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Home My WebLink About204-0731. 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 Completion w/Screens 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,348 NA Casing Collapse Conductor NA Surface 2,470psi Production 4,790psi Liner 6,590psi 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:WSW GINJ Op Shutdown Abandoned Contact Name: Contact Email:Hayden.Moser@hilcorp.com Contact Phone:907-793-1231 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Length AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Hayden Moser See Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025515, ADL0025517, ADL0025906 204-073 MILNE PT UNIT J-25 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23207-00-00 Hilcorp Alaska, LLC Size Proposed Pools: 3,872 3,887 3,621 888 SCHRADER BLUFF OIL Tertiary Undef WTRSP (525130) PRESENT WELL CONDITION SUMMARY 112' 112' 12.6/ L-80 / BTC R3 TVD Burst 2,772 MD NA 7,910psi 5,210psi 6,890psi 2,377' 3,726' 3,872' 2,399' 4,037' Operations Manager December 10, 2025 3-1/2" 78' 20" 10-3/4" 7-5/8" 2,365' Perforation Depth MD (ft): 4,445' Tertiary Undef WTRSP, statewide rules Hyratrieve LTC, Retrievable packer, ZXP Liner top packer and NA 2,817' MD / 2,773' TVD, 3,858' MD / 3,601' TVD, 3,914' MD / 3,640' TVD, and NA 3,887 8,348' See Schematic 4" 4,005' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.11.21 14:21:30 - 09'00' Taylor Wellman (2143) 325-720 By Grace Christianson at 2:50 pm, Nov 21, 2025 * BOPE pressure test to 2500 psi. 24 hour notice to AOGCC * CBL to AOGCC if contingency cementing required. DSR-11/21/25MGR21NOV2025 10-404 A.Dewhurst 24NOV25 11/24/25 - - - - - - _____________________________________________________________________________________ Revised By: TDF 8/5/2025 SCHEMATIC Milne Point Unit Well: MPU J-25 Last Completed: 4/21/2025 PTD: 204-073 Excluder Screen (4,857-8,303) TD =8,348(MD) / TD =3,872(TVD) 20 Tubing Cut @ 3,846 E-Line MD 4/5/2025 7-5/8 17 14 10-3/4 18 19 PBTD =3,387(MD) / TD = 3,621(TVD) Orig. KB Elev.:70.14/ Orig. GL Elev.:36.1 RKB Hanger: 30.15 (Doyon 14) 20 16 15 1 2221 Top of cement tagged at 3,887 (slm) on 7/13/2020 Top of cement calculated at 2,795` 2 & 3 4 5 & 6 11 & 12 13 7 & 8 9 & 10 NB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,399 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 4,037 4-1/2 Liner 12.6 / L-80 / BTC BxP 3.930 2,813 2,857 4-1/2 Screen Liner110 JFE Bear EnerG Screen 3.849 2,857 3,382 4 Liner 9.5 / L-80 / IBT 3.548 3,846 8,348 TUBING DETAIL 4-1/2 Tubing 12.6 / L-80 / BTC R3 3.958 Surface 2,772 JEWELRY DETAIL No Depth Item 1 2,647 Sensor, Discharge Adapter, 4-1/2'' 8rd EUE, SS 2 2,648 Pump #2: 538,SJ11500,56S,INC,15,1:1AR,HTEM 3 2,672 Pump #1: 538,SJ11500,56S,INC,15,1:1AR,HTEM 4 2,696 Intake Sub Assy: A/R-X2, 513X, 416 SS, Inconel Shaft 5 2,697 Upper Tandem Seal: 513 Series, BPBSBPB, Premium Seals 6 2,708 Lower Tandem Seal: 513 Series, BPBSBPB, Premium Seals 7 2,720 Motor #2: 562 Series, KMS2UT, 360HP/1715V/129A 8 2,744 Motor #1: 562 Series, KMS2LT, 360HP/1715V/129A 9 2,767 Sensor: Vigilant, Adapter, 456 Summit Motor to Vigilant Sensor 10 2,768 Sensor Gauge & Centralizer: 177C,8K PSI,SS Btm @ 2,772 11 2,813 5.00" TriPoint Polished Bore Receptacle LTC Pin 12 2,817 7 5/8" x 4-1/2", 24-29.7# Hydratrieve LTC BxP 40K Shear To Release 13 2,843 XN Nipple: 3.813"/3.725" No-Go BTC BxP 14 3,381 Bullnose: Bakerlok Btm @ 3,382 15 3,858 Retrievable Packer 16 3,891 3-1/2 XN Profile -2.750 No-Go Min ID 17 3,899 Overshot Btm @ 3,903 18 3,914 NB Lateral ZXP Liner Top Packer 19 3,923 NB Lateral 7-5/8 x 5-1/2 HMC Liner Hanger 20 4,724 HMCV Cementing Valve 21 4,748 NB Lateral Baker Payzone ECP Packer 22 8,348 NB Lateral 4-1/2 Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 430 sx AS Lite, 258 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 286 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 440 MD Hole Angle Passes 50+ deg @ 4,070 MD 45 deg @ Max Deviation in Tubing TREE & WELLHEAD Tree 4-1/165M FMC Wellhead 11 x 4-1/2 5M Gen 6 w/ 4.5 TCII T&B TubingHanger CIW H BPV Profile GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14 8/28/2004 Install Jet Pump by ASR#1 10/16/2019 Install Lower Comp and ESP by ASR 4/21/2025 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status Prince Creek 2,840 3,300 2,793 3,174 460 6 4.5 12/25/2024 Open Perf Guns 4.5 TCP 6 spf 60 Deg HSD _____________________________________________________________________________________ Revised By: TDF 8/5/2025 PROPOSED Milne Point Unit Well: MPU J-25 Last Completed: 4/21/2025 PTD: 204-073 TD =8,348(MD) / TD =3,872(TVD) 20 Tubing Cut @ 3,846 E-Line MD 4/5/2025 7-5/8 20 17 10-3/4 21 22 PBTD =3,387(MD) / TD = 3,621(TVD) Orig. KB Elev.:70.14/ Orig. GL Elev.:36.1 RKB Hanger: 30.15 (Doyon 14) 23 19 18 1 2524 Top of cement tagged at 3,887 (slm) on 7/13/2020 Top of cement calculated at 2,795` 2 & 3 4 5 & 6 14 & 15 11 7 & 8 9 & 10 12 13 16 Cement Pumped into 7-5/8 x 10-3/4 Annulus from ±2,100 to Surface NB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4 Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,399 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 4,037 4-1/2 Gravel Pack Liner 12.6 / L-80 / BTC BxP 3.930 ±X,XXX ±X,XXX 4-1/2 Liner 12.6 / L-80 / BTC BxP 3.930 2,813 2,857 4-1/2 Screen Liner110 JFE Bear EnerG Screen 3.849 2,857 3,382 4 Liner 9.5 / L-80 / IBT 3.548 3,846 8,348 TUBING DETAIL 4-1/2 Tubing 12.6 / L-80 / BTC R3 3.958 Surface 2,772 JEWELRY DETAIL No Depth Item 1 ±X,XXX Sensor, Discharge Adapter: 2 ±X,XXX Pump #2: 3 ±X,XXX Pump #1: 4 ±X,XXX Intake Sub Assy: 5 ±X,XXX Upper Tandem Seal: 6 ±X,XXX Lower Tandem Seal: 7 ±X,XXX Motor #2: 8 ±X,XXX Motor #1: 9 ±X,XXX Sensor: 10 ±X,XXX Sensor Gauge & Centralizer: Btm @ ±X,XXX 11 ±X,XXX 7-5/8 Gravel Pack Packer 12 ±X,XXX 4-1/2 Screens, (±XXX total length) 13 ±X,XXX 7-5/8 Sump Packer Tubing Tail @ ±X,XXX 14 2,813 5.00" TriPoint Polished Bore Receptacle LTC Pin 15 2,817 7 5/8" x 4-1/2", 24-29.7# Hydratrieve LTC BxP 40K Shear To Release 16 2,843 XN Nipple: 3.813"/3.725" No-Go BTC BxP 17 3,381 Bullnose: Bakerlok Btm @ 3,382 18 3,858 Retrievable Packer 19 3,891 3-1/2 XN Profile -2.750 No-Go Min ID 20 3,899 Overshot Btm @ 3,903 21 3,914 NB Lateral ZXP Liner Top Packer 22 3,923 NB Lateral 7-5/8 x 5-1/2 HMC Liner Hanger 23 4,724 HMCV Cementing Valve 24 4,748 NB Lateral Baker Payzone ECP Packer 25 8,348 NB Lateral 4-1/2 Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42 Hole 10-3/4" Cmt w/ 430 sx AS Lite, 258 sx Class G in 13-1/2 Hole 7-5/8 Cmt w/ 286 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 440 MD Hole Angle Passes 50+ deg @ 4,070 MD 45 deg @ Max Deviation in Tubing TREE & WELLHEAD Tree 4-1/165M FMC Wellhead 11 x 4-1/2 5M Gen 6 w/ 4.5 TCII T&B TubingHanger CIW H BPV Profile Excluder Screen (4,857-8,303) _____________________________________________________________________________________ Revised By: TDF 8/5/2025 PROPOSED Milne Point Unit Well: MPU J-25 Last Completed: 4/21/2025 PTD: 204-073 GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14 8/28/2004 Reservoir Abandonment 7/1/2020 Install Lower Comp and ESP by ASR 4/21/2025 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status Upper Prince Creek ±2,157 ±2,223 ±2,140 ±2,205 ±66 12 4-1/5 Future Future ±2,309 ±2,339 ±2,290 ±2,318 ±30 12 4-1/5 Future Future ±2,366 ±2,402 ±2,345 ±2,380 ±36 12 4-1/5 Future Future ±2,498 ±2,513 ±2,474 ±2,488 ±15 12 4-1/5 Future Future ±2,526 ±2,570 ±2,500 ±2,542 ±44 12 4-1/5 Future Future ±2,580 ±2,626 ±2,552 ±2,595 ±46 12 4-1/5 Future Future ±2,664 ±2,717[ ±2,633 ±2,682 ±53 12 4-1/5 Future Future ±2,734 ±2,752 ±2,698 ±2,715 ±18 12 4-1/5 Future Future Prince Creek 2,840 3,300 2,793 3,174 460 6 4.5 12/25/2024 Open Perf Guns 4.5 TCP 6 spf 60 Deg HSD Milne Point ASR Rig 1 BOPE 2025 Updated 7/31/2025 11 BOPE 4.48' 4.54' 2.00' INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR 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 HCRManualManualManual Stripping Head Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025022 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 14B 50133205390200 222057 4/10/2025 AK E-LINE CBL BRU 241-23 50283201910000 223061 4/7/2025 AK E-LINE Perf BRU 241-26 50283201970000 224068 4/12/2025 AK E-LINE CIBP BRU 244-27 50283201850000 222038 4/8/2025 AK E-LINE Perf MPU B-21 50029215350000 186023 4/7/2025 AK E-LINE LDL MPU C-24A 50029230200100 209134 4/6/2025 AK E-LINE CBL MPU J-25 50029232070000 204073 4/5/2025 AK E-LINE JetCut NCIU A-21 50883201990000 224086 4/4/2025 AK E-LINE Perf NCIU A-18 50883201890000 223033 4/5/2025 AK E-LINE Perf PBU Z-235 50029237600000 223055 4/1/2025 READ InjectiojnProfile HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL HVB 18 50231201210000 225001 4/4/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40328 T40329 T40330 T40331 T40332 T40333 T40334 T40335 T40336 T40337 T40338 T40339 MPU J-25 50029232070000 204073 4/5/2025 AK E-LINE JetCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:42:09 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/14/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: MPU J-25 PTD: 204073 API: 50-029-23207-00-00 FINAL LWD FORMATION EVALUATION LIS FILE + LISTING (04/28/2004) x ROP, GR, EWR-4 SFTP Transfer – Folder Contents: Please include current contact information if different from above. 204-073 T15345 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.14 15:44:37 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Completion w/Screens 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10. Field: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,348 NA Casing Collapse Conductor NA Surface 2,470psi Production 4,790psi Liner 6,590psi 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:WSW GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Todd Sidoti STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025515, ADL0025517, ADL0025906 204-073 MILNE PT UNIT J-25 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23207-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,872 3,887 3,621 1,347 SCHRADER BLUFF OIL Tertiary Undef WTRSP (525130) PRESENT WELL CONDITION SUMMARY 112' 112' 9.3 / L-80 / EUE 8rd TVD Burst 3,903 MD NA 7,910psi 4,005' 5,210psi 6,890psi 2,377' 3,726' 3,872' 2,399' 4,037' See Schematic 78' 20" 10-3/4" 7-5/8" 2,365' 4"4,445' See Schematic 907-777-8443 todd.sidoti@hilcorp.com Operations Manager March 15, 2025 3-1/2" Perforation Depth MD (ft): Tertiary Undef WTRSP, statewide rules Retrievable packer, ZXP Liner top packer and NA 3,858' MD / 3,601' TVD, 3,914' MD / 3,640' TVD, and NA 3,887 8,348' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:47 pm, Mar 13, 2025 325-141 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.03.05 12:58:35 - 09'00' Taylor Wellman (2143) * BOPE test to 2000 psi. Tertiary Undef WTRSP 10-404 A.Dewhurst 19MAR25MGR14MAR2025 Perforate New Pool *&: 03/20/25Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.20 08:01:15 -08'00' RBDMS JSB 032125 RWO Well: MPU J-25 Date: 19 Feb 2025 Well Name:MPU J-25 API Number:50-029-23207-00-00 Current Status:Res P&A Pad:J-Pad Estimated Start Date:March 15, 2025 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:204-073 First Call Engineer:Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1747 psi @ 4000’ TVD Reservoir Abandoned |8.4 PPGE MPSP:1347 psi Gas Column Gradient (0.1 psi/ft) 70° Inclination:4235’ MD Max Dogleg:15.3°/100ft @ 4224’ MD Brief Well Summary: The Milne Point J-25 is a reservoir abandoned producer with a single lateral in the NB sand. The lateral was abandoned in 2020 to facilitate I-pad redevelopment. Notes Regarding Wellbore Condition x MIT-IA passed to 3100 psi on rig on 10/17/2019. x The Schrader Bluff reservoir is abandoned, slickline tagged top of cement at 3887’. x Post reservoir abandonment MIT-T Passed to 1500 psi on 7/13/2020. Objective: Abandon lower completion, perforate Ugnu M sands, run new lower screen completion, run ESP and convert well to water production. Eline 1. MIRU EL and pressure test PCE to 250 psi low / 1500 psi high. 2. RIH with jet cutter. Cut tubing above packer at 3850’. 3. POOH and RDMO eline. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 2. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 3. Circulate at least one wellbore volume with 8.7 ppg brine down tubing, taking returns up casing to 500 bbl returns tank. 4. RD Little Red Services and reverse out skid. 5. RD well house and flowlines. Clear and level area around well. 6. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 7. NU BOPE house. Spot mud boat. RWO Procedure: RWO Well: MPU J-25 Date: 19 Feb 2025 Pull Tubing 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with KWF prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with KWF as needed. Pull BPV. Lubricate if pressure is expected. 5. MU landing joint or spear and PU on the tubing hanger. 6. Recover the tubing hanger. 7. POOH and lay down the 3-1/2” tubing. Wash and inspect all joints. a. PU weight was 28k / SO weight was 28k b. Plan to recover 88 cannon clamps Perforate & Clean Out 1. MU and RIH with 460’ of 6 SPF HSD perforating guns on 3-1/2” WS. 2. RIH and perforate interval from 2840-3300’. 3. Maintain hole fill during perforating operations as we will be establishing communication with the reservoir. 4. POOH and confirm well is dead. Bullhead KWF as needed. 5. MU 7-5/8” RCJB cleanout assembly and perform clean out to top of tubing stub at 3850' MD. 6. POOH. Run Lower Screen Completion 1. Pick up and RIH with completion: a. 12 joints of 4-1/2” 110 micron Ener-Armor screens with solid bullplug on bottom. b. 7” x 4.5” mechanical set packer with a set depth of 2810’ 2. Set packer per vendor recommendations. 3. Release from packer and POOH. Run New ESP 1. MU Spooler to run cable and capillary tubing. 2. PU new ESP with single cap string and RIH on 4-1/2” tubing, making electrical checks on the cable and pressure tests on the cap string every 2,000 feet a. Set base of ESP assembly at ~2790’. b. 1 joint of 4-1/2” tubing perforate interval from 2840-3300’ RWO Well: MPU J-25 Date: 19 Feb 2025 c. 4-1/2” XN (3.750” No-Go) d. ~2700’ of 4-1/2” tubing 3. Land tubing hanger. RILDS. Lay down landing joint. Note PU and SO weights on tally. 4. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. ASR BOPE Schematic _____________________________________________________________________________________ Revised By: DH 07/1/2021 SCHEMATIC Milne Point Unit Well: MPU J-25 Last Completed: 10/16/2019 PTD: 204-073 Excluder Screen (4,857’-8,303’) TD =8,348’(MD) / TD =3,872’(TVD) 20” 7-5/8” 6 10-3/4” 7 8 PBTD =3,387’(MD)/ TD = 3,621’(TVD) Orig. KB Elev.: 70.14’/ Orig. GL Elev.: 36.1’ RKB – Hanger: 30.15’ (Doyon 14) 9 2 3 5 4 1 11 1 10 Top of cement tagged at 3,887’ (slm) on 7/13/2020 “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,399’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 4,037’ 4” Liner 9.5 / L-80 / IBT 3.548 3,903’ 8,348’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 3,903’ JEWELRY DETAIL No Depth Item 1 31’ 4-1/2” Blast Rings below tubing hanger (12”) 2 3,838’ 3-1/2” XD Sliding Sleeve ***Jet pump OOH, Sleeve closed*** 3 3,842’ 3-1/2” Suction Gauge 4 3,858’ Retrievable Packer 5 3,891’ 3-1/2” XN Profile -2.750” No-Go Min ID 6 3,899’ Overshot –Btm @ 3,903’ 7 3,903’ NB Lateral Tie Back Sleeve 8 3,914’ NB Lateral ZXP Liner Top Packer 9 3,923’ NB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 10 4,724’ HMCV Cementing Valve 11 4,748’ NB Lateral Baker Payzone ECP Packer 12 8,348’ NB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 430 sx AS Lite, 258 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 286 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 440’ MD Hole Angle Passes 50+ deg @ 4,070’ MD 45 deg @ Max Deviation in Tubing TREE & WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4-1/2” 5M Gen 6 w/ 4.5” TCII T&B TubingHanger CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 Install Jet Pump by ASR#1 – 10/16/2019 _____________________________________________________________________________________ Revised By: TCS 2/6/2025 PROPOSED SCHEMATIC Milne Point Unit Well:MPU J-25 Last Completed: 10/16/2019 PTD: 204-073 Excluder Screen (4,857’-8,303’) Excl (4,8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4”Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,399’ 7-5/8"Production 29.7 / L-80 / BTC-MOD 6.875 Surface 4,037’ 4”Liner 9.5 / L-80 / IBT 3.548 3,903’8,348’ TUBING DETAIL 4-1/2”Tubing 12.6 / L-80 / EUE 3.958 Surface ‘ JEWELRY DETAIL No Depth Item 1 ’Discharge Head 2 ’Pump 3 ’Gas Separator 4 ‘Upper Tandem Seal 5 ‘Lower Tandem Seal 6 ‘Motor 7 ‘Permanent Packer 8 ‘Bullnose @ ‘ 9 3,858’Retrievable Packer 10 3,891’3-1/2” XN Profile -2.750” No-Go Min ID 11 3,899’Overshot –Btm @ 3,903’ 12 3,914’NB Lateral ZXP Liner Top Packer 13 3,923’NB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 14 4,724’HMCV Cementing Valve 15 4,748’NB Lateral Baker Payzone ECP Packer 16 8,348’NB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20"Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4"Cmt w/ 430 sx AS Lite, 258 sx Class “G” in 13-1/2” Hole 7-5/8”Cmt w/ 286 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 440’ MD Hole Angle Passes 50+ deg @ 4,070’ MD 45 deg @ Max Deviation in Tubing TREE & WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4-1/2” 5M Gen 6 w/ 4.5” TCII T&B TubingHanger CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 Install Jet Pump by ASR#1 – 10/16/2019 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs Suspended Well Inspection Review Report InspecNu: sus6D[210627060831 Date Inspected: 6/27/2021 - Inspector: Guy Cook Well Name: K4|LNE PTUNIT ]-25 ' Permit Number: 2040730 Suspension Approval: Sundry ' # 320'273 � Suspension Date: 7/13/2020 ' Location Verified? 180 |fVerified, How? Other (specify incomments) Df&hore9 El Type ofInspection: Initial Date AOG[ZNotified: 6/26/2021 Operator: Hi|corpAlaska, LLC Operator Rep: Josh McNeal Wellbore DiagramAvai|? W Photos Taken? E/1 Well Pressures (pyi): Tubing: 62 Fluid }nCellar? [] |A: 0 ' 8PV|nstaUed? El OA: 180 VR Plug(s) Installed' El wellhead Condition Wellhead binvery good condition. The well isprotected byameUhuusethat isingood shape and keeps itfrom the . elements. Condition ofCellar Cellar isdry with nostanding woter/Uuid. No obvious signs of hydrocarbons seen. - Surrounding Surface Condition Good dry gravel pad with no signs of hydrocarbons. Comments The power fluid has been disconnected from this well and is being used for MPU J-29. The flmm|inesare still intact and connected tothe well. The location was verified byapad map. Supemisor[nmments Photos(7)attached ' �\��7.� \^ Monday, August Z'2O21 Suspended Well Inspection — MPU J-25 AOGCC Inspect # susGDC210627060831 PTD 2040730 Photo by AOGCC Inspector G. Cook WELL NAME MPJ -25 OWNER Milne Point Unit OPERATOR HILCORP Alaska, LLC API NUMBER 50.029-23207-01-00 SUR. LOCATION NW 14. Sec. 08, T11N. R13E DRILLING PERMIT 204-073 2021-0627 Suspend MPU_J-25_photos.docx Page 1 of 4 2021-0627_ Suspend_MPU _J-25_photos. docx Page 2 of 4 I 2021-0627_ Suspend_MPU _J-25_photos. docx Page 4 of 4 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,348 feet N/A feet true vertical 3,872 feet N/A feet Effective Depth measured 3,887 (SLM)feet 3,858 & 3,914 feet true vertical 3,621 feet 3,600 & 3,640 feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 / EUE 8rd 3,903' 3,632' Retrievable & Packers and SSSV (type, measured and true vertical depth) ZXP LTP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8405 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,470psi 4,790psi 6,590psi7,910psi 20" 10-3/4' 7-5/8" 4" 2,377' Length 112' 2,377' 3,726' Burst N/A 5,210psi 6,890psi Surface Production N/A measured 4,445' N/A measured 3,726' 3,872' Casing Pressure Tubing Pressure Junk Liner Casing Conductor Size 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: Authorized Name: Chad Helgeson chelgeson@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-073 50-029-23207-00-00 Plugs ADL0025515 / ADL0025906 / ADL0025517 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Hilcorp Alaska LLC MILNE PT UNIT J-25 Gas-McfOil-Bbl measured true vertical Packer 8,348' 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.28 WINJ WAG Water-Bbl MD 112' 2,399' 4,037' TVD 112' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad Helgeson (1517) 2021.07.26 13:01:08 - 08'00' By Meredith Guhl at 2:05 pm, Jul 26, 2021 MGR30JUL2021 SFD 7/28/2021DSR-7/26/21 RBDMS HEW 7/26/2021 _____________________________________________________________________________________ Revised By: DH 07/1/2021 SCHEMATIC Milne Point Unit Well: MPU J-25 Last Completed: 10/16/2019 PTD: 204-073 Excluder Screen (4,857’-8,303’) TD =8,348’(MD) / TD =3,872’(TVD) 20” 7-5/8” 6 10-3/4” 7 8 PBTD =3,387’(MD)/ TD = 3,621’(TVD) Orig. KB Elev.: 70.14’/ Orig. GL Elev.: 36.1’ RKB – Hanger: 30.15’ (Doyon 14) 9 2 3 5 4 1 11 1 10 Top of cement tagged at 3,887’ (slm) on 7/13/2020 “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,399’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 4,037’ 4” Liner 9.5 / L-80 / IBT 3.548 3,903’ 8,348’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 3,903’ JEWELRY DETAIL No Depth Item 1 31’ 4-1/2” Blast Rings below tubing hanger (12”) 2 3,838’ 3-1/2” XD Sliding Sleeve ***Jet pump OOH, Sleeve closed*** 3 3,842’ 3-1/2” Suction Gauge 4 3,858’ Retrievable Packer 5 3,891’ 3-1/2” XN Profile -2.750” No-Go Min ID 6 3,899’ Overshot –Btm @ 3,903’ 7 3,903’ NB Lateral Tie Back Sleeve 8 3,914’ NB Lateral ZXP Liner Top Packer 9 3,923’ NB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 10 4,724’ HMCV Cementing Valve 11 4,748’ NB Lateral Baker Payzone ECP Packer 12 8,348’ NB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 430 sx AS Lite, 258 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 286 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 440’ MD Hole Angle Passes 50+ deg @ 4,070’ MD 45 deg @ Max Deviation in Tubing TREE & WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4-1/2” 5M Gen 6 w/ 4.5” TCII T&B TubingHanger CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 Install Jet Pump by ASR#1 – 10/16/2019 24 23 1 4 10 3 8 2 11 22 21 20 19 18 17 16 15 7 27 5 13 9 12 6 25 26 28 MILNE P OI N T J P A D Sec. 28 ADL25906 U013N010E MILNE POINT UNIT F B CL S EJ I KH A MINE CFP D G M MINE N S&K MOOSE PAD TEXACO MILNE POINT UNIT MPU J PAD LOCATION MAP Date: December 2020 Map Author: HAK - MRA Map 12 of 23 Map Center Coordinates: LAT: 70.451015 LON: -149.577931 NAD 1983 Decimal Degrees Map Imagery Date: 8/2020 (QSI) 1 inch = 125 feet 1500 FeetMap Scale 1: Well J-25 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL:36.1 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 NA (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 112' 10-3/4" L-80 2,377' 7-5/8" L-80 3,726' 4-1/2" L-80 3,872' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Gas-Oil Ratio: Flow Tubing Choke Size:Water-Bbl: PRODUCTION TEST Date of Test: Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 29.7 8,348' 32' 3,632' 92 45.5 112' 32' 4,037' CASING WT. PER FT.GRADE 12.7 550552 547266 TOP SETTING DEPTH MD 34' 3,903' 9-7/8" 34' 13-1/2" 260sx Arctic Set (Approx) 34' CEMENTING RECORD 60161201 SETTING DEPTH TVD 6017735 N/A TOP suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ADL0025515 / ADL0025906 / ADL00255173,887 (SLM) / 3,621 8,348 / 3,872551903 6015138 3,735' NSL, 4,756' WEL, SEC. 28 T13N, R10E, UM 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7/13/2020 2,741' NSL, 3,413' WEL, SEC. 28 T13N, R10E, UM 89' NSL, 2,746' WEL, SEC. 20 T13N, R10E, UM 6/27/2004 50-029-23207-00-00 7/6/2004 MILNE PT UNIT J-25 MILNE POINT / SCHRADER BLUFF OIL 70.17 BOTTOM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 204-073 / 320-273 DEPTH SET (MD) 3,858 / 3,600 PACKER SET (MD/TVD) 286sx Class 'G' 3,914 / 3,640 3,9033-1/2" SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 137sx Class 'G'6-3/4" TUBING RECORD NA ±1,800' NA NA 34' 2,399' 42" HOLE SIZE AMOUNT PULLED 430sx Arctic Set Lite, 258sx 'G' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Jody Colombie at 9:01 am, Jul 23, 2020 Suspension Date 7/13/2020 HEW RBDMS HEW 7/24/2020 xGDLB 07/24/2020 SFD 8/4/2020 DLB DSR-7/24/2020MGR16OCT2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface ±1,800'±1,790' Top of Productive Interval 3,896' 3,627' 3,544' 3,368' TMA 3,850' 3,595' TIMB1 3,867' 3,607' TIMB2 3,936' 3,655' TMC 4,120' 3,780' TNA 4,218' 3,828' TNB 4,260' 3,842' TNC 4,314' 3,853' 4,350' 3,858' 4,426' 3,866' TOA 4,485' 3,973' TSBC 4,534' 3,877' TOB 4,590' 3,880' BOB 4,637' 3,882' Schrader Schrader 31. List of Attachments: Wellbore schematic & weekly operations summarries. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Chad Helgeson Contact Name: David Haakinson Operations Manager Contact Email:dhaakinson@hilcorp.com Authorized Contact Phone:777-8343 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TNF Formation at total depth: TUZC TNE If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Chad A Helgeson 2020.07.23 08:49:48 -08'00' 3,873'DLB _____________________________________________________________________________________ Revised By: TDT 7/21/2020 SCHEMATIC Milne Point Unit Well: MPU J-25 Last Completed: 10/16/2019 PTD: 204-073 12Med Excluder Screen TD =8,348’(MD) / TD =3,872’(TVD) 20” 7-5/8” 6 10-3/4” 7 8 PBTD =8,348’ (MD) / TD = 3,872’(TVD) TOC at 3,887’ SLM “NB” Lateral Orig. KB Elev.: 70.14’/ Orig. GL Elev.: 36.1’ RKB – Hanger: 30.15’ (Doyon 14) 9 2 3 5Min ID = 3.725” ID Min ID = 3.548” ID 4 1 11 1 10 NB Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,399’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 4,037’ 4” Liner 9.5 / L-80 / IBT 3.548 3,903’ 8,348’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 3,903’ JEWELRY DETAIL No Depth Item 1 31’ 4-1/2” Blast Rings below tubing hanger (12”) 2 3,838’ 3-1/2” XD Sliding Sleeve 3 3,842’ 3-1/2” Suction Gauge 4 3,858’ Retrievable Packer 5 3,891’ 3-1/2” XN Profile -2.750” No-Go Min ID 6 3,899’ Overshot –Btm @ 3,903’ 7 3,903’ NB Lateral Tie Back Sleeve 8 3,914’ NB Lateral ZXP Liner Top Packer 9 3,923’ NB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 10 4,724’ HMCV Cementing Valve 11 4,748’ NB Lateral Baker Payzone ECP Packer 12 8,348’ NB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 430 sx AS Lite, 258 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 286 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 440’ MD Hole Angle Passes 50+ deg @ 4,070’ MD 45 deg @ Max Deviation in Tubing TREE & WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4-1/2” 5M Gen 6 w/ 4.5” TCII T&B TubingHanger CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 Install Jet Pump by ASR#1 – 10/16/2019 Abandon Lateral and Suspend CTU – 7/13/2020 Well Name Rig API Number Well Permit Number Start Date End Date MP J-25 SL / CTU 50-029-23207-00-00 204-073 7/1/2020 7/13/2020 7/3/2020 - Friday Well Shut in. MU cementing BHA. PT to 300/4,000 psi. RIH with 2.25" OD BDJSN. Set down at 3,910' ctmd (liner top packer). Unable to pass. With nozzle at 3,905' ctmd, bullhead 54 bbls 15.8 ppg "G" cement into liner. Hesitate squeeze with remaining 14 bbls cement. Unable to obtain squeeze. Over displace cement and call out for more cement. Pump 2nd squeeze with 5 bbls neat 15.8 ppg "G" cement, 15 bbls with fluid loss fibers, and 20 bbls neat 15.8. Build squeeze pressure up to 900psi but still having losses. Hesitate for 1 hour. Contaminate and cleanout to 3,840' ctmd getting 1:1 returns. Chase returns out and freeze protect to 2,500' with diesel. RDMO. 7/1/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MIRU SLB CTU #6 with 2" CT. MU FCO BHA with 2.5" DJN. PT to 300/ 4,000 psi. RIH and dry tag at 5,847' ctmd. (IBP set at 5,828' ctmd). Jet on top of IBP and POOH jetting with no returns. MU and RIH with 1-3/8" hydraulic JDC overshot. Latch and pull IBP from 5,837' ctmd. Let IBP bag relax, RIH past latch depth, then POOH. Recovered IBP with no rubber ring elements attached. L/D tools. Secure well. SDFN. 7/2/2020 - Thursday No operations to report. No operations to report. No operations to report. 7/4/2020 - Saturday No operations to report. 7/7/2020 - Tuesday 7/5/2020 - Sunday No operations to report. 7/6/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP J-25 SL / CTU 50-029-23207-00-00 204-073 7/1/2020 7/13/2020 7/10/2020 - Friday Pre state MIT-T (Pressure test equipment 259/2,001 psi) Pumped 1.3 bbls Criesel to achieve test pressure. MIT-T pass @ 1,584. 1st 15 lost 103 psi, 2nd 15 min lost 25 psi. Bled back ~ 1 bbl. 7/8/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/9/2020 - Thursday No operations to report. No operations to report. No operations to report. 7/11/2020 - Saturday WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. DRIFT AND TAG WITH 2.65" CENT AND 1.75"" SAMPLE BAILER AND TAG CEMENT AT 3,887' SLM (state witness, sample of cement). RD Slickline and rig up little Red Services. (Pressure test equipment 250/2500 psi) Pumped 1 bbl diesel to test. TP lost 139 psi 1st 15 mn & 28 psi 2nd 15 min. Bled back~1 bbl to start pressure. FWHPs=75/vac/104. AOGCC MIT-T pressured up to 1,780, TP lost a total of 167psi over 30min, PASSED. Test was witnessed by Matt Harrera of AOGCC. 7/14/2020 - Tuesday 7/12/2020 - Sunday No operations to report. 7/13/2020 - Monday MEMORANDUM TO: Jim Regg P.I. Supervisor ` FROM: Matt Herrera Petroleum Inspector Section: 28 Township: Drilling Rig: Hal S/L #214 Rig Elevation: Operator Rep: Josh McNeal Casing/Tubing Data: Conductor: 20" - 0. D. Shoe@ Surface: 10 3/4" - 0. D. Shoe@ Intermediate: Feet 0. D. Shoe@ Production: 7 5/8" - 0. D. Shoe@ Liner: 4" - 0. D. Shoe@ Tubing: 31/2" " 0. D, Tail@ Plugging Data: Test Data: MIT -T State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 13, 2020 SUBJECT: Well Bore Plug & Abandonment MPU J-25 Hilcorp PTD # 2040730; Sundry 320-273 13N Range: 10E 36 ft Total Depth: 8348 ft MD Suspend: 112 Feet 2399 Feet Csg Cut@ Feet 4037 Feet 8348 - Feet 3903 Feet Meridian: Umiat. Lease No.: ADL0025906 P&A: X Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing - Retainer 5827 ft MD _ 3887 ftMD 15.8 ppg Wireline tag 104 _ 104. Initial 15 min :in min 45 min PAQ"14 Tubing 1780 1641 1613 - IA 0 0 0 P OA 104 104 _ 104. Remarks: J-25 single lateral producer in the NB sands reservoir. Newly proposed MPU I Pad development requires NB sand lateral of this well to be plugged and abandoned. I witnessed successful plug tag and pressure test. 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ƵŶƚŝůĐůĞĂŶĞĚŽƵƚƚŽƚŚĞ/WĂƚϱ͕ϴϮϴ͛dD͘ Ă͘ >ĂƐƚ&KŽŶϭͬϭϭͬϬϳĐůĞĂŶĞĚŽƵƚĨƌŽŵϰ͕ϲϭϲ͛dDƚŽϴ͕ϯϬϰ͛dDǁŝƚŚs'ĨůƵŝĚƌĂƚĞŽĨ ϭ͘ϱWDĂŶĚEϮƌĂƚĞŽĨϱϬϬ^&͘ ď͘ ĚƌŝĨƚǁĂƐƉĞƌĨŽƌŵĞĚƚŽϲ͕ϬϬϬ͛dDŽŶϮͬϭϳͬϬϴƉƌŝŽƌƚŽƐĞƚƚŝŶŐƚŚĞ/W͘ ϲ͘ Z/,ǁͬƉƵůůŝŶŐƚŽŽůƚŽ/WƐĞƚĂƚϱ͕ϴϮϴ͛dD͘ Ă͘ ϭ͘ϯϳϱ͟:&ŝƐŚŝŶŐEĞĐŬůŽŽŬŝŶŐƵƉ͘WƵůůZĞůĞĂƐĞсϱ͕ϱϬϬη͕WƵƐŚŽǁŶƚŽƋƵĂůŝǌĞсϭ͕ϴϰϬη ϳ͘ ŶŐĂŐĞĂŶĚĂƚƚĞŵƉƚƚŽĞƋƵĂůŝǌĞĂŶĚƉƵůůϮ͘ϱ͟K/W Ă͘ ZĞůĞĂƐĞ/WĂŶĚĂůůŽǁĞůĂƐƚŽŵĞƌƐƚŽƌĞůĂǆĨŽƌϭϱͲϯϬŵŝŶƵƚĞƐƉƌŝŽƌƚŽƉƵůůŝŶŐ͘ ď͘ /ĨƵŶĂďůĞƚŽƉƵůůƚŚƌŽƵŐŚϮ͘ϳϱ͟/yEƌĞƐƚƌŝĐƚŝŽŶĂƚϯϴϵϭ͛D͕ĂƚƚĞŵƉƚƚŽƉƵƐŚ/WƉĂƐƚ ƚĂƌŐĞƚĐůĞĂŶŽƵƚĚĞƉƚŚŽĨϳ͕ϲϱϬ͛D͘WKK,͘ ϴ͘ tŝƚŚ/WƉƵůůĞĚ͕Z/,ǁŝƚŚĐůĞĂŶŽƵƚ,ĂŶĚĐŽŶƚŝŶƵĞƚŽĐůĞĂŶŽƵƚƚŚĞϰ͟>ŝŶĞƌƚŽdǁŝƚŚEŝƚƌŽŐĞŶ͕<> ĂŶĚŐĞůƐǁĞĞƉƐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞϯͲϭͬϮ͟ƚƵďŝŶŐ͘ Ă͘ DŝŶŝŵƵŵƚĂƌŐĞƚĐůĞĂŶŽƵƚĚĞƉƚŚĨŽƌWΘŝƐĂƚůĞĂƐƚϳ͕ϲϱϬ͛D ϵ͘ DhĐĞŵĞŶƚŝŶŐŶŽǌǌůĞĂŶĚZ/,ƚŽĨŝŶĂůĐůĞĂŶŽƵƚĚĞƉƚŚ ϭϬ͘ ĞŐŝŶƚŽŵŝǆϭϱ͘ϴƉƉŐĐůĂƐƐ'ĐĞŵĞŶƚ͘KŶĐĞďůĞŶĚŝƐƵƉ͕ƉƵŵƉцϲϴďďůƐŽĨůĂƐƐ'ĐĞŵĞŶƚĚŽǁŶƚŚĞ ĐŽŝůƚƵďŝŶŐ͘ ΎΎΎEŽƚĞ͗ ĞŵĞŶƚ ǀŽůƵŵĞƐ ďĂƐĞĚ ŽŶ ůŝŶĞƌ ǀŽůƵŵĞ ĞƐƚŝŵĂƚĞƐ ŽŶůǇ͘ ĐƚƵĂů ǀŽůƵŵĞƐ ƉƵŵƉĞĚ ŵĂǇ ǀĂƌǇ͘ ŐŐƌĞŐĂƚĞŵĂǇďĞĂĚĚĞĚƚŽĐĞŵĞŶƚďĂƐĞĚŽŶŝŶũĞĐƚŝǀŝƚǇƌĞƐƉŽŶƐĞ͘ΎΎΎ Ă͘ hƐĞĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌƐĂƐŶĞĞĚĞĚĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚ͘ ď͘ ƵůůŚĞĂĚĨůƵŝĚƐŝŶƚŽEƐĂŶĚƐĂŚĞĂĚŽĨĐĞŵĞŶƚ͘ ϭϭ͘ >ĂǇŝŶцϱϴďďůƐŽĨĐĞŵĞŶƚŝŶĂƚϭ͗ϭƵƉĨƌŽŵĐůĞĂŶŽƵƚĚĞƉƚŚƚŽ͕ϯϴϱϬ͛͘ Ă͘ ϰ͟ůŝŶĞƌǀŽůƵŵĞĨƌŽŵdĂƚϴ͕ϯϰϴ͛DƚŽϰ͕ϴϱϲ͛Dсϯ͕ϰϵϮΎ͘ϬϭϮϱďƉĨсϰϮ͘ϳďďůƐ ď͘ ϰͲϭͬϮ͟ůŝŶĞƌǀŽůƵŵĞĨƌŽŵϰ͕ϴϱϲ͛DƚŽϯ͕ϴϱϬ͛Dсϭ͕ϬϬϲΎ͘ϬϭϱϮďƉĨсϭϱ͘ϯďďůƐ ϭϮ͘ ƚƚĞŵƉƚƚŽƐƋƵĞĞǌĞĂǁĂǇƌĞŵĂŝŶŝŶŐцϭϬďďůƐŽĨϭϱ͘ϴƉƉŐĐůĂƐƐ'ŝŶƚŽEͲƐĂŶĚƐ͘ŽŶŽƚĞǆĐĞĞĚϭ͕ϬϬϬƉƐŝ ƚƵďŝŶŐ;ďĂĐŬƐŝĚĞͿƉƌĞƐƐƵƌĞ͘ Ă͘ ^ƋƵĞĞǌŝŶŐĐĞŵĞŶƚƚŚƌŽƵŐŚƵŶĐĞŵĞŶƚĞĚƉŽƌƚŝŽŶŽĨE>ŝŶĞƌ͘ ϭϯ͘ WhƚŽƐĂĨĞƚǇĚĞƉƚŚĂƚцϯ͕ϳϬϬ͛DĂŶĚƐǁĂƉƚŽEͲsŝƐĨŽƌĐŽŶƚĂŵŝŶĂƚŝŽŶ͘ ϭϰ͘ Z/,ƚŽĐůĞĂŶŽƵƚĨƌŽŵцϯ͕ϴϱϬ͛DƚŽƐƵƌĨĂĐĞ͘ ϭϱ͘ ŝƌĐƵůĂƚĞĐŽŝůƚƵďŝŶŐĐůĞĂŶĂƐŶĞĞĚĞĚ͘ ϭϲ͘ &ƌĞĞǌĞWƌŽƚĞĐƚƚƵďŝŶŐƵƉĨƌŽŵϮ͕ϱϬϬ͛DƚŽƐƵƌĨĂĐĞ͘ Ă͘ ϯͲϭͬϮ͟ƚƵďŝŶŐǀŽůƵŵĞсϮ͕ϱϬϬΎ͘ϬϬϳϳсϮϮďďŬƐ ϭϳ͘ >ŶŽǌǌůĞ,͘ ϭϴ͘ ZdƵŶŝƚ͘ ^ůŝĐŬůŝŶĞŶĚ,ŽƚKŝůWůƵŐsĞƌŝĨŝĐĂƚŝŽŶ ϭϵ͘ EŽƚŝĨǇK'ĂƚůĞĂƐƚϮϰŚƌƐƉƌŝŽƌƚŽƉůƵŐƉƌĞƐƐƵƌĞƚĞƐƚŝŶŐĂŶĚĚĞƉƚŚǀĞƌŝĨŝĐĂƚŝŽŶ͘ ϮϬ͘ D/Zh^>ƵŶŝƚĂŶĚ,ŽƚKŝů Ϯϭ͘ WƌĞƐƐƵƌĞƚĞƐƚƚŽϯϬϬƉƐŝůŽǁĂŶĚϭϱϬϬƉƐŝŚŝŐŚ ϮϮ͘ Z/,ǁŝƚŚĚƌŝĨƚĂŶĚƚĂŐĐĞŵĞŶƚƉůƵŐ͕ĞƐƚŝŵĂƚĞĚĂƚϯϴϱϬ͛D Ϯϯ͘ D/dͲdƚƵďŝŶŐƚŽϭϱϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ Ϯϰ͘ ZDK 1RWLI\ $2*&& LQVSHFWRU 0,7 ,$ WR SVL PLQXWHV ĞŐŝŶƚŽĐůĞĂŶŽƵƚƚŚĞϰ͟>ŝŶĞƌǁŝƚŚEŝƚƌŽŐĞŶ͕<ůĂŶĚŐĞůƐǁĞĞƉƐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞϯͲϭͬϮ͟ƚƵďŝŶŐ)&2 SXOO ,%3 # 2+ YROXPH LV DSSUR[ EEOV tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗DWh:ͲϮϱ ĂƚĞ͗ϬϲͬϭϵͬϮϬϮϬ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϰ͘ EŝƚƌŽŐĞŶKƉĞƌĂƚŝŽŶƐWƌŽĐĞĚƵƌĞ ϱ͘ EŝƚƌŽŐĞŶΘ&ŽĂŵ&ůŽǁŝĂŐƌĂŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗/dϬϲͬϭϵͬϮϬϮϬ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϮϱ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϬͬϭϲͬϮϬϭϵ Wd͗ϮϬϰͲϬϳϯ ϭϮDĞĚǆĐůƵĚĞƌ^ĐƌĞĞŶ dс ϴ͕ϯϰϴ͛;DͿͬdсϯ͕ϴϳϮ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ Wdс ϴ͕ϯϰϴ͛;DͿ ͬdсϯ͕ϴϳϮ͛;dsͿ ³1%´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϳϬ͘ϭϰ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϲ͘ϭ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϬ͘ϭϱ͛;ŽǇŽŶϭϰͿ 0LQ,' ´,' 0LQ,' ´,' ,%3#¶ &70' ³1%´/DWHUDO ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ<ͲϱϱΘ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ Ϯ͕ϯϵϵ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϰ͕Ϭϯϳ͛ ϰ͟ >ŝŶĞƌ ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϱϰϴ ϯ͕ϵϬϯ͛ ϴ͕ϯϰϴ͛ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϵϵϮ͟ ^ƵƌĨĂĐĞ ϯ͕ϵϬϯ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϯϭ͛ ϰͲϭͬϮ͟ůĂƐƚZŝŶŐƐďĞůŽǁƚƵďŝŶŐŚĂŶŐĞƌ;ϭϮ͟Ϳ Ϯϯ͕ϴϯϴ͛ϯͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞ ΎΎΎ^ĞƚϵũĞƚƉƵŵƉŽŶϲͬϰͬϮϬΎΎΎ ϯ ϯ͕ϴϰϮ͛ ϯͲϭͬϮ͟^ƵĐƚŝŽŶ'ĂƵŐĞ ϰ ϯ͕ϴϱϴ͛ ZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ ϱ ϯ͕ϴϵϭ͛ ϯͲϭͬϮ͟yEWƌŽĨŝůĞͲϮ͘ϳϱϬ͟EŽͲ'ŽDŝŶ/ ϲ ϯ͕ϴϵϵ͛ KǀĞƌƐŚŽƚʹƚŵΛϯ͕ϵϬϯ͛ ϳ ϯ͕ϵϬϯ͛ E>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϴ ϯ͕ϵϭϰ͛ E>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϵ ϯ͕ϵϮϯ͛ E>ĂƚĞƌĂůϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ ϭϬ ϰ͕ϳϮϰ͛ ,DsĞŵĞŶƚŝŶŐsĂůǀĞ ϭϭ ϰ͕ϳϰϴ͛ E>ĂƚĞƌĂůĂŬĞƌWĂǇǌŽŶĞWWĂĐŬĞƌ ϭϮ ϴ͕ϯϰϴ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ŵƚǁͬϰϯϬƐǆ^>ŝƚĞ͕ϮϱϴƐǆůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟ ŵƚǁͬϮϴϲƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϰϰϬ͛D ,ŽůĞŶŐůĞWĂƐƐĞƐϱϬнĚĞŐΛϰ͕ϬϳϬ͛D ϰϱĚĞŐΛDĂǆĞǀŝĂƚŝŽŶŝŶdƵďŝŶŐ dZΘt>>, dƌĞĞ ϰͲϭͬϭϲ͟ʹϱD&D tĞůůŚĞĂĚ ϭϭ͟ǆϰͲϭͬϮ͟ϱD'ĞŶϲǁͬϰ͘ϱ͟d//dΘ dƵďŝŶŐ,ĂŶŐĞƌ/t͞,͟WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϬϳͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďǇŽǇŽŶϭϰʹϴͬϮϴͬϮϬϬϰ /ŶƐƚĂůů:ĞƚWƵŵƉďǇ^ZηϭʹϭϬͬϭϲͬϮϬϭϵ 1% /DWHUDO ,%3#¶ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗/dϬϲͬϭϵͬϮϬϮϬ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϮϱ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϬͬϭϲͬϮϬϭϵ Wd͗ϮϬϰͲϬϳϯ ϭϮDĞĚǆĐůƵĚĞƌ^ĐƌĞĞŶ dс ϴ͕ϯϰϴ͛;DͿͬdсϯ͕ϴϳϮ͛;dsͿ ϮϬ´ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ Wdс ϴ͕ϯϰϴ͛;DͿͬdсϯ͕ϴϳϮ͛;dsͿ 72&DW ¶0' ³1%´/DWHUDO KƌŝŐ͘<ůĞǀ͗͘ϳϬ͘ϭϰ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϲ͘ϭ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϬ͘ϭϱ͛;ŽǇŽŶϭϰͿ 0LQ,' ´,' 0LQ,' ´,' ³1%´/DWHUDO ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ<ͲϱϱΘ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ Ϯ͕ϯϵϵ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdͲDK ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϰ͕Ϭϯϳ͛ ϰ͟ >ŝŶĞƌ ϵ͘ϱͬ>ͲϴϬͬ/d ϯ͘ϱϰϴ ϯ͕ϵϬϯ͛ ϴ͕ϯϰϴ͛ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϵϵϮ͟ ^ƵƌĨĂĐĞ ϯ͕ϵϬϯ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϯϭ͛ ϰͲϭͬϮ͟ůĂƐƚZŝŶŐƐďĞůŽǁƚƵďŝŶŐŚĂŶŐĞƌ;ϭϮ͟Ϳ Ϯ ϯ͕ϴϯϴ͛ ϯͲϭͬϮ͟y^ůŝĚŝŶŐ^ůĞĞǀĞ ϯ ϯ͕ϴϰϮ͛ ϯͲϭͬϮ͟^ƵĐƚŝŽŶ'ĂƵŐĞ ϰ ϯ͕ϴϱϴ͛ ZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ ϱ ϯ͕ϴϵϭ͛ ϯͲϭͬϮ͟yEWƌŽĨŝůĞͲϮ͘ϳϱϬ͟EŽͲ'ŽDŝŶ/ ϲ ϯ͕ϴϵϵ͛ KǀĞƌƐŚŽƚʹƚŵΛϯ͕ϵϬϯ͛ ϳ ϯ͕ϵϬϯ͛ E>ĂƚĞƌĂůdŝĞĂĐŬ^ůĞĞǀĞ ϴ ϯ͕ϵϭϰ͛ E>ĂƚĞƌĂůyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϵ ϯ͕ϵϮϯ͛ E>ĂƚĞƌĂůϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ ϭϬ ϰ͕ϳϮϰ͛ ,DsĞŵĞŶƚŝŶŐsĂůǀĞ ϭϭ ϰ͕ϳϰϴ͛ E>ĂƚĞƌĂůĂŬĞƌWĂǇǌŽŶĞWWĂĐŬĞƌ ϭϮ ϴ͕ϯϰϴ͛ E>ĂƚĞƌĂůϰͲϭͬϮ͟ƚŵŽĨ'ƵŝĚĞ^ŚŽĞ KWE,K>ͬDEdd/> ϮϬΗ 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&RLO7XELQJ8QLW)OXLG)ORZ'LDJUDP&OHDQRXWZ1LWURJHQ )RDP8SGDWHG/(*(1')OXLGV3XPSHG )OXLGV5HWXUQHG9DOYH 2SHQ 9DOYH &ORVHG*DWH9DOYH %DOO9DOYH%XWWHUIO\9DOYH /R7RUT9DOYH&KHFN9DOYH 0DQXDO&KRNH3UHVVXUH*DXJHϱϬϬ></>>dE<ŚŽŬĞ DĂŶŝĨŽůĚWϰϬϬ> hWZ/',dWKƉĞŶsZ>/EK/>WhDWϰϬϬ>hWZ/',dKƉĞŶůŽƐĞĚKƉĞŶKƉĞŶKƉĞŶKƉĞŶKƉĞŶKƉĞŶKƉĞŶW^tŽƌ<>tͬ&KDZKZ&Z/d/KEZhZϱϬ>&ZWZKdddE<^tŽƌ<>tͬ&KDZKZ&Z/d/KEZhZdŽ&ůŽǁůŝŶĞE/dZK'EWhDWΘdE<WK/>hE/dt/d,ϭ͘ϱ͟ƚŽϮ͘Ϭ͟K/>ϰϬϬ>hWZ/',d^tdZtͬ&KDZdZ/W>y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS �vit�l'rr r;t,� NOV 01 2019 1. Operations Abandon Plug Perforations LJ Performed: Suspend ❑ Perforate ❑ Fracture StimulatLj Pull Tubing [VJ utdown Other Stimulat❑ Alter Casing ❑ 'CR a ro ram 9 ❑ Plug for Redrill ❑ :rforate New Pool ❑ Repair We❑ Re-enter Susp Well ❑ Other: JP RWO ❑Q 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 204-073 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23207-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025515 / ADL0025906 / ADL0025517 MI LNE PT UNIT J-25 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 8,348 feet Plugs measured N/A feet true vertical 3,872 feet Junk measured N/A feet 3,858, 3,914 & Effective Depth measured 8,348 feet Packer measured 4,748 feet 3,600, 3,640 & true vertical 3,872 feet true vertical 3.888 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 112' 112' N/A N/A Surface 2,365' 10-3/4" 2,399' 2,377' 5,210psi 2,470psi Production 4,005' 7-5/8" 4,037' 3,726' 6,890psi 4,790psi Liner 4,445' 4" 8,348' 3,872' 7,910psi 6,590psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3 / L-80 / EUE 8rd 3,903' 3,632' Retrievabl, ZXP Packers and SSSV (type, measured and true vertical depth) LTP @ ECP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 140 p Subsequent to operation: 189 18 736 1 2,496 1 223 14. Attachments (required per 20 MC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-364 Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinsonphilcorp.cor i ✓ � Authorized Signature:-' - Date: 10/31/2019 Contact Phone: 777-8343 Form 10-404 Revised 4/2017 RBDMS±" N0V 0 5 2019 Submit Original Only n llilcoru Alaska, LLC Orig. KB Elev.: 70.14'/Orig. GL Bev: 36.1' RKB—Hanger. 30.15' (Doyon 14) SCHEMATIC TD=8,348' (M])/TD=3,872'M) PBTD= 8,348' (fvD) /TD= 3,87Z0W) Milne Paint Unit Well: MPU J-25 Last Completed: 10/16/2019 PTD: 204-073 TREE & WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x4-1/2"51vlGen6w/4.5"TCIIT&B TubingHanger CIW "H" BPV Profile OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42" Hale 10-3/4" Cmt w/430 sx AS Lite 258 sx Class "G" in 13-1/2" Hole I -Wb I Cmt w/ 286 sx Class "G" in 9-7/8" Hole CASING DETAII Type Wt/ Grade/ Conn ID Tap Btm Conductor 92/H-40/Welded N/A Surface 112' Surface 45.5/K-5S&L-80/BTC 9.950 Surface 2,399' Production 29.7/L-80/BTC-MOD 6.875 Surface 4,037' Liner 9.5/L-80/IBT 3.548 3,903' 8,348' TUBING DETAIL Tubing 9.3/L-80/EUE Brd 2.992" Surface 3.903' WELL INCLINATION DETAIL KO @ 440' MD Hole Angle Passes50+deg @4,070'MD 45 deg @ Max Deviation in Tubing JEWELRY DETAIL Item 4-1/2" Blast Rings below tubing hanger (12") 3-1/2" XD Sliding Sleeve 3-1/2" Suction Gauge Retrievable Packer 3-1/2" XN Profile -2.750" No -Go Min ID Ove rshot —Btm @ 3,903' NB Lateral Tie Back Sleeve NB Lateral ZXP Liner Top Packer NB Lateral 7-5/8" x 5-1/2" HMC Liner Hanger HMCV Cementing Valve NB Lateral Baker Payzone ECP Packer NB Lateral 4-1/2" Btm of Guide Shoe GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14-8/28/2004 Install Jet Pump by ASR#1-10/16/2019 Revised By: TDF 10/31/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start DateEnd Date MP J-25 ASR #1 50-029-23207-00-00 204-073 10/10/2019 1 10/16/2019 10/9/2019- Wednesday No operations to report. 10/10/2019 - Thursday PJSM, MIRU LRS. PT surface lines 250/2,500 psi -good test. Pump 60 bbls source water down Tbg. Pump 138 bbls source water down IA. Monitored Tbg and IA on a vacuum. Pump 5 bbls 60/40 to freeze protect surface lines. Set BPV and RDMO LRS. Waiting on ASR to Mobilize from J-26. 10/11/2019 - Friday PJSM and crew change, Start unloading equipment from trailers. Spot in Mud Boat, Spot in and unload pits, Move Camps to location, Lay containment. Roads and pads assisted with crane and trucks, ND production tree, Spot well house and NU BOP Stack, Spot Rig Floor continue spot and R/U pits , pumps, conex's, and ancillary equipment. Raised Derrick and latched lock pins. Ran control lines for the BOP'S, fluid lines, choke /kill lines. Loaded pit w/ 30 bbls F/W for BOP test, Finish RU to BOPE Test. RU 6" flow line, Grease the mud cross and choke manifold. NU Spacer Spool;While functioning the Accumulator the PRV cut out. Call I -rig for Mechanic for assistance Replace component;Conduct shell test had Leak at Annular flange Bleed of and Torque up Flange Re -Test Good;Conduct BOPE test as per sundry 250psi Low/ 3,500psi High on all Equipment With 4.5"-3.5" Test mandrills No failures.Witness Waived by Matt Herrera;L/D BOP Test Equipment Blow lines and stack dry. Pick up T -Bar Pull Test Plug, Sting into the BPV and Bleed off tbg pressure and Pull BPV. Pick up and Make up 4.5" Landing Jnt and make up to hanger. BOLDS. Pull up on TBG hanger unseat @ 50K Continue to work String in increments from 50K up to 150K to pull seal ext free. Made about 8' of hole at report time. 10/12/2019 -Saturday Crew change PJSM, Continue to work Tbg String in increments from neutral weight 50K up to 150K to pull seal assebly free. Was able to Pull about 12' of the seal assembly free. Continued working tbg only making about 2" per hr. Discuss plan with town engineer and decided to pump 2 tbg volumes of hot water down hole across seal assembly. Cont working trying to work seal assembly free while waiting on LRS to arrive. Landed completion in slips RU to pump down tbg. MIRU LRS tested lines to 3000psi-good test. Closed the annular and Pumped 120bbls of 190 deg source water down tbg. Monitored well on vacuum RDMO LRS;Working TBG string from 20K -150K made about V right away but nothing more. Call for Cold lake water and work while waiting. Water arrive. pump 150 bbls down the csg while working the tbg string 50K -150K. Did not gain anything. Cont. to work tbg String every 30min keeping tension of 150K in-between . Pumping 10 BBLS/hr while waiting for Pollard E/L to arrive. Service clean and inspect all equipment. re Certek Glycol Heater for next Job. Hilcorp Alaska, LLC Weekly Operations Summary Well Name =ig API Number Well Permit Number Start Date End Date MP J-25 I ASR #1 50-029-23207-00-00 204-073 10/10/2019 10/16/2019 10/16/2019- Wednesday PJSM and crew change, Checked fluids and serviced rig. Dropped ball and rod, BO/LD Landing Jt and lined up to pump down tbg. Pumped 13 bbls and pressured up to 3,500psi and held for 5 mins to set packer per Baker Rep. Bled back to 2,600psi and charted for 30 mins-good test. Bled Tbg back to 2000psi. Lined up to IA. Pumped 54bbls and catch pressure, cont pumping 2 more bbls and pressured up to 3,100psi and held, charted for 30mins-good test. Bled off IA and tbg. Set the BPV, circulated stack with clean fluid. Blowdown circulating lines and discounted. Cleaned and organized rig floor. MO Pipe Handler and pipe racks. RD Rig floor, LD Mass and moved rig off Mudboat, start crane operations, Fly off work floor, Load work floor RD well but stairs. Load floor and well but onto trailer. load HCR lines on the Pit catwalk. ND BOPE/NU PT Tested 500psi. S ®�=1ps� r 10/17/2019 -Fhursday No operations to report. 10/18/2019 - Friday No operations to report. 10/19/2019-Saturday No operations to report. 10/20/2019-Sunday No operations to report. 10/21/2019 - Monday No operations to report. 10/22/2019-Tuesday No operations to report. AN '5--z5- James '=z7 James B From: Brooks, Phoebe L (CED) Sent: To: Thursday, October 17, 2019 2:34 PM (�� L7 f� Wade Hudgens - (C) Cc: Regg, James B (CED) Subject: RE: MPU J-25 MIT -IA Attachments: MIT MPU J-25 10-16-19 Revised.xlsx Wade, Prn Zc 4p? 30 Attached is a revised report for MIT MPU J-25 10-16-19 correcting the formatting, including additional notes, well name, and changing the interval to "0". Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 firstsaving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska w. From: Wade Hudgens - (C) <whudgens@hilcorp.com> Sent: Wednesday, October 16, 2019 9:13 PM To: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov>; Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Carl Linaman - (C) <clinaman@hilcorp.com>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Cody Rymut - (C) <crymut@hilcorp.com> Subject: MPU 1-25 MIT -IA Attached 10-426 Thanks, Wade Hudgens WSM Hilcorp Alaska whudgens@hilcoa.com Office 907-283-2505 Cell 903-331-6711 The information contained in this e-mail message is confidential information intended only for the use of the mcipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submi to: iim.regq(r➢alaska.gpv: AOGCC.Inspeptors®alaska qpm phoebe brook nalaska ppv OPERATOR: Hilcprp FIELD/UNIT/PAD: Milne PoinVJ-25/J-Pad DATE: 10/16/19 OPERATOR REP: Wade Hungers AOGCC REP: 60 Min. chns.wallaceitalaska. gov Well MPU J-25 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040730 Type Inj N Tubing 1 0 1 20002000 2000 Type Test P Packer TVD 3857 ' BBLPump 1.5 - IA 0 3100 3100- 3100 Interval 0 Test psi 3000 '1 BBL Return 1 1.5 OA 0 0 0 0 Result j P Notes: Pmtlucer.MIT-IA per sundry 319,354. Held Tubing pressure 02,000pal while testing WeII Pressures: Pretest Initial 45 Min, 30 Min. 45 Min. 60 Min. PTD Type lnl Tubing Type Test Packer VD BE P1 IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Tesf Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBLREumj I OA I Result Notes: Well Pressures', Pratest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTO Type Inj Tubing I i i i i i Type Test Packer TVD BBLPumpj I IA I Interval Test psi BBL Return OA Result Notes: Wall Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD Type Inj Tubing Type Test Packei BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Cotles W=water G=Gas a = Slurry 1= Industrial Wastewater N= Na Iqi TYPE TEST Codes P= Pressure Test 0 = other Ideaerlee in Notes) INTERVAL Codes 1=III Test 4=Four Year Cycle V = Requeed by Valiance O = Other (Describe In notes) Form 10426 (Revised 01/2017) NIT MPH J-25 trate-m Revised Result Cotles P=Paso F = Fail 1=lnnondurns, THE STATE °fi-I - -- GOVERNOR MIKE DUNLEAVY Chad Helgeson . Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Pool, MPU J-25 Permit to Drill Number: 204-073 Sundry Number: 319-364 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaslka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -4�� Daniel T. Seamount, Jr. Commissioner DATED this' day of August, 2019. RBDMSl�' AUG 13 2019 STATE OF ALASKA A I (G 0 7 201 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO G C �/J 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing .❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: JP RWO ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0 . Stratigraphic ❑ Service ❑ 204-073 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23207-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT J-25 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025515 / ADL0025906 1n1-VQZ 13 MILNE POINT / SCHRADER BLUFF OIL Y 11. g/8f19 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,348' 3,872' 8,348' 3,872' 1,325 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 112' 112' N/A N/A Surface 2,365' 10-3/4" 2,399' 2,377' 5,210psi 2,470psi Production 4,005' 7-5/8" 4,037' 3,726' 6,890psi 4,790psi Liner 4,445' 4" 8,348' 3,872' 7,91 Opal 6,590psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6 / L-80 / IBT 3,912' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP LTP & ECP Packer and N/A 3,914 MD / 3,640 TVD & 4,748 MD / 3,888 TVD and N/A 12. Attachments: Proposal Summary � Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 91 Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/31/2019 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaaklrlson hi Cor .Corn Contact Phone: 777-8343 Authorized Signature: Date: 8/7/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3�q-3�u Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3SnV /as'L ,BoV Post Initial Injection MIT Req'd? Yes ❑ No ❑ �gpMS A(iT 1 31019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10 — Z16 if ))) APPROVED BY I4 / Q Approved by:Z5�� COMMISSIONER I I� THE COMMISSION Date: ` l �0114`r, 8-1-M ORIGINAL Submit Form and Form 10-403 ised 4/2017 Approved application is valid for 12 months from the date of aAttachments in Duplicate pprov U Hiles Alaska. LU RWO — Tubing Changeout Well: MPU 1-25 PTD: 204-073 API: 50-029-23207-00 Well Name: MPU API Number: 50-029-23207-00 Current Status: S —Tubing Lea Rig: ASR #1 Estimated Start Date: A , 2019 Estimated Duration: 3 Days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 204-073 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: Maximum Expected BHP: Max. Anticipated Surface Pressure: Original RKB: Max Inc. (Within Work Interval): Max DLS: BPV Type: 1,473 psi @ 4,000' TVD 1,725 psi @ 4,000' TVD 1,325 psi 30.2' (Doyon 16) 46° @ 3,904' MD 5.9°/100 ft @ 2,766' MD 4" CIW "H" 6.76 PPGE I SBHP Survey 5/27/13 8.3 PPGE I Highest Recorded SBHP Gas Column Gradient (0.1 psi/ft) Brief Well Summary: Milne Point producer J-25 was drilled in August 2004, and completed in the NB sand. The well was completed with a 4-1/2" jet pump completion and has run trouble free to date. On 7/18/19, the well was shut in due to a significant power fluid rate increase. Subsequent well -work found a tubing leak between 2,925' SLM and 2,950' SLM. Due to the 15 year run life, loss of downhole gauges, and high cost of pulling/replacing tubing hes for jet pump replacements, a rig workover provides the highest return on investment. Notes Recardine the Well & Design: • A passing combo MIT (IA and packer envelope) of the 7-5/8" casing to 2800 psig was completed on 8/3/19. • An updated SBHP will be obtained by 8/15/19 • 3-1/2" tubing will be installed versus 4-1/2" tubing due to the single lateral design and total flow -rate (power fluid plus formation fluid of approximately 1700 bbl/d) • Offset Injector Support: SI 7 days prior to RWO o J-15: Online, injecting 800 BWPD 0 1-17: Online, injecting 1000 BWPD 0 1-18: Shut-in o J-19: Online, injecting 90013WPD RWO Objective: 1. Pull Tubing String 2. Run anew 3-1/2" tubing completion with jet pump jewelry 3. Obtain passing MIT -IA Pre -Ria Procedure 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid, returns tank, and additional upright tanks as needed. 4. Pressure test lines to 3,000 psi. RWO — Tubing Changeout Well: MPU J-25 PTD: 204-073 Hila,rp Alaska. Lb API: 50-029-23207-00 5. Bullhead 8.3 ppg source water down tubing to formation. a. Tubing volume to top of NB lateral: 60 bbls 6. Bullhead 8.3 ppg source water down the IA to formation. 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services Pump and reverse out skid. 9. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD crane. a. Make scribe mark on tr�ientation for re -installation. b. Function test all prior to arrival of AOGCC inspectors. 10. NU BOPE house. Spot mud boat. Workover Procedure: 11. MIRU ASR #1 Workover rig, ancillary equipment and lines to returns tank. 12. Pull BPV after confirming zero surface wellhead pressure. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.3 ppg source -water prior to pul�li g BPV. Set TWC. 13. Test BOPE to 250psi Low/ 3,500psi High, annular to 250psi Low/ 3, psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and c rt tests. ayQ� a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 3-1/2" & 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to returns tank. Pull TWC. 16. RU spooler for tech -wire control line for downhole gauge pull. 17. MU 4-1/2" landing joint and BOLDS. 18. Unseat hanger and pull over string weight on tubing and confirm free. Replace blast rings as needed. The wellhead specialists have 4-1/2" blast rings in stock. U 1161.ra Alaska, LL RWO —Tubing Changeout Well: MPU 1-25 PTD: 204-073 API: 50-029-23207-00 b. 2014 Completion install: PU= 91K and Slack -off = 87K with 50K block weight i. Note that completion was landed in seal -bore in 2004. There may be a large over -pull to clear the seal assembly. c. Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. d. Contingency: (If a rolling test was conducted.) L MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 19. Pull the 4-1/2" tubing from ±3,948' MD a. Clamp Count: 52 clamps installed in 2004 b. Number all joints. c. Note condition of pipe in report and depths of any external corrosion or holes. Photograph and file pictures. d. Send tubing to G&I for cleaning and disposal. e. Dispose of downhole gauges, sliding sleeve, and XN nipple. f. Note the condition of the seal assembly 20. MU Cleanout BHA and RIH for cleanout run a. MU cleanout assembly on 3-1/2" workstring with following equipment: i. 4.75" OD (or slightly under gauge) seal bore polished mill ii. Prior to RIH, review with engineer for the need of the following BHA: 1. 4" Max -OD Bumper Jar 2. 4" Max -OD Oil Jars 3. 4" Max -OD HWDP or drill collars b. RIH and wash down to ±3,950' MD. c. Reciprocate from 3,903' to 3,950' MD and circulate 2x bottoms up from 3,950' MD. d. POOH and lay down cleanout BHA assembly. 21. Call out Baker Hughes Centrilift to run downhole gauge. 22. PU 3-1/2" tubing completion and space out as followed: a. 4.75" OD Seal Assembly b. 5.50" No -Go Locator c. Pup Joint: 3-1/2" L-80 tubing d. 3-1/2" XN Nipple (2.75" ID) e. Pup Joint: 3-1/2" L-80 tubing f. Suction Gauge g. Pup Joint: 3-1/2" L-80 tubing h. 3-1/2" XD Sliding Sleeve (Closed Position) i. Pup Joint: 3-1/2" L-80 tubing j. —123 joints 3-1/2" L-80 tubing k. Space Out Pup Joint I. Tubing hanger 23. RIH with completion, stopping at ±3,910' MD H I &,,rp Alaska, LG RWO —Tubing Changeout Well: MPU J-25 PTD: 204-073 API: 50-029-23207-00 24. Prior to seating seal bore assembly, reverse circulate (pumping down IA) 5 bbls of 1%CRW (or equivalent corrosion inhibitor) source water, followed by 128 bbls of untreated source water down IA to spot corrosion inhibited fluid between packers. a. This will spot corrosion inhibited fluid between the packer and sliding sleeve. 25. Continue running the completion in hole, no -going on 5.50" locator at±3,914' MD 26. Obtain pick-up and slack -off weights and note band/clamp summary. 27. After landing seal assembly, pick up slowly to neutral weight. 28. Close annular and Pressure test IA to 1000 psig to ensure the seal bore assembly is landed. 29. Land the tubing hanger. Terminate downhole gauge wire. 30. Pressure IA up to 3000 psig and perform a Charted MIT -IA for a minimum target pressure of 2700 psi for 30 min (charted). a. N conducting test. b. Contingency: If MIT -IA fails, backup plan will be to install a stacked packer at ±3,880' MD 31. Bleed tubing and inner -annulus pressures to zero. 32. RILDS and LD landing joint. 33. Set BPV. 34. Test tubing hanger void to 500 psig low/ 5000 psig high. 35. RD Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. Post Workover Procedure: 36. RD mud boat. RD BOPE house. 37. RU crane. ND BOPE. Pull BPV. Set TWC. 38. NU 4-1/16" 5,000# tree and adapter flange and test to 500 psi low/5,000 psi high. 39. Pull TWC. RD crane. 40. Move returns tank and rig mats. 41. Turn well over to wells team for post rig slickline work. 42. RU Slickline a. Shift open XD Sliding Sleeve b. Pump freeze protect (if well is not BOL within 24 hours). i. Pump 86 bbls of diesel or 60/40 ii. RU jumper and allow freeze protect to U-tube. c. Install jet pump in XD sliding sleeve. d. RD Slickline. e. Turn well over to operations. f. Test SSV within 5 -days of BOL per AOGCC regulations, 20 AAC 25.265. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic n corp Alaska, LLC Uig. KB Elev.: 70.14'/ Uig. GI-Elev.: 36.1' SCHEMATIC TD= 8,348' (MD) / TD= 3,872'(TVD) PBiD = 8,348' (MD) / TD = 3,87Z(TVD) Milne Point Unit Well: MPU J-25 Last Completed: 7/15/2004 PTD: 204-073 TREE & WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x4-1/2"SM Gen 6w/4.5"TCII T&B 7-5/8" TubingHanger CIW "H" BPV Profile OPEN HOLE / CEMENT DETAIL 20" Coot w/ 260 sx of Arcticset I in 42" Hole 30-3/4" Cmt w/ 430 sx AS Lite, 258 sx Class "G" in 13-1/2" Hole 7-5/8" Cmt w/ 286 sx Class "G" in 9-7/8" Hale CASING DETAIL Type Wt/ Grade/ Conn Drift ID Top Btm Conductor 92/H-40/Welded N/A Surface 112' Surface 45.5/K-55&L-80/BTC 9.794 Surface 2,399' Production 29.7 / L-80 / BTC -MOD 6.750 Surface 4,037' Liner 9.5/L-80/IBT 3.423 3,903' 81348' TUBING DETAIL Tubing 12.6/L-80/IBT-MOD 1 3.833" Surf 3.946' WELL INCLINATION DETAIL 'op @ 440' MD Hole Angle Passes 50+ deg @ 4,070' MD 45 deg @ Max Deviation in Tubing JEWELRY DETAIL Item 4-1/2" Blast Rings below tubing hanger (12") Sta All: GLM — Camco KBG-2 4-1/2" x 1" — DCK-2 Shear set 3/16/2013 4-1/2' NDPG-C Multi -drop Discharge Gauge (3.864" ID) 4-1/2' XD Sliding Sleeve (3.813" Packing Bore Min ID; 10C JP set 06-) 4-1/2" NDPG-C Single -drop Intake Gauge (3.864" ID) 4-1/2" XN Profile (3.813" Packing Bore; 3.725" No -Go Min ID) Locator Baker 80-47 Seal Assembly and Spacer Tubes (38' Long); Btm @ 3,946' NB Lateral Tie Back Sleeve NB Lateral ZXP Liner Top Packer NB Lateral 7-5/8" x 5-1/2" HMC Liner Hanger HMCV Cementing Valve NB Lateral Baker Payzone ECP Packer NB Lateral 4-1/2" Btm of Guide Shoe GENERAL WELL INFO API: 50-029-23207-00-00 Drilled and Completed by Doyon 14-8/28/2004 Revised By: TDF 7/26/2019 n 11 ileom Aloeke. LLC Orifi. KB Elev.: 70.14'/04GL Bev.: 36.1' PROPOSED TD=4348' (M7) /TD= 3,87Y(WD) PBTD=8,348' (M)) /TD=3,872'(TVD) Milne Point Unit Well: MPU J-25 Last Completed: 7/15/2004 PTD: 204-073 TREE & WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x4 -1/2"5M Gen 6w/4.5"TCII T&B Btm TubingHan er CIW "H" BPV Profile OPEN HOLE/ CEMENT DETAIL 20" Cmt w/ 260 sx of Arc[icset I in 42" Hole 10-3/4" Cmt w/ 430 sx AS Lite, 258 sx Class "G" in 13-1/2" Hole 7-5/8" Cmt w/ 286 sx Class "G" in 9-7/8" Hole CASING DETAIL Type Wt/ Grade/ Conn DriftID I Top Btm Conductor 92/H-40/Welded N/A Surface 112' Surface 45.5 / K -55&L-80 / BTC 9.794 Surface 2,399' Production 29.7/L-80/BTC-MOD 6.750 Surface 4,037' Liner 9.5/L-80/IBT 3.423 3,903' 8,348' TUBING DETAIL Tubing 9.3/L-80/EUE8RD 1 2.867" Surf 3,948' WELL INCLINATION DETAIL KC)@ 440' MD Hole Angle Passes 50+ deg @ 41070' MD 45 deg @ Max Deviation in Tubing JEWELRY DETAIL Item 4-1/2" Blast Rings below tubing hanger (12") 4-1/2" x 3-1/2" Tubing Crossover 3-1/2" XD Sliding Sleeve (3.813" X -Nipple packing bore) 3-1/2" Zenith Suction Gauge 3-1/2" XN Nipple (2.75" MIN ID) 5.5" OD No -Go Locator Baker 4.75" OD Seal Assembly and Spacer Tubes (36' Long); Btm @ 3,948' NB Lateral Tie Back Sleeve NB Lateral ZXP Liner Top Packer NB Lateral 7-5/8" x 5-1/2" HMC Liner Hanger HMCV Cementing Valve NB Lateral Baker Payzone ECP Packer NB Lateral 4-1/2" Btm of Guide Shoe GENERAL WELL INFO API: ed '0-9 207-00-00 DrillCompleted by Doyon 34-8/28/2004 Revised By: TDF 7/26/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 1/05/2018 2-7/8" x 5" VBR lind Pes bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 .. SLANNEDREB u Z012. Mr. Tom Maunder g j3 `'F v Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ-05 1910950 50029221960000 Dust Cover _ NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor ' NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated - 3 1 " MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 • • ~°"`~' ~ '• ~ 03~o~~zoos DO NOT PLACE .: ~. ~' , .. ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CbrPgs_InsertslMicrofilm Marker.doc e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 10, 2007 RE: MWD Formation Evaluation Logs MPJ-25 AK-MW-3149211 1 LIS formatted CD with verification listing. API#: 50-029-23207-00 GCANNt.D AUG 2 7 Z007 PLEASE ACK1~OWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 o BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Signed: é~~ Date: Ai \(' Sì ':'; 7007 rv \..it -- ,) A!as~..a ~ Û~ fYimllmiSSicn \,;-..' ' cXf-1-O-:¡3 # 15"3~!J- e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 10, 2007 RE: MWD Formation Evaluation Logs MPJ-25 PBl AK-MW-3149211 1 LIS formatted CD with verification listing. API#: 50-029-23207-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 F ~ Dat~;,n ii L~ ;,;{ n._ " 41 U 7'"0''' _U I Signed: Lt,.flJ~ SCANNED AUG 2 7 Z007 ,'2oJaska Oil 8, Gas Commission Anchor~~e ~o4- CR3 ~ JS-3~to MPU J-25 . . Andy, We have the OH CMR data for MPU J-25 PB 1, but we do not have the OH data for the final hole. Please send over bluelines, reproduceables, and digital logging data for MPU J-25 API 50-029-23207 -00. TNX Howard 1 of 1 8/8/20068:41 AM Of~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 5, u.¿ ..t) Jw....-M-Ð'1 API No. 50-029-23207-00-00 Permit to Drill 2040730 Well NamelNo. MILNE PT UNIT SB J-25 Operator BP EXPLORATION (ALASKA) INC MD 8348/ TVD 3872,../'· Completion Date 7/9/2004 /' Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, IFR / CASANDRA, GYRO, RES, NEU, DEN Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ D Asc Directional Survey 3997 8348 7/16/2004 IIFR ,..:..R¡5t Directional Survey 3997 8348 7/16/2004 IIFR c..e-b. D Asc Directional Survey 3997 8348 MWD ~t Directional Survey 3997 8348 7/16/2004 MWD ~ D Asc Directional Survey 0 4800 7/16/2004 IIFR PB1 ~t Directional Survey 0 4800 7/16/2004 IIFR PB1 ¢D Asc Directional Survey 0 4800 MWD PB1 ~ Directional Survey 0 4800 MWD PB1 ~C 12726 Magnetic Resonance 3484 4802 9/22/2004 COMBINABLE MAGNETIC ~ RESONANCE TOOL 12726 Magnetic Resonance Blu 3484 4802 9/22/2004 COMBINABLE MAGNETIC RESONANCE TOOL ~ Caliper log Blu 3500 4802 9/22/2004 CALIPER LOG/PEX-TLD % C Lis 13203 Injection Profile 3820 8290 Case 7/14/2005 0 0 Well CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . . MD 8348 TVD 3872 Completion Date 7/9/2004 ADDITIONAL INFORMATION Well Cored? ~/ N S ~ c.. (DP\t") Chips Received?' Y / N Analysis Th N Received? Permit to Drill 2040730 Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Well Name/No. MILNE PT UNIT SB J-25 Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L Daily History Received? 0/N QN Formation Tops !Jp Date: API No. 50-029-23207-00-00 UIC N --~ ;8 It, ~~ . . · STATE OF ALASKA . ALASKA1IIf!"JíL AND GAS CONSERVATION COMrJr§SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD , GR , IFR / CASANDRA , GYRO, RES, NEU , DEN CASING, LINER AND CEMENTING RECORD SETTIJllGDEPTH MD SETTINGOeprfltvD QOTTOM lOP BOTTOM 112' 34' 112' 2399' 34' 2377' 32' 4037' 32' 3726' 3903' 8348' 3632' 3872' 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: 2741' NSL, 3413' WEL, SEC. 28, T13N, R10E, UM Top of Productive Horizon: 3735' NSL, 4756' WEL, SEC. 28, T13N, R10E, UM Total Depth: 89' NSL, 2746' WEL, SEC. 20, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 551903 y- 6015138 Zone- ASP4 TPI: x- 550551 y- 6016123 Zone- ASP4 Total Depth: x- 547266 y- 6017735 Zone- ASP4 18. Directional Survey 0 Yes 1m No 22. CASING SIZE 20" 92# 45.5# 29.7# 12.7# 4-1/2" x 5" x 4" H-40 L-80 L-80 L-80 34' 34' 10-314" 7-5/8" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 5" x 4" Excluder Sand Screens MD TVD MD 4857' - 8209' 3896' - 3892' 26. Date First Production: August26,2004 Date of Test Hours Tested PRODUCTION FOR 8/25/2004 6 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 24-HoUR RATE One Other 5. Date Comp., Susp., or Aband. 7/9/2004 6. Date Spudded 6/27/2004 7. Date T.D. Reached 7/612004 8. KB Elevation (ft): KBE = 70.14' 9. Plug Back Depth (MD+ TVD) 8348 + 3872 10. Total Depth (MD+ TVD) 8348 + 3872 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL .",.' Revision: 09/10/04, Start Production 1b. Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-073 13. API Number 50- 029-23207-00-00 14. Well Name and Number: MPJ·25 15. Field / Pool(s): Milne Point Unit / Schrader Bluff Ft Ft 16. Property Designation: ADL 025515 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 42" 260 sx Arctic Set (Approx.) 13-1/2" 430 sx Arctic Set Lite, 258 sx 'G' 9-7/8" 286 sx Class 'G' 6-3/4· 137 sx Class 'G' (Banzai em! Job and Sand Screens) SIZE 4-1/2" 12.6#, L-80 TVD DEPTH SET (MD) 3912' PACKER SET (MD) N/A 25. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 30 Bbls Crude and 50 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Hydraulic Pump OIL-BsL GAs-McF WATER-BsL 344 65 0 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". . .. . ....... Sea.'. 2... '¡\Ink, CE\VEO See Attachment RBDMS eFl . t: r . R E . OR f GIN A l SEP 1 :6~~~~t!U11Ì$Si60 M&()\{a Qi\ & Gas . ~nchQ{a\}e OIL-BsL 1376 27. Form 10-407 Revised 12/2003 GAs-McF 261 W A TER-BsL o CONTINUED ON REVERSE SIDE I GAS-OIL RATIO 189 OIL GRAVITY-API (CORR) CHOKE SIZE 19~ G 28. - 29. e GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC TMA TMB1 TMB2 TMC TNA TNB TNC TNE TNF TOA TSBC TOB BOB 3544' 3850' 3867' 3936' 4120' 4218' 4260' 4314' 4350' 4426' 4485' 4534' 4590' 4637' 3368' 3595' 3607' 3655' 3780' 3828' 3842' 3853' 3858' 3866' 3873' 3877' 3880' 3882' None 30. List of Attachments: Side Wall Core Analysis. 31. I hereby certify ~ng i~correct to the best of my knowledge. Signed Sondr~wman ~J /'-- "!itle Technical Assistant MP J-25 204-073 Prepared By Name/Number: Well Number Drilling Engineer: Date ()q -IO-()~ Permit No.1 Approval No. INSTRUCTIONS Sondra Stewman, 564-4750 Skip Coyner, 564-4152 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible. Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP Alaska MPJ 25 Milne Point Field File No.: 57111-104248 API No.: Date: 8\18\2004 Sidewall Core Analysis Results 1 3580.0 0.8 184.2 32.4 36.5 60.6 0.60 97.1 2.67 10.5 (2) Sd brn vf-fgr/mgrs slty c1y m-d stn dgld flor 2 3588.0 0.5 266.1 34.4 0.0 86.4 0.00 86.4 2.66 9.6 (2) Sd gry vf-fgr slty carb no stn no flor e 3 3605.0 0.5 1642.2 33.8 42.2 53.7 0.79 95.9 2.65 10.3 (2) Sd brn vf-mgr slslty d stn dorng flor 4 3641.0 0.6 12.4 33.5 0.0 89.2 0.00 89.2 2.66 9.9 (3) Sd gry vf-fgr vslty c1y no stn no flor 5 3680.0 0.5 9.9 33.8 0.0 90.1 0.00 90.1 2.71 9.6 (3) Sd gry vfgr vslty cly no stn no flor 6 3700.0 0.6 1617.6 37.5 54.0 44.1 1.22 98.0 2.64 8.5 (2) Sd brn vf-fgr slslty d stn dorng flor 7 3760.0 0.4 <5.0 28.8 0.0 84.8 0.00 84.8 2.68 6.2 (4) Sd gry vf-mgr vs1ty/ cly lam no stn no flor 8 3783.0 0.7 261.4 36.2 50.8 45.9 1.11 96.6 2.66 11.5 (2) Sd brn vfgr/fgrs slty slcly d stn dorng flor 9 3850.0 0.8 9.6 31.4 13.8 74.6 0.18 88.4 2.65 9.9 (3) Sd gry-brn vf-fgr/mgrs vslty msp stn gld flor 10 3872.0 0.4 744.7 35.3 45.3 54.1 0.84 99.4 2.66 9.4 (2) Sd brn vf-fgr slslty-slty d stn dorng flor 11 3880.0 0.6 4.6 31.1 0.0 97.6 0.00 97.6 2.68 10.1 (3) Sd gry vf-fgr/mgrs vslty vcly no stn no flor 12 3890.0 0.6 87.9 30.4 10.5 87.0 0.12 97.6 2.63 12.6 (2) Sd brn-gry vf-mgr vslty cly carb lsp stn dgld flor 13 3900.0 0.7 54.1 31.7 27.0 71.6 0.38 98.6 2.68 14.5 (2) Sd brn-gry vf-mgr vsltyl c1y lam m stn dorng flor e 14 3910.0 0.5 49.4 33.0 35.0 61.6 0.57 96.7 2.66 11.7 (2) Sd brn vf-mgr vslty s1c1y d stn dorng flor 15 3920.0 0.4 <50.0 36.9 10.6 81.3 0.13 91.9 2.63 6.7 (4) Sd lbrn vfgr/fgrs vs1ty carb l-m stn dgld flor 16 3930.0 0.3 <50.0 35.1 18.5 65.8 0.28 84.3 2.67 7.0 (4) Sd brn vfgr/fgrs vslty s1c1y l-m stn dorng flor 17 3940.0 0.3 52.7 33.5 20.7 67.0 0.31 87.7 2.66 7.3 (3) Sd brn vf-fgr/mgrs vslty s1cly 1-m stn dorng flor 18 3943.0 0.6 197.6 34.1 53.5 43.9 1.22 97.4 2.66 12.5 (2) Sd brn vf-mgr slty d stn dorng flor 19 3950.0 0.4 12.0 30.6 5.9 84.0 0.07 90.0 2.61 9.7 (3) Sd gry-tan vf-fgr vslty cly carb msp stn dgld flor 20 3955.0 0.3 <5.0 30.4 7.9 75.0 0.11 82.9 2.62 9.5 (4) Sd gry-Ibrn vf-fgr vslty c1y mstrk stn dgld flor 21 3963.0 0.3 1000.0 40.0 14.1 75.9 0.19 90.0 2.50 7.3 (4) Sd brn vf-fgr/cgrs slslty carb 1-m stn dorng flor 22 3970.0 0.2 2500.0 36.2 44.5 39.1 1.14 83.6 2.61 7.2 (4) Sd brn vf-mgr/cgrs slslty d stn dorng flor 23 3984.0 0.5 900.7 32.1 37.3 57.6 0.65 94.9 2.62 11.3 (2) Sd brn vf-fgr/cgrs slslty m-d stn dorng flor BP Alaska MPJ 25 Milne Point Field File No.: 57111-104248 API No.: Date: 8\18\2004 Sidewall Core Analysis Results 24 3990.0 0.2 2000.0 36.8 27.8 60.1 0.46 87.9 2.60 7.0 (4) Sd brn vf-fgr/cgrs sIsIty m-d stn dorng flor 25 4000.0 0.5 1954.9 31.1 44.3 50.3 0.88 94.7 2.61 9.9 (2) Sd brn vf-cgr sIsIty d stn dorng flor e 26 4010.0 0.2 503.9 30.9 15.7 73.5 0.21 89.2 2.63 7.0 (3) Sd Ibrn vf-cgr sIty I-m stn dorng flor 27 4016.0 0.4 105.0 30.0 6.7 89.1 0.08 95.8 2.65 13.3 (2) Sd Ibrn vf-mgr/cgrs sIty I stn dorng flor 28 4030.0 0.6 5.1 27.8 7.0 88.2 0.08 95.3 2.69 14.4 (2) Sd gry-Ibrn vfgr vslty c1y msp stn dorng flor 29 4050.0 0.3 <1.0 30.8 0.0 87.5 0.00 87.5 2.72 8.9 (4) Mdst gry sdy sIty no stn no flor 30 4070.0 0.4 <50.0 30.2 1.0 91.7 0.01 92.7 2.66 9.5 (4) Sd gry-tan vfgr/mgrs vslty 1 stn dorng flor 31 4200.0 0.5 36.2 32.6 19.0 74.1 0.26 93.1 2.69 13.0 (2) Sd brn vfgr/fgrs vslty cly I-m stn dorng flor 32 4237.0 0.5 47.6 32.1 34.2 63.6 0.54 97.8 2.69 13.5 (2) Sd brn vf-fgr vslty m-d stn dorng flor 33 4268.0 0.3 21.6 27.8 0.0 85.3 0.00 85.3 2.65 9.4 (3) Sd gry vf-mgr/cgrs vslty c1y no stn no flor 34 4284.0 0.8 71.4 30.4 34.7 62.3 0.56 97.0 2.71 17.1 (2) Sd brn vf-fgr vslty m-d stn dorng flor 35 4295.0 1.0 F/2431.2 31.2 12.1 79.3 0.15 91.5 2.69 18.1 (2) Sd Ibrn vf-fgr vsIty slcly I-m stn dgld flor 36 4318.0 0.7 301.5 32.7 43.2 54.3 0.80 97.5 2.69 12.9 (2) Sd brn vf-mgr sIty d stn dgld flor e 37 4495.0 1.2 F/1614.9 33.3 21.3 70.2 0.30 91.5 2.69 19.5 (2) Sd Ibrn vfgr/fgrs vsIty c1y m stn dg1d flor 38 4510.0 0.3 <5.0 30.0 11.6 67.6 0.17 79.2 2.69 10.9 (4) SIt tan vcly sdy I-m stn dg1d flor 39 4525.0 0.5 F/1997.4 32.6 24.7 67.2 0.37 91.9 2.69 13.8 (2) Sd brn vf-fgr vsIty m stn dor flor 40 4600.0 0.5 14.6 32.9 14.7 74.3 0.20 89.0 2.69 12.9 (2) Sd brn vf-fgr vsIty m stn dor flor 41 4625.0 0.6 F/3944.3 33.3 24.0 63.4 0.38 87.4 2.70 16.9 (2) Sd brn vf-fgr vsIty m stn dor flor FI Indicates Visible Fracture(s) Present . STATE OF ALASKA . ... ALASKA AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ~ Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD , GR , IFR / CASANDRA , GYRO, RES, NEU , DEN CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE Top BOTTOM Top BOTTOM SIZE 34' 112' 34' 112' 42" 34' 2399' 34' 2377' 13-1/2" 32' 4037' 32' 3726' 9-7/8" 3903' 8348' 3632' 3872' 6-3/4" 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: 2741' NSL, 3413' WEL, SEC. 28, T13N, R10E, UM Top of Productive Horizon: 3735' NSL, 4756' WEL, SEC. 28, T13N, R10E, UM Total Depth: 89' NSL, 2746' WEL, SEC. 20, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 551903 y-_ 6015138 Zone-__~~£>,±_ TPI: x- 550551 y- 6016123 Zone- ASP4 --'"--,~~ ._----~----,-- ------------- Total Depth: x- 547266 y- 6017735 Zone- ASP4 18. Directional Survey ~ Yes 0 No 22. CASING SIZE WT. PER FT. 92# 45.5# 29.7# 12.7# GRADE H-40 L-80 L-80 L-80 20" 10-3/4" 7-5/8" 4·112" x 5" x 4" 23. Perforations open to Production (MD + rvD of Top and Bottom Interval, Size and Number; if none, state "none"): 5" x 4" Excluder Sand Screens MD TVD MD 4857' - 8209' 3896' - 3892' 26. Date First Production: Not on Production Date of Test Hours Tested One Other 5. Date Comp., Susp., or Aband. 7/9/2004 6. Date Spudded 6/27/2004 7. Date T.D. Reached 7/6/2004 8. KB Elevation (ft): KBE = 70.14' 9. Plug Back Depth (MD+ TVD) 8348 + 3872 10. Total Depth (MD+TVD) 8348 + 3872 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. SIZE 4-112" 12.6#, L-80 rvD 1b. Well Class: ~ Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-073 13. API Number 50- 029-23207-00-00 14. Well Name and Number: MPJ·25 15. Field / Pool(s): Milne Point Unit / Schrader Bluff Ft Ft 16. Property Designation: ADL 025515 17. Land Use Permit: 20. Thickness of Permafrost 1800'(Approx. ) CEMENTING RECORD 260 sx Arctic Set (Approx.) 430 sx Arctic Set Lite, 258 sx 'G' 286 sx Class 'G' AMOUNT PUllED 137 sx Class '8' (Banzai Cmt Job and Sand Screens) TUBING RECORD DEPTH SET (MD) 3912' PACKER SET (MD) N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 30 Bbls Crude and 50 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-BBl GAs-McF WATER-Bsl PRODUCTION FOR TEST PERIOD ... CALCULATED ...... 24-HoUR RATE""'" Oll-BBl Flow Tubing Casing Pressure Press. GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ,...",-~.,,.,.b<;,,,,;,:,,,,,,,,,.,~ Sidk;~1r~~jIYSiS is not available at this time. Will resumbit 10-407 with core analysis. ?/~ÄI ~ .~ ~ÐOMSBFt AUG 1 1. ?OO~ [; Ý ~,-~.,~,-""~,'--..,..",, Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS. 29. .MATION 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 TUZC TMA TMB1 TMB2 TMC TNA TNB TNC TNE TNF TOA TSBC TOB BOB 3544' 3850' 3867' 3936' 4120' 4218' 4260' 4314' 4350' 4426' 4485' 4534' 4590' 4637' 3368' 3595' 3607' 3655' 3780' 3828' 3842' 3853' 3858' 3866' 3873' 3877' 3880' 3882' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Post Rig Summary and a Leak-Off Test Summary. 31. I hereby certify that the fore Signed Title Technical Assistant Date D~- ù1-{)Lj - MPJ-25 Well Number 204-073 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Skip Coyner, 564-4152 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-25 MPJ-25 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: Rig Release: Rig Number: 6/26/2004 7/9/2004 14 Spud Date: 6/27/2004 End: 7/9/2004 6/26/2004 03:00 - 04:30 1.50 MOB P PRE Rig down on MPL-43, Move off well 04:30 - 07:00 2.50 MOB P PRE Install Rear Booster wheels, Move camp off location 07:00 - 15:30 8.50 MOB P PRE Move rig to MPJ pad 15:30 - 16:30 1.00 MOB P PRE Remove Rear Booster wheels 16:30 - 19:30 3.00 MOB P PRE Spot rig over well MPJ-25 19:30 - 20:30 1.00 MOB P PRE Skid rig floor over well 20:30 - 21 :00 0.50 MOB P PRE Spot rockwasher, Water tanks, Rig up rig floor 21 :00 - 00:00 3.00 RIGU P PRE N/u 20" diverter riser, flow lines, Rig accept @ 2100 6/26/2004 6/27/2004 00:00 - 01 :00 1.00 RIGU P PRE N/u 20" diverter riser, flow lines, mixing spud mud 01 :00 - 10:00 9.00 DRILL P SURF Load pipe shed, picking up 4" Drill pipe standing in derrick, mixing spud mud 10:00 - 11 :30 1.50 DRILL P SURF Change handling tools to 5", picking up HWDP and dcs and standing in derrick 11 :30 - 12:00 0.50 DRILL P SURF Rig up Gyro unit 12:00 - 13:00 1.00 DRILL P SURF M/U Bit and motor,float sub,xo. 13:00 - 14:00 1.00 DRILL P SURF Pre Spud meeting, 14:00 - 14:30 0.50 DRILL P SURF Diverter test, the right to witness diverter test was wavier by Lou Grimaldi, Fill stack w/fuilds, checked all connection 14:30 - 16:00 1.50 DRILL P SURF Spud well, Drilling from 112 to 225 with 350 gals per min., 800 psi, 80 rpms 16:00 - 18:00 2.00 DRILL P SURF Poh, Stand back HWP,make up MWD, orient 18:00 - 20:00 2.00 DRILL N DFAL SURF Drilling from 225 to 258 with 350 gals per min., 800 psi, 80 rpms, attemp to run GYRO made 3 runs, tattle tale not giving indication of landing 20:00 - 21 :30 1.50 DRILL N DFAL SURF POH, found top part of rubber plug from last well on top of landing tool, had to have been hung in stand pipe when we reverse out 21 :30 - 00:00 2.50 DRILL P SURF Drilling from 258 to 400 with 400 gals per min., 850 psi, 80 rpms, running GYRO every 100 ft. AST 1.33 Art 1.48 6/28/2004 00:00 - 21 :00 21.00 DRILL P SURF Drilling from 440' t02409' with 466 gals per min., 1880 psi, 80 rpms, run GYROs to 531 ft. AST 5.9, ART 8.75 21 :00 - 23:00 2.00 CASE P SURF Circ three bottoms up with 550 gals min., 2210 psi, 100 rpms 23:00 - 00:00 1.00 CASE P SURF Pumping out to HWDP with full drilling rate 6/29/2004 00:00 - 01 :00 1.00 CASE P SURF Trip back to bottom @ 2409 01 :00 - 02:30 1.50 CASE P SURF Circ three bottoms up with 550 gals min., 2210 psi, 100 rpms 02:30 - 04:00 1.50 CASE P SURF Pumping out to HWDP with full drilling rate 04:00 - 06:00 2.00 CASE P SURF Laying down BHA 06:00 - 08:30 2.50 CASE P SURF Clear floor, Rig up to run csg, PJSM 08:30 - 11 :30 3.00 CASE P SURF Picking up 103/445# L-80 Csg total of 57 jts, PU 140K, S/o 100K, Shoe 2399', Float 2314' 11 :30 - 12:30 1.00 CASE P SURF Rig down franks tool,Rig up cement head 12:30 - 13:30 1.00 CASE P SURF Circ and thin mud for cement job, 9 bbls min 300 psi 13:30 - 16:00 2.50 CEMT P SURF Cement with Schlumberger. Pump 10 bbls water ahead,test lines to 3500, 15 bbls water, 75 bbls mudpush II mixed @ 10.0# with one gal. dye, drop bottom plug, mix and pumped 430 sx. Artic Set lite 10.7#, Yield 4.44,340 bbls slurry pumped @ 7 bbls min. 230 psi, Tail 260 sxs. Class G, yield 1.17, 15.8#,54.5 bbls slurry, kicked out top plug with 30 bbls water, displace with rig pumps 6 bbls min. 193 bbls mud, bump plug with 1600 psi,floats held, bump plug @ 1600 hrs, 210 bbls of good cement to surface 16:00 - 17:30 1.50 CASE P SURF Lay down landing jt.flush diverter and flow lines Printed: 7/13/2004 9:11 :55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-25 MPJ-25 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/26/2004 Rig Release: 7/9/2004 Rig Number: 14 Spud Date: 6/27/2004 End: 7/9/2004 6/29/2004 17:30 - 19:00 1.50 CASE P SURF Clear floor of csg tools, change out long bales 19:00 - 20:00 1.00 CASE P SURF Pjsm, Nipple down Diverter and Diverter lines 20:00 - 21 :00 1.00 CASE P SURF Nipple up Gen 5 wellhead and tubing spool, test seal to 1000 psi for 10 min. 21 :00 - 23:30 2.50 CASE P SURF Nipple up BOP stack, Flowlines, Riser, Turnbuckles 23:30 - 00:00 0.50 CASE P SURF Rig up to test BOPS 6/30/2004 00:00 - 05:00 5.00 CASE P SURF Test BOPs and manifold to 250-4500 psi, 5 min. per test, Hydril 250-2500 psi, 5 min per test, the right to witness test was wavier by John Spaulding AOGCC 05:00 - 06:00 1.00 CASE P SURF Service top drive, change out saver sub 06:00 - 10:00 4.00 CASE P SURF picking up BHA #2 MX-1 with 3-12,1-10 jets,7" sperry drill 1.22 bend,float sub,stab,6 3/4 DGR+EWD+PWD,Hang off collar,6 3/4 SLD/Nuke,6 3/4 BAT Sonic,stab,6 3/4 MRIL,3 Flex dC.,12 HWDP,jars,5 HWDP 10:00 - 10:30 0.50 CASE P SURF Trip in to 2249' 10:30 - 11 :30 1.00 CASE P SURF Test Csg to 2500 psi for 30 min. 11 :30 - 12:30 1.00 CASE P SURF Slip and cut drilling line 12:30 - 15:00 2.50 DRILL P INT1 Drilling shoe track, 20 ft of new hole to 2430', Attempt to log 120 ft per hr across 2249 to 2344' while drilling shoe track, logs were not good, due to pump rate 15:00 - 16:00 1.00 DRILL P INT1 Circ and displace hole with new 9.0 LSND mud 16:00 - 17:00 1.00 DRILL P INT1 FIT test 2430 MD,TVD 2377' 380 psi, 9.0 MW= 12 EMW, pressure bleed from 380 psi to 140 psi in 10 min. 17:00 - 18:30 1.50 DRILL P INT1 Mad pass from 2307' to 2430 18:30 - 00:00 5.50 DRILL P INT1 Control Drilling 2430' to 2900' with 85 rpms, 425 GPM, 1200 psi, AST 2.79, ART 1.32 7/1/2004 00:00 - 06:00 6.00 DRILL P INT1 Control Drilling 2900' to 3398' with 85 rpms, 425 GPM, 1200 psi 06:00 - 07:00 1.00 DRILL P INT1 Circ, Two bottoms up,with 450 gals per min, 1300 psi, 80 rpms 07:00 - 07:30 0.50 DRILL P INT1 Pumping out to csg shoe @ 2,399 wit full drilling rate 07:30 - 08:00 0.50 DRILL P INT1 Circ bottoms up @ Csg shoe 08:00 - 08:30 0.50 DRILL P INT1 Service top drive 08:30 - 09:00 0.50 DRILL P INT1 Trip to bottom, ream last stand to bottom 09:00 - 00:00 15.00 DRILL P INT1 Control Drilling 3398' to 4560' with 90 rpms, 500 GPM, 2250 psi, AST 4.47, ART 10.83, TQ. 5K,ECD 9.7 7/2/2004 00:00 - 03:00 3.00 DRILL P INT1 Control Drilling 4,560' to 4,800" TD with 90 rpms, 500 GPM, 2250 psi, Bottom of OB sand 4,638' 03:00 - 04:30 1.50 DRILL P INT1 Circ, Three bottoms up with 550 GPM, 2400 psi, 100 rpms 04:30 - 17:00 12.50 DRILL P INT1 Mad pass from TD to 3600', @ 120 ft per hr., 50 rpms, 500 gpms, 2300 psi 17:00 - 18:00 1.00 DRILL P INT1 Pump out of hole to 2399' 18:00 - 18:30 0.50 DRILL P INT1 Circ bottoms up, slug pipe 18:30 -19:30 1.00 DRILL P INT1 Tripping out to BHA 19:30 - 22:30 3.00 DRILL P INT1 Down loading logging tools, lay down same 22:30 - 23:00 0.50 DRILL P INT1 Clear floor 23:00 - 00:00 1.00 EVAL P INT1 Rig up E-line loggers 7/3/2004 00:00 - 08:00 8.00 EVAL P INT1 Logging with Schlumberger, run #1 CMR/GRfTDL,logger TD 4800 to 3500 ft, run repeat and pull into csg for town to read logs, rerun CMR/GRfTDL as per town 08:00 - 14:30 6.50 EVAL P INT1 Rehead e-line,run #2 Side wall cores, shots 45, recovered 41 cores 14:30 - 15:00 0.50 EV AL P INT1 Rig down loggers 15:00 - 16:00 1.00 CASE P INT1 Pick up Johnny Wacker, Tripping in to 4800 with drill pipe Printed: 7/13/2004 9:11:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-25 MPJ-25 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/26/2004 Rig Release: 7/9/2004 Rig Number: 14 Spud Date: 6/27/2004 End: 7/9/2004 7/3/2004 16:00 - 18:00 2.00 CASE P INT1 Circ for open hole plug 18:00 - 19:00 1.00 CEMT P INT1 Cement with 5 bbls water, test lines to 2500 psi, 17 bbls water, 131 bbls Class G mixed @ 15.8,3 bbls water, displace with 28 bbls 9.2 mud 19:00 - 19:30 0.50 CASE P INT1 POH to 3,937 19:30 - 21:00 1.50 CASE P INT1 Circ, drop wiper plug, circ out 40 bbls of good cement to surface, pump nut plug sweep 21 :00 - 22:00 1.00 CASE P INT1 Poh, lay down Johnny wacker 22:00 - 22:30 0.50 CASE P INT1 Pick up 9.875 bit and 12 HWDP, Jars, 5 HWDP 22:30 - 00:00 1.50 CASE P INT1 Tripping in with bit to 3850', tag cement @ 3937 7/4/2004 00:00 - 01 :00 1.00 DRILL P INT1 Wash and Drill cement 3937 to 4048' with 500 GPM 1800 psi,60 rpms, 5-7K bit wt., would not pump off, had to drill 01 :00 - 02:00 1.00 DRILL P INT1 Circ 3 bottoms up 500 GPM 1800 psi,80 rpms 02:00 - 03:00 1.00 DRILL P INT1 Pumping out to Csg 2399' 03:00 - 04:00 1.00 DRILL P INT1 Circ bottoms up @ 2399 04:00 - 04:30 0.50 DRILL P INT1 Slug pipe and tripping out to BHA 04:30 - 06:00 1.50 DRILL P INT1 Laying down BHA, and 9 stands out of derrick 06:00 - 07:30 1.50 DRILL P INT1 Changing rams, Pull wear ring, test door seals to 2500 psi 07:30 - 08:30 1.00 CASE P INT1 PJSM, rig up to run csg 08:30 - 11 :00 2.50 CASE P INT1 Picking up 7.625 29# L-80 csg to 2355' 11 :00 - 11 :30 0.50 CASE P INT1 Circ, Csg volume, 6 bbls min 460 psi 11:30 -13:00 1.50 CASE P INT1 Picking up 7.625 29# L-80 csg to 4037, total of 98 jts run, shoe @ 4037, float 3955' 13:00 - 13:30 0.50 CASE P INT1 Rig down Franks fill up tool, rig up cementing head 13:30 - 14:30 1.00 CASE P INT1 Circ and reciprocate csg, thin mud for cement job 14:30 - 16:00 1.50 CEMT P INT1 Cement csg with Schlumberger with, 5 bbls water,test lines to 4,000 psi,15 bbls CW 100,30 bbls mud push mixed @ 10.5,59 bbls Class G, 276 sxs mixed @ 15.8 Yield 1.16,drop top plug, displace with 181 bbls 9.3 oil base mud @ 6 bbls min, bump plug with 1500 psi, floats held, full returns thru out job, 16:00 - 18:00 2.00 CASE P INT1 Rig down cement head, rig up and blowout landing jt.,flush BOPS 18:00 - 20:30 2.50 CASE P INT1 Change top rams to 2 7/8 X 5, rig up to test BOPS 20:30 - 00:00 3.50 CASE P INT1 Test Bops and Manifold to 250-4500 psi, Hydrill 2500-2500 psi 5 min. per test, the right to witness test was wavier by John Spalding AOGCC, install wear ring 7/5/2004 00:00 - 02:00 2.00 CASE P INT1 Picking up BHA #4 6.75 bit DSXi146 with 6x10,5" ABI motor with 1.5 bend,stab,float sub,GrammalResistivity,DM hang off sub,Tm hang off sub,3 flex dc,jars,2 hwdp 02:00 - 02:30 0.50 CASE P INT1 Picking up 27 jts of pipe from pipe shed 02:30 - 03:30 1.00 CASE P INT1 Tripping in to 3913' 03:30 - 04:30 1.00 CASE P INT1 Slip and cut drilling line 04:30 - 05:00 0.50 CASE P INT1 Break eirc, Test csg to 2500 psi for 30 min. 05:00 - 07:00 2.00 DRILL P PROD1 Drill cement float and shoe to 4037, Drill new hole to 4068', (drill shoe track @ 120 ft' per hr for tie in log) 07:00 - 07:30 0.50 DRILL P PROD1 Circ, bottoms up, 275 GPM ,2350 psi, 60 rpms 07:30 - 08:00 0.50 DRILL P PROD1 FIT test, with 9.3 MW 620 psi, TVD 3746 = 12.5 EMW 08:00 - 00:00 16.00 DRILL P PROD1 Drilling 4068' to 6120' with 90 rpms, 280 GPM, 2800 psi, AST 4.43, ART 5.37, Tq 3K 7/6/2004 00:00 - 20:00 20.00 DRILL P PROD1 Directional Drill from 6650' to 8348' TD 6 3/4" hole - WOB 5 to 6 - RPM 70 - TQ on 4 - off 3 - GPM 293 - PP on 3380 - off 3160 - PU 125 - SO 63 - ROT 93 20:00 - 22:30 2.50 CASE P PROD1 CBU 4 X - GPM 300 - PP 3160 psi - Shakers clean - Flow Printed: 7/13/2004 9:11:55AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-25 MPJ-25 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: 6/26/2004 Rig Release: 7/9/2004 Rig Number: 14 Spud Date: 6/27/2004 End: 7/9/2004 7/6/2004 20:00 - 22:30 2.50 CASE P PROD1 check well - Well static 22:30 - 00:00 1.50 CASE P PROD1 Pump out from 8348' to 6328' - Pump at drilling rate 293 gpm 7/7/2004 00:00 - 08:00 8.00 CASE P PROD1 Con't pumping out from 6325 to 6317' - Packing off - slow pump to 200 gpm - (any more pump and hole packs off) - Back ream from 6317' to 6005' with 250 gpm - RPM 60 to 80 - TO 4- Hole loaded with cuttings - Pump with out rotary from 6005' to 5840' - Attempting to pack off - Back ream from 5840' to 4730' with 80 rpm - 300 gpm - Pack off 4730' - RIH from 4730' to 4822' - establish circulation @ 4822' - pack off RIH to 4850' string free - Pull with out pump to 4730' - PU weight 115K - Hole not tight - Establish circulation @ 4750' - Pull with out pump to 4625' - RIH to 4655' - establish circulation - Con't POH - break circulation each stand from 4700' to 4100' 08:00 - 08:30 0.50 CASE P PROD1 CBU 1 X @ 325 gpm - 3100 psi - Rpm 60 08:30 - 09:00 0.50 CASE P PROD1 Rig service - Top drive sevice - Monitor well - Well static 09:00 - 10:30 1.50 CASE P PROD1 RIH from 4037' to 8235' - Precautionary wash from 8235' to 8348' - Fill pipe every 25 stands on trip in 10:30 - 14:30 4.00 CASE P PROD1 CBU 4 X - @ 300 gpm - 3450 psi - RPM 100 - TO 4 14:30 - 15:30 1.00 CASE P PROD1 Displace with 35 bbls hi-vis spacer - New 9.3 ppg Versa Pro - Flow check well - Well static 15:30 - 18:00 2.50 CASE P PROD1 Pump out from 8348' to 4037' - Pump at drilling rate 292 gpm - PP 2700 18:00 - 19:00 1.00 CASE P PROD1 CBU 1 X - GPM 325 - PP 2315 - RPM 61- Flow check - Well Static - Drop 2.25" rabbit 19:00 - 20:00 1.00 CASE P PROD1 POH to BHA 20:00 - 21 :30 1.50 CASE P PROD1 Lay down BHA 21 :30 - 22:30 1.00 CASE P PROD1 Clear floor of bha - Extra tools / equipment 22:30 - 23:30 1.00 CASE P PROD1 Rig up casing tools to run 4" screen liner 23:30 - 00:00 0.50 CASE P PROD1 PJSM - Pick up 4" screen liner 7/8/2004 00:00 - 04:00 4.00 CASE P PROD1 PU 4" Screen Liner 04:00 - 04:30 0.50 CASE P PROD1 Change out 4" handling equipment to 2 7/8" 04:30 - 08:00 3.50 CASE P PROD1 Make up and RIH with 2 7/8" Inner string - Assembly hanging up in liner 08:00 - 09:00 1.00 CASE P PROD1 POH with 2 7/8" assembly - Inspect cups - RIH with same 09:00 - 10:00 1.00 CASE P PROD1 Con't Make up 2 7/8" assembly - Change out handling equipment 10:00 - 10:30 0.50 CASE P PROD1 Make up Baker CMC liner hanger - with ZXP Liner top packer to Liner - Inspect same - PU 103 - SO 93 - Total Baker 4" C-27 Med Excluder Screens ran 43 - Total 4" Blanks ran 58 - Total 4.5" tubing ran 20 - Top of Baker tie back 3898' 10:30 -11:00 0.50 CASE P PROD1 Break Circ @ 2 bpm - 200 psi - Clear rig floor 11 :00 - 13:30 2.50 CASE P PROD1 RIH with 4" liner from 4457' to 8343' - PU 150 - SO 85 13:30 - 14:00 0.50 CASE P PROD1 Make up Baker Swivel Cementing head - Cementing lines 14:00 - 15:30 1.50 CASE P PROD1 Circulate DP volume @ 2 bpm - 450 psi - PJSM on cementing liner 15:30 - 19:30 4.00 CEMT P PROD1 Test lines to 5000 psi - Displace 2 stage plug to plug catcher 32.1 bbls @ 2 bpm 480 psi - Shear inner string plug @ 2100 psi - Displace Inner string to RPC 4.6 bbls total displacement 36.7 bbls - Pressure up to 3200 psi to release Baker HR Running tool - Bleed off presure - Inflate ECP 1140 psi to open - bled to 156 psi .45 bbl to inflate - Pressure up to 1300 psi to release closing sleeve hold for 2 mins - Increase to 2168 to shear open HMVC valve - Circulate @ 5 bpm 1480 psi two Printed: 7/13/2004 9:11:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-25 MPJ-25 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 6/26/2004 7/9/2004 14 Spud Date: 6/27/2004 End: 7/9/2004 7/8/2004 15:30 - 19:30 4.00 CEMT P PROD1 open hole vol Batch mix cement - Pump 10 bbls CW-101 @ 5 bpm 1000 psi - Pump 15 bbls Mud Push 10.5 ppg @ 5 bpm 1500 - Pump 29.3 bbls 15.8 ppg 137 sxs Class "G" yield 1.2 cu fVsx @ 5 bpm 1600 psi Displace with 35.7 bbls oil base mud @ 5 bpm 1600 psi @ 2 bpm 600 psi Pick up close HMCV - Pressure test HMCV to 1000 psi - Close Hydril reverse back 4 bbls into liner 1 bpm @ 490 psi - Pressure up with Dowell to 4630 to shear out drain sub - Circulate out cement - Reciprocating pipe 12 foot strokes- Estimated cement to surface 5 bbls - Cement strung out - lots of cuttings sand back - Set down on ZXP Packer - Test Liner top to 1000 psi for 10 mins with drill pipe open at surface monitoring returns - Test good 19:30 - 20:00 0.50 CASE P PROD1 Pick up - Break out Cementing lines - Break off Baker Cementing head - Pull 3 singles lay down 20:00 - 23:30 3.50 CASE P PROD1 CBU 5 X - Lots of sand and cuttings back - Circulate till shakers clean - 5 bpm @ 1800 psi - Reciprocate pipe 90 feet stroke - Displace Oil base mud with 9.6 Brine 5 bpm @ 1200 psi 23:30 - 00:00 0.50 CASE P PROD1 Monitor well - Well static - Clean out ditches and underneath shakers 7/9/2004 00:00 - 02:30 2.50 CASE P PROD1 Lay down 4" drill pipe from 4000' to Baker running tool 02:30 - 03:00 0.50 CASE P PROD1 Service break Baker running tool and lay down same 03:00 - 05:00 2.00 CASE P PROD1 Rig up to lay down 2 7/8" Inner string - Lay down Tubing - Inspect cups - Clear rig floor of all handling tools and equipment 05:00 - 09:00 4.00 CASE P PROD1 Change elevators to 4" - Lay down 4" drill pipe from derrick in mouse hole 09:00 - 10:00 1.00 CASE P PROD1 Cut drlg line - Rig service 10:00 - 11 :30 1.50 CASE P PROD1 Pull wear ring - Rig up to run 4.5" completion 11 :30 - 13:00 1.50 CASE P PROD1 Rig up I-Wire - Test 13:00 - 17:00 4.00 CASE P PROD1 Pick up - 4.5" completion with I-Wire to 3879' 17:00 - 18:30 1.50 CASE P PROD1 RIH from 3879' to 3912' Tag up space out - Make up hanger- Test I-Wire - Land tubing @ 3912' - PU 90 - SO 86 18:30 - 19:00 0.50 CASE P PROD1 Retest I-Wire - Torque up LDS - Drop ball and rod - Backout landing joint- Lay down same - Set TWC 19:00 - 19:30 0.50 CASE P PROD1 Clear rig floor 19:30 - 20:30 1.00 CASE P PROD1 Nipple down BOP's 20:30 - 21 :30 1.00 CASE P PROD1 Nipple up FMC 41/16" 5K Adapter Flange / CIW 41/8" 5K Tree - Test I-Wire - Test Tree / Adapter Flange to 5000 psi for 10 mins 21 :30 - 22:00 0.50 CASE P PROD1 Rig up to test Tubing and Annulus - Pull TWC 22:00 - 23:00 1.00 CASE P PROD1 Test Tubing to 4500 psi for 30 mins - Bleed to 3000 psi - Test Annulus to 4500 psi for 30 mins - Bleed off Annulus - Bleed off Tubing 23:00 - 23:30 0.50 CASE P PROD1 Install BPV in tree 23:30 - 00:00 0.50 CASE P PROD1 Secure well - Suck out cellar - Rig released at 00:00 hrs on 7/9/2004 Printed: 7/13/2004 9:11:55 AM . . Well: Field: API: Permit: MPJ-25 Milne Point Unit / Schrader Bluff 50-029-23207-00-00 204-073 Accept: Spud: Release: Rig: 06/26/04 06/27/04 07/09/04 Doyon 14 POST-RIG WORK 07/24/04 PULLED BALL& ROD, PULLED RP SHEAR VALVE, SET 1" DGLV, PULLED RHC PLUG BODY, SHIFTED SSD OPEN. WILL RETURN IN AM W/ FESCO, PUMP DOWN IA TO VERIFY SSD IS OPEN, AND SET JET PUMP. 07/25/04 VERIFIED SSD IS OPEN WITH PUMP TRUCK. SET 11 C JET PUMP (SER# BP-1111). NOTIFIED PAD OPERATOR OK TO POP WELL. PUMP 45 BBLS PRODUCED WATER DOWN IA TO LOAD WELL AND VERIFY INJECTIVITY THROUGH THE SSD. 33.6 BBLS TO CATCH FLUID ALLOWING 11.4 TO PASS THROUGH THE SSD. 07/27/04 WELL SUPPORT TECHS RIGGED UP AND PRESSURE TESTED THE PRODUCTION AND THE TEST LINES TO 1150 PSI AND THE POWER FLUID LINE TO 3500 PSI. 07/29/04 PUMP 30 BBLS CRUDE DOWN lA, 40 BBLS DIESEL DOWN TUBING TO FREEZE PROTECT WELL. 07/30/04 PULLED JET PUMP, FOUND SMALL AMOUNT OF METAL DEBRIS IN JET PUMP. ROCK SCREEN WAS COLLAPSED AND ALMOST COMPLETELY SEALED OFF, NOZZLE & THROAT APPEARED TO BE IN GOOD CONDITION. JET PUMP WAS CLEANED UP AND IS READY FOR REUSE. SET 11C JET PUMP (SER# BP-1036) W/ FLOW THROUGH SUB/BOMB HANGER ON BOTTOM IN PLACE OF THE ROCK SCREEN. 08/01/04 FREEZE PROTECT TBG.-IA AND SURFACE LINES. INITIAL-T/I/O=0/0/160. RIG UP TO IA AND ATTEMPT TO PUMP 30 BBLS OF CRUDE FOR FREEZE PROTECT. AFTER PUMPING 15 BBLS THE SURFACE PRESSURE WENT TO 3000 PSI. MONITOR lAP AND IT ONLY DROPPED 100 PSI IN 10 MINUTES. OPENED SSV AND PUMPED ANOTHER 15 BBLS OF CRUDE AND 50 BBLS OF DIESEL INTO THE IA. FINAL lAP WAS 2400 PSI. 08/03/04 PULLED (BP-1036) JET PUMP. BOMB HANGER FULL OF TEFLON RING PIECES AND METAL PIECES TOOK SAMPLE DRIFTED TUBING TO 4200' WLM. COULD NOT MAKE IT ANY FURTHER DO TO INCLINE. TOOLS PULLED HEAVY UNTIL JUST BELOW INTAKE PHEONIX. LIGHTENED UP BY ABOUT 450#. OOH W/ SAND, METAL CHUNKS, AND A PIECE OF RUBBER Legal Name: MPJ-25 Common Name: MPJ-25 6/26/2004 6/30/2004 7/5/2004 FIT FIT FIT 1.0 (ft) 2,430.0 (ft) 4,068.0 (ft) 1.0 (It) 2,377.0 (ft) 3,725.0 (ft) (ppg) 9.00 (ppg) 9.30 (ppg) (psi) 371 (psi) 620 (psi) (psi) 1,482 (psi) 2,420 (psi) (ppg) 12.00 (ppg) 12.50 (ppg) . . Printed: 7/13/2004 9:11:47 AM . . 15-Jul-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPJ-25 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: 3,997.97' MD 4,048.00' MD 8,348.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I U J}.rt"\ Signed Wðlw Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) J O'--(--Ol:> DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ·25 . Job No. AKZZ0003149211, Surveyed: 6 July, 2004 14 July, 2004 ~ o -1... ( o -.J V Your Ref: API 500292320700 Surface Coordinates: 6015136.98 N, 551902.91 E (70027'07.5495" N, 149034'35.4132" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1015136.98 N, 51902.91 E (Grid) Surface Coordinates relative to Structure Reference: 1718.45 N, 479.79 E (True) Kelly Bushing Elevation: 70. 14ft above Mean Sea Level Kelly Bushing Elevation: 70. 14ft above Project V Reference Kelly Bushing Elevation: 70. 14ft above Structure Reference SI:J:E!!!r'r'\I-SUf1 DAtL-L.tNG SSAVtc:eS A Halliburton Company Survey Ref: svy1431 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25 Your Ref: API 500292320700 Job No. AKZZ0003149211, Surveyed: 6 July, 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) 3997.97 45.730 301.840 3628.55 3698.69 674.45 N 850.24 W 6015805.49 N 551047.99 E 1073.55 Tie On Point 4048.00 46.570 302.540 3663.21 3733.35 693.67 N 880.77 W 6015824.50 N 551017.33 E 1.959 1109.60 Window Point 4127.49 54.000 303.000 3713.96 3784.10 726.75 N 932.14 W 6015857.22 N 550965.73 E 9.358 1170.64 4224.40 68.780 304.040 3760.24 3830.38 773.65 N 1002.84 W 6015903.62 N 550894.70 E 15.280 1255.31 4317.19 82.140 305.860 3783.49 3853.63 825.02 N 1076.27 W 6015954.48 N 550820.92 E 14.522 1344.59 . 4367.08 83.820 305.740 3789.58 3859.72 853.98 N 1116.43 W 6015983.16 N 550780.56 E 3.376 1393.85 4412.46 83.630 305.520 3794.54 3864.68 880.26 N 1153.09 W 6016009.19 N 550743.71 E 0.638 1438.74 4461.76 82.700 304.230 3800.41 3870.55 908.25 N 1193.25W 6016036.89 N 550703.36 E 3.211 1487.51 4507.52 85.180 302.650 3805.24 3875.38 933.32 N 1231.22W 6016061.70 N 550665.22 E 6.416 1532.92 4562.37 87.840 297.670 3808.58 3878.72 960.81 N 1278.54 W 6016088.86 N 550617.71 E 10.278 1587.65 1605.50 87.4 70 296.560 3810.35 3880.49 980.45 N 1316.89 W 6016108.24 N 550579.22 E 2.711 1630.69 4649.83 37.410 296.930 381233 3382.4 7 1000.40 N 1356.49 W 6016127.91 N 550539.49 E 0.844 1674.95 4699.07 87.160 295.650 3814.66 3884.80 1022.17 N 1400.54 W 6016149.37 N 550495.29 E 2.648 1723.98 4746.24 36'17 0 293310 3817.40 3887.54 1041.68 N 144339 W 6016168.58 N 550452.30 E 5.379 1770.85 ,¿;7~)'1 294.000 3°';1' h-' 3é~DD.65 1(1:5985 N 142-4.88 \IV 50'161(,)6.46 N 55041069 E 1.573 1815.87 ULU.0 ' 4848.96 85.490 293.540 3824.77 3894.91 1082.89 N 1537.19 W 6016209.14 N 550358.21 E 1.171 1872.69 4891.49 87.280 293.770 3827.46 3897.60 1099.92 N 1576.07 W 6016225.90 N 550319.22 E 4.243 1914.87 4938.86 92.970 294.380 3827.35 3897.49 1119.24 N 1619.30 W 6016244.91 N 550275.85 E 12.081 1961.97 4987.60 90.860 296.150 3825.72 3895.86 1140.03 N 1663.35 W 6016265.39 N 550231.66 E 5.649 2010.51 5036.46 88.770 295.530 3825.88 3896.02 1161.32N 1707.32 W 6016286.38 N 550187.54 E 4.462 2059.24 5083.82 90.430 296.610 3826.21 3896.35 1182.13 N 1749.86 W 6016306.89 N 550144.86 E 4.182 2106.49 5131.99 89.510 297.120 3826.24 3896.38 1203.90 N 1792.83 W 6016328.36 N 550101.74 E 2.184 2154.58 . 5180.17 91.240 296.890 3825.92 3896.06 1225.77 N 1835.75 W 6016349.94 N 550058.66 E 3.622 2202.70 5231.35 92.470 296.520 3824.27 3894.41 1248.76 N 1881.45 W 6016372.61 N 550012.81 E 2.510 2253.76 5275.10 90.740 294.650 3823.04 3893.18 1267.65 N 1920.89 W 6016391.22 N 549973.24 E 5.822 2297.36 5326.61 91.110 293.620 3822.21 3892.35 1288.71 N 1967.89 W 6016411.95 N 549926.09 E 2.124 2348.60 5369.64 88.400 290.790 3822.39 3892.53 1304.96 N 2007.72 W 6016427.93 N 549886.15 E 9.105 2391 .22 5415.93 87.590 290.560 3824.01 3894.15 1321.30 N 2051.00 W 6016443.96 N 549842.75 E 1.819 2436.87 5465.42 85.920 288.850 3826.81 3896.95 1337.96 N 2097.52 W 6016460.29 N 549796.13 E 4.826 2485.48 5515.57 87.530 288.530 3829.68 3899.82 1354.00 N 2144.94 W 6016476.01 N 549748.59 E 3.273 2534.57 5561.83 88.890 290.020 3831.12 3901.26 1369.26 N 2188.59 W 6016490.97 N 549704.84 E 4.360 2580.00 5611.44 89.630 290.810 3831.76 3901.90 1386.57 N 2235.08 W 6016507.94 N 549658.23 E 2.182 2628.91 5653.83 89.810 292.020 3831.97 3902.11 1402.04 N 2274.54 W 6016523.15 N 549618.66 E 2.886 2670.83 5712.07 90.250 292.970 3831.94 3902.08 1424.33 N 2328.35 W 6016545.05 N 549564.70 E 1.798 2728.57 5754.19 89.200 291.410 3832.14 3902.28 1440.23 N 2367.34 W 6016560.69 N 549525.59 E 4.464 2770.30 14 July, 2004· 15:20 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ·25 Your Ref: API 500292320700 Job No. AKZZ0003149211, Surveyed: 6 July, 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) 5803.07 87.530 289.060 3833.54 3903.68 1457.13 N 2413.18 W 6016577.27 N 549479.64 E 5.896 2818.44 5849.36 87.280 289.140 3835.63 3905.77 1472.26 N 2456.88 W 6016592.09 N 549435.84 E 0.567 2863.85 5900.97 87.410 287.670 3838.02 3908.16 1488.54 N 2505.80 W 6016608.03 N 549386.81 E 2.856 2914.35 5945.40 86.480 287.560 3840.39 3910.53 1501.96 N 2548.08 W 6016621.16 N 549344.43 E 2.108 2957.69 5995.42 88.150 286.360 3842.74 3912.88 1516.54N 2595.87 W 6016635.40 N 549296.54 E 4.110 3006.36 . 6041.77 88.020 286.180 3844.28 3914.42 1529.52 N 2640.34 W 6016648.07 N 549251.98 E 0.479 3051.36 6091.41 91.230 288.250 3844.61 3914.75 1544.21 N 2687.75 W 6016662.43 N 549204.47 E 7.694 3099.76 6138.96 91.300 289.280 3843.56 3913.70 1559.50 N 2732.76 W 6016677.41 N 549159.36 E 2.171 3146.39 6187.13 90.560 288.520 3842.78 3912.92 1575.10 N 2778.32 W 6016692.69 N 549113.68 E 2.202 3193.65 6233.94 91.480 284.690 3841.94 3912.08 1588.47 N 2823.17 W 6016705.75 N 549068.75 E 8.413 3239.17 628418 91.170 284.140 3840.78 391092 1600.97 ~! 2871.81 W 6016717.91 N 549020.02 E 1.256 328755 5330.81 92.4 70 283.900 3839.30 3909.44 1612.27 ~J 2917.03W 6016728.89 N 548974.72 E 2.835 333235 637986 92.290 283920 3837.26 3907.40 1624.05 ~~ 2964.60 W 6016740.34 N 548927.07 E 0.369 3379.44 (34;::7.30 91.230 284.790 3835.81 3905.95 1635.80 N 3010.53 W 6016751.77 ~i 548881.05 E 2.890 342510 38.700 286.3;~U :3905.98 1 648 8 ï 3057A7 W 60! 6764 5'~ 54i3834.02 E '5.()(37 3LL72.?9 6523.34 88.890 289.070 383ê.83 3906.97 1663.24 3"102.53 W 6016778.57 N 548788.87 E 5.825 3518.49 657258 89.380 292.130 3837.58 3907.72 1680.56N 3148.61 W 6016795.57 N 548742.67 E 6.293 3567.06 6619.97 91.170 294.340 3837.35 3907.49 1699.26 N 3192.15 W 6016813.96 N 548699.00 E 6.001 3614.12 6668.31 90.560 296.640 3836.62 3906.76 1720.06 N 3235.78 W 6016834.46 N 548655.23 E 4.922 3662.30 6716.32 89.630 299.580 3836.54 3906.68 1742.68 N 3278.12 W 6016856.78 N 548612.73 E 6.423 3710.28 6765.09 91.730 302.930 3835.96 3906.10 1767.97 N 3319.80 W 6016881.79 N 548570.87 E 8.106 3759.02 6812.83 92.470 305.390 3834.21 3904.35 1794.76 N 3359.28 W 6016908.30 N 548531.21 E 5.378 3806.60 . 6861.37 91.730 309.330 3832.43 3902.57 1824.19 N 3397.82 W 6016937.46 N 548492.46 E 8.254 3854.70 6907.05 90.620 312.860 3831.49 3901.63 1854.20 N 3432.24 W 6016967.23 N 548457.84 E 8.099 3899.51 6956.16 90.000 315.470 3831.23 3901.37 1888.42 N 3467.46 W 6017001.20 N 548422.38 E 5.462 3947.12 7003.15 91.050 320.670 3830.80 3900.94 1923.36 N 3498.85 W 6017035.92 N 548390.75 E 11 .289 3991.77 705268 90.120 320.400 3830.29 3900.43 1961.60 N 3530.33 W 6017073.94 N 548359.00 E 1.955 4038.15 7097.09 91 .400 320.320 3829.70 3899.84 1995.79 N 3558.66 W 6017107.93 N 548330.44 E 2.888 4079.78 7147.23 90.860 319.730 3828.71 3898.85 2034.21 N 3590.86 W 6017146.13 N 548297.97 E 1.595 4126.88 7195.46 90.000 318.610 3828.35 3898.49 2070.70 N 3622.39 W 6017182.40 N 548266.18 E 2.928 4172.43 7245.08 91 .480 315.420 3827.71 3897.85 2106.99 N 3656.22 W 6017218.45 N 548232.11 E 7.086 4219.87 7290.06 91.610 312.640 3826.50 3896.64 2138.24 N 3688.54 W 6017249.47 N 548199.56 E 6.185 4263.49 7340.02 90.800 310.130 3825.45 3895.59 2171.25 N 3726.02 W 6017282.23 N 548161.86 E 5.278 4312.45 7383.93 89.380 307.550 3825.38 3895.52 2198.79 N 3760.21 W 6017309.53 N 548127.47 E 6.707 4355.83 7437.44 90.190 305.400 3825.58 3895.72 2230.60 N 3803.24 W 6017341.03 N 548084.23 E 4.294 4409.00 14 July, 2004 - 15:20 Page 3 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25 Your Ref: API 500292320700 Job No. AKZZ0003149211, Surveyed: 6 July, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (OI100ft) 7481.60 91.110 301.670 3825.08 3895.22 2254.99 N 3840.04 W 6017365.17 N 548047.26 E 8.699 4453.06 7528.52 89.810 298.510 3824.70 3894.84 2278.51 N 3880.63 W 6017388.40 N 548006.51 E 7.282 4499.98 7578.27 89.380 295.340 3825.05 3895.19 2301.03 N 3924.98 W 6017410.62 N 547962.00 E 6.430 4549.65 7626.71 87.960 293.400 3826.18 3896.32 2321.01 N 3969.09 W 6017430.29 N 547917.75 E 4.962 4597.84 7672.31 90.370 294.170 3826.84 3896.98 2339.40 N 4010.81 W 6017448.39 N 547875.91 E 5.548 4643.16 . 7723.29 89.510 293.760 3826.89 3897.03 2360.11 N 4057.39 W 6017468.77 N 547829.18 E 1.869 4693.86 7770.03 89.940 293.230 3827.12 3897.26 2378.74 N 4100.25 W 6017487.10 N 547786.19 E 1.460 4740.29 7819.03 90.740 293.280 3826.83 3896.97 2398.09 N 4145.27 W 6017506.13 N 547741.03 E 1.636 4788.95 7867.06 89.750 292.540 3826.62 3896.76 2416.78 N 4189.51 W 6017524.52 N 547696.67 E 2.573 4836.62 7914.92 88.770 292.700 3827.24 3897.38 2435.19 N 4233.69 W 6017542.62 N 547652.36 E 2.075 4884.07 7962.83 90.620 294210 3827.50 38976L1 245426 N 4277.63 W 6017561.38 N 547608.28 E 4.984 493167 8011.62 90.740 295.960 3826.92 3897.06 2474.94 i'~ 432'1.82 W 60'17581.76 !\! 547563.96 E 3.595 4980.27 8059.20 90.870 297.73C 3826.25 3896.39 2L196.42 i--J 4364.26 W 6017602.94 N 547521.36 E 3.730 5027.78 8103.90 89.380 297 590 3826 '5 3896.29 2517.1: !\~ 4403.85 IN 6017:32342 ¡.J 547481.63 E 3.348 5072.44 8153.84 382f;,1 0 32-96.24 4448,::,~3 vv 5~1743f'.09 E :~í 32 8204.65 97.240 29/ 3822.56 3392.70 2563..2"';· f\~ 4493.29 W 601 ?f368.ßô 547391.88 E -,2.823 5172.92 8250.91 97.920 299.220 3816.46 3886.60 2585.00 N 4533.65 W 6017690.34 N 547351.37 E 4088 5218.75 8276.13 98.490 297.710 3812.86 3883.00 2596.89 N 4555.59 W 6017702.08 N 547329.34 E 6.342 5243.70 8348.00 98.490 297.710 3802.25 3872.39 2629.95 N 4618.52 W 6017734.69 N 547266.18 E 0.000 5314.73 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 300.0000 (True). . Based upon Minimum Curvature type calculations, at a Measured Depth of 8348.00ft., The Bottom Hole Displacement is 5314.82ft., in the Direction of 299.6590 (True). 14 July, 2004 - 15:20 Page 4 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25 Your Ref: API 500292320700 Job No. AKZZ0003149211, Surveyed: 6 July, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3997.97 4048.00 8348.00 3698.69 3733.35 3872.39 674.45 N 693.67 N 2629.95 N 850.24 W 880.77 W 4618.52 W Tie On Point Window Point Projected Survey . Survey tool program for MPJ·25 From To Measured Verticai Measured Vertical Depth DepÜ' Depth SUiVej Oescrjption :ft) (ft; ,.;..,C,. \'''j 0.00 531.00 u,uu 53 í .00 8348.00 530.84 CBSSGYi':;O (MPJ-25PB1) 3872.39 MWD+IIFR+MS (MPJ-25PB1) 530.84 . 14 July, 2004 - 15:20 Page 5 of 5 DrillQuest 3.03.06.002 . . 15-Jul-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPJ-25 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: 3,997.97' MD 4,048.00' MD 8,348.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date \ \ J.l¡/x\-\ Signed ~J ()IJ.J Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ .·l· ~'l> I'- Ò \.¡ ,. ok Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ-25 MWD . Job No. AKMW0003149211, Surveyed: 6 July, 2004 14 July, 2004 Your Ref: API 500292320700 Surface Coordinates: 6015136.98 N, 551902.91 E (70027' 07.5495" N, 149034' 35.4132" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . ~ ( o -1 V Surface Coordinates relative to Project H Reference: 1015136.98 N, 51902.91 E (Grid) Surface Coordinates relative to Structure Reference: 1718.45 N, 479.79 E (True) Kelly Bushing Elevation: 70. 14ft above Mean Sea Level Kelly Bushing Elevation: 70. 14ft above Project V Reference Kelly Bushing Elevation: 70. 14ft above Structure Reference C? (~ -. SpE!í'í'Y-SUI1 CFtIL.LING seRVices A Halliburton Company Survey Ref: svy1435 Halliburton Sperry-Sun " Survey Report for Milne Point MPJ - MPJ-25 MWD Your Ref: API 500292320700 Job No. AKMW0003149211, Surveyed: 6 July, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (OI100ft) 3997.97 45.730 302.420 3628.56 3698.70 678.16 N 847.71 W 6015809.22 N 551050.50 E 1073.22 Tie On Point 4048.00 46.570 302.540 3663.22 3733.36 697.54 N 878.14 W 6015828.38 N 551019.93 E 1.688 1109.26 Window Point 4127.49 54.000 303.100 3713.97 3784.11 730.67 N 929.48 W 6015861.16 N 550968.36 E 9.363 1170.29 4224.40 68.780 305.380 3760.25 3830.39 778.50 N 999.55 W 6015908.50 N 550897.97 E 15.389 1254.88 4317.19 82.140 309.720 3783.51 3853.65 833.18 N 1070.51 W 6015962.69 N 550826.62 E 15.089 1343.68 . 4367.08 83.820 310.500 3789.60 3859.74 865.08 N 1108.38 W 6015994.32 N 550788.53 E 3.708 1392.43 4412.46 83.630 310.020 3794.56 3864.70 894.23 N 1142.80 W 6016023.23 N 550753.91 E 1.132 1436.81 4461.76 82.700 308.660 3800.43 3870.57 925.26 N 1180.66 W 6016054.00 N 550715.84 E 3.326 1485.11 4507.52 85.180 308.130 3805.26 3875.40 953.52 N 1216.32 W 6016082.01 N 550679.98 E 5.541 1530.13 456237 87.840 302.440 380860 3878.74 985.13 N 1260.99 W 6016113.30 N 550635.09 E 11 .433 1584.61 4605.50 87.4 70 301.180 3810.37 3880.51 1007.84 N 1297.61 W 6016135.76 N 550598.31 E 3.042 1627.68 464988 87.41 (J 303.400 3812.35 3882.4Si 1031.53N 1335.09 IN 6016159.18 r~ 550560.67 E 4.999 1671. 98 4699.07 87.160 304.870 3814.68 3884.82 1059.10 N 1375.76 W 6016186.4 7 N 550519.81 E 3.028 1720.99 474624 86.'170 289.270 3817.44 38.87,52, 1080.46N 1417.53 \V 6016207.54 N 55C477,86 E 33.082 1767.87 "780 382D.:S\:; 1099 1·:: ?£~ 6016226.74 55C;4.'3C 27.49·] 1 4848.96 85.490 299.140 3824.83 3894.91 1128.91 N 1507.61 VV 6016255.37 N 550387.47 E 4.672 1870.09 4891.49 87.280 305.150 3827.51 3897.65 1151.49 N 1543.53 W 601627769 N 550351.39 E 14.717 1912.48 4938.86 92.970 284.930 3827.41 3897.55 1171.43N 1586.21 W 6016297.33 N 550308.58 E 44.326 1959.41 4987.60 90.860 304.970 3825.76 3895.90 1191.87N 1630.15 W 6016317.47 N 550264.50 E 41.318 2007.69 5036.46 88.770 291.040 3825.92 3896.06 1214.76 N 1673.18 W 6016340.06 N 550221.31 E 28.827 2056.39 5083.82 90.430 294.790 3826.25 3896.39 1233.19 N 1716.79W 6016358.19 N 550177.57 E 8.659 2103.38 5131.99 89.510 294.790 3826.27 3896.41 1253.39 N 1760.52 W 6016378.08 N 550133.70 E 1.910 2151.35 . 5180.17 91.240 305.890 3825.96 3896.10 1277.69 N 1802.03 W 6016402.09 N 550092.02 E 23.315 2199.45 5231.35 92.470 297.270 3824.30 3894.44 1304.45 N 1845.57 W 6016428.55 N 550048.30 E 17.004 2250.54 5275.10 90.740 301.330 3823.07 3893.21 1325.85 N 1883.70 W 6016449.68 N 550010.02 E 10.084 2294.26 5326.61 91110 300.310 3822.24 3892.38 1352.24 N 1927.93W 6016475.76 N 549965.61 E 2.106 2345.75 5369.64 88.400 285.250 3822.43 3892.57 1368.85 N 1967.48 W 6016492.09 N 549925.94 E 35.557 2388.31 5415.93 87.590 290.290 3824.05 3894.19 1382.96 N 2011.52 W 6016505.90 N 549881.80 E 11.021 2433.51 5465.42 85.920 286.830 3826.85 3896.99 1398.69 N 2058.35 W 6016521.30 N 549834.86 E 7.753 2481.93 5515.57 87.530 288.430 3829.71 3899.85 1413.85 N 2106.07 W 6016536.13 N 549787.05 E 4.522 2530.83 5561.83 88.890 296.810 3831.16 3901.30 1431.62 N 2148.71 W 6016553.60 N 549744.28 E 18.343 2576.65 5611.44 89.630 294.790 3831.80 3901.94 1453.21 N 2193.37 W 6016574.88 N 549699.47 E 4.336 2626.12 5653.83 89.810 294.790 3832.01 3902.15 1470.98 N 2231.85 W 6016592.38 N 549660.87 E 0.425 2668.33 5712.07 90.250 294.790 3831.98 3902.12 1495.40 N 2284.72 W 6016616.43 N 549607.83 E 0.755 2726.33 5754.19 89.200 294.790 3832.18 3902.32 1513.06N 2322.96 W 6016633.83 N 549569.47 E 2.493 2768.27 14 July, 2004 - 15:20 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25 MWD Your Ref: API 500292320700 Job No. AKMW0003149211, Surveyed: 6 July, 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) 5803.07 87.530 302.130 3833.58 3903.72 1536.33 N 2365.89 W 6016656.79 N 549526.38 E 15.394 2817.08 5849.36 87.280 299.310 3835.67 3905.81 1559.95 N 2405.64 W 6016680.14 N 549486.47 E 6.110 2863.32 5900.97 87.410 287.980 3838.07 3908.21 1580.59 N 2452.78 W 6016700.45 N 549439.18 E 21.931 2914.47 5945.40 86.480 287.460 3840.44 3910.58 1594.10 N 2495.05 W 6016713.66 N 549396.82 E 2.397 2957.82 5995.42 88.150 283.220 3842.78 3912.92 1607.31 N 2543.22 W 6016726.54 N 549348.56 E 9.101 3006.15 . 6041.77 88.020 284.460 3844.33 3914.47 1618.39 N 2588.20 W 6016737.30 N 549303.50 E 2.688 3050.64 6091.41 91.230 287.660 3844.66 3914.80 1632.12 N 2635.89 W 6016750.70 N 549255.72 E 9.130 3098.80 6138.96 91.300 289.350 3843.61 3913.75 1647.21 N 2680.96 W 6016765.47 N 549210.54 E 3.556 3145.39 6187.13 90.560 288.090 3842.83 3912.97 1662.66 N 2726.58 W 6016780.61 N 549164.82 E 3.033 3192.62 6233.94 91.480 283.090 384199 3912.13 1675.24 N 2771.65 W 6016792.87 N 54911966 E 10.859 3237.93 6284.18 91.170 280.460 3840.83 3910.97 1685.49 N 2820.81 W 6016802.78 N 549070.43 E 5.270 3285.64 633D.S"¡ 92.470 280.670 3839.35 3909.49 169403 N 286663 W 6016811.00 i'~ 54902'1.55 E 2.824 332959 6379.86 92.290 278.580 3837.3""; 3907.45 1702.23 ¡~ 2914.94 W 6016818.861\1 548976i8E 4.273 3375.53 ?~1?-:" 91.230 281040 3335.26 3906.00 1710.30 r,i 29f:1.56 \^J 60i 6826.61 I\! 5,18929.41 E 5.644 342003 0 '1720 S836,"1 1::2 E' oJ¿J.j4 88.89G 28, .830 3836.86 3907.02 1730.05 \j 3055.63 VV 60i 6845.7\ i~ 54b835.30 E 1.09í 35\ 1.28 6572.58 89.380 282.740 3837.62 3907.76 1740.53 N 3103.74 W 6016855.85 N 548787.12 E 2.099 3558.18 6619.97 91.170 286.810 3837.40 3907.54 1752.61 N 3149.55 W 6016867.61 N 548741.23 E 9.382 3603.90 6668.31 90.560 301.820 3836.66 3906.80 1772.46 N 3193.47 W 6016887.15 N 548697.17 E 31.073 3651.85 6716.32 89.630 300.640 3836.58 3906.72 1797.35 N 3234.52 W 6016911.76N 548655.95 E 3.129 3699.85 6765.09 91.730 305.600 3836.00 3906.14 1823.99 N 3275.35 W 6016938.11 N 548614.93 E 11.043 3748.53 6812.83 92.470 307.920 3834.25 3904.39 1852.53 N 3313.57 W 6016966.39 N 548576.52 E 5.098 3795.90 . 6861.37 91.730 312.310 3832.47 3902.61 1883.78N 3350.65 W 6016997.38 N 548539.22 E 9.166 3843.64 6907.05 90.620 313.560 3831.54 3901.68 1914.89 N 3384.09 W 6017028.25 N 548505.56 E 3.659 3888.15 6956.16 90.000 317.570 3831.27 3901.41 1949.95N 3418.46 W 6017063.07 N 548470.95 E 8.262 3935.45 7003.15 91.050 321.790 3830.84 3900.98 1985.77 N 3448.86 W 6017098.67 N 548440.30 E 9.254 3979.68 7052.68 90.120 322.560 3830.34 3900.48 2024.89 N 3479.23 W 6017137.58 N 548409.66 E 2.438 4025.55 7097.09 91.400 321.790 3829.75 3899.89 2059.96 N 3506.46 W 6017172.47 N 548382.18 E 3.363 4066.67 7147.23 90.860 322.330 3828.76 3898.90 2099.50 N 3537.29 W 6017211.79 N 548351.09 E 1.523 4113.13 7195.46 90.000 319.330 3828.40 3898.54 2136.88 N 3567.74 W 6017248.96 N 548320.37 E 6.4 71 4158.20 7245.08 91 .480 316.310 3827.75 3897.89 2173.64 N 3601.05 W 6017285.49 N 548286.80 E 6.777 4205.43 7290.06 91.610 314.950 3826.54 3896.68 2205.78 N 3632.50 W 6017317.41 N 548255.14 E 3.036 4248.73 7340.02 90.800 311.270 3825.49 3895.63 2239.91 N 3668.96 W 6017351.28 N 548218.44 E 7.541 4297.37 7383.93 89.380 310.440 3825.42 3895.56 2268.64 N 3702.17 W 6017379.77 N 548185.03 E 3.746 4340.49 7437.44 90.190 308.480 3825.62 3895.76 2302.64 N 3743.48 W 6017413.49 N 548143.49 E 3.963 4393.27 14 July, 2004 - 15:20 Page 3 of 5 Dril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25 MWD Your Ref: API 500292320700 Job No. AKMW0003149211, Surveyed: 6 July, 2004 Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 7481.60 91.110 306.140 3825.12 3895.26 2329.40 N 3778.60 W 6017440.01 N 548108.18 E 7528.52 89.810 302.160 3824.74 3894.88 2355.74 N 3817.42 W 6017466.07 N 548069.18 E 7578.27 89.380 302.860 3825.10 3895.24 2382.47 N 3859.37 W 6017492.51 N 548027.04 E 7626.71 87.960 303.950 3826.22 3896.36 2409.13N 3899.79 W 6017518.89 N 547986.43 E 7672.31 90.370 304.290 3826.89 3897.03 2434.71 N 3937.54 W 6017544.20 N 547948.51 E 7723.29 89.510 303.460 3826.94 3897.08 2463.12 N 3979.86 W 6017572.32 N 547905.99 E 7770.03 89.940 302.800 3827.16 3897.30 2488.67 N 4019.00 W 6017597.59 N 547866.67 E 7819.03 90.740 299.490 3826.87 3897.01 2514.01 N 4060.93 W 6017622.64 N 547824.56 E 7867.06 89.750 304.530 3826.67 3896.81 2539.46 N 4101.65 W 6017647.81 N 547783.67 E 791492 88.770 288.260 382729 3897.43 2560.66 N 4144.37 W 6017668.71 N 547740.81 E 7962.83 90.620 287.600 38.27.54 3897.68 257541 N 4189.95 W 6017683.14 N 547695.12 E i .62 90.740 287.600 3822,96 3897.10 2590.1 423645 W 6017697.57 1'1 547648.52 E 8059.20 90.870 302."760 3826.29 3896.43 26',0.34 i\J 4279.38 W 60 '17"7 17.45 1'1 547605.45 E 8103.90 89.380 305010 382619 3896.33 2635.25 Ì'.] 4316.49 W 5·17568.17 E 90. 3B96.:2¿, ;:,\.:1 752f.. ') ,.- "-_ c 8204.65 97.240 296./ SO ¿¿¿L.U! 3892. ï 5 2Ò8G.;Jj I',·. 4402.69 VV 601 7793.20 ¡~ 541481.61 E 8250.91 97.920 298.570 3816.50 3886.6"· 27m3 2j N 4443.30 W 6017814.20 N 547440.85 E 8276.13 98.490 296.820 3812.91 3883.05 2719.84i~ 4465.40 W 6017825.65 I~ 547418.67 E 8348.00 98.490 296.820 3802.29 3872.43 2751.91 N 4528.84 W 6017857.28 N 547355.01 E 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 300.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8348.00ft., The Bottom Hole Displacement is 5299.38ft., in the Direction of 301.285° (True). 14 July, 2004 - 15:20 Page 4 of 5 BPXA Dogleg Vertical Rate Section Comment (OI100ft) 5.693 4437.06 8.923 4483.85 1.651 4533.55 3.695 4581.89 5.337 4627.36 . 2.344 4678.22 1.685 4724.89 6.949 4773.87 10.694 4821.86 34.053 486946 4.100 4916.31 0.246 4963.96 31.860 5011.22 6037 :,c':::i5.82 15.314 5 Lj6.J2 4168 5.2021 3 7.230 5227.07 0.000 5298.04 Projected Survey . DrillQuest 3.03.06.002 Milne Point Unit Comments Measured Depth (ft) 3997.97 4048.00 8348.00 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25 MWD Your Ref: API 500292320700 Job No. AKMW0003149211, Surveyed: 6 July, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3698.70 3733.36 3872.43 678.16 N 697.54 N 2751.91 N Comment 847.71 W 878.14 W 4528.84 W . Tie On Point Window Point Projected Survey Survey tcol proqram for J\1PJ-25 M~'VD Measured Depttl 0.00 531.00 14 July, 2004 - 15:20 en Vertical Depth lJ.JCì 530.84 Tc Measured Depth Vertic,,! Depth 53·1.00 530.84 3872.43 8348.00 Survey Tool Description CB-SS-GY!:ZO \iVli'J-25PB I iVlvVúj MWD Magnetic (MPJ-25PB1 MWD) . Page 5 of 5 DrillQuest 3.03.06.002 . . 15-Jul-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPJ-25 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 4,800.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ¡ l Jl?.1t" Please call me at 273-3545 if you have any questions or concerns. Regards, Signed tLJ. ð~ William 1. Allen Survey Manager Attachment(s) d--O+ Ö7J .. Halliburton Sperry-Sun DEFINITIVE Milne Point Unit BPXA Milne Point MPJ MPJ-25PB1 . Job No. AKZZ0003149211, Surveyed: 2 July, 2004 Survey eport 14 July, 2004 Your Ref: API 500292320770 Surface Coordinates: 6015136.98 N, 551902.91 E (70027' 07.5495" N, 149034' 35.4132" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1015136.98 N, 51902.91 E (Grid) Surface Coordinates relative to Structure Reference: 1718.45 N, 479.79 E (True) Kelly Bushing Elevation: 70. 14ft above Mean Sea Level Kelly Bushing Elevation: 70. 14ft above Project V Reference Kelly Bushing Elevation: 70. 14ft above Structure Reference spef""'f""'Y-SUI'1 DRIL.l"ING seRVices A Halliburton Company Survey Ref: svy1430 Halliburton Sperry-Sun ,. Survey Report for Milne Point MPJ - MPJ-25PB1 Your Ref: API 500292320770 Job No. AKZZ0003149211, Surveyed: 2 July, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -70.14 0.00 0.00 N 0.00 E 6015136.98 N 551902.91 E 0.00 CB-SS-GYRO 114.00 0.000 0.000 43.86 114.00 0.00 N 0.00 E 6015136.98 N 551902.91 E 0.000 0.00 171.00 0.900 176.000 100.86 171.00 0.45S 0.03 E 6015136.53 N 551902.94 E 1.579 -0.25 260.00 0.800 163.000 189.85 259.99 1.74 S 0.26 E 6015135.24 N 551903.18 E 0.243 -1.10 350.00 0.800 50.000 279.84 349.98 1.94 S 0.93 E 6015135.05 N 551903.85 E 1 .482 -1.77 . 440.00 2.000 28.000 369.82 439.96 0.14 S 2.15 E 6015136.85 N 551905.06 E 1.437 -1.93 531.00 3.600 13.000 460.70 530.84 4.04 N 3.53 E 6015141.05 N 551906.42 E 1.919 -1.04 MWD+IIFR+MS 561 .71 4.330 11.240 491.34 561.48 6.12 N 3.98 E 6015143.13 N 551906.84 E 2.410 -0.38 651.03 7.670 3.810 580.16 650.30 15.38 N 5.03 E 6015152.39 N 551907.83 E 3.831 3.33 748.72 8.450 1.600 676.88 747.02 29.06 N 5.66 E 6015166.07 N 551908.37 E 0.859 9.62 844.77 8.780 349.470 77186 842.00 43.32 N 4.52 E 6015180.33 N 551907.13 E 1.919 17.74 941.07 7.810 338.750 867.16 937.30 56.64 N 0.81 E 6015193.63 N 551903.32 E 1.891 27.62 1036.55 6.280 333.890 961.91 1032.05 67.38 N 3.84W 6015204.33 N 551898.60 E 1.718 37.02 1131.41 6.620 335.330 1056.17 1126.31 n01 N 8.41 W 6015213.93 N 551893.96 E 0.397 45.79 122"7.12 6.980 333.600 1151.21 1221.35 87.23 N '13.30W 6015224.11 N 551889.00 E 0.433 55.13 1323.44 6.280 335.550 1246.88 1317.02 97.27 N 18.08 W 6015234.12 N 551884.15 E 0,763 64.29 1419.93 6.190 336.560 1342.80 1412.94 106.84 N 22.33 W 6015243.67 N 551879.83 E 0.147 72.76 1515.45 6.130 337.040 1437.77 1507.91 116.27 N 26.37 W 6015253.06 N 551875.73 E 0.083 80.97 1611.25 6.480 337.390 1532.99 1603.13 125.97 N 30.45 W 6015262.73 N 551871.59 E 0.368 89.35 1707.08 7.670 340.360 1628.09 1698.23 136.98 N 34.67 W 6015273.72 N 551867.28 E 1.299 98.52 1802.79 8.990 332.160 1722.79 1792.93 149.61 N 40.31 W 6015286.31 N 551861.56 E 1.852 109.72 1899.85 9.840 330.220 1818.55 1888.69 163.51 N 47.97 W 6015300.16 N 551853.80 E 0.935 123.30 . 1995.27 9.760 329.660 1912.57 1982.71 177.57 N 56.11 W 6015314.16 N 551845.56 E 0.130 137.38 2091.79 11.410 320.990 2007.45 2077.59 192.05 N 66.25 W 6015328.57 N 551835.32 E 2.371 153.40 2187.92 12.220 316.770 2101.55 2171.69 206.85 N 79.21 W 6015343.28 N 551822.26 E 1.232 172.02 2284.03 13.680 318.760 2195.21 2265.35 222.81 N 93.67 W 6015359.13 N 551807.69 E 1.588 192.52 2351.93 13.830 318.530 2261.16 2331.30 234.93 N 104.33 W 6015371.18 N 551796.94 E 0.235 207.82 2399.00 14.320 316.950 2306.82 2376.96 243.40 N 112.03 W 6015379.59 N 551789.18 E 1.323 218.72 2468.96 15.040 314."780 2374.50 2444.64 256.12 N 124.38 W 6015392.22 N 551776.75 E 1.295 235.78 2562.84 15.670 311.890 2465.03 2535.17 273.16 N 142.47 W 6015409.14 N 551758.54 E 1.056 259.96 2659.08 17.800 309.040 2557.19 2627.33 291.11 N 163.57 W 6015426.94 N 551737.32 E 2.371 287.21 2755.66 23.490 307.280 2647.53 2717.67 312.08 N 190.37 W 6015447.73 N 551710.37 E 5.926 320.91 2850.57 28.880 303.940 2732.67 2802.81 336.35 N 224.47 W 6015471.76 N 551676.11 E 5.885 362.57 2947.84 32.700 299.660 2816.23 2886.37 362.48 N 266.81 W 6015497.60 N 551633.59 E 4.525 412.30 3044.01 35.970 297.490 2895.63 2965.77 388.38 N 314.45 W 6015523.16 N 551585.76 E 3.630 466.51 14 July, 2004·15:20 Page 20f4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun .. Survey Report for Milne Point MPJ - MPJ-25PB1 Your Ref: API 500292320770 Job No. AKZZ0003149211, Surveyed: 2 July, 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) (01100ft) 3138.39 35.490 296.860 2972.25 3042.39 413.56 N 363.48 W 6015548.00 N 551536.56 E 0.641 521.56 3234.03 36.040 297.120 3049.85 3119.99 438.93 N 413.29 W 6015573.02 N 551486.57 E 0.597 577.38 3331.38 35.370 297.380 3128.90 3199.04 464.94 N 463.80 W 6015598.68 N 551435.89 E 0.706 634.13 3426.45 36.760 296.690 3205.75 3275.89 490.37 N 513.65 W 6015623.76 N 551385.86 E 1.523 690.02 3522.57 39.750 296.410 3281.22 3351.36 516.97 N 566.88 W 6015649.99 N 551332.44 E 3.116 749.42 . 3618.57 42.140 298.11 0 3353.73 3423.87 545.80 N 622.79 W 6015678.43 N 551276.33 E 2.747 812.25 3712.72 41.540 299.200 3423.87 3494.01 575.91 N 677.90 W 6015708.15 N 551221.01 E 1.001 875.03 3807.80 42.930 299.520 3494.27 3564.41 607.25 N 733.60 W 6015739.10 N 551165.10 E 1.479 938.94 3904.04 45.840 299.220 3563.04 3633.18 640.25 N 792.26 W 6015771.70 N 551106.21 E 3.032 1006.24 3997.97 45.730 301.840 3628.55 3698.69 674.45 N 850.24 W 6015805.49 N 551047.99 E 2.003 1073.55 4093.07 47.340 303.150 3693.97 3764.11 711.53 N 908.45 W 6015842.17 N 550989.53 E 1.966 1142.50 4187.74 48.430 305.200 3757.46 3827.60 750.98 N 966.53 W 6015881.21 N 550931.17 E 1.976 1212.54 4284.29 48.750 305.960 3821.32 3891.46 793.12 N 1025.43 W 6015922.94 N 550871.98 E 0.677 1284.60 4381.12 50.270 305920 3884.19 3954.33 83634 N 108505 W 6015965.74 N 550812.06 E 1.570 1357.85 4476.ri 50.990 305.nO 3944.49 4014.63 879.05 N ì 144.83 W 601600804 N 550751.98 E 0.973 1430.98 4572.75 52490 305.280 4004.29 4074.43 922.79 N 1206.78 W 6016051.34 hi 550689.73 E 1.556 1506.50 4668.30 51.840 304.660 4062.90 4133.04 966.05 N 1268.62 W 6016094.17 N 550627.59 E 0.852 1581.68 4733.33 52.130 303.860 4102.95 4173.09 994.89 N 1310.96 W 6016122.71 N 550585.05 E 1.067 1632.77 4800.00 52.130 303.860 4143.88 4214.02 1024.21 N 1354.67 W 6016151.73 N 550541.14 E 0.000 1685.28 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 300.0000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4800.00ft., The Bottom Hole Displacement is 1698.27ft., in the Direction of 307.0910 (True). 14 July, 2004 - 15:20 Page 3 of4 Dri/lQuest 3.03.06.002 ... Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25PB1 Your Ref: API 500292320770 Job No. AKZZ0003149211, Surveyed: 2 July, 2004 Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4800.00 4214.02 1024.21 N 1354.67 W Projected Survey . Survey tool program for MPJ-25PB1 From Measured Vertical Depth Depth (It) (ft) To Measured Depth (ft) Vertical Depth (ft) Survey Too! Description C.OO 53'1.00 000 530.84 531,00 4800.00 530,84 CB-SS-GYRO 4214.02 MWD+IIFR+MS . 14 July, 2004 - 15:20 Page 4 of 4 DrillQuest 3.03.06.002 . . 15-Jul-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPJ-25 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 4,800.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 f 7/ /' (\ j I Date ,~ ,)~ lJ.W1 Signed j~ úð.M4 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ;1 Ð L(_ 07 > ... Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPJ MPJ-25PB1 MWD . Job No. AKMW0003149211, Surveyed: 2 July, 2004 '>ù D (' - 14 July, 2004 l o -J v-J Your Ref: API 500292320770 Surface Coordinates: 6015136.98 N, 551902.91 E (70027' 07.5495" N, 149034' 35.4132" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1015136.98 N, 51902.91 E (Grid) Surface Coordinates relative to Structure Reference: 1718.45 N, 479.79 E (True) Kelly Bushing Elevation: 70. 14ft above Mean Sea Level Kelly Bushing Elevation: 70. 14ft above Project V Reference Kelly Bushing Elevation: 70. 14ft above Structure Reference SpE!r"r")/-SUI'1 DRIL.L..ING seRVices A Halliburton Company Survey Ref: svy1434 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25PB1 MWD Your Ref: API 500292320770 Job No. AKMW0003149211, Surveyed: 2 July, 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) (01100ft) 0.00 0.000 0.000 -70.14 0.00 0.00 N 0.00 E 6015136.98 N 551902.91 E 0.00 CB-SS-GYRO 114.00 0.000 0.000 43.86 114.00 0.00 f\1 0.00 E 6015136.98 N 551902.91 E 0000 000 171.00 0.900 176.000 100.86 171.00 0.45 S 0.03 E 6015136.53 N 551902.94 E 1.579 -0.25 260.00 0.800 163.000 189.85 259.99 1.74 S 0.26 E 6015135.24 N 551903.18 E 0.243 -1.10 350.00 0.800 50.000 279.84 349.98 1.94 S 0.93 E 6015135.05 N 551903.85 E 1 .482 -1.77 . 440.00 2.000 28.000 369.82 439.96 0.14 S 2.15 E 6015136.85 N 551905.06 E 1.437 -1.93 531.00 3.600 13.000 460.70 530.84 4.04 N 3.53 E 6015141.05 N 551906.42 E 1.919 -1.04 MWD Magnetic 561.71 4.330 12.070 491.34 561.48 6.11 N 3.99 E 6015143.12 N 551906.86 E 2.386 -0.40 651.03 7.670 4.020 580.16 650.30 15.36 N 5.12 E 6015152.38 N 551907.92 E 3.847 3.25 748.72 8.450 1.320 676.89 747.03 29.04 N 5.74 E 6015166.06 N 551908.45 E 0.887 9.55 844.77 8.780 349.200 771.86 842.00 43.30 N 4.53 E 6015180.31 N 551907.14 E 1.917 17.73 941.07 7.810 338.400 867.16 937.30 56.60 N 0.74 E 6015193.59 N 551903.26 E 1.902 27.66 1036.55 6.280 333.390 961.91 1032.05 67.30 N 3.99W 6015204.25 N 551898.46 E 1.725 37.10 1131.41 6.620 334.610 1056.17 1126.31 76.88 N 8.65W 6015213.80 N 551893.72 E 0.386 45.94 1227.12 6.980 333.250 1'151.21 Î 22: .35 87.061\1 13.64 VI! Ö015223.94 N 551888.67 E 0.412 55.3·:1 ~i 323.44 335.37'0 246.88 97.071\! 18Al c;015233.92 N 55'188377 to no 64.53 1419.93 6.190 336.i 00 1342.80 '\412.94 1 06.63 r~ 22.77 VV 6015243.45 N 551879.39 L 0.124 73.04 1515.45 6.130 337.130 1437.77 1507.91 116.03 N 26.84 W 6015252.82 N 551875.26 E 0.132 81.26 1611.25 6.480 337.180 1532.99 1603.13 125.73 N 30.93 W 6015262.49 N 551871.11E 0.365 89.65 1707.08 7.670 340.700 1628.09 1698.23 136.75 N 35.14 W 6015273.48 N 551866.82 E 1.321 98.81 1802.79 8.990 332.480 1722.79 1792.93 149.41 N 40.71 W 6015286.10 N 551861.17 E 1.854 109.96 1899.85 9.840 330.270 1818.55 1888.69 163.34 N 48.32 W 6015299.98 N 551853.45 E 0.952 123.52 . 1995.27 9.760 330.040 1912.57 1982.71 177.43 N 56.40 W 6015314.01 N 551845.27 E 0.093 137.56 2091.79 11.410 321.460 2007.45 2077.59 191.98 N 66.44 W 6015328.50 N 551835.13 E 2.360 153.53 2187.92 12.220 317.570 2101.55 2171.69 206.93 N 79.23 W 6015343.35 N 551822.24 E 1.181 172.08 2284.03 13.680 318.870 2195.21 2265.35 223.00 N 93.57 W 6015359.32 N 551807.79 E 1.549 192.53 2351.93 13.830 319.450 2261.16 2331.30 235.21 N 104.13 W 6015371.46 N 551797.15 E 0.300 207.78 2399.00 14.320 316.950 2306.82 2376.96 243.74 N 111.76W 6015379.94 N 551789.46 E 1.659 218.66 2468.96 15.040 315.090 2374.50 2444.64 256.49 N 124.07 W 6015392.60 N 551777.06 E 1.230 235.70 2562.84 15.670 312.170 2465.03 2535.17 273.63 N 142.07 W 6015409.62 N 551758.94 E 1.062 259.85 2659.08 17.800 309.610 2557.19 2627.33 291.74N 163.04 W 6015427.58 N 551737.85 E 2.341 287.06 2755.66 23.490 308.330 2647.53 2717.67 313.10 N 189.53 W 6015448.76 N 551711.20E 5.910 320.69 2850.57 28.880 304.860 2732.67 2802.81 337.96 N 223.20 W 6015473.37 N 551677.36 E 5.902 362.28 2947.84 32.700 300.080 2816.23 2886.37 364.56 N 265.23 W 6015499.69 N 551635.14 E 4.661 411.98 3044.01 35.970 297.310 2895.64 2965.78 390.55 N 312.82 W 6015525.34 N 551587.37 E 3.768 466.19 14 July, 2004 - 15:39 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25PB1 MWD Your Ref: API 500292320770 Job No. AKMW0003149211, Surveyed: 2 July, 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) 3138.39 35.490 295.310 2972.25 3042.39 414.98N 362.22 W 6015549.43 N 551537.81 E 1.338 521.18 3234,03 36CiO 297.490 3049.86 3120.00 439.84 N 412.28 If\! 6015573.94 N 551487.58 E 1 .451 576.96 3331.38 35.370 297.580 3128.91 3199.05 466.10 N 462.66 W 6015599.85 N 551437.02 E 0.690 633.73 3426.45 36.760 296.980 3205.76 3275.90 491.75 N 512.40 W 6015625.15 N 551387.10 E 1.509 689.63 3522.57 39.750 297.080 328123 335'¡ .37 5í8.80~~ 565.41 VV 601565182 N 551333.90 E 3.111 749.06 . 3618.57 42.140 298.320 3353.74 3423.88 548.05 N 621.10 W 6015680.69 N 551278.01 E 2.629 811.91 3712.72 41.540 299.730 3423.88 3494.02 578.52 N 676.01 W 6015710.77 N 551222.89 E 1.185 874.70 3807.80 42.930 299.600 3494.28 3564.42 610.15 N 731.54 W 6015742.02 N 551167.13 E 1 .465 938.61 3904.04 45.840 299.690 3563.05 3633.19 643.44 N 790.04 W 6015774.90 N 551108.41 E 3.024 1005.92 3997.97 45.730 302.420 3628.56 3698.70 678.16 N 847.71 W 6015809.22 N 551050.50 E 2.086 1073.22 4093.07 47.340 304.070 3693.98 3764.12 716.01 N 905.42 W 6015846.66 N 550992.53 E 2.110 1142.12 4187.74 48.430 306.430 3757.47 3827.61 756.54 N 962.75 W 6015886.80 N 550934.91 E 2.178 1212.04 4284.29 48.750 306.520 3821.33 3891.47 799.59 N 1020.98 W 6015929.44 N 550876.39 E 0.339 1283.99 4381.12 50.270 306.600 3884.20 3954.34 843.46 N 1080.13 W 6015972.89 N 550816.93 E 1.571 1357.15 76. j~' 305.630 39443,0 10·'~;J4 8136.1'5 N -1 "j :39.49 6016015.73 ~~ ~j50757 .27 E 1.094 ·,430.21 93·1.~~¡O N 60'¡6CbD.'J9 r\j 550695.CG 1.700 505.62 4668.30 5 L840 306.810 4062.91 4133.05 976.44 N 1261.34 VV 6016104.61 N 550634.80 E 0.733 i 580.57 4733.33 52.130 304.890 4102.96 4173.10 1006.44 N 1302.87 W 6016134.32 N 550593.07 E 2.368 1631.53 4800.00 52.130 304.890 4143.89 4214.03 1036.54 N 1346.04 W 6016164.12 N 550549.69 E 0.000 1683.97 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical deptrs are relative to Well. Northings and Eastings are relative to Well. Global Nor·things 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 300.000° (True). . Based upon Minimum Curvature type calculations, at a Measured Depth of 4800.00ft., The Bottom Hole Displacement is 1698.89ft., in the Direction of 307.599° (True). 14 July, 2004 - 15:39 Page 3 of4 Dri/lQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPJ - MPJ-25PB1 MWD Your Ref: API 500292320770 Job No. AKMW0003149211, Surveyed: 2 July, 2004 Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4800.00 4214.03 1036.54 N 1346.04 W Projected Survey . Survey tool program for MPJ-25PB1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 53LOO 53C.84 CB-SS-CYRO 4214.03 MWD Magnetic 531.00 530.84 4800.00 . 14 July, 2004 - 15:39 Page 4 of 4 DrillQuest 3.03.06.002 Re: BPXA, MPJ-25 . . Subject: Re: BPXA, MPJ-25 d()~ -0 ~ ~ From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 01 Jul2004 08:32:41 -0800 To: "Coyner, Skip (NATCHIQ)" <coynsO@BP.com> CC: "Archey, Pat" <ArcheyPJ@BP.com> Skip and Pat, How did the LOT pressure curve look?? Was the slope steady up to 12.0 EMW and then a sharp break or did the pressure just decline after pumping was stopped?? Based on what the L WD showed you, it would think the latter. You have established that the open interval below the shoe will hold 10.0 EMW which is 1.0 ppg higher than your planned mud weight and 1.5 ppg above the maximum anticipated formation pressure. ECD may add to the EMW, but it is unlikely that there would be 1.0 ppg EMW additional seen by the interval tested. It is likely that filter cake will build up over the sand intervals and possibly improve the "formation strength" as drilling proceeds. Your only other alternative would be to set the intermediate casing early, prior to drilling the Schrader Bluff. It appears that you have evaluated the information and determined a valid plan forward. Please call with any questions. Tom Maunder, PE AOGCC Coyner, Skip (NATCHIQ) wrote: I left you a phone message at +/- 5:00 pm yesterday about the shoe test on MPJ-25. As programmed, we tested to a 12.0 ppg EMW, however, it bled down to 10.0 ppg EMW in +/-10 minutes. BP does not believe that the cement job is bad and has elected to drill ahead. The pilot hole will only penetrate the Ugnu & Schrader Bluff sections which has BHP = 8.4 ppg EMW. We will drill this pilot hole with at least 9.0 ppg mud and we plan to pump out of the hole to prevent swabbing. In that the Schrader Bluff, etc. are often drilled with diverter only and because there is minimal risk of hydrates on J Pad, BP believes that drilling ahead is safe and prudent in this case. After the LWD's logged the hole below the shoe, it was apparent that the shoe is not in a shale. It is in silt & sand. As such, any attempt to squeeze the shoe would most likely have little or no effect. Skip Coyner 6IP ~c~~; Energy SIII'VIceII 907-564-4395 BPXA 907-748-3689 cell 1 of 1 7/1/20048:32 AM . . FRANK H. MURKOWSKI, GOVERNOR .AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point Unit MPJ-25 BP Exploration (Alaska) Inc. Permit No: 204-073 Surface Location: 2741' NSL, 3413' WEL, SEe. 28, T13N, RlOE, UM Bottomhole Location: 156' NSL, 2815' WEL, SEe. 20, 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. In accordance with 20 AAC 25.005 (f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name J-25PH and API number 50-029-23207-70 from records, data and logs acquired for well Milne Point Unit J-25. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659 7 (pager). Si e ly, BY ORDER O~ THE COMMISSION DATED this1!t day of May, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. B Drill 0 Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: / 2741' NSL, 3413' WEL, SEC. 28, T13N, R10E, UM (As Staked) Top of Productive Horizon: 3815' NSL, 4941' WEL, SEC. 28, T13N, R10E, UM Total Depth: 156' NSL, 2815' WEL, SEC. 20, T13N, R10E, UM' I STATE OF ALASKA . RE·· ~ ALASKA· IL AND GAS CONSERVATION COMMISSION CErVED PERMIT TO DRILL MAY 0 3 2004 20 MC 25.005 AluL< nil íI.. r. ----c r. .. 1b. Current Well Class 0 Exploratory B I~H~\~18e~ñto1t'cl'ilij~fî¢éI~8H~SIOn o Stratigraphic Test 0 Service 0 Development <?f\IJ!lcia~ele Zone 5. Bond: a Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 MPJ·25 6. Proposed Depth: 12. Field I Pool(s): MD 8458' ,/ TVD 3885' Milne Point Unit I Schrader Bluff 7. Property Designation: ADL 025515 ) t'-z.~-'icf7 8. Land Use Permit: jb d 6-~/()'C" 13. Approximate Spud Date: 05/20/04 9. Acres in Property: 2560 14. Distance to Nearest Property: 8040' 4b. Location of Well (State Base Plane Coordinates): Surface: x-551903/ y-6015138" Zone-ASP4 16. Deviated Wells: Kickoff Depth 18. Casing Program Size Casinç¡ 20" 10-3/4" 7-5/8" 13-1/2" 9-7/8" 6-3/4" 4-1/2" x 5" x 4" Weiç¡ht 92# 45.5# 29.7# 12.7# Maximum Hole Angle 91,300 Specifications Grade Couplinç¡ H-40 Weld L-80 BTC L-80 BTC-M L-80 IBT-M IIBT Lenç¡th 80' 2350' 4000' 4525' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plann:g;BE = feet 260' away from MPJ-09A 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 1781./ psig Surface: 1372' psig Setting OepthQuantity of Cement Top> Bottom (c.t or sack$) MD TVD MD TVD (includinç¡ staç¡e data) 34' 34' 114' 114' 260 sx Arctic Set (Approx.) 32' 32' 2382' 2360' 422 sx Arctic Set Lite, 260 sx 'G' 30' 30' 4030' 3729' 275 sx Class 'G' 3930' 3665' 8455' 3860' 98 sx Class 'G' {Banzai Cm! Job and Sand Screens~ 300 ft Hole 42" 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments 0 Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): a Drilling Program 0 Time vs Depth Plot o Seabed Report a Drilling Fluid Program Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer f ak --.s Phone o Shallow Hazard Analysis a 20 MC 25.050 Requirements Date: Contact Sk~ 2oyr;er, 564-4152 ~p5t~umber Sondra Stewman, 564-4750 Permit To Drill , / .. "_ 3 API Number: 3 "- Number: ;2.L.:::'f.c, 7. 50- é>;?f-l- 2.. Zö7··C-)(..J Conditions of Approval: Samples Required Yes ~o Hydrogen Sulfide Measures [J Yes ®No Other' \-.\ C F'ti '" ~ ~\) . \ ", '\ . '\'-..<;> ~>= "(" , ' " '-J X; \\ê s, ~ ~ ~ Q" t'...Q' I;.j \ Permit AP..B!"9(al{) Þ . I Date: -:)) -, '-I Mud Log Req ired Directional Survey Required See cover letter for other requirements DYes ~o ~es D No ORIG\NAL BY ORDER OF THE COMMISSION oate~~~e/ · I II~e Point MPJ-25 Well Permit I Well Name: I MPJ-25 Drill and Complete Plan Summary I Type of Well (service / prod~er / injector): I Horizontal Schrader Bluff "NB" Producer Surface Location: 2741' FSL & 3413' Fa:: SEC. 28, T13N, R10E, UM .I E = 551 ,903.29' N = 6,015,137.64' 1547' FNL & 581' FWL, SEC. 28, T13N, R10E, UM E = 550,608.87' N = 6,016,119.82' Z = 4,170' TVD /1465' FNL & ~~WL, SEC. 28, T13N, R1OE, UM E .1550 ' 365.2'2'-/N = 6,016,200.84' Z = 3,885' TVD 156' FSL & 2465' FWL, SEC. 20, T13N, R10E, UM / E = 547,196.69' N = 6,017,801.10' Z = 3,860' TVD 8040 ft to Unit Boundary 260 ft to nearest "NB" penetration: MPJ-09A Target Location: Pilot Hole Target Location: "NB" T1 Entry (heel) Target Location: BHL Well TD (toe) Distance to Property line Distance to nearest pool 1 AFE Number: I I Rig: I Doyon 14 1 Estimated Start Date: I May 20 2004 I Operating days to complete: 110 I Pilot Hole: 1 MD: 14708' 1 I TVD: 14170' I Max Inc: 1 49.50 I I KOP: 1 300' 1 I Lateral: I MD: 18458' 1,1 I TVD: 13885' I,; I Max Inc: I 91.3° I I KOP: 14050' 1 1 Design: a) Pilot Hole: Build & Hold. ,b) "NB" Horizontal Producer 0/ I I Objective: Schrader Bluff "NB" Sand Horizontal Producer I Mud Program: 13-1/2" Surface Hole Mud Properties: Density (ppg) I Funnel Vis YP 8.6 - 9.0 75 - 150 25 - 60 HTHP N/A 9-7/8" Intermediate Hole Mud Properties: Density (ppg) PV YP HTHP 8.8 - 9.3 15 - 20 20 - 25 10- 12 6-3/4" Production Hole Mud Properties: Density (ppg) PV YP HTHP 8.9 - 9.3 15 - 20 15 - 20 <4 Spud - LSND Freshwater Mud pH API Filtrate I LG Solids 8.5-9.5 <15 <12 LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 6 < 10 Oil Base Mud ES O/w Ratio LG Solids 600 - 900 80 / 20 < 10 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation 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 · 'ne Point MPJ-25 Well Permit Cement Program: Casing Size: Basis for Volume Calculations: Total Cement Volume: 387 bbl Open Hole Plug Basis for Volume Calculations: Total Cement Volume: 119 bbl Casing Size Basis for Volume Calculations: Total Cement Volume: 56.7 bbl Banzai Liner Basis for Volume Calculations: Total Cement Volume: 21 bbl 10-3/4",45.5 I bItt, L-80, BTC Surface Casing set at 2,382' MD. 175% excess over gauge hole in permafrost (0' - 1871' MD). 40% excess below permafrost (1871' - 2382' MD). 80 tt shoe track. Wash: 25 bbl water Spacer: 75 bbl MUDPUSH at 10.0 ppg Lead 333 bbl, 422 sx 10. 7 Ib/~al, Arctic Set Lite cement + 1.5% CaCI2 mixed at 4.44 tt Isx (Lead: 1871' MD to surface) 54 bbl, 260-sx 15.8 Ib/gal class "G" cement + 0.7% CaCI2 mixed at 1.17 fe/sx 2382' to 1 Tail Temp Casing Point BHST ~ 45°F estimated by Dowell 9-7/8" hole to be plugged back from 4708' MD to 3808' (900 ft) 40% excess over gauge hole (or caliper + 20%) TOC to be ± 220 ft MD above the 7-5/8" CSG Point. TOC = 3,808'. Spacer: 22 bbl of fresh water ahead of the slurry 3 bbl of fresh water behind the Cement 119 bbl, 576 sx 15.8 Ib/gal class "G" + 1 % CaCb mixed at 1.16 fe/sx. Spot at TO via 4" OEDP. Temp BHST ~ 80°F from SOR, BHST 75°F estimated by Dowell 7-5/8",29.7 Ib/tt, L-80, BTC-M Intermediate Casing at 4,030' MD. 40% excess over gauge hole (or caliper + 20%). 85 tt shoe track. TOC to cover 500 tt MD above top of Ugnu. TOC = 3,043'. Wash: 15 bbl CW 100 (8.32 ppg) Spacer: 30 bbl MudPush 0.5 Cement 56.7 bbl, 275 sx 15.81b/gal class "G" plus 0.4% CaCI2 mixed at 1.16 tt3/sx Temp BHST ~ 70°F from SOR and estimated by Dowell 4-1/2", 12.6 I b/ft , L-80, IBT-M Upper Liner: 3,930' MD to 4,530' MD. 25% excess over gauge hole (Oil Base Mud). 100 tt Liner Lap. 100 tt above TOL (7-5/8" x 4" DP annulus). Wash: 10 bbl CW101 (8.32 ppg) Spacer: 15 bbl MudPush 0.5 Cement 21 bbl, 98 sx 15.81b/gal class "G" plus 3% BWOC 0174 & 2 gal/sx 0600G "GASBLOCK" mixed at 1.2 tt3/sx Temp BHST ~ 70°F from SOR, BHCT 70°F estimated by Dowell 2 · .e Point MPJ-25 Well Permit Evaluation Program: 13-1/2" Section Open Hole: MWD/GR IFRlCASANDRA Gyro as required Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GRlRES/NEU/DEN IFRlCASANDRA Cased Hole: N/A 6-3/4"Section Open Hole: MWD/GRlRES IFRlCASANDRA Formation Markers: Formation Tops Base Permafrost TUZC SBF2-NA SBF2-NB SB-OA SB-OB Pilot Hole TO MD (ft) 1871 3543 4194 4249 4469 4579 4708 TVD (ft) 1861 3373 3836 3872 4015 4086 4170 CasinglTubing Program: Pore Pressure Estimated EMW (psi) (Ib/gal)* 1438 1671 1686 1750 1781 8.2 8.4 8.4 8.4 8.4 Hole Csg I Lnr Wt/Ft Grade Conn Length Top Bottom Size Tbg MD/TVD MD I TVD 42-in 20"* 92# H-40 Weld 80' 34' 114' I 114' 13-1/2" 1 0-3/4" 45.5# L-80 BTC 2350' 32' 2382' I 2360' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 4000' 30' 4030' I 3729' 4-1/2" 12.7# L-80 IBT-M 520' 3930' I 3665' 4500' I 3870' 6-3/4" 4-1/2" MHCV, ECP IBT 55' 4500' I 3870' 4555' I 3870' 5" x4" 4" Excluders SLHT 3900' 4555' I 3870' 8455' I 3860' 4-1/2" 12.7# I L-80 IBT-M 3900' 30' I 30' 3930'/3665' *The 20" casing is insulated. The 10-3/4" is special drift (9-7/8") Recommended Bit Program: BHA Hole Size 1 13-1/2" 2 9-7/8" 3 6-1/8" Depth (MD) o - 2,382' 2,536' -5148' 5148' - TO Bit Type Mill tooth Mill tooth POC NozzlefTFA 0.8 - 1.0 0.66 - 0.86 0.33 - 0.45 Flow Rate 550 - 700 550 - 650 250 - 350 3 . tine Point MPJ-25 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. Intermediate and Production Intervals · Integrity test: · Kick tolerance: 1,781 psi (8.4 ppg at 4,086' TVD - top OS-sand) ,/ 1 ,372 psi @ surface .- (Based on BHP and a full column of gas from TO at 0.1 psi/ft) Diverter will be function tested. BOPs: Test annular 250 psi low and 2,500 psi high, and rams to 250 psi low and 4,500 psi high. 7-5/8" casing and packoff tested to 4,500 psi before drilling out. An FIT to 12.0 Iblgal will be made on the 10-3/4" & 7-5/8" shoes. 46 bbl with 9.1 Iblgal mud and FIT of 11.5 Ib/gal at 10-3/4" shoe. Kick Tolerance is infinite with FIT of 11.5 at the 7-5/8" shoe. 9.6 Iblgal NaCI brine and 6.8-lb/gal Diesel · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: . Planned completion fluid: Drilling Hazards & Contingencies: Hydrates . Hydrates have not been seen on J pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur below the Permafrost (± 1870' MD). Hydrates may be present in shallower SV sands, and also, as deep as 3000 ft. Be alert for the possibility of shallow gas andlor hydrates. Use recommended practices for drilling hydrates. Pre-treat mud with DrilTreat; Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and Reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another possible hazard is gravel in or below the Permafrost. Gravels that "run" or calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. · Due to the abundance of reactive clay in these wells, swabbing, tight hole and packing off are always a potential hazard. Use high flow rates and high rotary speeds to clean the hole. Lost Circulation · We do not expect losses while drilling this well. . Offset wells on J-Pad have experienced minor losses and seepage in the Schrader Bluff interval. J-08 lost 35 bbls during the completion. J-05 differentially stuck the liner. Mud losses, seepage and differential sticking can be averted with proper mud density, good wall cake and properly sized LCM particulate matter in the mud. Also, ECD must be managed carefully. Expected Pressures · It is unlikely there will be any unexpected overpressure when drilling the Schrader Bluff formation. Reservoir pressure is expected to be (8.4 Iblgal EMW). 4 . Ie Point MPJ-25 Well Permit Pad Data Sheet · Please read the S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Heavy hydrocarbons will be encountered in the TUZV down through the Schrader Bluff. Faults · The mother well bore will cut two faults above the lateral KOP: an 80' fault at ± 3000' MD, and a 30' fault at ± 3525' MD. Neither of these faults is expected to cause any drilling problems. · In the "NB" lateral, four minor faults will be cut. The pore pressures are normal throughout the lateral and we are drilling with oil base mud. Therefore, we do not expect significant drilling problems related to drilling through these faults: minor seepage, minor caving. Hydrogen Sulfide · MPJ Pad is not designated as an H2S Pad. Anti-collision Issues · There are several close approach issues, primarily in the surface hole down to ± 500' MD. Close approach issues will be mitigated by running gyro surveys while drilling the surface hole. 5 · ene Point MPJ-25 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. Install 20-in insulated conductor. Procedure 1. MIRU. NU diverter on 20-in conductor and function test. 2. Drill 13-1/2" surface hole to 2382' MD as per directional plan. 3. Run and cement 10-3/4" surface casing with cement to surface. 4. ND diverter, NU BOPE and test. 5. Drill out. Perform FIT. 6. Drill 9-7/8" pilot hole through the Schrader Bluff section as per directional plan. 7. Run E-Line logs and SWC's in the pilot hole as directed. 8. Plug back the pilot hole with cement to ± 4030' MD as per directional plan. 9. Run and cement 7-5/8" intermediate casing. Freeze protect the OA with diesel. 10. Change over to Oil Base Mud. 11. Drill out the 7-5/8" shoe and 20-ft new formation and perform FIT. 12. Drill 6-3/4" NB-sand lateral as per directional plan. 13. Run 4" x 5" sand screens below a 4-1/2" Banzai Liner. Hang the liner with 2: 100 ft of overlap inside 7-5/8" casing and cement same from the T/NB sand to the TOL. 14. Displace oil base mud to kill weight brine. 15. Run 4-1/2" jet pump completion as per schematic. 16. Land tubing hanger and test. 17. Set BPV. 18. ND BOP. 19. Install and test tree. 20. Pull BPV. 21. Set the production packer. 22. Test 7-5/8" x 4-1/2" annulus. 23. Freeze protect thru GLM. 24. Install BPV and secure well. 25. RD/MO. 6 ~ .1-1 NORTH ~ A: tL, ~ qe N 1BOO + o C) '<t 20 PROJECT AREA IJJ . v- .- 0) !') ,/J 1-1 z « ~ ...J ti: D- (5 -~- I n MPU J-PAD (------------- --~) I ! ! ! ! ! ! ! I I ! ! I I I ! _---..J ( .J , ! ! ! I I ! I I ! I I ! I I ! 20. ! ! 21. I I.CPJ--22 ~ J-26 I Œ'± Sr=UTH ! "BIINOONED I OT l \ ~-----------------,~ ! ! ! ! ! ! I ! ! , J-2 SOUlH ~ ~ ~ ~ ~ '" o C) J w +N 400 ~ (¡ .. ¿ ¡¡¡ 1, t ë ¡; g ~ 1, ~ ó ~ f ~ Q ., " ~~ Š 0 ~/2JJ/O~ ~ fa< '0.-00""1100 ~ NCL DA.1E 1r J-25 z+. ~. 1. 11. 2 . B . J . 10. .. . VICINI TY MAP N.T.S. 1S. 1a. 17· 18. 19. .r; .12 .0 .1J .5 .14 .7 NOTES: 1. STATE PLANE COORDINATES ARE ALASKA ZONE 4, NAD27. 2.. GEODETIC COORDINATES ARE NAD-27. 3. MPU J-PAD FACILITY SCALE FACTOR IS 0.9999031. 4. HORIZDNTAL CONTRa.. BASED ON MPU J-PAD OPERATOR MONUMENTS J-1 AND J-2. 5. ELEVATIONS ARE BPX MILNE POINT DATUM MEAN SEA LEVEL. 6. DATE OF SURVEY: APRIL 12 & 18, 2004. 7. REFERENCE FIELD BOOK: MP04-03 (Pgs 12-15 & 25-27). LEGEND -$- AS-STAKED CONDUCTOR . EXISTING CONDUCTOR -0- SURVEY CONlROL MONUMENT LOCA TED 'MTHIN PROTRACTED SEC. 28, T. 13 N., R. 10 L, UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION NO. COORDINATES COORDINATES POSITlON(DMS) POSITION(D.DD) ELEVATION OFFSETS J-25 y= 6.015.137.64 N= 1,390.00 70"27'07.556" 70.4520989' 36." 2,741'FSL x= 551,903.29 E= 1,120.00 149"34'35.402" 149.5765006' 3,413' FEL J-26 y= 6,014,554-.57 N= 795.00 70'27'01.811" 70.4505031' 34.8' 2,156'FSL x= 552,054.97 E= 1,025.00 149"34'31.066" 149.5752961" 3,267' FEL ]¡I æAVIN; Obp ONEIL Q£1XEt JACOBS []All: 4/20/1>4 IJRA~Q. "'EEl> ~g04 I.4PJ 01-00 MILNE POINT UNIT J-PAD ~ ffi~(] .œ 1«1: scoæ. AS-STAKED WELL CONDUCTORS 1 IF 1 NLO .U __\..ØG~ MUS MPJ-25 & MPJ-26 "'.., f'IIIICIIIIIJ lAC 1--200' 1£\1 g CO< BY CHK ---. ~ - ~ 4-1/16" - SM Cameron . Wellhead: 11 n x 4.S" SM Gen 6 w/4.S" TCII T&B Tubing Hanger CIW "H" BPV profile I I TBD I ..4 20" x 34" insulated conductor 10-3/4" 4S.S #Ift L-80 BTC 12382' MDI ~ 9-7/8" Pilot Hole MPJ-25 ~ 2J ~ §) S ~ = = ~ ~ @ @ ~ ~ d Ori_elev. = 60.4' (Doyon 14) Pad GL. elev.= 36.1· (Doyon 14) ~ Planned KOP @ 300'. Ini BUR = 1°/100' Increase BUR to 4°/100 while drilling. Hold angle at 49.So: 3961' to 4708' MD. ~ 12360' TVO 14708' MD I I- _ _ _ _ _ _ _ ... DATE REV. BY 4/28/04 Skip Coyner COMMENTS I TUZC 3543' MDI I Inclination = 49.50 I Azimuth = 3050 I TINA 4194' MD I I TINS 4249' MD I I T/OA 4469' MD I I TlOB 4579' MD I MILNE POINT UNIT WELL J-25 API NO: 50-029- BP EXPLORATION (AK) Iœe.;. 4-1/16" - 5M Cameron . Wellhead: 11" x 4.5" 5M Gen 6 wI 4.5" TCII T&B Tubing Hanger CIW "H" BPV profile I I TBD I ~ 20" x 34" insulated conductor 10-3/4" 45.5 #Ift L-80 BTC MPJ-25 Orieelev. = 60.4· (Doyon 14) Pad GL. elev.= 36.1' (Doyon 14) l Planned KOP @ 300'. Ini BUR = 10/100. Increase BUR to 40/100 while drilling. Hold angle at 49.5°: 3961' to 4708' MD. 12382' MDI ~ ~ 12360' TVDI I I I I I I I I 13043' MD I I 7-5/8" 29.7# L-80 IBT-M casing (drift = 6.75", cap = .0459 BPF) 7-5/8" Float Collar 3990' MD 7-5/8" Float Shoe 4030' MD 9-7/8" Pilot Hole Plugged Sack wI ± 119 bbl cement 14708' MD I DATE REV. BY 4/28104 Skip Coyner Dress off cement plug ± 4030' MD. Set & CMT CSG. Drill out with BHA oriented high side. COMMENTS I TUZC 3543' MDI I Inclination = 49.5° I Azimuth = 3050 I TINA 4194' MD I I TINS 4249' MD I I T/OA 4469' MD 1 I T/OB 4579' MD I MILNE POINT UNIT WELL J-25 API NO: 50-029- BP EXPLORATION (AK) ~ 4-1116" - SM Cameron . Wellhead: 11" x 4.S" SM Gen 6 w/4.S" TCII T&B Tubing Hanger CIW "H" BPV profile I I TBD I ~ 20" x 34" insulated conductor 10-3/4" 4S.S #/ft L-80 BTC MPJ-25 Orig._lev. = 60.4' (Doyon 14) Pad GL. elev.= 36.1' (Doyon 14) ~ Planned KOP @ 300'. Ini BUR = 1°/100' Increase BUR to 4°/100 while drilling. Hold angle at 49.So: 3961' to 4708' MD. 12382' MDI ~ ~ 12360' TVDI I I I I I I I I 13043' MD I I 7-S/8" 29.7# L-80 IBT-M casing (drift = 6.7S", cap = .04S9 BPF) 7-5/8" Float Collar 3990' MD 7-5/8" Float Shoe 4030' MD 9-7/8" Pilot Hole Plugged Back wI ± 119 bbl cement 14708' MD I DATE REV. BY 4128/04 Skip Coyner COMMENTS I TUZC 3543' MDI Inclination = 49.50 I Azimuth = 3050 ________________________1 "Na" lateralS8S5( - 3860' TVD -----------------------. MILNE POINT UNIT WELL J-25 API NO: 50-029- BP EXPLORATION (AK) ~ 4-1/16" - 5M Cameron . Wellhead: 11" x 4.5" 5M Gen 5 w/4.5" TCII T&B Tubing Hanger CIW "H" BPV profile MPJ-25 I TSD I ... 20" x 34" insulated, 215 lIft A-53 10-3/4" 45.5 #/ft L-80 BTC I 2382'1 .. 7-5/8" 29.7# L-80 IBT-M casing (drift = 6.75", cap = .0459 BPF) 4-1/2" 12.6# L-80 IBT-M tubing (ID = 3.958", cap = .0152 BPF) 7-S/8" Float Collar 3990' MD 7 -S/8" Float Shoe 4030' MD 9-7/8" Pilot Hole Plugged Back wI Cement DATE REV. BY COMMENTS Drilled and Completed by Doyon 14 MILNE POINT UNIT WELL J-25 API NO: 50-029- 4/26/04 Skip Coyner Oriaelev. =: 60.4' (Doyon 14) Pad GL. elev. =: 36.1' (Doyon 14) L Cameo 4.5" x 1" w/ BK latch side pocket KG B-2 GLM 119SO' MD I ~ Phoenix Discharge gauge (3.956 10) 4.5" HES "XD" Dura sliding sleeve 3.813" 10 (Opens down ) Phoenix Jet Pump gauge sensor (3.833" ID) 1 388S' MD Baker Premier PKR: 7-5/8" x 4-1/2" 13910' MD I 4.5" HES 'XN' Nipple (3.S13 Pkg ID, 3.725 No-go 10) 13920' MD I EOT: 3930' Mol TOl: 3930' MD 4-1/2" WLEG (3.933 Drift) (sting into TBR) 7 5/S" x 5.5" Lnr Tie Back Sleeve 7 5IS" x 5.5" Baker ZXP (4.S9" Min ID) 7 5IS" x 5.5" Baker CMC (Mechanical Set) liner Hanger 5.5" BTC X 4.5" X-over Pup I Baker, Payzone ECP & HMCV at 4550' MD (above the NB sand) I / 14" x 5" Excluders: 4700' - TMD (8458' MD) I ------------------- 6-314" Hole to 8458' MD (3886' -3860 TVD) 14 jt 4-1/2" LNR & X-O to 4" SLHTI BP EXPLORATION (AK) coMPANY DETAILS REfERENCE INYORMA TION Co-ol\Jinate (NÆ) Reference: Well Centre: Plan MPj·2S, True Nor1h '/ Yel1i1:al (TVD) Reference: 36.1+34.3 fiO.40 Section (VS) Reference: 5101· (O.(K)N,O.OOE) Measured De~th Reference: 36.1+34.3 (,0.40 Call:ulation Method Minimum CW'Vllture AI' Amoco Calculation Method: Minimum CUI'\Iature Error System: ISCWSA Scan Method: Tr-.IV Cylinder North ErrorSutface: ElHrtkal + CasIng Warning Method: Rules Based Dir 1/100': 300J' MD, 300J"TVD CASING DETAJLS No, TVD MD Name 2360.40 2381.57 103/4" 3729.34 4030.00 7 5/8" 10.750 7.625 Size 700 I I I 2800 I I I I I Start Dir 3/100': 767J9' MD, 766.72"TVD FORMATION TOP DETAILS No, TYDPath MDPath Fonnation I 1860.70 1870,51 BPRF 2 3372.70 3542.92 TUZC 3 3605.70 3844.78 Ugnu-MA 4 3615.70 3859.01 Ugnu-MBI 5 3676.70 3949.01 Ugnu-MB2 6 3797,70 4135.26 Ugnu-MC 7 3835.70 4193.77 SBF2·NA 8 3871. 70 4249,20 SBFI-NB 9 3898.70 4290.78 SBFI-NC 10 3917.70 4320.03 SBE2-NE II 3974,70 4407.80 SBEI-NF 12 4014,70 4469.39 TSBD-Top OA 13 4047.70 4520.20 TSBC·Base OA 14 4085.70 4578.71 TSBB-Top OB 15 4113.70 4621.83 SBA5·Base OB End Dir : 817.62' MD. 816,63' TVD 1400 Start Dir3/100': 1707.62'MD, 1700"TVD : 1882.52' MD, 1872.46' TVD '2 2100 0.:: '" o Ë "' õ. ë SURVEY 'ROCiRAM Depth Pm Depth To SurveylPlln 34.30 1200.30 Planned: MPJ·2SPBI WJ>06 VS2 1200.30 4708.43 Planned: MPJ·2SPBI WI'()6 V52 Plan: MPJ·2~PO wrOt. (Plan MPJ-25/Plan MPJ·2S PB I) Created By: Troy Jakabosky Date: 4I2112(XJ4 Tool CB.CJYRO-SS MWD+IFR+MS Checked: Date:_ Date:_ Reviewed: WELL DETAILS N.... +N/-S +fj-W NorthIng Eastlng Latitude Longitude Slot PlanMPJ·2S 11111.30 480.11 6015137.M S51903.29 10027'01.5S6N 149°34'35.402W N/A TARGET DETAILS N""" 1VD +N/·S +FJ·W Northing ~~Iing Share MPJ·2S TIc 38f,O.40 174.30 .997.54 f,OS904.90 550900.48 Clrtle(Radius:200) MPJ·2ST2c 4()80.40 922.0S ·1208.S0 601 IiOS 1.1(, SSOó8R.s1 Cin:le (Radius: 200) SECTION DETAILS Sec MD Inc Azi TVD +N/·S +E/-W DLeg TF ace VSec Target I 34.30 0.00 0.00 34.30 0,00 0,00 0.00 0.00 0.00 2 300.30 0.00 0.00 300.30 0.00 0.00 0.00 0.00 0.00 3 600.30 3.00 350.00 600.16 7.73 ·1.36 1.00 350.00 5,76 4 767,39 6.00 330.00 766.72 19.60 -6.49 2.00 322.17 17.02 5 817.62 7.00 340.00 816.63 24.75 -8.85 3.00 53.58 22.01 6 1707.62 7,00 340.00 1700.00 126.68 -45,95 0.00 0.00 113.18 . 7 1882.52 12.00 330.00 1872.46 152.46 ·58,69 3.00 336.75 138.91 8 2319.61 12.00 330.00 2300.00 231.16 -104.13 0.00 0.00 222.68 9 2927,10 33.46 296.27 2858.93 361.94 ·288.64 4.00 -48.06 448.72 10 3535.47 33.46 296.27 3366.50 510.40 ·589,38 0.00 0.00 778.04 II 3961.00 49.50 305.00 3684.53 656.19 ·828.86 4.00 23.21 1056.94 12 4011.00 49,50 305.00 3717.00 678.00 ·860.00 0.00 0.00 1094.93 13 4231.80 49.50 305.00 3860.40 774.30 -997.54 0.00 0.00 1262.7] MPJ·25 TIc 14 4570.55 49.50 305.00 4080.40 922.05 ·1208.54 0.00 0.00 1520.11 MPJ·25 T2c 15 4608.43 49.50 305.00 4105.00 938.57 -1232,13 0.00 0.00 1548.89 ,./ 16 4708.43 49.50 305.00 4169.94 982.18 ·1294.42 0.00 0.00 1624.87 Start Dir 4/1 00' : 2319.61' MD, 2300"TVD SpSi'i'y-sun OAIL.L.ING SeAVIc:eS A U....LLJÐl'R;TnN (~-'"fI'AM' . 'J -> " ~ 2800 Dir : 2927.1" MD, 2858,93'TVD 3500 Total Depth: 4708.43' MD, 4169.94' TVD 4200 WP06 4900 I I I I I ¡ I 700 1400 2100 Vertical Section at 307,19' [700ft/in] Pilot Hole o # "'.5"00 Calculation Method: Minimum CUl'Vature Error Sy~tem: ISCWSA Scan Method: Trav Cylinder North Error Surface: EHirtkal ~ Casing Warning Method: Rules Ih.'\Cd COMPANY DETAILS 1800- 1500- DP Amcxo REFERENCE INFORMA TlON CoV;:::~e(~~ ~~=oc~: ~~:~~~~)~(r MPJ.25, True North Section (VS) Reference: Slot· (O.OON,O.OOE) Measured Depth Rerercnœ~ 36.1+34.3 60.40 Calculation Mf.1hod Minimum Curv.ttu.rc SURVEY PROGRAM Depth Fm Depth To SurveyIPlan 34.30 1200.30 Planned: MPJ·25PB I WP06 VS2 1200.30 410R.43 Planned: MPJ·25PBI WP06 V52 Date Plan: MPJ-2SPBl WPQ6 (Plan MPJ·25/Plan MPJ-25 PBI) Tool CB-GYRo.SS MWD+IFR+MS Created By: Troy Jakabosky Checked: WELL DETAILS Date: 4/21/2004 ""'" +N/·S +Ð·W Northing Easting Latituú: Longitude Slot PlanMPJ·25 171930 480.11 ('(}15137.li4 55190329 7()"27'07.556N 149"34'35.402W NiA TARGET DETAILS N~ TVD +N/·S +EI·W Northing Basting Shape MPJ·2STh: 38(,(}.40 774.30 -997.S4 6015904.90 550900.48 Circle (Radius: 200) MPJ-2S TIc 4080.411 922.05 -1208.50 6016051.16 550688.51 Circle (Radius: 200) i ··--"'I'w~ _ ¡If _',\ I:'i+ , -...< £ :::::---r V ~ "'t~\> ,'_ , , ./ 1'¿ ~ ---' k-- ~ ~." Þlú, ,~" ,~~ , j'iil;v,rJJ\;¡ ! AM~.t ?' e- )-- ""~"~\AI ¡l¡iI1±Ft ,- C- - ,. N, . "f~'" ~ ~/ ~Æ;±.t,. "ii' - . / ~rgßtJäÎi_ .. ..,- SECTION DETAILS See MD [ne Azi TVD +N/·S +E/·W DLeg TFaee VSee Target I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 300.30 0.00 0.00 300.30 0.00 0.00 0.00 0.00 0.00 3 600.30 3.00 350.00 600.[6 7.73 -1.36 1.00 350.00 5.76 4 767.39 6.00 330.00 766.72 [9.60 -6.49 2.00 322.17 17.02 5 817.62 7.00 340.00 816.63 24.75 -8.85 3.00 53.58 22.0[ . 6 1707.62 7.00 340.00 1700.00 126.68 -45.95 0.00 0.00 [ 13.18 7 1882.52 12.00 330.00 1872.46 152.46 -58.69 3.00 336.75 138.9[ 8 2319.6[ 12.00 330.00 2300.00 231.[ 6 -104.13 0.00 0.00 222.68 9 2927.[0 33.46 296.27 2858.93 361.94 -288.64 4.00 ·48.06 448.72 10 3535.47 33.46 296.27 3366.50 510.40 -589.38 0.00 0.00 778.04 1[ 3961.00 49.50 305.00 3684.53 656.[9 -828.86 4.00 23.2[ 1056.94 12 4011.00 49.50 305.00 3717.00 6 78.00 -860.00 0.00 0.00 [ 094.93 13 4231.80 49.50 305.00 3860.40 7 74.30 -997.54 0.00 0.00 [262.7[ MPJ-25 Tic 14 4570.55 49.50 305.00 4080.40 9 22.05 . [208.54 0.00 0.00 [520.1 [ MPJ-25 T2e 15 4608.43 49.50 305.00 4[05.00 9 38.57 ·[232.13 0.00 0.00 [ 548.89 16 4708.43 49.50 305.00 4[69.94 9 82.[8 . [294.42 0.00 0.00 [ 624.87 CASING DETAILS No. TVD MD Name Size 2360.40 2381.57 [03/4" 10.750 3729.34 4030.00 7 5/8" 7.625 1200 it ~ .........i¡ ¢: 0 ..... Ë 900 t +- 'E t 0 ~ , 'E '5 't 0 V> 600 , . . . _ 300 ..... . .. ... . ·1800 '"'"' "P'": 4708. 13' tv D)4169.94' TVD ",-. iit nn'n ,n ., . FORMATION TOP DETAILS No. TVDPath MDPath Formation [ [860.70 1870.5[ BPRF 2 3372.70 3542.92 ruzc 3 3605.70 3844.78 Ugnu-MA . 4 36[5.70 3859.01 Ugnu-MB1 5 3676.70 3949.01 Ugnu·MB2 6 3797.70 4[35.26 Ugnu-MC 7 3835.70 4[93.77 SBF2-NA 8 3871.70 4249.20 SBFI-NB 9 3898.70 4290.78 SBFI-NC 10 39[7.70 4320.03 SBE2-NE 11 3974.70 4407.80 SBEI-NF [2 4014.70 4469.39 TSBD-Top OA [3 4047.70 4520.20 TSBC·Base OA 14 4085.70 4578.71 TSBB-Top OB 15 4113.70 4621.83 SBA5-Base OB .il , I . 'UT"! ~if4i~~Hrò;iff~2300'TVD "' / LllU '"72.46' "' "" MD, 1700'TVD ,"" .-- ........... ....... , .. .t¡i¡, i , ....., . , .j- , , I . . , , . . '" , , , ................. ...L ; , ................. , , , ·1200 ·900 -600 A 1W..lØt'ItT,,~ <....."",. 500 , , , I I I I I J I Spe!I""'i'y-sun a"It-L.INJ .."VII:.. I ¡ I I I , I 600 ·1500 -300 300 West(-)/East(+) [300ft/in] e BP Planning Report . Plan: MPJ-25PB1 WP06 Principal: Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M Pt J 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 MPJ-25 New Conductor Location Well Position: +N/-S 1719.30 ft Northing: +E/-W 480.11 ft Easting: Position Uncertainty: 0.00 ft Wellpath: Plan MPJ-25 PB1 Current Datum: Magnetic Data: Field Strength: Vertical Section: 36.1+34.3 4/23/2004 57557 nT Depth From (TVD) ft 34.30 Casing Points Date Composed: Version: Tied-to: Map Zone: Coordinate System: Geomagnetic Model: 4123/2004 52 From Well Ref. Point Alaska, Zone 4 Well Centre bggm2003 6013415.23 ft / Latitude: 70 26 50.647 N 551435.10 ft / Longitude: 149 34 49.503 W North Reference: True Grid Convergence: 0.40 deg Slot Name: 6015137.64 ft Latitude: 70 27 7.556 N 551903.29 ft Longitude: 149 34 35.402 W Height 60.40 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 34.30 ft Mean Sea Level 24.90 deg 80.86 deg Direction deg 307.19 +N/-S ft 0.00 2381.57 2360.40 10.750 13.500 103/4" 4030.00 3729.34 7.625 9.875 75/8" Formations 1870.51 1860.70 BPRF 3542.92 3372.70 TUZC 3844.78 3605.70 Ugnu-MA 3859.01 3615.70 Ugnu-MB1 3949.01 3676.70 Ugnu-MB2 4135.26 3797.70 Ugnu-MC 4193.77 3835.70 SBF2-NA 4249.20 3871.70 SBF1-NB 4290.78 3898.70 SBF1-NC 4320.03 3917.70 SBE2-NE 4407.80 3974.70 SBE1-NF 4469.39 4014.70 TSBD-Top OA 4520.20 4047.70 TSBC-Base OA 4578.71 4085.70 TSBB-Top OB 4621.83 4113.70 SBA5-Base OB 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 . . BP Planning Report Targets MPJ-25 T1c 3860.40 774.30 -997.54 6015904.90 550900.48 70 27 15.170 N 149 35 4.703 W -Circle (Radius: 200) -Plan hit target MPJ-25 T2c 4080.40 922.05 -1208.50 6016051.16 550688.51 70 27 16.623 N 149 35 10.901 W -Circle (Radius: 200) -Plan hit target Plan Section Information 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 300.30 0.00 0.00 300.30 0.00 0.00 0.00 0.00 0.00 0.00 600.30 3.00 350.00 600.16 7.73 -1.36 1.00 1.00 0.00 350.00 767.39 6.00 330.00 766.72 19.60 -6.49 2.00 1.80 -11.97 322.17 817.62 7.00 340.00 816.63 24.75 -8.85 3.00 1.99 19.91 53.58 1707.62 7.00 340.00 1700.00 126.68 -45.95 0.00 0.00 0.00 0.00 1882.52 12.00 330.00 1872.46 152.46 -58.69 3.00 2.86 -5.72 336.75 2319.61 12.00 330.00 2300.00 231.16 -104.13 0.00 0.00 0.00 0.00 2927.10 33.46 296.27 2858.93 361.94 -288.64 4.00 3.53 -5.55 -48.06 3535.47 33.46 296.27 3366.50 510.40 -589.38 0.00 0.00 0.00 0.00 3961.00 49.50 305.00 3684.53 656.19 -828.86 4.00 3.77 2.05 23.21 4011.00 49.50 305.00 3717.00 678.00 -860.00 0.00 0.00 0.00 0.00 4231.80 49.50 305.00 3860.40 774.30 -997.54 0.00 0.00 0.00 0.00 MPJ-25 T1c 4570.55 49.50 305.00 4080.40 922.05 -1208.54 0.00 0.00 0.00 0.00 MPJ-25 T2c 4608.43 49.50 305.00 4105.00 938.57 -1232.13 0.00 0.00 0.00 0.00 4708.43 49.50 305.00 4169.94 982.18 -1294.42 0.00 0.00 0.00 0.00 Survey 34.30 0.00 0.00 34.30 0.00 0.00 -480.11 -1719.30 CB-GYRO-SS 100.00 0.00 0.00 100.00 0.00 0.00 -480.11 -1719.30 CB-GYRO-SS 200.00 0.00 0.00 200.00 0.00 0.00 -480.11 -1719.30 CB-GYRO-SS if 300.30 0.00 0.00 300.30 0.00 0.00 -480.11 -1719.30 CB-GYRO-SS 400.00 1.00 350.00 399.99 0.85 -0.15 -479.96 -1720.16 CB-GYRO-SS 500.00 2.00 350.00 499.96 3.43 -0.60 -479.51 -1722.73 CB-GYRO-SS 600.30 3.00 350.00 600.16 7.73 -1.36 -478.75 -1727.04 CB-GYRO-SS 700.00 4.74 335.02 699.63 14.03 -3.55 -476.56 -1733.34 CB-GYRO-SS 767.39 6.00 330.00 766.72 19.60 -6.49 -473.62 -1738.91 CB-GYRO-SS 800.00 6.63 336.84 799.14 22.81 -8.08 -472.03 -1742.12 CB-GYRO-SS 817.62 7.00 340.00 816.63 24.75 -8.85 -471.26 -1744.06 CB-GYRO-SS 900.00 7.00 340.00 898.40 34.19 -12.28 -467.83 -1753.49 CB-GYRO-SS 1000.00 7.00 340.00 997.66 45.64 -16.45 -463.66 -1764.95 CB-GYRO-SS 1100.00 7.00 340.00 1096.91 57.09 -20.62 -459.49 -1776.40 CB-GYRO-SS 1200.00 7.00 340.00 1196.17 68.55 -24.79 -455.32 -1787.85 CB-GYRO-SS 1300.00 7.00 340.00 1295.42 80.00 -28.96 -451.15 -1799.30 MWD+IFR+MS 1400.00 7.00 340.00 1394.68 91.45 -33.12 -446.99 -1810.75 MWD+IFR+MS 1500.00 7.00 340.00 1493.93 102.90 -37.29 -442.82 -1822.21 MWD+IFR+MS 1600.00 7.00 340.00 1593.18 114.35 -41 .46 -438.65 -1833.66 MWD+IFR+MS 1707.62 7.00 340.00 1700.00 126.68 -45.95 -434.16 -1845.98 MWD+IFR+MS 1800.00 9.61 333.43 1791.41 138.87 -51.32 -428.79 -1858.17 MWD+IFR+MS 1870.51 11.65 330.41 1860.70 150.32 -57.47 -422.64 -1869.62 BPRF 1882.52 12.00 330.00 1872.46 152.46 -58.69 -421.42 -1871.76 MWD+IFR+MS 1900.00 12.00 330.00 1889.56 155.60 -60.51 -419.60 -1874.91 MWD+IFR+MS 2000.00 12.00 330.00 1987.37 173.61 -70.90 -409.21 -1892.91 MWD+IFR+MS 2100.00 12.00 330.00 2085.19 191.62 -81.30 -398.81 -1910.92 MWD+IFR+MS . . BP Planning Report Survey 2200.00 12.00 330.00 2183.00 209.62 -91.70 -388.42 -1928.93 MWD+IFR+MS 2300.00 12.00 330.00 2280.82 227.63 -102.09 -378.02 -1946.93 MWD+IFR+MS 2319.61 12.00 330.00 2300.00 231.16 -104.13 -375.98 -1950.46 MWD+IFR+MS 2381.57 13.78 322.24 2360.40 242.57 -111.87 -368.24 -1961.88 103/4" 2400.00 14.35 320.31 2378.28 246.06 -114.67 -365.44 -1965.37 MWD+IFR+MS 2500.00 17.65 312.05 2474.40 265.76 -133.85 -346.26 -1985.06 MWD+IFR+MS 2600.00 21.18 306.40 2568.71 286.64 -159.66 -320.46 -2005.94 MWD+IFR+MS 2700.00 24.85 302.32 2660.74 308.60 -191.97 -288.14 -2027.90 MWD+IFR+MS 2800.00 28.61 299.25 2750.04 331.54 -230.63 -249.48 -2050.85 MWD+IFR+MS 2900.00 32.42 296.84 2836.18 355.35 -275.45 -204.66 -2074.66 MWD+IFR+MS 2927.10 33.46 296.27 2858.93 361.94 -288.64 -191.47 -2081.24 MWD+IFR+MS 3000.00 33.46 296.27 2919.75 379.73 -324.67 -155.44 -2099.03 MWD+IFR+MS 3100.00 33.46 296.27 3003.18 404.13 -374.11 -106.00 -2123.44 MWD+IFR+MS 3200.00 33.46 296.27 3086.61 428.53 -423.54 -56.57 -2147.84 MWD+IFR+MS 3300.00 33.46 296.27 3170.04 452.94 -472.98 -7.13 -2172.24 MWD+IFR+MS 3400.00 33.46 296.27 3253.47 477.34 -522.41 42.30 -2196.65 MWD+IFR+MS 3500.00 33.46 296.27 3336.90 501.74 -571.85 91.74 -2221.05 MWD+IFR+MS 3535.47 33.46 296.27 3366.50 510.40 -589.38 109.27 -2229.71 MWD+IFR+MS 3542.92 33.73 296.48 3372.70 512.23 -593.08 112.96 -2231.54 TUZC 3600.00 35.84 298.01 3419.58 527.15 -622.02 141.91 -2246.45 MWD+IFR+MS 3700.00 39.58 300.34 3498.68 557.00 -675.38 195.27 -2276.31 MWD+IFR+MS 3800.00 43.36 302.32 3573.60 591.46 -731.91 251.80 -2310.77 MWD+IFR+MS 3844.78 45.06 303.13 3605.70 608.35 -758.17 278.06 -2327.65 Ugnu-MA 3859.01 45.60 303.37 3615.70 613.89 -766.64 286.52 -2333.20 Ugnu-MB1 3900.00 47.17 304.05 3643.98 630.36 -791.32 311.21 -2349.67 MWD+IFR+MS 3949.01 49.04 304.82 3676.70 650.99 -821.40 341.29 -2370.30 Ugnu-MB2 3961.00 49.50 305.00 3684.53 656.19 -828.86 348.74 -2375.50 MWD+IFR+MS 4000.00 49.50 305.00 3709.86 673.20 -853.15 373.04 -2392.51 MWD+IFR+MS 4011.00 49.50 305.00 3717.00 678.00 -860.00 379.89 -2397.30 MWD+IFR+MS 4030.00 49.50 305.00 3729.34 686.29 -871.83 391.72 -2405.59 75/8" 4100.00 49.50 305.00 3774.80 716.82 -915.44 435.32 -2436.12 MWD+IFR+MS 4135.26 49.50 305.00 3797.70 732.20 -937.40 457.29 -2451.50 Ugnu-MC 4193.77 49.50 305.00 3835.70 757.72 -973.85 493.73 -2477.02 SBF2-NA 4200.00 49.50 305.00 3839.74 760.43 -977.73 497.61 -2479.74 MWD+IFR+MS 4231.80 49.50 305.00 3860.40 774.30 -997.54 517.42 -2493.61 MPJ-25 T1c 4249.20 49.50 305.00 3871.70 781.89 -1008.37 528.26 -2501.20 SBF1-NB 4290.78 49.50 305.00 3898.70 800.02 -1034.27 554.16 -2519.33 SBF1-NC 4300.00 49.50 305.00 3904.69 804.05 -1040.01 559.90 -2523.35 MWD+IFR+MS 4320.03 49.50 305.00 3917.70 812.78 -1052.49 572.38 -2532.09 SBE2-NE 4400.00 49.50 305.00 3969.63 847.66 -1102.30 622.19 -2566.97 MWD+IFR+MS 4407.80 49.50 305.00 3974.70 851.06 -1107.16 627.05 -2570.37 SBE1-NF 4469.39 49.50 305.00 4014.70 877.93 -1145.53 665.41 -2597.23 TSBD- T op OA 4500.00 49.50 305.00 4034.58 891.28 -1164.59 684.48 -2610.58 MWD+IFR+MS 4520.20 49.50 305.00 4047.70 900.09 -1177.18 697.06 -2619.39 TSBC-Base OA 4570.55 49.50 305.00 4080.40 922.05 -1208.54 728.43 -2641.35 MPJ-25 T2c 4578.71 49.50 305.00 4085.70 925.61 -1213.62 733.51 -2644.91 TSBB-Top OB 4608.43 49.50 305.00 4105.00 938.57 -1232.13 752.02 -2657.87 MWD+IFR+MS 4621.83 49.50 305.00 4113.70 944.41 -1240.48 760.36 -2663.72 SBA5-Base OB 4708.43 49.50 305.00 4169.94 982.18 -1294.42 814.31 -2701.49 MWD+IFR+MS . . BP Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 34.30 to 4708.43 ft Maximum Radius: 667.41 ft Reference: Error Model: Scan Method: Error Surface: Plan: MPJ-25PB1 WP06 & NOT PLANNED PROGI ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points 2381.57 2360.40 4030.00 3729.34 10.750 7.625 13.500 9.875 10314" 7 5/8" Plan: MPJ-25PB1 WP06 Date Composed: Version: Tied-to: 4/23/2004 52 From Well Ref. Point Principal: Yes Summary M PtJ Pad MPJ-01 MPJ-01 V3 2437.05 2500.00 100.73 46.98 53.76 Pass: Major Risk M pt J Pad MPJ-01 MPJ-01A V2 2437.05 2500.00 100.73 46.98 53.75 Pass: Major Risk M PtJ Pad MPJ-01 MPJ-01AL 1 V6 2437.05 2500.00 100.73 46.98 53.76 Pass: Major Risk M pt J Pad MPJ-02 MPJ-02 V1 339.19 350.00 151.48 7.98 143.50 Pass: Major Risk M PtJ Pad MPJ-03 MPJ-03 V1 411.18 425.00 212.94 11.43 201.51 Pass: Major Risk MPtJPad MPJ-06 MPJ-06 V1 3049.84 3275.00 308.63 48.63 260.00 Pass: Major Risk M pt J Pad MPJ-08A MPJ-08A V7 3411.72 3550.00 134.57 82.79 51.78 Pass: Major Risk MPtJPad MPJ-08 MPJ-08 V1 3411.72 3550.00 134.57 82.70 51.87 Pass: Major Risk M PtJ Pad MPJ-09A MPJ-09A V3 2203.07 2375.00 250.96 61.31 189.66 Pass: Major Risk M PtJ Pad MPJ-09 MPJ-09 V1 2203.07 2375.00 250.96 61.31 189.66 Pass: Major Risk M PtJ Pad MPJ-10 MPJ-10 V1 402.05 400.00 240.12 8.11 232.01 Pass: Major Risk M PtJ Pad MPJ-11 MPJ-11 V1 1599.48 1625.00 112.69 33.58 79.10 Pass: Major Risk M PtJ Pad MPJ-15 MPJ-15 V5 1522.08 1675.00 135.21 47.14 88.08 Pass: Major Risk M ptJ Pad MPJ-16 MPJ-16 V1 2090.44 2250.00 83.33 57.96 25.37 Pass: Major Risk M PtJ Pad MPJ-18 MPJ-18 V2 2053.78 2200.00 277.19 58.66 218.54 Pass: Major Risk M PtJ Pad MPJ-23 MPJ-23 VO 60.40 0.00 60.25 No Offset Stations M PtJ Pad MPJ-23 MPJ-23L 1 VO 60.40 0.00 60.25 No Offset Stations M Pt J Pad MPJ-24 MPJ-24 V11 517.87 525.00 30.59 9.86 20.74 Pass: Major Risk MPtJPad MPJ-24 MPJ-24L 1 V4 517.87 525.00 30.59 9.75 20.84 Pass: Major Risk M pt J Pad MPJ-24 MPJ-24L 1 PB 1 VO 60.40 66.05 29.32 No Offset Stations MPtJPad MPJ-24 MPJ24L 1 PB2 V3 517.87 525.00 30.59 9.75 20.84 Pass: Major Risk M PtJ Pad Plan MPJ-14 Plan MPJ-14 V15 Plan: 3029.07 3425.00 334.02 59.42 274.60 Pass: Major Risk MPtJPad Plan MPJ-14 Plan MPJ-14L 1 V5 Plan: 3029.07 3425.00 334.02 59.42 274.60 Pass: Major Risk M PtJ Pad Plan MPJ-25 old Plan MPJ-25 KlO Plug 0 3963.68 4250.00 168.90 0.00 168.90 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25 option VO 4058.95 4425.00 14.18 0.00 14.17 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25 VO Plan: M 4244.67 4550.00 53.09 0.00 53.09 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25PB1 VO Plan 4687.82 4975.01 65.79 0.00 65.78 Pass: NOERRORS M PtJ Pad Plan MPJ-25 Plan MPJ-25 VO Plan: M 2900.00 2900.00 0.00 0.00 0.00 FAIL: NOERRORS M PtJ Pad Plan MPJ-Cipher Plan MPJ-Cipher VO Pia 1164.85 1225.00 253.91 30.32 223.58 Pass: Major Risk M PtJ Pad Plan MPJ-Dozer Plan MPJ-Dozer VO Plan 4501.37 7825.00 1 02.48 0.00 102.48 Pass: NOERRORS M PtJ Pad Plan MPJ-Jax Plan MPJ-Jax VO Plan: 669.74 700.00 271.21 15.48 255.73 Pass: Major Risk M pt J Pad Plan MPJ-Kali Plan MPJ-Kali VO Plan: 1282.85 1350.00 220.65 33.12 187.54 Pass: Major Risk MPtJPad Plan MPJ-L Plan MPJ-L V11 Plan: M 722.15 725.00 35.50 15.28 20.22 Pass: Major Risk MPtJPad Plan MPJ-L Plan MPJ-LL 1 V6 Plan: 722.15 725.00 35.50 15.18 20.32 Pass: Major Risk M pt J Pad Plan MPJ-N6 Plan MPJ-N6 V10 Plan: 468.88 475.00 19.37 11.23 8.14 Pass: Major Risk M pt J Pad Plan MPJ-N6 Plan MPJ-N6L 1 V1 Plan: 468.88 475.00 19.37 11.32 8.05 Pass: Major Risk M pt J Pad Plan MPJ-Y Plan MPJ-Y V5 Plan: MP 294.40 300.00 3.31 0.00 3.31 Pass: NOERRORS M ptJ Pad Plan MPJ-Y Plan MPJ-YL 1 V5 Plan: 294.40 300.00 3.31 No Reference Casings M PtJ Pad Plan MPJ-Zee Plan MPJ-Zee VO Plan: 1186.80 1250.00 239.25 31.76 207.49 Pass: Major Risk COMPANY DETAILS aÞAlTIOCö Cakulatilln M~thuJ: Minimum CUfVJIun: ~~:~ ~~=: ~~vWè~~m~r North Em¡rSurlil.ce: ElJiplÎCal+C:I.(ing WamingMett..xJ: RulellHa.'Ie\I spe¡-,¡-,y-sun C~IL.,LINC3 se~vlc:es \ Il~lLlII!'k"f{1'" C'UMJ>A.,,^ 3000 " " 3500 - 0 Ë .c E. Ö ~ > ~ 4000 " f- 4500 I I I I I I I I I I I I I I I I 1000 1500 2000 REFERENCE INFORM^ TION cov~:~e~15~ ~~~~~:~ ~~:I+~:~~)~~r MPJ·25, T~ Nurth Section (VS) Reference: SIoI· (().OON.{),U()E) MeWlUfedDerthReference: 3fi,1~34J MAn Calculation Method: Minimum Curvature SURVEY PROGRAM Plan: MPJ·2S WPI6 (Plan MPJ·2SlPlan MPJ·2S) Created By: Troy Jaknbosky Date: 4/27f2<X)4 Checked: Dale:_ Depth Fm Derth To SurveyJPlan "U5n,On 11451t.40 Planned; MPJ·25 WP16 V63 Tool MWD+lFR+MS ! ,¡ ,¡' !!' ! ¡, ~,,~lml~ : ,. . ......... .!mmm : i' / ,,~nd Di m,>. 'YOU, ,~". , , . .. m 16···· WELL DETAILS CASING DETAILS FORMA nON TOP DETAILS Name +N/·S +'i!J.W Northing Easting Latitude Longitude Slot No. TVD MD Name Size No. TVDPath MDPath Formation Plan MP J-25 1719.30 480.11 6015137.64 551903.29 70·27·07.556N 149·34'35.402W N/A 3860.41 8458.00 411 Screens 4.000 I 3885.90 5636.70 Fault 3 2 3870.32 6851. 70 Fault 4 TARGET DETAILS 3 3882.08 7456.70 Fault 5 4 3864.59 8271.70 Fault 6 Name TVD +N/·S +E/.W Northing Easting Sh.pe 5 3797.70 4147.48 Ugnu·MC 6 3835.70 4244.61 SBF2·NA MPJ-25LI T4 3860.40 2663.46 -4706.31 6017768.00 547179.00 Point 7 3871.70 4574.65 SBFI-NB MPJ-25LI T2. 3870.40 1825.23 -3394.99 6016939.00 548496.00 Point MPJ·25T0 3870.40 944.80 -1288.55 6016073.36 550608.31 Point MPJ·25L1 T3. 3880.40 2321.70 ·3884.59 6017432.00 548003.00 Point MPJ·25LI TI. 3885.40 1469.29 ·2405.35 6016590.00 549488.00 Point MPJ·25LI Tin' 3885.40 1063.20 -1538.07 6016190.00 550358.00 Point SECTION DETAILS Sec MD Jnc Azi TVD +N/-S +E/·W DLeg TFace VSec Target I 4050.00 49.50 305.00 3742.33 695.01 ·884.29 0.00 0.00 1111.91 . 2 4070.00 51.89 304.79 3755.00 703.86 -896.98 12.00 -4.00 1127.31 3 4354.57 85.86 300.90 3856.09 844.82 ·1117.26 12.00 ·6.91 1388.44 4 4507.71 85.86 300.90 3867.15 923.27 ·1248.31 0.00 0.00 1541.14 5 4553.48 86.00 295.40 3870.40 944.80 ·1288.55 12.00 -88.72 1586.77 MPJ·25 TO 6 4562.07 86.60 295.41 3870.95 948.48 ·1296.30 7.00 1.23 1595.32 7 4781.33 86.60 295.41 3883.95 1042.41 ·1493.99 0.00 0.00 1813.63 8 4830.10 90.00 295.09 3885.40 1063.20 ·1538.07 7.00 ·5.42 1862.24 MPJ·25L1 TInt "NB" Lateral 9 4833.45 89.96 295.32 3885.40 1064.63 ·1541.10 7.00 98.76 1865.58 10 5707.77 89.96 295.32 3885.95 1438.59 ·2331.42 0.00 0.00 2737.57 ~ ~~, 11 5787.86 90.82 289.78 3885.40 1469.29 -2405.35 7.00 ·81.24 2817.03 MPJ-25L1 Tla ~ /, 12 5900.22 9 J.30 281.93 3883.32 1499.96 ·2513.33 7.00 -86.40 2926.12 / ~~~ 13 6377.95 91.30 281.93 3872.47 1598.69 -2980.62 0.00 0.00 3381.42 / }~ 14 6857.01 89.18 315.40 3870.40 1825.23 -3394.99 7.00 93.45 3853.62 MPJ·25L1 T2a //~/ 15 697 J.37 88.32 326.02 3872.90 1913.58 ·3467.28 9.32 94.72 3960.06 16 7180.32 88.32 326.02 3879.03 2086.78 ·3584.0 I 0.00 0.00 4146.95 'y ;/', ,..";'q¡, 17 7568.21 91.29 290.00 3880.40 2321.70 -3884.59 9.32 ·85.51 4524.25 MPJ·25L1 na "';< /~ 18 7605.90 91.29 292.64 3879.55 2335.40 ·3919.69 7.00 89.97 4561.54 .: :'/ð 19 8458.40 91.29 292.64 3860.40 2663.46 -4706.31 0.00 0.00 5407.72 MPJ-25L1 T4 -. ".,...../' #~ '.. . ! · ................±t¡ · 1',~i;tTI';y, I / ,nu Uoe }~;ff·'" .....! .. mmm; ..: 111 II m/ ............. l /...../ Ehd;:;'~,:r:i·¡;,lrftl...'~~~".I.4.......'...'. ...../...../ i ! Äml,/. · / / 3l45'.MD,' '1' / .~úJ:,.i·~~' I;;¡"~, ·1 ...., ...... ..... ",,,~-JJ~ .v:~:~ .. i U'. ·fr'""'ilr±tJ\ I .~ - F ,. "" .MJ~J'¿' ,I". MI"'¿'"I In"... '.uIl3, .. ....m, ...........,. .. .., " '+i' , ¡ ,... , . : , ; I : i I I . i ¡ . i' M)o jilt·u ~. "DJ", · . . / / . . " . . " ." "",. .. .. . \ ' 4" Scree --'-"1/ ;,\;,m l 80~ i \ M Z5LI13' i "~ " >or' "l~f -,", I ·I····:·····j·····:··i.... . . ······iIL .... , , . v,. , ...... , , 1 .... , ..... . +... . ...., '.m. ,... .... ...... , . . , , i , ¡ I , ¡ . . , . , , I , , , , I , , , , , , , I , , , , , , I , , , , 2500 3000 3500 4000 4500 Vertical Section at 299.5" [500ft/in] . I , , , , , I I , , , i I ! I : , , , 5000 5500 e . BP Planning Report Plan: MPJ-25 WP16 Principal: Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M pt J Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013415.23 ft 551435.10 ft Well: Plan MPJ-25 New Conductor Location Well Position: +N/-S 1719.30 ft Northing: 6015137.64 ft +E/-W 480.11 ft Easting: 551903.29 ft Position Uncertainty: 0.00 ft Wellpath: Plan MPJ-25 Current Datum: Magnetic Data: Field Strength: Vertical Section: 36.1 +34.3 4123/2004 57557 nT Depth From (TVD) ft 34.30 Height 60.40 ft +N/-S ft 0.00 Casing Points Date Composed: Version: Tied-to: 4/19/2004 64 From: Definitive Path Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Latitude: 70 26 Longitude: 149 34 North Reference: Grid Convergence: 50.647 N 49.503 W True 0.40 deg Slot Name: Latitude: Longitude: 70 27 7.556 N 149 34 35.402 W Drilled From: TIe-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Plan MPJ-25 PB1 4050.00 ft Mean Sea Level 24.90 deg 80.86 deg Direction deg 299.51 6.750 4" Screens 8458.00 3860.41 4.000 Formations 5636.70 3885.90 Fault 3 0.00 0.00 6851.70 3870.32 Fault 4 0.00 0.00 7456.70 3882.08 Fault 5 0.00 0.00 8271.70 3864.59 Fault 6 0.00 0.00 0.00 BPRF 0.00 0.00 0.00 TUZC 0.00 0.00 0.00 Ugnu-MA 0.00 0.00 0.00 Ugnu-MB1 0.00 0.00 0.00 Ugnu-MB2 0.00 0.00 4147.48 3797.70 Ugnu-MC 0.00 0.00 4244.61 3835.70 SBF2-NA 0.00 0.00 4574.65 3871.70 SBF1-NB 0.00 0.00 0.00 SBF1-NC 0.00 0.00 0.00 SBE2-NE 0.00 0.00 0.00 SBE1-NF 0.00 0.00 0.00 TSBD-Top OA 0.00 0.00 0.00 TSBC-Base OA 0.00 0.00 0.00 TSBB-Top OB 0.00 0.00 0.00 SBA5-Base OB 0.00 0.00 e . BP Planning Report Targets MPJ-25L 1 T4 3860.40 2663.46 -4706.31 6017768.00 547179.00 70 27 33.736 N 149 36 53.679 W MPJ-25L 1 T2a 3870.40 1825.23 -3394.99 6016939.00 548496.00 70 27 25.499 N 1493615.139W MPJ-25 TO 3870.40 944.80 -1288.55 6016073.36 550608.31 70 27 16.847 N 149 35 13.252 W MPJ-25L 1 T3a 3880.40 2321.70 -3884.59 6017432.00 548003.00 70 27 30.379 N 149 36 29.531 W MPJ-25L 1 T1a 3885.40 1469.29 -2405.35 6016590.00 549488.00 70 27 22.002 N 149 35 46.063 W MPJ-25 Poly 3885.40 1469.29 -2405.35 6016590.00 549488.00 70 27 22.002 N 149 35 46.063 W -Polygon 1 3885.40 2168.34 -3827.63 6017279.05 548061.03 70 27 28.871 N 149 36 27.855 W -Polygon 2 3885.40 1692.79 -3471.91 6016806.04 548420.01 70 2724.196 N 149 36 17.397 W -Polygon 3 3885.40 1536.67 -3172.97 6016652.03 548720.00 70 27 22.662 N 149 36 8.613 W -Polygon 4 3885.40 1327.42 -2426.34 6016448.00 549467.99 70 27 20.607 N 149 35 46.678 W -Polygon 5 3885.40 665.88 -1075.81 6015795.95 550822.97 70 27 14.104 N 149 35 7.002 W -Polygon 6 3885.40 854.81 -919.47 6015985.94 550977.98 70 27 15.962 N 149 35 2.410 W -Polygon 7 3885.40 1543.01 -2220.81 6016664.99 549672.00 70 27 22.728 N 149 35 40.642 W -Polygon 8 3885.40 1746.17 -2954.48 6016863.02 548937.01 70 27 24.723 N 149 36 2.197 W -Polygon 9 3885.40 1895.46 -3279.47 6017010.03 548611.02 70 27 26.190 N 149 36 11.747 W -Polygon 10 3885.40 2326.95 -3627.49 6017439.05 548260.03 70 27 30.432 N 149 36 21.977 W -Polygon 11 3885.40 2800.73 -4730.31 6017905.09 547154.05 70 27 35.086 N 149 36 54.386 W -Polygon 12 3885.40 2597.52 -4846.74 6017701.09 547039.04 70 27 33.086 N 149 36 57.804 W MPJ-25L 1 Tint 3885.40 1063.20 -1538.07 6016190.00 550358.00 70 27 18.011 N 149 35 20.583 W Plan Section Information 4050.00 49.50 305.00 3742.33 695.01 -884.29 0.00 0.00 0.00 0.00 4070.00 51.89 304.79 3755.00 703.86 -896.98 12.00 11.97 -1.06 -4.00 4354.57 85.86 300.90 3856.09 844.82 -1117.26 12.00 11.94 -1.36 -6.91 4507.71 85.86 300.90 3867.15 923.27 -1248.31 0.00 0.00 0.00 0.00 4553.48 86.00 295.40 3870.40 944.80 -1288.55 12.00 0.31 -12.03 -88.72 MPJ-25 TO 4562.07 86.60 295.41 3870.95 948.48 -1296.30 7.00 6.99 0.15 1.23 4781.33 86.60 295.41 3883.95 1042.41 -1493.99 0.00 0.00 0.00 0.00 4830.10 90.00 295.09 3885.40 1063.20 -1538.07 7.00 6.97 -0.66 -5.42 MPJ-25L1 Tint 4833.45 89.96 295.32 3885.40 1064.63 -1541.10 7.00 -1.07 6.92 98.76 5707.77 89.96 295.32 3885.95 1438.59 -2331.42 0.00 0.00 0.00 0.00 5787.86 90.82 289.78 3885.40 1469.29 -2405.35 7.00 1.06 -6.92 -81.24 MPJ-25L 1 T1a 5900.22 91.30 281.93 3883.32 1499.96 -2513.33 7.00 0.43 -6.99 -86.40 6377.95 91.30 281.93 3872.47 1598.69 -2980.62 0.00 0.00 0.00 0.00 6857.01 89.18 315.40 3870.40 1825.23 -3394.99 7.00 -0.44 6.99 93.45 MPJ-25L1 T2a 6971.37 88.32 326.02 3872.90 1913.58 -3467.28 9.32 -0.75 9.29 94.72 7180.32 88.32 326.02 3879.03 2086.78 -3584.01 0.00 0.00 0.00 0.00 7568.21 91.29 290.00 3880.40 2321.70 -3884.59 9.32 0.76 -9.29 -85.51 MPJ-25L 1 T3a 7605.90 91.29 292.64 3879.55 2335.40 -3919.69 7.00 0.00 7.00 89.97 /8458.40 91.29 292.64 3860.40 2663.46 -4706.31 0.00 0.00 0.00 0.00 MPJ-25L 1 T4 . . BP Planning Report Survey 4050.00 49.50 305.00 3742.33 695.01 -884.29 404.18 -2414.31 MWD+IFR+MS 4070.00 51.89 304.79 3755.00 703.86 -896.98 416.87 -2423.17 MWD+IFR+MS 4075.00 52.49 304.70 3758.06 706.11 -900.23 420.12 -2425.42 MWD+IFR+MS 4100.00 55.47 304.26 3772.76 717.56 -916.90 436.79 -2436.86 MWD+IFR+MS 4125.00 58.45 303.86 3786.39 729.29 -934.26 454.15 -2448.60 MWD+IFR+MS 4147.48 61.13 303.52 3797.70 740.07 -950.42 470.31 -2459.37 Ugnu-MC 4150.00 61.43 303.48 3798.91 741.29 -952.27 472.15 -2460.59 MWD+IFR+MS 4175.00 64.42 303.12 3810.29 753.50 -970.87 490.76 -2472.81 MWD+IFR+MS 4200.00 67.40 302.78 3820.49 765.91 -990.02 509.91 -2485.22 MWD+IFR+MS 4225.00 70.38 302.45 3829.50 778.48 -1009.66 529.55 -2497.79 MWD+IFR+MS 4244.61 72.73 302.20 3835.70 788.43 -1025.38 545.27 -2507.74 SBF2-NA 4250.00 73.37 302.14 3837.27 791.18 -1029.74 549.63 -2510.48 MWD+IFR+MS 4275.00 76.35 301.83 3843.80 803.96 -1050.21 570.10 -2523.26 MWD+IFR+MS 4300.00 79.34 301.54 3849.06 816.79 -1071.01 590.89 -2536.10 MWD+IFR+MS 4325.00 82.33 301.24 3853.04 829.65 -1092.07 611.96 -2548.95 MWD+IFR+MS 4350.00 85.31 300.96 3855.74 842.48 -1113.35 633.24 -2561.79 MWD+IFR+MS 4354.57 85.86 300.90 3856.09 844.82 -1117.26 637.15 -2564.13 MWD+IFR+MS 4400.00 85.86 300.90 3859.37 868.10 -1156.14 676.03 -2587.40 MWD+IFR+MS 4507.71 85.86 300.90 3867.15 923.27 -1248.31 768.20 -2642.58 MWD+IFR+MS 4525.00 85.91 298.82 3868.39 931.86 -1263.27 783.16 -2651.16 MWD+IFR+MS 4550.00 85.99 295.82 3870.16 943.30 -1285.42 805.31 -2662.61 MWD+IFR+MS 4553.48 86.00 295.40 3870.40 944.80 -1288.55 808.44 -2664.11 MPJ-25 TO 4562.07 86.60 295.41 3870.95 948.48 -1296.30 816.19 -2667.79 MWD+IFR+MS 4574.65 86.60 295.41 3871.70 953.87 -1307.64 827.52 -2673.18 SBF1-NB 4600.00 86.60 295.41 3873.20 964.73 -1330.49 850.38 -2684.04 MWD+IFR+MS 4700.00 86.60 295.41 3879.13 1007.57 -1420.66 940.55 -2726.87 MWD+IFR+MS 4781.33 86.60 295.41 3883.95 1042.41 -1493.99 1013.88 -2761.71 MWD+IFR+MS 4800.00 87.90 295.29 3884.85 1050.39 -1510.84 1030.73 -2769.70 MWD+IFR+MS 4830.10 90.00 295.09 3885.40 1063.20 -1538.07 1057.96 -2782.51 MPJ-25L 1 Tint 4833.45 89.96 295.32 3885.40 1064.63 -1541.10 1060.99 -2783.93 MWD+IFR+MS 4900.00 89.96 295.32 3885.44 1093.09 -1601.26 1121.15 -2812.40 MWD+IFR+MS 5000.00 89.96 295.32 3885.50 1135.87 -1691.65 1211.54 -2855.17 MWD+IFR+MS 5100.00 89.96 295.32 3885.57 1178.64 -1782.04 1301.93 -2897.94 MWD+IFR+MS 5200.00 89.96 295.32 3885.63 1221.41 -1872.44 1392.32 -2940.71 MWD+IFR+MS 5300.00 89.96 295.32 3885.69 1264.18 -1962.83 1482.72 -2983.48 MWD+IFR+MS 5400.00 89.96 295.32 3885.75 1306.95 -2053.22 1573.11 -3026.26 MWD+IFR+MS 5500.00 89.96 295.32 3885.82 1349.72 -2143.61 1663.50 -3069.03 MWD+IFR+MS 5600.00 89.96 295.32 3885.88 1392.49 -2234.00 1753.89 -3111.80 MWD+IFR+MS 5636.70 89.96 295.32 3885.90 1408.19 -2267.17 1787.06 -3127.50 Fault 3 5707.77 89.96 295.32 3885.95 1438.59 -2331.42 1851.31 -3157.89 MWD+IFR+MS 5750.00 90.41 292.40 3885.81 1455.67 -2370.03 1889.92 -3174.97 MWD+IFR+MS 5787.86 90.82 289.78 3885.40 1469.29 -2405.35 1925.24 -3188.60 MPJ-25L1 T1a 5800.00 90.87 288.93 3885.22 1473.32 -2416.80 1936.69 -3192.62 MWD+IFR+MS 5850.00 91.09 285.44 3884.37 1488.09 -2464.56 1984.44 -3207.39 MWD+IFR+MS 5900.22 91.30 281.93 3883.32 1499.96 -2513.33 2033.22 -3219.27 MWD+IFR+MS 6000.00 91.30 281.93 3881.05 1520.58 -2610.93 2130.82 -3239.89 MWD+IFR+MS 6100.00 91.30 281.93 3878.78 1541.25 -2708.75 2228.63 -3260.55 MWD+IFR+MS 6200.00 91.30 281.93 3876.51 1561.91 -2806.56 2326.45 -3281.22 MWD+IFR+MS 6300.00 91.30 281.93 3874.24 1582.58 -2904.38 2424.26 -3301.89 MWD+IFR+MS 6377.95 91.30 281.93 3872.47 1598.69 -2980.62 2500.51 -3317.99 MWD+IFR+MS 6400.00 91.21 283.47 3871.98 1603.54 -3002.13 2522.02 -3322.84 MWD+IFR+MS 6450.00 90.99 286.96 3871.02 1616.66 -3050.36 2570.25 -3335.96 MWD+IFR+MS 6500.00 90.77 290.46 3870.25 1632.69 -3097.7rJ 2617.59 -3352.00 MWD+IFR+MS . . BP Planning Report Survey 6550.00 90.55 293.95 3869.67 1651.58 -3143.98 2663.87 -3370.89 MWD+IFR+MS 6600.00 90.33 297.44 3869.29 1673.26 -3189.03 2708.92 -3392.57 MWD+IFR+MS 6650.00 90.10 300.94 3869.10 1697.64 -3232.67 2752.56 -3416.95 MWD+IFR+MS 6700.00 89.88 304.43 3869.10 1724.64 -3274.75 2794.64 -3443.94 MWD+IFR+MS 6750.00 89.65 307.92 3869.31 1754.15 -3315.10 2834.99 -3473.45 MWD+IFR+MS 6800.00 89.43 311.42 3869.71 1786.06 -3353.58 2873.47 -3505.37 MWD+IFR+MS 6850.00 89.21 314.91 3870.30 1820.26 -3390.04 2909.93 -3539.56 MWD+IFR+MS 6851.70 89.20 315.03 3870.32 1821.46 -3391.25 2911.14 -3540.76 Fault 4 6857.01 89.18 315.40 3870.40 1825.23 -3394.99 2914.88 -3544.53 MPJ-25L 1 T2a 6900.00 88.85 319.39 3871.14 1856.86 -3424.08 2943.97 -3576.16 MWD+IFR+MS 6950.00 88.48 324.04 3872.31 1896.08 -3455.04 2974.93 -3615.39 MWD+IFR+MS 6971.37 88.32 326.02 3872.90 1913.58 -3467.28 2987.17 -3632.89 MWD+IFR+MS 7000.00 88.32 326.02 3873.74 1937.32 -3483.28 3003.17 -3656.62 MWD+IFR+MS 7100.00 88.32 326.02 3876.67 2020.21 -3539.14 3059.03 -3739.51 MWD+IFR+MS 7180.32 88.32 326.02 3879.03 2086.78 -3584.01 3103.90 -3806.09 MWD+IFR+MS 7200.00 88.46 324.19 3879.58 2102.92 -3595.27 3115.15 -3822.22 MWD+IFR+MS 7250.00 88.84 319.55 3880.76 2142.23 -3626.12 3146.01 -3861.53 MWD+IFR+MS 7300.00 89.22 314.90 3881.60 2178.91 -3660.06 3179.95 -3898.22 MWD+IFR+MS 7350.00 89.61 310.26 3882.12 2212.74 -3696.86 3216.75 -3932.04 MWD+IFR+MS 7400.00 89.99 305.62 3882.29 2243.47 -3736.29 3256.17 -3962.77 MWD+IFR+MS 7450.00 90.38 300.98 3882.13 2270.91 -3778.06 3297.95 -3990.22 MWD+IFR+MS 7456.70 90.43 300.36 3882.08 2274.33 -3783.83 3303.72 -3993.63 Fault 5 7500.00 90.77 296.33 3881.63 2294.88 -3821.93 3341.81 -4014.19 MWD+IFR+MS 7550.00 91.15 291.69 3880.79 2315.22 -3867.58 3387.47 -4034.52 MWD+IFR+MS 7568.21 91.29 290.00 3880.40 2321.70 -3884.59 3404.48 -4041.00 MPJ-25L 1 T3a 7600.00 91.29 292.23 3879.69 2333.15 -3914.24 3434.13 -4052.45 MWD+IFR+MS 7605.90 91.29 292.64 3879.55 2335.40 -3919.69 3439.58 -4054.70 MWD+IFR+MS 7700.00 91.29 292.64 3877.44 2371.61 -4006.52 3526.41 -4090.91 MWD+IFR+MS 7800.00 91.29 292.64 3875.19 2410.09 -4098.79 3618.68 -4129.40 MWD+IFR+MS 7900.00 91.29 292.64 3872.95 2448.57 -4191.06 3710.95 -4167.88 MWD+IFR+MS 8000.00 91.29 292.64 3870.70 2487.06 -4283.33 3803.22 -4206.36 MWD+IFR+MS 8100.00 91.29 292.64 3868.45 2525.54 -4375.61 3895.49 -4244.84 MWD+IFR+MS 8200.00 91.29 292.64 3866.21 2564.02 -4467.88 3987.77 -4283.33 MWD+IFR+MS 8271.70 91.29 292.64 3864.59 2591.61 -4534.04 4053.92 -4310.92 Fault 6 8300.00 91.29 292.64 3863.96 2602.50 -4560.15 4080.04 -4321.81 MWD+IFR+MS 8400.00 91.29 292.64 3861.71 2640.99 -4652.42 4172.31 -4360.29 MWD+IFR+MS 8458.00 91.29 292.64 3860.41 2663.31 -4705.94 4225.83 -4382.61 4" Screens ,/ 8458.40 91.29 292.64 3860.40 ,¡ 2663.46 -4706.31 4226.20 -4382.77 MPJ-25L 1 T 4 . . BP Anticollision Report GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 34.30 to 4708.43 ft Maximum Radius: 667.41 ft Reference: Error Model: Scan Method: Error Surface: Plan: MPJ-25PB1 WP06 & NOT PLANNEß PROGI ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points 2381.57 2360.40 4030.00 3729.34 10.750 7.625 13.500 9.875 103/4" 7 5/8" Plan: MPJ-25PB1 WP06 Date Composed: Version: Tied-to: 4/23/2004 52 From Well Ref. Point Principal: Yes Summary MPtJPad MPJ-01 MPJ-01 V3 2437.05 2500.00 100.73 46.98 53.76 Pass: Major Risk M PtJ Pad MPJ-01 MPJ-01A V2 2437.05 2500.00 100.73 46.98 53.75 Pass: Major Risk M pt J Pad MPJ-01 MPJ-01AL1 V6 2437.05 2500.00 100.73 46.98 53.76 Pass: Major Risk M pt J Pad MPJ-02 MPJ-02 V1 339.19 350.00 151.48 7.98 143.50 Pass: Major Risk M PtJ Pad MPJ-03 MPJ-03 V1 411.18 425.00 212.94 11.43 201.51 Pass: Major Risk M PtJ Pad MPJ-06 MPJ-06 V1 3049.84 3275.00 308.63 48.63 260.00 Pass: Major Risk M PtJ Pad MPJ-08A MPJ-08A V7 3411.72 3550.00 134.57 82.79 51.78 Pass: Major Risk M Pt J Pad MPJ-08 MPJ-08 V1 3411.72 3550.00 134.57 82.70 51.87 Pass: Major Risk MPtJPad MPJ-09A MPJ-09A V3 2203.07 2375.00 250.96 61.31 189.66 Pass: Major Risk MPtJPad MPJ-09 MPJ-09 V1 2203.07 2375.00 250.96 61.31 189.66 Pass: Major Risk M PtJ Pad MPJ-10 MPJ-10 V1 402.05 400.00 240.12 8.11 232.01 Pass: Major Risk M PtJ Pad MPJ-11 MPJ-11 V1 1599.48 1625.00 112.69 33.58 79.10 Pass: Major Risk M PtJ Pad MPJ-15 MPJ-15 V5 1522.08 1675.00 135.21 47.14 88.08 Pass: Major Risk M Pt J Pad MPJ-16 MPJ-16 V1 2090.44 2250.00 83.33 57.96 25.37 Pass: Major Risk M PtJ Pad MPJ-18 MPJ-18 V2 2053.78 2200.00 277.19 58.66 218.54 Pass: Major Risk M Pt J Pad MPJ-23 MPJ-23 VO 60.40 0.00 60.25 No Offset Stations M PtJ Pad MPJ-23 MPJ-23L 1 VO 60.40 0.00 60.25 No Offset Stations M PtJ Pad MPJ-24 MPJ-24 V11 517.87 525.00 30.59 9.86 20.74 Pass: Major Risk M PtJ Pad MPJ-24 MPJ-24L 1 V4 517.87 525.00 30.59 9.75 20.84 Pass: Major Risk M Pt J Pad MPJ-24 MPJ-24L1PB1 VO 60.40 66.05 29.32 No Offset Stations M Pt J Pad MPJ-24 MPJ24L1PB2 V3 517.87 525.00 30.59 9.75 20.84 Pass: Major Risk M Pt J Pad Plan MPJ-14 Plan MPJ-14 V15 Plan: 3029.07 3425.00 334.02 59.42 274.60 Pass: Major Risk M Pt J Pad Plan MPJ-14 Plan MPJ-14L 1 V5 Plan: 3029.07 3425.00 334.02 59.42 274.60 Pass: Major Risk M PtJ Pad Plan MPJ-25 old Plan MPJ-25 KIO Plug 0 3963.68 4250.00 168.90 0.00 168.90 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25 option VO 4058.95 4425.00 14.18 0.00 14.17 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25 VO Plan: M 4244.67 4550.00 53.09 0.00 53.09 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25PB1 VO Plan 4687.82 4975.01 65.79 0.00 65.78 Pass: NOERRORS M Pt J Pad Plan MPJ-25 Plan MPJ-25 VO Plan: M 2900.00 2900.00 0.00 0.00 0.00 FAIL: NOERRORS M PtJ Pad Plan MPJ-Cipher Plan MPJ-Cipher VO Pia 1164.85 1225.00 253.91 30.32 223.58 Pass: Major Risk M PtJ Pad Plan MPJ-Dozer Plan MPJ-Dozer VO Plan 4501.37 7825.00 102.48 0.00 102.48 Pass: NOERRORS M PtJ Pad Plan MPJ-Jax Plan MPJ-Jax VO Plan: 669.74 700.00 271.21 15.48 255.73 Pass: Major Risk M PtJ Pad Plan MPJ-Kali Plan MPJ-Kali VO Plan: 1282.85 1350.00 220.65 33.12 187.54 Pass: Major Risk M PtJ Pad Plan MPJ-L Plan MPJ-L V11 Plan: M 722.15 725.00 35.50 15.28 20.22 Pass: Major Risk M PtJ Pad Plan MPJ-L Plan MPJ-LL 1 V6 Plan: 722.15 725.00 35.50 15.18 20.32 Pass: Major Risk M PtJ Pad Plan MPJ-N6 Plan MPJ-N6 V10 Plan: 468.88 475.00 19.37 11.23 8.14 Pass: Major Risk M PtJ Pad Plan MPJ-N6 Plan MPJ-N6L 1 V1 Plan: 468.88 475.00 19.37 11.32 8.05 Pass: Major Risk M Pt J Pad Plan MPJ-Y Plan MPJ-Y V5 Plan: MP 294.40 300.00 3.31 0.00 3.31 Pass: NOERRORS M Pt J Pad Plan MPJ-Y Plan MPJ-YL 1 V5 Plan: 294.40 300.00 3.31 No Reference Casings M PtJ Pad Plan MPJ-Zee Plan MPJ-Zee VO Plan: 1186.80 1250.00 239.25 31.76 207.49 Pass: Major Risk MPU J-25 and J-25 Pilot ole r~ ~ 1\ ~",j Gridlines outline governmental 1/4-1/4-1/4 drillling units required by CO 477. I I o . I 500 Feet I . 1,000 J 1,500 SFD 5/1012004 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 101 "Mastercard Check" DATE PAY TO THE '\ +r:: A·· ~\,. Cli't A ~iA· ()6rJc $ Il'·) ORDER OF ~ ) ~ ,- .ç _..- I ,- ..¡ ex') ~ndJ\j2Ü ¡ " OLr·-············ First National Bank Alaska Anchorage, AK 99501 DOITARS . MEMO ~Vì .: * 2 5 2000 b 0.: ~ ~ * 1...111 b 2 2 7111 * 5 5 b II- 0 * 0 * . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME \-\.~ '0 ~\7 t-'> "\..:-:-> "'\ ~ (-) ~ç- PTD# <\;;a L_\ - CJ ~ -S / Development Service CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dum ber last two (2) digits are between 60-69) Exploration Stratigraphic "CLUE" Tbe permit is for a new well bore segment of existing well, . Permit No, . API No. Production.sbould continue to be reported as a function' of tbe original API number. stated above. /' HOLE In accordance witb 20 AAC 25.005(t), all records, data and logs acquired for tbe pilot hole must be clearly differentiated In both name (name on permit plus PH) ...¡:: 25"'f?H and API Dumber (50 {) 2-"/' ~ 2- 3;zL7 - 7Ò ~. from records, data and logs acquired for well (name on permit). PD..,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:Jception. (Company Name) assumes tbe liability of any protest to tbe spacinge:Jception tbat may occur. An dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrougb target zones. D D Well bore seg Annular Disposal On Program DEV On/Off Shore 11328 Unit Well Name: MILNE PT UNIT SB J-25 DEV / PEND GeoArea890 intervalitl ADL 025~906; J"DJn ADL 025515, Ae!ditioo mad~ to .40I: SUJface and top ~pJQductiYe a Qu~arter-CLuarteJ-çuarter goyernmental ~edioo. requirements. tb~ CO.47I $paciog ~conforming çonJOflJ1S to~ 1Q-acJe drilling uoits CO .47I requires This hOJi~o~ntal produ~tiQnwel . Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA NA Initial ClasslType MILNE POINT, SCHRADER BLFF OIL - 525140 INC Field & Pool BP EXPLORATION (ALASKA) Permitfee attached Company Leasenumb~r appropriate ~U-"i~ue wel'-n~ame ~atld ou~mber Jo~cated i-"-a~defined pool distance~ WeJ WeJI WeJ boundary ~ from~ drilling unit from otbeJ wells Jo~cated proper Jocated proper distance~ ~Sutficient acreage ~aYail¡;¡ble in~dJilJiog unit Jfdeviated, 2 3 4 5 6 7 8 9 PTD#: 2040730 Administration is wellboJe platincludee! bas~appropriate~b.ond il Jorce~ catl be issu~ed wjtbo~ut conservation ord~r Catl be i~su~ed witho~ut ~"'~'n'~""""~~ ",..n· ,'~" be approved befol JQ d within area an~d~~ 'Jtljection Order # (puUO# yU-, l!h!I",,!:LI_IU.~h_~ ""-;f"'I'pvaJ only affected paJty Permit Can pe."... .operator .operator Permit in~commetltsUfor only) reyiew dur¡;¡{jo_n _of pre-produdion less_ tban 3 months_(for .seryiœ welt ACMPFinding .of Con~istetlcyhas been is.suedJorJbis prolect only) idetltlfiee! (For s.ervice welJ WeJ All wells.witþio Jl4J1Jile.are.a.of Pre.-produœd. itljector 10 11 12 13 14 15 16 7 Date Appr SFD 5/10/2004 driJIee! fro.mexistioge!riJling pad, Wel Altaquifers exempted 40 CfR 147;102(b)(3) Screened completion planned welJ(s) I NOJe$eNe.pjtptanne.d. At' wa$te to.Class Rig js.e.quippedwitb steelpit$. GyrO$ plan.nee! io.surfaçe Þole. I:'ro~imity. analysi$ peJformed.. Ctose apprQache~ id.e!1tified. . 9.3 ppg. - I:'lanned m!ld weights S.8 MaxJmum 61:11:' 8..4EMW. I:'lann.ed BOP .test pre$s.ure4500 psJ Calculat~d_MASP 1372 p$i .Yes NA .Yes N.o. No. Yes Yes NA Yes Yes Yes Yes Yes Yes Yes N_o~ NA. ÇOtle!uçtor $trin.9-PJovided Surface "a~:nn n'^'ð"~"1 known. USDW$ CMTvol ,Iate.oo_conductor :"J.....-_II!>:7 I'""_."'!!:L~~_L"'_~I & $urf.C$g tie-in IQng ~tJi!1g to surf CS.9. .CMT vol. a.deQu_ate~ to KnOwn productiye hOJllon~ C, Adequ¡;¡tetankageoJ re~erye pit Jf.a.re-drJII, bas~a 10-4.03 fOJ ¡;¡ba.ndonment beeo aPPJQved Adequate .w.et!bore. $eparation propO$ed t Jfdivert~r DJiUiog ftuid_pJogJam schematlc_&_ equip Jist.adeCLuate meet reguJaJions J~quiJ~d. dQes p$ig io ~comment$) 84) to (pu.t ÇÞokemanifQld cQmpJies_ w/API RP-53. (M.ay WOJk will occur without .operatioo ~butdown .BOPEs..do Jhey meetreguJa.tion BOPE.pre~ss ratiog appropriate; J~st 8 9 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Engineering T, 6 _&.permafrost .CMTwill coyer at .Casitlg desigtlS ad.equaJe for Date 5/4/2004 Appr TEM Js~ presence. oJ H2S gas pJob.able Mechanical.coodjti.otl of. weJls within AOR verified~ (For service well onJy) W¡;¡lteJ Quay, 6P..412010.4; 00 H2S I<nown In.J~-l:'adwell$ to.d¡;¡te. SFD E$timate .res.ervoiJ pressure.is SA ppb EMW; wit! be drilled with 8.9 -. 9.3 PP.9~mud. J-P¡;¡d.. SED l:Iydrates~have not been_seen at Yes Yes NA NA catl be i~su.ed wlo hydrogen s_utfide measures Permit .Data.PJ~sentee! on. potential oveJpres~sure zones Seismic analysis. oJ shaJlow gaszoo~s_ 35 36 37 38 Date 5/10/2004 Geology Appr SFD Date Public Commissioner Date Off-shore) Engineering Commissioner Jif .Seabed ~conditioo survey Date: S/ID/1 Geologic Commissioner [>TS . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this 1ature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . mpj-25.tapx sperry-sun Drilli~g.services LIS Scan Utlllty $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 10 12:14:00 2007 Reel Header Service name............ .LISTPE Date. . . . . . . .. . . . . . . . . . . . .07/08/10 origi n . . . . . ... . . . . . . . . . . . STS Ree 1 Name................ UNKNOWN Continuation Number..... .01 previous Reel Name...... . UNKNOWN Comments....... ..........STS LIS writing Library. Scientific Technical services Tape Header Service name.... .........LISTPE Date............. ..... ...07/08/10 Ori gi n . . . . . . . . . . . . . . . . . . . STS Tape Name.... ........... . UNKNOWN Continuation Number......01 Previous Tape Name.... ...UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical services phys i ca 1 EOF Comment Record TAPE HEADER Milne point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA SCANNED AUG 2 7 Z007 MPJ-25 500292320700 BP Exploration (Alaska), Inc. Sperry Sun 10-AUG-07 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 Mw0003149211 C. ZAWADZKI E. VAUGHN MWD RUN 2 Mw0003149211 T. MCGUIRE D. GREEN MWD RUN 3 MW0003149211 T. MCGUIRE D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 28 13N 10E 2741 3413 .00 34.04 36.10 # WELL CASING RECORD page 1 f)ol..!-D'1ß :tJ= /6~z.¡~ . . 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13 . 500 9.875 6.750 mpj-25.tapx CASING DRILLERS SIZE (IN) DEPTH eFT) 10.750 7.625 2397.0 4037.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED . DEPTHS REFER TO BIT DEPTHS. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DGR, ELECTROMAGENTIC WAVE RESISITIVTY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO-DENSITY (SLD), BIMODAL ACOUSTIC TOOL (BAT), MAGNETIC RESONANCE IMAGING-WHILE DRILLING (MRI-WD), AND PRESSURE WHILE DRILLING (PWD). DATA FOR CURVES OTHER THAN GR-EWR-4 CAN BE FOUND IN THE LOGS FROM MPJ-25 PB1 WELLBORE. 4. MWD RUN 3 IS DIRECTIONAL WITH DGR AND EWR-4. THIS WELL KICKS OFF FROM WELL MPJ-25 PB1 AT 4037'MD/3726' TVD. 5. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. MRI-WD DATA IS ALSO SMOOTHED TO ALl FT WINDOW. ACAL CALIBRATION FACTOR = 0.963 6. MWD DATA IS DEPTH SHIFTED TO THE PDC GR LOG (SWS CMR-GR) OF 03-JUL-2004. LOG HEADER AND REMARKS SECTIONS RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 7. MWD RUNS 1-3 REPRESENT WELL MPJ-25 WITH API#: 50-029-23207-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8348' MD, 3872' 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. page 2 $ . File Header service name............ .STSLIB.001 service sub Level Name... version Number.......... .1.0.0 Date of Generation...... .07/08/10 Maximum physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPX RPM RPD RPS $ 1 . mpj-25.tapx clipped curves; all bit runs merged. .5000 START DEPTH 91.0 131. 5 2346.5 2348.5 2348.5 2348.5 2348.5 STOP DEPTH 8290.0 8346.5 8297.5 8297.5 8297.5 8297.5 8297.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --. BASELINE DEPTH 91.0 3484.0 3489.5 3496.5 3513.0 3526.0 3540.0 3548.5 3552.0 3569.5 3578.0 3586.5 3591. 0 3606.0 3610.5 3625.0 3630.0 3638.5 3647.0 3659.0 3665.0 3691. 5 3715.0 3723.5 3734.5 3749.5 3757.5 3764.0 3787.5 3805.5 3808.5 GR 94.5 3487.5 3493.0 3499.5 3516.0 3529.0 3543.0 3551. 0 3554.5 3574.0 3580.5 3589.5 3594.5 3609.0 3613.0 3628.0 3632.5 3642.0 3650.0 3661. 0 3667.5 3694.0 3717.0 3725.5 3736.5 3751. 5 3759.5 3766.0 3788.5 3807.0 3810.5 page 3 . . 3816.5 3826.0 3834.5 3840.0 3854.0 3860.0 3862.5 3870.5 3877 .5 3892.5 3913 .5 3926.0 3937.0 3947.0 3951. 0 3953.0 3955.0 3957.0 3995.5 4003.0 4006.5 4011.0 4026.5 4029.5 4035.5 8290.0 8346.5 $ 3818.5 3828.0 3836.5 3842.0 3856.0 3862.5 3865.0 3872.5 3879.5 3895.0 3916.5 3929.0 3938.0 3949.0 3952.5 3954.5 3956.5 3958.5 3997.0 4004.5 4008.0 4012.5 4028.0 4031. 0 4037.0 8291.5 8348.0 mpj-25.tapx # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 94.5 2409.5 4037.0 MERGE BASE 2409.5 4037.0 8348.0 # REMARKS: MERGED MAIN PASS. $ # Data Format specification Record Data Record Type..................O Data specification Block Type.....O Logging Direction................ . Down optlcal log depth units.......... .Feet Data Reference Point............ ..Undefined Frame spacing... ............. .....60 .1IN Max frames per record........ .....undefined Absent value...... ........... .....-999.25 Depth uni ts. . . . . . . . . . . . . . . . . . . . . . . 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 page 4 . . mpj-25.tapx Fi rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 91 8346.5 4218.75 16512 91 8346.5 ROP MWD FT/H 0 825.153 190.198 16431 131. 5 8346.5 GR MWD API 12.29 116.853 61.1431 16399 91 8290 RPX MWD OHMM 1. 24 2000 46.2701 11899 2348.5 8297.5 RPS MWD OHMM 1. 35 2000 61.1567 11899 2348.5 8297.5 RPM MWD OHMM 1.0662 2000 86.0911 11899 2348.5 8297.5 RPD MWD OHMM 0.2 2000 109.07 11899 2348.5 8297.5 FET MWD HOUR 0.1778 86.9531 0.935617 11903 2346.5 8297.5 First Reading For Entire File..........91 Last Reading For Entire File. ..........8346.5 File Trailer service name.. ...........STSLIB.001 service sub Level Name... Version Number... ........1.0.0 Date of Generation.......07/08/10 Maximum physical Record..65535 Fi 1 e Type..... . . . . . . . . . . . LO Next File Name.......... .STSLIB.002 phys i ca 1 EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .07/08/10 Maximum physical Record. .65535 Fi 1 e 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 94.5 135.0 STOP DEPTH 2369.0 2409.5 # 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 28-JUN-04 Insite o Memory 2409.5 94.5 2409.5 Page 5 . mpj-25.tapx # 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.......... ........0 Data specification Block Type.....O Logging Direction................ . Down optlcal log depth units...... .... .Feet Data Reference Point......... .....undefined Frame spacing..... .... ............60 .1IN Max frames per record... ..........undefined Absent value............. .........-999.25 Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Name Service order DEPT ROP MWD010 GR MWD010 .0 2409.0 TOOL NUMBER 61497 13 . 500 .0 spud Mud 9.40 80.0 8.0 300 9.4 .000 .000 .000 .000 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 Name Service unit DEPT FT ROP MWD010 FT/H GR MWD010 API Min 94.5 8.2479 16.9829 Max 2409.5 481. 82 116.853 First Reading For Entire File... .......94.5 Page 6 Mean 1252 169.06 64.3173 Nsam 4631 4550 4550 . .0 80.6 .0 .0 Fi rst Reading 94.5 135 94.5 Last Reading 2409.5 2409.5 2369 . . mpj-25.tapx Last Reading For Entire File.... ...... .2409.5 File Trailer service name............ .STSLIB.002 Service Sub Level Name... version Number.... .......1.0.0 Date of Generation...... .07/08/10 Maximum physical Record. .65535 Fi 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.......07/08/10 Maximum physical Record..65535 Fi 1 e 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 FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2350.0 2352.0 2352.0 2352.0 2352.0 2369.5 2410.0 STOP DEPTH 4036.5 4036.5 4036.5 4036.5 4036.5 4037.0 4036.5 # 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: 02-JUL-04 Insite 6.02 Memory 4037.0 2409.5 4037.0 15.0 52.5 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 163686 157645 page 7 . # mpj-25.tapx # 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 optlcal log depth units...... .....Feet Data Reference Point.... ..... .....undefined Frame spacing...... .......... .....60 .1IN Max frames per record.. ...... .....undefined Absent value........... ..... ......-999.25 Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O . 9.875 2397.0 LSND 9.00 47.0 8.0 175 9.0 2.800 1. 925 5.800 4.000 72.0 107.8 72.0 72.0 Name Service order Units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Fi rst Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 2350 4037 3193.5 3375 2350 4037 ROP MWD020 FT/H 13.91 283.43 121. 654 3254 2410 4036.5 GR MWD020 API 12.29 114.63 60.5246 3336 2369.5 4037 RPX MWD020 OHMM 1. 24 972 . 39 12.0065 3370 2352 4036.5 RPS MWD020 OHMM 1. 35 2000 13 . 6966 3370 2352 4036.5 RPM MWD020 OHMM 1.45 2000 22.0975 3370 2352 4036.5 RPD MWD020 OHMM 0.2 2000 55.8878 3370 2352 4036.5 FET MWD020 HOUR 0.29 45.88 2.15125 3374 2350 4036.5 Page 8 . . mpj-25.tapx First Reading For Entire File......... .2350 Last Reading For Entire File.......... .4037 Fi 1 e Trai 1 er service name...... .... ...STSLIB.003 Service sub Level Name... version Number.... ..... ..1.0.0 Date of Generation..... ..07/08/10 Maximum physical Record. .65535 Fi 1 e 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...... .07/08/10 Maximum physical Record. .65535 Fi 1 e 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 RPX RPD ROP RPM RPS FET $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 3992.5 4037.0 4037.0 4037.0 4037.0 4037.0 4037.0 # 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 # STOP DEPTH 8291.5 8299.0 8299.0 8348.0 8299.0 8299.0 8299.0 06-JUL-04 Insite 6.02 Memory 8348.0 4037.0 8348.0 46.6 98.5 TOOL NUMBER Page 9 . . DGR EWR4 $ mpj-25.tapx DUAL GAMMA RAY 129046 ELECTROMAG. RESIS. 4 162742 # # 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 optlcal log depth units.......... .Feet Data Reference point............. .Undefined Frame Spacing.... ..... ....... .....60 .1IN Max frames per record... ..........Undefined Absent value. ............ ..... ....-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 6.750 4037.0 VERSA PRO 9.30 85.0 1.7 35000 .0 .000 .000 .000 .000 .0 111.2 .0 .0 Name service order Units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 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 Fi rst Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3992.5 8348 6170.25 8712 3992.5 8348 ROP MWD030 FPH 0 825.153 227.276 8623 4037 8348 GR MWD030 API 17.2734 113.605 59.3996 8599 3992.5 8291. 5 RPX MWD030 OHMM 2.1376 2000 59.818 8525 4037 8299 RPS MWD030 OHMM 2.1548 2000 79.9292 8525 4037 8299 page 10 . . RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR 1.0662 2.2735 0.1778 mpj-25.tapx 2000 111.411 2000 130.125 86.9531 0.454569 8525 8525 8525 4037 4037 4037 8299 8299 8299 First Reading For Entire File......... .3992.5 Last Reading For Entire File.......... .8348 File Trailer Service name...... .... ...STSLIB.004 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .07/08/10 Maximum physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO Next File Name. ..........STSLIB.005 physical EOF Tape Trailer Service name.. ..... ..... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .07/08/10 ori gi n. . . . . . . . . . . . . . . . . . . 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.... ................ .07/08/10 ori gi n . . . . . . . . . . . . . . . . . . . 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 Fi 1 e Page 11 . . MPJ-25PB1. tapx Sperry-sun Drilli~g.services LIS Scan Utlllty $Revision: 3 $ LisLib $Revision: 4 $ Tue Aug 07 16:28:58 2007 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .07/08/07 Ori gi n . . . . . . . . . . . . . . . . . . . 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......... ........... .07/08/07 ori gi n. . . . . . . . . . . . . . . . . . . STS Tape Name. ........ .......UNKNOWN continuation Number..... .01 Previous Tape Name.. .... . UNKNOWN Comments......... .... ....STS LIS writing Library. scientific Technical Services ~CA.NNED AUG 2 7 Z007 physi cal EOF Comment Record TAPE HEADER Milne point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPJ-25 PB1 500292320770 BP Exploration (Alaska), Inc. Sperry Sun 03-AUG-07 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003149211 C. ZAWADZKI E. VAUGHN MWD RUN 2 Mw0003149211 T. MCGUIRE D. GREEN MAD RUN 2 Mw0003149211 T. MCGUIRE D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 28 13N 10E 2741 3413 .00 34.04 36.10 # WELL CASING RECORD page 1 Sö4-0-::;-Ô"lt 1f>3'1to . . 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13 . 500 9.875 9.875 MPJ -25PB1. tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2397.0 10.750 2397.0 10.750 2397.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. DEPTHS REFER TO BIT DEPTHS. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DGR, ELECTROMAGENTIC WAVE RESISITIVTY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO-DENSITY (SLD), BIMODAL ACOUSTIC TOOL (BAT), MAGNETIC RESONANCE IMAGING-WHILE DRILLING (MRI-WD), AND PRESSURE WHILE DRILLING (PWD). A MEASUREMENT AFTER DRILLING REPEAT PASS WAS PERFORMED WHILE PULLING OUT OF THE HOLE FROM 4801 TO 3541 FT MD (4215 TO 3359 FT TVD). 4. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. MRI-WD DATA IS ALSO SMOOTHED TO ALl FT WINDOW. ACAL CALIBRATION FACTOR = 0.963 5. MWD DATA IS DEPTH SHIFTED TO THE PDC GR LOG (SWS CMR-GR) OF 03-JUL-2004. LOG HEADER AND REMARKS SECTIONS RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 6. MWD RUNS 1 & 2 REPRESENT WELL MPJ-25 PB1 WITH API#: 50-029-23207-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4800'MD, 4214'TVD SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT SMOOTHED RUNNING SPEED WHILE NOT DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY LIMESTONE page 2 . . MPJ-25PB1. tapx MATRIX. CTFA = SMOOTHED FAR NEUTRON DETECTOR'S AVERAGE COUNT RATE. CTNA = SMOOTHED NEAR NEUTRON DETECTOR'S AVERAGE COUNT RATE. SBDC = SMOOTHED CONVENTIONAL BULK DENSITY. SBD2 = SMOOTHED BULK DENSITY (LOW COUNT RATE BIN). sc02 = SMOOTHED STANDOFF CORRECTION (LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN). ACAL = SMOOTHED ACOUSTIC CALIPER. DTCP = SMOOTHED COMPRESSIONAL SLOWNESS - POST WELL PROCESSED. T1PTOT = SNOOTHED TOTAL MRIL POROSITY (T1 ACTIVATION). T1MIC = SMOOTHED TOTAL MRIL MICROPOROSITY - < 6 ms (T1 ACTIVATION). T1PIRRM = SMOOTHED TOTAL MRIL IRREDUCIBLE POROSITY - <600 ms (T1 ACTIVATION). TILM = SMOOTHED MRIL T1 LOG MEAN RELAXATION TIME. T1KCOATES = SMOOTHED MRIL DERIVED COATES PERMEABILITY. CURVES WITH AN "M" SUFFIX DENOTE MAD PASS DATA. PARAMETERS USED IN POROSITY LOG CALCULATIONS: HOLE SIZE: 8.5" DETERMINATION MUD SALINITY: MUD WEIGHT: FORMATION WATER FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ (NOMINAL) - ACAL USED IN 175 PPM CHLORIDES 9.0 PPG - 9.2 PPG SALINITY: 20,000 PPM CHLORIDES 1. 0 G/CC 2.65 G/CC SANDSTONE File Header Service name............ .STSLIB.001 Service Sub Level Name... version Number...... .... .1.0.0 Date of Generation.......07/08/07 Maximum physical Record..65535 Fi 1 e Type.... . . . . . . . . . . . . LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP DTC FCNT NPHI NCNT PEF CALA FET RPD 1 clipped curves; all bit runs merged. .5000 START DEPTH 92.0 132.5 2296.0 2302.0 2302.0 2302.0 2314.5 2336.0 2347.5 2349.5 STOP DEPTH 4763.5 4800.5 4680.0 4704.5 4704.5 4704.5 4720.0 4708.5 4756.0 4756.0 Page 3 RPS DRHO RHOB RPM RPX T1LM T1PM T1PI T1KC T1PT $ . 2349.5 2349.5 2349.5 2349.5 2349.5 2467.5 2467.5 2467.5 2467.5 2467.5 . MPJ-25PB1. tap x 4756.0 4720.0 4720.0 4756.0 4756.0 4657.5 4657.5 4657.5 4657.5 4657.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 3485.0 3489.0 3496.0 3499.0 3504.0 3513.5 3515.0 3521. 5 3526.5 3552.0 3555.0 3565.5 3569.0 3577.5 3585.5 3601. 5 3608.0 3610.0 3616.5 3624.0 3630.0 3638.5 3647.0 3653.5 3659.0 3663.0 3665.5 3668.0 3679.0 3691. 5 3705.0 3715.5 3718 . 5 3723.5 3732.0 3734.0 3742.5 3749.5 3755.0 3757.0 3759.5 3762.0 3766.5 3770.0 3776.5 3787.5 3793.5 GR 3487.5 3491.0 3499.0 3501. 0 3506.5 3516.0 3517.5 3524.0 3529.5 3555.0 3558.0 3569.0 3573.5 3581.0 3589.0 3605.0 3610.5 3612.5 3619.5 3627.5 3632.5 3642.0 3650.0 3656.0 3661. 5 3665.5 3668.0 3670.5 3681.5 3694.0 3707.5 3717.5 3720.5 3725.5 3733.5 3736.0 3744.5 3752.0 3757.5 3759.5 3762.0 3764.5 3769.0 3772.0 3778.5 3789.5 3795.5 page 4 . . MPJ-25PB1. tapx 3797.5 3799.5 3803.0 3804.5 3809.5 3811. 0 3815.0 3816.5 3826.0 3828.0 3829.5 3832.0 3836.0 3838.5 3840.0 3842.5 3845.5 3848.0 3849.0 3851. 5 3853.5 3856.0 3862.5 3865.5 3865.0 3868.0 3872.0 3874.5 3877.0 3879.5 3884.0 3886.5 3887.0 3891. 0 3890.5 3895.0 3897.0 3900.5 3913 .5 3917.0 3918.0 3921. 0 3922.0 3925.0 3926.0 3929.0 3937.0 3938.0 3941. 5 3943.5 3947.5 3949.5 3950.5 3952.5 3953.0 3954.5 3955.0 3956.5 3957.5 3959.5 3982.0 3983.0 3984.0 3985.0 3985.0 3986.5 3995.0 3996.0 4007.0 4008.5 4011.0 4012.5 4017.5 4019.0 4026.5 4028.0 4029.5 4031.0 4035.0 4036.5 4037.0 4038.5 4039.5 4041.5 4044.5 4046.5 4047.5 4049.0 4053.0 4055.0 4056.5 4058.5 4060.5 4062.0 4064.0 4066.0 4069.0 4070.5 4075.0 4076.5 4084.0 4085.0 4087.5 4089.0 4095.0 4096.0 4111.5 4112.5 4116. 5 4117.5 4122 .0 4123.5 4134. 5 4136.0 4141.0 4142.0 4148.0 4149.5 4150.5 4151. 5 4153.5 4154.5 4155.5 4157.0 4159.5 4161.0 page 5 . . MPJ-25PB1. tapx 4167.5 4169.5 4170.0 4172 . 0 4171. 5 4173.5 4175.0 4176.5 4177 . 0 4179.0 4180.0 4182.0 4188.5 4190.0 4196.5 4198.0 4200.5 4202.5 4222.0 4224.0 4226.0 4228.0 4230.5 4232.5 4233.5 4235.5 4240.5 4243.0 4244.0 4246.0 4266.0 4268.5 4271. 5 4272.5 4276.5 4277 .5 4280.5 4281. 0 4287.5 4288.5 4288.5 4290.0 4294.5 4296.0 4300.5 4302.0 4302.0 4303.5 4306.5 4308.0 4308.0 4309.5 4314.0 4315. 5 4346.5 4348.0 4353.0 4354.0 4359.0 4360.5 4364.0 4364.5 4369.5 4370.5 4380.0 4381.0 4393.5 4394.0 4402.5 4403.5 4410.5 4411.0 4415.5 4416.0 4424.0 4424.5 4428.5 4429.0 4432.5 4432.5 4436.5 4436.5 4456.5 4457.0 4462.0 4462.5 4467.0 4467.5 4486.0 4486.5 4492.0 4493.0 4500.0 4501. 0 4509.5 4510.5 4513 .5 4514.0 4520.0 4519.5 4533.0 4533.5 4537.0 4537.5 4543.5 4544.5 4577.0 4577 .5 4588.0 4587.5 4605.0 4605.0 4617.5 4617.5 4624.5 4626.0 4629.0 4629.0 4642.5 4642.5 4645.0 4645.5 4650.0 4651. 0 4665.5 4665.5 page 6 . . 4676.0 4683.5 4688.0 4697.0 4704.5 4715.0 4720.0 4723.0 4732.0 4745.0 4759.0 $ MPJ-25PB1. tapx 4676.5 4684.0 4688.5 4697.5 4705.0 4715.5 4720.5 4723.5 4732.0 4744.5 4759.0 # MERGED DATA PBU TOOL MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP MERGE BASE 1 94.5 2409.5 2 2298. 5 4800.5 MERGED MAIN PASS. $ # REMARKS: # Data Format specification Record Data Record Type.. ... ........ .....0 Data specification Block Type.....O Logging Direction......... ........Down optlcal log depth units.......... . Feet Data Reference point............. .undefined Frame spacing.. .................. .60 .1IN Max frames per record............ .undefined Absent value.... ................. .-999.25 Depth uni ts. . . . . . . . . . . . . . . . . . . . . . . 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 HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD IN 4 1 68 56 15 T1KC MWD MD 4 1 68 60 16 T1LM MWD MS 4 1 68 64 17 T1PI MWD PU 4 1 68 68 18 T1PM MWD PU 4 1 68 72 19 T1PT MWD PU 4 1 68 76 20 DTC MWD USPF 4 1 68 80 21 Name service unit DEPT FT ROP MWD FT/H Min 92 5.11 Max 4800.5 481. 82 Page Mean 2446.25 143.134 7 Nsam 9418 9337 Fi rst Reading 92 132.5 Last Reading 4800.5 4800.5 GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD CALA MWD T1KC MWD T1LM MWD T1PI MWD T1PM MWD T1PT MWD DTC MWD API OHMM OHMM OHMM OHMM HR PU-S CNTS CNTS G/CM G/CM BARN IN MD MS PU PU PU USPF . 12.29 1. 24 1. 35 1.45 0.2 0.29 3.63 449 105353 0.746 -1. 267 1.19 8.94 o 1. 36 5.23 0.11 10.14 52 MPJ-25PB1. tapx 116.853 64.9034 972.39 10.2716 2000 11. 5013 2000 17.3786 2000 41.1099 45.88 1.68486 87.86 36.9426 2908 754.538 181460 125341 2.871 2.10721 0.752 0.0560461 12.89 2.80806 15.38 10.446 4134.53 240.544 292.51 35.1911 53.07 19.3885 46.43 9.35065 60.56 30.5226 191 129.089 First Reading For Entire File..........92 Last Reading For Entire File. ........ ..4800.5 File Trailer Service name..... ........STSLIB.001 service sub Level Name... version Number.......... .1.0.0 Date of Generation...... .07/08/07 Maximum physical Record..65535 File Type............... .LO Next File Name.... ..... ..STSLIB.002 physical EOF File Header service name.... .........STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .07/08/07 Maximum physical Record..65535 Fi 1 e Type..... . . . . . . . . . . . LO previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE T1PI T1LM T1KC T1PT T1PM DTC RHOB 2 . 9344 4814 4814 4814 4814 4818 4806 4806 4806 4702 4702 4812 4683 4381 4381 4381 4381 4381 4769 92 2349.5 2349.5 2349.5 2349.5 2347.5 2302 2302 2302 2349.5 2349.5 2314.5 2336 2467.5 2467.5 2467.5 2467.5 2467.5 2296 4763.5 4756 4756 4756 4756 4756 4704.5 4704.5 4704.5 4720 4720 4720 4708.5 4657.5 4657.5 4657.5 4657.5 4657.5 4680 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 3391. 0 3391. 0 3391. 0 3391. 0 3391. 0 3392.5 3427.5 STOP DEPTH 4656.5 4656.5 4656.5 4656.5 4656.5 4682.5 4721. 5 page 8 . PEF DRHO NPHI NCNT FCNT CALA RPD RPS FET RPM RPX GR ROP $ 3427.5 3427.5 3429.5 3429.5 3429.5 3447.0 3461.0 3462.0 3462.0 3462.0 3462.0 3469.5 3520.5 . MPJ-25PB1. tapx 4721. 5 4721.5 4706.5 4706.5 4706.5 4710.5 4756.0 4756.0 4757.5 4756.0 4756.0 4764.0 4800.0 # MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 2 1 2298.5 4800.5 $ # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.......... ..... ..Down optlcal log depth units.......... .Feet Data Reference point......... .., ..undefined Frame spacing............. ........60 .1IN Max frames per record...... ...... .undefined Absent value... ..... ............. .-999.25 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Name Service Order Units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU 4 1 68 32 9 FCNT MAD CNTS 4 1 68 36 10 NCNT MAD CNTS 4 1 68 40 11 RHOB MAD G/CM 4 1 68 44 12 DRHO MAD G/CM 4 1 68 48 13 PEF MAD BARN 4 1 68 52 14 DTC MAD USPF 4 1 68 56 15 T1KC MAD MD 4 1 68 60 16 T1LM MAD MS 4 1 68 64 17 T1PI MAD PU 4 1 68 68 18 T1PM MAD PU 4 1 68 72 19 T1PT MAD PU 4 1 68 76 20 CALA MAD IN 4 1 68 80 21 Name service Unit DEPT FT Min 3391 Max Mean Nsam 4800 4095.5 2819 Page 9 Fi rst Reading 3391 Last Reading 4800 RAT MAD GR MAD RPX MAD RPS MAD RPM MAD RPD MAD FET MAD NPHI MAD FCNT MAD NCNT MAD RHOB MAD DRHO MAD PEF MAD DTC MAD T1KC MAD T1LM MAD T1PI MAD T1PM MAD T1PT MAD CALA MAD FT/H API OHMM OHMM OHMM OHMM HOUR PU CNTS CNTS G/CM G/CM BARN USPF MD MS PU PU PU IN . -866.97 27.49 2.19 2.12 2.07 2.21 2.18 6.39 593 114589 1.7969 -0.0496 1.29 61 o 6.25 5.03 0.04 11.95 9.53 MPJ-25PB1. tapx 521.09 -116.375 113.26 68.3952 65.39 8.76483 89.09 9.81839 208.7 10.5565 282.28 11.5345 31.17 17.0227 51.31 34.4365 2549 808.573 172686 128174 2.782 2.18103 0.3351 0.0260625 5.81 2.13734 151 125.959 3629.85 147.336 308.08 37.5903 34.87 18.8138 18.17 6.85271 46.11 28.3636 12.79 10.3955 First Reading For Entire File. ........ .3391 Last Reading For Entire File.. ........ .4800 File Trailer Service name. ...... ..... .STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .07/08/07 Maximum physical Record. .65535 Fi 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.... ...07/08/07 Maximum physical Record..65535 Fi 1 e 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 . 2560 2573 2559 2559 2559 2561 2592 2532 2532 2532 2541 2541 2541 2546 2532 2532 2532 2532 2532 2528 3520.5 3469.5 3462 3462 3462 3461 3462 3429.5 3429.5 3429.5 3427.5 3427.5 3427.5 3392.5 3391 3391 3391 3391 3391 3447 header data for each bit run in separate files. 1 .5000 # LOG HEADER DATA START DEPTH 94.5 135.0 STOP DEPTH 2369.0 2409.5 page 10 4800 4764 4756 4756 4756 4756 4757.5 4706.5 4706.5 4706.5 4721.5 4721.5 4721. 5 4682.5 4656.5 4656.5 4656.5 4656.5 4656.5 4710.5 . . MPJ-25PB1. tapx 28-JUN-04 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 TERM PERATURE: 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 optlcal log depth units...... .... .Feet Data Reference Point............. .undefined Frame spacing.. .................. .60 .1IN Max frames per record............ .Undefined Absent value.............. .... ....-999.25 Depth uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Insite o Memory 2409.0 112.0 2409.0 .0 2409.0 TOOL NUMBER 727402 727402 13 . 500 .0 spud Mud 9.40 80.0 8.0 300 9.4 .000 .000 .000 .000 .0 80.6 .0 .0 Name Service Order DEPT ROP MWD010 GR MWD010 units Size Nsam FT 4 1 FT/H 4 1 API 4 1 Rep 68 68 68 Page 11 Code offset channel o 1 4 2 8 3 Name service unit DEPT FT ROP MWD010 FT /H GR MWD010 API . Min 94.5 8.2479 16.9829 Max 2409.5 481. 82 116.853 MPJ-25PB1. tapx Mean 1252 169.06 64.3173 First Reading For Entire File..........94.5 Last Reading For Entire File...........2409.5 File Trailer Service name..... ........STSLIB.003 service sub Level Name... version Number.. .........1.0.0 Date of Generation.......07/08/07 Maximum physical Record. .65535 Fi 1 e 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.......07/08/07 Maximum physical Record..65535 File Type...... ......... .LO previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE DTC NCNT NPHI FCNT PEF CALA FET RPM RPS RPX RHOB RPD DRHO GR ROP T1LM T1PI 4 . Nsam 4631 4550 4550 Fi rst Reading 94.5 135 94.5 Last Reading 2409.5 2409.5 2369 header data for each bit run in separate files. 2 .5000 START DEPTH 2298. 5 2304.5 2304.5 2304.5 2317.0 2338.5 2350.0 2352.0 2352.0 2352.0 2352.0 2352.0 2352.0 2369.5 2410.0 2470.0 2470.0 STOP DEPTH 4680.5 4705.0 4705.0 4705.0 4720.5 4709.0 4756.0 4756.0 4756.0 4756.0 4720.5 4756.0 4720.5 4763.5 4800.5 4658.0 4658.0 page 12 . T1PT T1KC T1PM $ 2470.0 2470.0 2470.0 MPJ-25PB1. tapx 4658.0 4658.0 4658.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN BAT MRIL $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON BIMODAL ACOUSTIC MAG RESONANCE IMG WD # 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 optlcal log depth units.......... .Feet Data Reference point............. .undefined Page 13 . 02-JUL-04 Insite 6.02 Memory 4800.0 2409.0 4800.0 15.0 52.5 TOOL NUMBER 163686 157645 340 10 111111 90124263 9.875 2397.0 LSND ,9.00 47.0 8.0 175 9.0 2.800 1. 925 5.800 4.000 72.0 107.8 72.0 72.0 . . MPJ-25PB1. tapx Frame spacing... ................. .60 .1IN Max frames per record............ .undefined Absent value... ..... ............. .-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 NPHI MWD020 pU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 CALA MWD020 IN 4 1 68 56 15 T1KC MWD020 MD 4 1 68 60 16 T1LM MWD020 MS 4 1 68 64 17 T1PI MWD020 PU 4 1 68 68 18 T1PM MWD020 PU 4 1 68 72 19 T1PT MWD020 PU 4 1 68 76 20 DTC MWD020 USPF 4 1 68 80 21 Fi rst Last Name service Unit Mi n Max Mean Nsam Reading Reading DEPT FT 2298.5 4800.5 3549.5 5005 2298.5 4800.5 ROP MWD020 FT/H 5.11 283.43 118.459 4782 2410 4800.5 GR MWD020 API 12.29 114.63 65.4854 4789 2369.5 4763.5 RPX MWD020 OHMM 1. 24 972 . 39 10.2421 4809 2352 4756 RPS MWD020 OHMM 1. 35 2000 11.4668 4809 2352 4756 RPM MWD020 OHMM 1.45 2000 17.3516 4809 2352 4756 RPD MWD020 OHMM 0.2 2000 41.1045 4809 2352 4756 FET MWD020 HR 0.29 45.88 1. 68581 4813 2350 4756 NPHI MWD020 PU-S 3.63 87.86 36.9595 4802 2304.5 4705 FCNT MWD020 CNTS 449 2908 754.452 4802 2304.5 4705 NCNT MWD020 CNTS 105353 181460 125349 4802 2304.5 4705 RHOB MWD020 G/CM 0.746 2.871 2.10686 4698 2352 4720.5 DRHO MWD020 G/CM -1. 267 0.752 0.056176 4698 2352 4720.5 PEF MWD020 BARN 1.19 12.89 2.80739 4808 2317 4720.5 CALA MWD020 IN 8.94 15.38 10.445 4679 2338.5 4709 T1KC MWD020 MD 0 4134.53 240.455 4377 2470 4658 T1LM MWD020 MS 1. 36 292.51 35.2298 4377 2470 4658 T1PI MWD020 PU 5.23 53.07 19.3882 4377 2470 4658 T1PM MWD020 PU 0.11 46.43 9.35431 4377 2470 4658 T1PT MWD020 PU 10.14 60.56 30.5372 4377 2470 4658 DTC MWD020 USPF 52 191 129.117 4765 2298.5 4680.5 First Reading For Entire File..........2298.5 Last Reading For Entire File.... .......4800.5 Fil e Trai 1 er service name.. .......... .STSLIB.004 service sub Level Name... Page 14 . MPJ -25PB1. tapx version Number........ ...1.0.0 Date of Generation.... ...07/08/07 Maximum physical Record..65535 File Type. ....... .... ....LO Next File Name. ..........STSLIB.005 physical EOF File Header service name...... .... ...STSLIB.005 service sub Level Name... version Number... ........1.0.0 Date of Generation.......07/08/07 Maximum physical Record..65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE T1KC T1PI T1LM T1PT T1PM DTCP ACAL SNP2 sc02 SBD2 CTNA CTFA TNPS SFXE SEDP SEXP SESP SEMP SGRC SRAT $ 5 . header data for each pass of each run in separate files. .5000 2 1 START DEPTH 3393.5 3393.5 3393.5 3393.5 3393.5 3395.0 3424.5 3430.0 3430.0 3430.0 3432.0 3432.0 3432.0 3462.0 3463.5 3464.5 3464.5 3464.5 3472.0 3523.0 # 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 STOP DEPTH 4657.0 4657.0 4657.0 4657.0 4657.0 4683.0 4711. 0 4722.0 4722.0 4722 . 0 4707.0 4707.0 4707.0 4757.5 4756.0 4756.0 4756.0 4756.0 4764.0 4800.0 Page 15 02-JUL-04 Insite 6.02 Memory 4800.0 3400.0 4800.0 . MPJ-25PB1. tapx # MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 BAT MRIL $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON ELECTROMAG. RESIS. 4 BIMODAL ACOUSTIC MAG RESONANCE IMG WD # # 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 optlcal log depth units...... .....Feet Data Reference Point. ........ .....undefined Frame spacing... ................. .60 .1IN Max frames per record............ .undefined Absent value.. ..... .............. .-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type. ..0 . 15.0 52.5 TOOL NUMBER 163686 340 10 157645 111111 90124263 9.875 2397.0 LSND 9.00 47.0 8.0 175 9.0 2.800 1. 925 5.800 4.000 72.0 107.8 72.0 72.0 Name Service Order Units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RAT MAD021 FT/H 4 1 68 4 2 GR MAD021 API 4 1 68 8 3 RPX MAD021 OHMM 4 1 68 12 4 RPS MAD021 OHMM 4 1 68 16 5 RPM MAD021 OHMM 4 1 68 20 6 RPD MAD021 OHMM 4 1 68 24 7 NPHI MAD021 PU 4 1 68 28 8 FCNT MAD021 CNTS 4 1 68 32 9 page 16 . . MPJ-25PB1. tapx NCNT MAD021 CNTS 4 1 68 36 10 RHOB MAD021 G/CM 4 1 68 40 11 DRHO MAD021 G/CM 4 1 68 44 12 PEF MAD021 BARN 4 1 68 48 13 DTC MAD021 USPF 4 1 68 52 14 T1KC MAD021 MD 4 1 68 56 15 T1LM MAD021 MS 4 1 68 60 16 T1PI MAD021 PU 4 1 68 64 17 T1PM MAD021 PU 4 1 68 68 18 T1PT MAD021 PU 4 1 68 72 19 CALA MAD021 IN 4 1 68 76 20 FET MAD021 HOUR 4 1 68 80 21 Fi rst Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3393.5 4800 4096.75 2814 3393.5 4800 RAT MAD021 FT/H -866.97 521. 09 -116.524 2555 3523 4800 GR MAD021 API 27.49 113 . 26 68.4144 2568 3472 4764 RPX MAD021 OHMM 2.19 65.39 8.7261 2554 3464.5 4756 RPS MAD021 OHMM 2.12 89.09 9.76584 2554 3464.5 4756 RPM MAD021 OHMM 2.07 208.7 10.4981 2554 3464.5 4756 RPD MAD021 OHMM 2.21 282.28 11.4705 2557 3463.5 4756 NPHI MAD021 PU 6.39 51. 31 34.4586 2528 3432 4707 FCNT MAD021 CNTS 593 2549 808.292 2528 3432 4707 NCNT MAD021 CNTS 114589 172686 128178 2528 3432 4707 RHOB MAD021 G/CM 1.646 2.782 2.1804 2537 3430 4722 DRHO MAD021 G/CM -0.0496 0.3351 0.0259267 2537 3430 4722 PEF MAD021 BARN 1. 29 5.81 2.13687 2537 3430 4722 DTC MAD021 USPF 61 151 125.969 2542 3395 4683 T1KC MAD021 MD 0 3629.85 148.176 2528 3393.5 4657 T1LM MAD021 MS 6.25 308.08 37.7124 2528 3393.5 4657 T1PI MAD021 PU 5.03 34.87 18.8155 2528 3393.5 4657 T1PM MAD021 PU 0.04 18.17 6.85273 2528 3393.5 4657 T1PT MAD021 PU 11. 95 46.11 28.3895 2528 3393.5 4657 CALA MAD021 IN 9.53 12.79 10.3958 2530 3424.5 4711 FET MAD021 HOUR 2.18 31.17 17.0227 2592 3462 4757.5 First Reading For Entire File......... .3393.5 Last Reading For Entire File.......... .4800 File Trailer service name... ..........STSLIB.005 service Sub Level Name... version Number.... .... ...1.0.0 Date of Generation...... .07/08/07 Maximum physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.. .........STSLIB.006 physical EOF Tape Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .07/08/07 Ori gi n . . . . . . . . . . . . . . . . . . . STS Tape Name... ............ . UNKNOWN continuation Number..... .01 Page 17 · . MPJ-25PB1. tapx Next Tape Name......... ..UNKNOWN Comments............... ..STS LIS writing Library. scientific Technical services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .07/08/07 Ori gi n . . . . . . . . . . . . . . . . . . . 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 page 18