 1402.5 1403.5 1420.5 1415.0 1436.5 1432.0 1474.0 1469.0 1515.0 1506.0 1600.5 1592.0 1669.5 1660.5 1699.0 1689.0 1710.5 1703.0 1736.0 1725.5 1770.5 1762.5 1778.5 1772.0 1790.5 1782.5 1809.0 1803.0 1876.5 1875.0 1891.0 1888.5 1899.0 1897.0 1909.5 1908.5 1915.0 1914.5 1917.5 1917.0 1930.0 1930.0 1942.5 1941.0 1951.5 1948.0 1982.0 1981.5 2010.5 2011.5 2015.0 2015.5 2056.5 2057.0 2070.0 2069.0 2080.0 2080.0 2119.5 2119.5 2146.5 2149.5 2160.5 2163.0 2171.0 2172.5 2178.0 2181.0 2197.5 2200.5 2221.0 2223.0 2229.5 2231.5 2249.0 2249.0 2261.0 2259.5 2268.0 2267.5 2275.5 2275.0 2365.5 2361.5 2372.5 2369.5 2387.5 2386.5 2396.5 2394.0 2408.0 2406.5 2413.5 2411.0 2418.0 2415.5 2422.5 2421.0 2451.5 2449.0 2457.0 2455.5 2477.0 2475.5 2497.0 2497.0 2512.5 2510.5 2520.5 2520.5 2554.5 2553.0 2573.5 2570.0 2580.5 2577.5 2592.5 2587.0 2606.0 2602.5 2633.0 2630.5 2659.0 2655.0 2680.0 2677.5 -)¡ ) 2691.0 2690.5 J 2702.0 2699.5 2714.0 2714.5 2720.0 2720.0 2735.5 2734.5 2757.0 2754.0 2774.5 2772.5 2779.0 2778.0 2790.5 2791.0 2797.5 2797.0 2815.0 2814.0 2822.5 2822.5 2839.5 2837.5 2852.5 2856.5 2871.5 2874.0 2884.5 2883.5 2900.5 2901.0 2906.0 2905.5 2914.0 2915.0 2917.0 2919.0 2934.0 2936.5 2937.5 2939.0 2960.5 2959.5 2963.0 2962.0 2970.0 2966.0 2979.0 2976.5 2991.5 2990.5 3018.0 3016.0 3022.5 3021.5 3026.5 3026.0 3031.5 3031.5 3068.0 3066.5 3149.0 3149.5 3177.0 3175.0 3183.5 3182.5 3201.0 3200.0 3208.0 3207.0 3220.0 3218.5 3231.0 3228.0 3235.0 3231.0 3245.0 3241.0 3249.0 3245.0 3266.5 3262.5 3280.0 3279.5 3292.0 3291.0 3307.5 3303.0 3333.0 3331.0 3348.0 3346.5 3358.5 3357.0 3379.5 3381.0 3392.5 3393.0 3397.5 3396.5 3401.5 3400.0 3459.0 3461.5 3500.0 3500.0 3505.5 3506.5 3523.5 3522.0 3544.5 3544.0 3561.0 3562.0 3570.0 3571.5 3589.0 3588.5 3610.0 3608.5 3626.5 3623.5 3639.5 3638.0 3663.5 3658.5 3746.0 3748.5 3762.5 3762.0 3770.5 3769.0 ) ') 3780.0 3780.0 3801.5 3801.0 3827.5 3826.5 3843.5 3842.5 3854.5 3855.0 3895.0 3894.5 3897.5 3897.0 3909.0 3908.0 3918.5 3920.5 3927.5 3928.5 3959.0 3957.5 3966.5 3964.5 3982.5 3979.5 3991.5 3991.0 4019.0 4017.5 4028.0 4029.0 4041.5 4045.0 4064.0 4069.0 4072.5 4075.5 4075.0 4080.0 4099.5 4100.0 4111.0 4111.5 4127.5 4129.0 4164.0 4166.0 4182.5 4183.0 4203.5 4203.5 4226.0 4225.5 4235.5 4234.0 4342.5 4344.0 4372.0 4374.0 4442.0 4440.5 4450.0 4448.5 4468.5 4467.5 4535.0 4535.0 4548.5 4548.0 4560.0 4561.0 4573.5 4574.5 4606.0 4607.0 4614.5 4616.0 4626.0 4626.0 4633.0 4634.0 4642.5 4642.5 4657.0 4657.5 4678.0 4679.0 4702.0 4703.5 4717.0 4717.0 4721.5 4719.5 4733.5 4733.0 4741.5 4741.0 4772.5 4773.0 4790.0 4789.0 4804.0 4805.0 4849.0 4845.5 4858.0 4856.5 4867.0 4869.0 4886.5 4888.5 4906.0 4910.5 4911.0 4917.0 4935.5 4938.5 4955.5 4955.5 4963.5 4963.5 5002.0 5002.5 5018.5 5017.0 5035.5 5032.5 5045.5 5044.5 5067.0 5063.5 5108.0 5110.0 5115.5 5115.0 ) ) 5123.5 5121.0 5126.5 5125.5 5132.0 5133.5 5168.5 5166.5 5175.0 5173.5 5188.5 5186.5 5203.5 5203.0 5233.5 5235.0 5256.5 5256.0 5268.5 5271.0 5273.5 5276.5 5287.0 5292.0 5299.0 5300.5 5301.0 5303.5 5307.0 5308.5 5313.5 5313.5 5317.0 5318.0 5328.0 5331.0 5359.5 5362.0 5364.0 5366.5 5375.0 5375.5 5379.0 5380.0 5429.0 5422.5 5451.5 5443.0 5455.0 5446.5 5499.5 5495.5 5507.5 5504.0 5520.5 5520.5 5527.5 5525.0 5550.5 5552.0 5557.5 5557.0 5570.0 5571.5 5593.0 5594.0 5599.0 5601.5 5609.0 5608.5 5617.5 5618.5 5621.5 5624.5 5648.0 5644.0 5665.5 5657.0 5694.0 5689.5 5709.5 5704.5 5725.5 5719.5 5756.5 5755.0 5771.0 5769.5 5779.0 5781.5 5823.0 5824.5 5832.5 5833.0 5836.0 5835.5 5839.5 5839.0 5845.5 5845.0 5854.5 5851.5 5866.0 5864.5 5881.0 5879.0 5917.0 5915.0 5930.5 5927.0 5946.0 5943.0 5960.0 5961.0 5985.0 5985.0 5996.5 5996.0 6006.5 6004.5 6021.0 6019.0 6037.0 6037.5 6047.0 6047.0 6060.0 6060.5 6073.0 6071.5 6082.0 6080.0 6085.0 6081.5 6098.5 6098.0 6101.0 6111.0 6115.0 9311.5 $ ): ). 6099.5 6107.5 6109.5 9306.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 67.5 3050.0 6106.0 MERGE BASE 3050.0 6106.0 9306.0 # 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. ..0 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 67.5 9311.5 4689.5 18489 67.5 9311.5 ROP MWD FT/H 0.29 1174.14 292.942 18401 111.5 9311.5 GR MWD API 17.64 260.25 81.1547 18386 67.5 9260 RPX MWD OHMM 0.84 2000 3.51311 6364 6088.5 9270 RPS MWD OHMM 0.82 2000 4.40391 6364 6088.5 9270 RPM MWD OHMM 0.81 2000 5.89564 6364 6088.5 9270 RPD MWD OHMM 0.07 2000 7.6604 6364 6088.5 9270 FET MWD HOUR 0.09 59.43 0.849657 6364 6088.5 9270 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .9311.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/22 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.... ...04/09/22 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 67.5 113.5 STOP DEPTH 3004.0 3050.0 # 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 DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 07-JAN-04 Insite 66.37 Memory 3050.0 112.0 3050.0 .9 51.5 TOOL NUMBER 61497 12.250 112.0 Spud Mud 9.40 115.0 9.0 1650 12.6 .000 .000 .000 .000 .0 68.0 .0 .0 REMARKS: ) ') $ # Data Format Specification Record Data Record Type....... ......... ..0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record.. .......... .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT Rap MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3050 1558.75 5966 67.5 3050 Rap MWD010 FT/H 35.34 970.68 273.934 5874 113.5 3050 GR MWD010 API 18.2 126.08 63.0834 5874 67.5 3004 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .3050 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/22 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...... .04/09/22 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 Rap $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3004.5 3050.5 STOP DEPTH 6060.0 6106.0 # 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 DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 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 08-JAN-04 Insite 66.37 Memory 6106.0 3050.0 6106.0 48.0 54.2 TOOL NUMBER 61497 12.250 112.0 Spud Mud 9.50 120.0 8.3 1000 8.0 .000 .000 .000 .000 Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) .0 80.6 .0 .0 First Last " ) ) Name Service Unit Min Max Mean Nsam heading Reading DEPT FT 3004.5 6106 4555.25 6204 3004.5 6106 ROP MWD020 FT/H 7.61 1174.14 326.432 6112 3050.5 6106 GR MWD020 API 17.64 122.45 71.5345 6112 3004.5 6060 First Reading For Entire File......... .3004.5 Last Reading For Entire File.......... .6106 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/22 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...... .04/09/22 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 RPD RPM RPS RPX FET ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 6060.5 6085.5 6085.5 6085.5 6085.5 6085.5 6106.5 STOP DEPTH 9254.5 9264.5 9264.5 9264.5 9264.5 9264.5 9306.0 # 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: 12-JAN-04 Insite 66.37 Memory 9306.0 6106.0 9306.0 1.6 52.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER 155789 '. } . ) EWR4 ELEC'l'!{OMAG. RES IS. 4 145654 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 6097.0 # BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) : 9.90 MUD VISCOSITY (S) : 45.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 300 FLUID LOSS (C3) : 6.0 RESISTIVITY ( OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.600 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .880 219.0 MUD FILTRATE AT MT: 6.000 70.0 MUD CAKE AT MT: 1.950 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6060.5 9306 7683.25 6492 6060.5 9306 ROP MWD030 FT/H 0.29 680 277.578 6400 6106.5 9306 GR MWD030 API 42.8 260.25 107.124 6389 6060.5 9254.5 RPX MWD030 OHMM 0.84 2000 3.21288 6359 6085.5 9264.5 RPS MWD030 OHMM 0.82 2000 3.80902 6359 6085.5 9264.5 RPM MWD030 OHMM 0.81 2000 5.69977 6359 6085.5 9264.5 RPD MWD030 OHMM 0.07 2000 7.8032 6359 6085.5 9264.5 FET MWD030 HOUR 0.09 59.43 0.834784 6359 6085.5 9264.5 First Reading For Entire File......... .6060.5 ) Last Reading For Entire File.......... .9306 \ j File Trailer Service name..... ....... .STSLIB.004 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/09/22 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/22 Or ig in. . . . . . . . . . . . . . . . . . . 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. . . . . . . . . . . . . . . . . . . . .04/09/22 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 Sperry-Sun Drl bg Services LIS Scan Utility ). ) 8)03'~d 0.1- $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 12 07:22:09 2004 J ) iff { Reel Header Service name.... 00...... .LISTPE Date. . 0 . . . . . . . . . 0 . . . . . . . .04/02/12 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. . . . . . . . . . . . . . . . . . . . .04/02/12 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 MPL-43 500292319000 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 12-FEB-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-285129 J. STRAHAN C. DIXON MWD RUN 2 AK-MW-285129 J. STRAHAN C. DIXON MWD RUN 3 AK-MW-285129 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 13N 10E 3636 5040 .00 50.80 16.30 RECEIV'ED MSL 0) # WELL CASING RECORD Fr-r""', 1 r (~nn4 -:oo, i-' ~) r'! U .....u ,'......" 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.750 9.625 6097.0 Alaska Oil & Gas Cons. Comn1isian ~Ji!jftœ1ge # "~~~('\\~ REMARKS: ) ) 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS or1J.J:r.:.RWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 3 COMPRISED DIRECTIONAL WITH DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); PRESSURE WHILE DRILLING (PWD); AND ACOUSTIC CALIPER (ACAL). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 2/9/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL MPL-43 WITH API#: 50-029-23190-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9306'MD/6989'TVD. 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. SLIDE = NON-ROTATED INTERVALS $ RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/12 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 67.5 113.5 6085.5 6085.5 6085.5 6085.5 6085.5 STOP DEPTH 9254.5 9306.0 9264.5 9264.5 9264.5 9264.5 9264.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ) \ ') --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 67.5 3050.0 6106.0 MERGE BASE 3050.0 6106.0 9306.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 9306 4686.75 18478 67.5 9306 ROP MWD FT/H 0.29 1174.14 292.654 18386 113.5 9306 GR MWD API 17.64 260.25 81.2073 18375 67.5 9254.5 RPX MWD OHMM 0.84 2000 3.21288 6359 6085.5 9264.5 RPS MWD OHMM 0.82 2000 3.80902 6359 6085.5 9264.5 RPM MWD OHMM 0.81 2000 5.69977 6359 6085.5 9264.5 RPD MWD OHMM 0.07 2000 7.8032 6359 6085.5 9264.5 FET MWD HOUR 0.09 59.43 0.834784 6359 6085.5 9264.5 First Reading For Entire File......... .67.5 Last Reading For Entire File... ....... .9306 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/12 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...... .04/02/12 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 67.5 113.5 STOP DEPTH 3004.0 3050.0 # 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 DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 07-JAN-04 Insite 66.37 Memory 3050.0 67.0 3050.0 .9 51.5 TOOL NUMBER 61497 12.250 112.0 Spud Mud 9.40 115.0 9.0 1650 12.6 .000 .000 .000 .000 .0 68.0 .0 .0 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3050 1558.75 5966 67.5 3050 ROP MWD010 FT/H 35.34 970.68 273.934 5874 113.5 3050 GR MWD010 API 18.2 126.08 63.0834 5874 67.5 3004 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .3050 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/12 Maximum Physical Record. .65535 F i 1 e 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...... .04/02/12 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. 2 .5000 START DEPTH 3004.5 3050.5 STOP DEPTH 6060.0 6106.0 ) # 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 DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 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 08-JAN-04 Insite 66.37 Memory 6106.0 3050.0 6106.0 48.0 54.2 TOOL NUMBER 61497 12.250 112.0 Spud Mud 9.50 120.0 8.3 1000 8.0 .000 .000 .000 .000 Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) .0 80.6 .0 .0 First Last Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 3004.5 7.61 17.64 ) Max 6106 1174.14 122.45 Mean 4555.25 326.432 71.5345 First Reading For Entire File......... .3004.5 Last Reading For Entire File.......... .6106 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/02/12 Maximum Physical Record. .65535 F i 1 e Typ e . . . . . . . . . . . . . . . . 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...... .04/02/12 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 RPD RPM RPS RPX FET ROP $ 4 Nsam 6204 6112 6112 }ding 3004.5 3050.5 3004.5 Reading 6106 6106 6060 header data for each bit run in separate files. 3 .5000 START DEPTH 6060.5 6085.5 6085.5 6085.5 6085.5 6085.5 6106.5 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 9254.5 9264.5 9264.5 9264.5 9264.5 9264.5 9306.0 12-JAN-04 Insite 66.37 Memory 9306.0 6106.0 9306.0 1.6 52.9 TOOL NUMBER 155789 1MAG. \ EWR4 ELEL RES IS. 4 145654 ) $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 6097.0 # BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY ( LB / G) : 9.90 MUD VISCOSITY (S) : 45.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 300 FLUID LOSS (C3) : 6.0 RESISTIVITY ( OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.600 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .880 219.0 MUD FILTRATE AT MT: 6.000 70.0 MUD CAKE AT MT: 1.950 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.... ...... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6060.5 9306 7683.25 6492 6060.5 9306 ROP MWD030 FT/H 0.29 680 277.578 6400 6106.5 9306 GR MWD030 API 42.8 260.25 107.124 6389 6060.5 9254.5 RPX MWD030 OHMM 0.84 2000 3.21288 6359 6085.5 9264.5 RPS MWD030 OHMM 0.82 2000 3.80902 6359 6085.5 9264.5 RPM MWD030 OHMM 0.81 2000 5.69977 6359 6085.5 9264.5 RPD MWD030 OHMM 0.07 2000 7.8032 6359 6085.5 9264.5 FET MWD030 HOUR 0.09 59.43 0.834784 6359 6085.5 9264.5 First Reading For Entire File......... .6060.5 Last Reading For Entire Fil~ ) . . . . . . . .9306 J File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/02/12 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name... ...... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/02/12 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. . . . . . . . . . . . . . . . . . . . .04/02/12 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
