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Home My WebLink About203-123Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2025 InspectNo:susSTS250729150450 Well Pressures (psi): Date Inspected:7/25/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:2/25/2025 #325-011 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Chris Casey Date AOGCC Notified:7/18/2025 Type of Inspection:Initial Well Name:MILNE PT UNIT S-08 Permit Number:2031230 Wellhead Condition Clean and freshly lubricated. Valves turn easily. New guages installed Surrounding Surface Condition clean with no debris and no sign of subsidence Condition of Cellar Clean and no sign of contaminants Comments location verified by plot map Supervisor Comments Photos (3) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, September 12, 2025 9 9 9 9 9 9 9 9 9 9 9 9 2025-0725_Suspend_MPU_S-08_photos_ss Page 1 of 2 Suspended Well Inspection – MPU S-08 PTD 2031230 AOGCC Inspection Rpt # susSTS250729150450 Photos by AOGCC Inspector S. Sullivan 7/25/2025 2025-0725_Suspend_MPU_S-08_photos_ss Page 2 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 12 Township: 12N Range: 10E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 10009 ft MD Lease No.: ADL0380109 Operator Rep: Suspend: X P&A: Conductor: 20" O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface: 10 3/4" O.D. Shoe@ 2776 Feet Csg Cut@ Feet Intermediate: 7 5/8" O.D. Shoe@ 5284 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 4" O.D. Shoe@ 9143 Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 4755 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Perforation Retainer 4718 ft MD 4087 ft MD 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1781 1727 1708 IA 1773 1694 1665 OA 12 13 17 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Reservoir plug for well suspension. Tagged cement at 4080 ft MD and drove down the bailer to 4087 ft MD. There is a 24 foot correction for wireline making the tag to good cement at 4111 ft MD. The tubing and IA were isolated from each other during the test. There was a sample of good cement in the drive-down bailer after the tag. BBLs in and BBLs out were the same at 1.5 BBLs for the CMIT-IA. February 25, 2025 Guy Cook Well Bore Plug & Abandonment MPU S-08 Hilcorp Alaska LLC PTD 2031230; Sundry 325-011 None Test Data: P Casing Removal: Jess Hall Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0225_Plug_Verification_MPU_S-08_gc 9 9 9 9 9 9 99 9 9 9 9 9 9 99 9 9 999 999 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.03.25 16:22:34 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Tubing Cut Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11.PRESENT WELL CONDITION SUMM Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,009'N/A Casing Collapse Conductor N/A Surface 2,090psi Intermediate 4,790psi Liner N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone:303-906-5178 Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other 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 4.5" 2/1/2025 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: MILNE PT UNIT S-08 MILNE POINT SCHRADER BLUFF OIL N/A 4,077' 6,000' 4,077' 456 6,000' 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): See Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 & ADL0380110 203-123 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23168-00-00 Hilcorp Alaska LLC C.O. 477.005 Length Size Proposed Pools: 112' 112' 12.6# / 13Cr80 / TC-II TVD Burst 4,755 MD N/A N/A 3,580psi 6,890psi 2,439' 4,000' 4,006' 2,776' 5,284' 112' 20" 10-3/4" 7-5/8" 2,776' 4" 5,284' 3,961' 9,143' Perforation Depth MD (ft): See Schematic 7-5/8" x 4.5" Premier Pkr / ZXP Liner Top Pkr and N/A 4,706(MD)/ 3,839(TVD) & 5,189(MD)/ 3,982(TVD) and N/A Ryan Lewis ryan.lewis@hilcorp.com No 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 3:33 pm, Jan 10, 2025 325-011 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.01.10 14:13:05 - 09'00' Taylor Wellman (2143) X X SFD 1/21/2025 DSR-1/16/25 Reservoir Plug AOGCC to witness slickline tag and pressure test of reservoir plug to 1500 psi. Fullbore cement retainer to have ball seat to ensure cement is not over displaced past retainers. 10-407 JJL 1/23/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.23 16:21:15 -09'00'01/23/25 RBDMS JSB 012425 RWO – Suspend Well: MPU S-08 Date: 2/1/25 Well Name: MPU S-08 API Number: 50-029-23168-00-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: Feb 1, 2025 Rig: Hal-Cement Reg. Approval Req’d? No Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-123 First Call Engineer: Ryan Lewis (303) 906-5178 (C) Second Call Engineer: Taylor Wellman (907) 777-8449 (907) 947-9533 (C) AFE Number: Job Type: Coil Cleanout Current Bottom Hole Pressure: 838 psi @ 3,823’ TVD (Last BHP measured 01/24/2023) Maximum Expected BHP: 838 psi @ 3,823’ TVD MPSP: 456 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary & Objective MPU S-08 was drilled in 2003 and completed in the Schrader N sand. 2016, this well was plugged back to 6,000’ MD. We are going to place a reservoir abandonment and leave the well as Suspended because the lateral will be 100’ away from the new development MP S-53. Notes Regarding Wellbore Condition x Max angle 95° @ 6,390’. x Deviation is 66° at pump (4,667’). x CMIT for CO-808 to 3,600 psi passed on 3/27/2024. Objective: Perform reservoir abandonment of the Schrader Bluff N sand. Pre-Rig Operations: 1) MIRU Slickline a. Pull JP. b. Drift for 4-1/2” Interventionless cmt retainer by Nine Energy c. Close SS. d. Obtain updated SBHP. 2) MIRU LRS a. Establish combined injection rate into open Schrader Bluff N Sands using produced fluid. b. FP well to await P&A of Schrader Bluff sands. 3) MIRU E-line a. RIH to set cmt retainer ±4718’ MD or mid-jt in 1 st handling pup below Baker Premier Pkr . b. RIH to w/ tbg punch to punch ±4699-ft MD or mid-jt in 1 nd handling pup above upper Baker Premier Pkr . 4) MIRU Cementers a. Circ out FP in tbg and IA through tbg punch with hot produced fluid. b. Close tbg/IA annulus and establish injection rate through the cmt retainer into the Schrader Bluff N sands by bullheading down the tbg. RWO – Suspend Well: MPU S-08 Date: 2/1/25 c. Commence bullheading ±63 bbls Class G neat (±15.8 lb/gal) through cmt retainer with the tbg/IA annulus closed. ıťώÍīèŜ «ĺīŪıôώ"ôŜèŘĖŕťĖĺĲ ĺŕ a" ťı a" [ôĲČťēώϼċťϽώ ÍŕÍèĖťƅώϼ>Ͻ «ĺīŪıô ϼææīϽ ĺııôĲťŜ ͖ϱ͔ϯ͗ГƄ͓ϱ͐ϯ͑ГώĲĲŪīŪŜ ͓͕͏͕ ͓͖͏͕ ͐͏͏ ͏ϟ͏͕͑͑ ͑ϟ͕ ͓ϱ͐ϯ͑ГťŪæĖĲČ ͓͕͏͕ ͓͖͐͗ ͐͐͑ ͏ϟ͏͔͐͑ ͐ϟ͖ ĺťÍī ͓ϟ͒ ͓ϱ͐ϯ͑ГťŪæĖĲČ ͓͖͐͗ ͓͖͔͓ ͕͒ ͏ϟ͏͔͐͑ ͏ϟ͔ ͖ϱ͔ϯ͗ГƄ͓ϱ͐ϯ͑ГώĲĲŪīŪŜ ͓͖͏͕ ͓͖͔͓ ͓͗ ͏ϟ͏͕͑͑ ͐ϟ͒ ͖ϱ͔ϯ͗ГèÍŜĖĲČ ͓͖͔͓ ͔͐͗͑ ͓͑͗ ͏ϟ͏͓͔͘ ͐͘ϟ͕ ͓ГώīĖĲôŘ ͔͐͗͑ ͕͏͏͏ ͗͐͗ ͏ϟ͏͐͑͑ ͐͏ϟ͏ ĺťÍī ͒͐ϟ͓ ĺťÍīώ«ĺīŪıôώѭώ͐͏͏҇ώôƄèôŜŜ ͕͑ϟ͘ d. Drop cmt wiper dart, pump cmt tail 5 BBL, and displace cmt with hot produced fluid. Tubing capacity to the retainer is 72 bbls. At 62 bbls (5bbl tail + 57 bbls flush), slow displacement pump rate to 2 BPM and bump the plug. e. Open tbg/IA annulus, pump +/-3 bbls cmt through the tbg punch. NOTE: Ensure returns from IA match cmt displacement rate f. MU jumper line from IA to tbg and allow cmt to hydrostatically balance between the tbg and IA. 5) MIRU Slickline a. Provide 24-hr notification to AOGCC for possible witness b. Tag TOC in tbg per AOGCC c. Perform Combo MIT-IA (1500 psi) Attachments: 1. As-built Schematic 2. Proposed Schematic 3. 11” Double BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 12/30/2024 SCHEMATIC Milne Point Unit Well: MPU S-08 Last Completed: 3/18/2010 PTD: 203-123 11 FLUSH TUBING EVERY TIME WITH DIESEL, POOR ACTION WHILE PULLING PUMP. TD =10,009’(MD) / TD = 4,077’(TVD) 20” Orig. DF Elev. = 72.45’ / Orig. GL Elev.= 38.6’ Doyon 14 7-5/8” 3 6 10 8 & 9 7 2 1 5 4 10-3/4” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 112' 0.355 10-3/4" Surface 45.5 / L-80 / BTC 9.950 Surface 2,776’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 5,284’ 0.0459 4” Production Liner 9.5/ L-80/ IBT 3.548 5,182 9,143’ 0.0122 TUBING DETAIL 4-1/2” Tubing 12.6/ 13Cr-80/ TC-II 3.958 Surface 4,755’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,024’ Camco 4.5” x 1” w/ BK Latch Side-pocket KGB-2 GLM 2 4,657’ Weatherford Gauge Mandrel 3 4,667’ 4.5” HES ‘XD’ Dura Sliding Sleeve – 3.813” ID, Opens Down w/ Rev. Circ. Jet Pump 4 4,679’ 4.5’ Weatherford Snorkel Sub 5 4,706’ 7-5/8” x 4.5” Baker Premier Packer – 3.870” ID 6 4,742’ 4.5” HES XN-Nipple -3.813” x 3.725” No Go 7 4,754’ WLEG – Bottom @ 4,755’ 8 5,182’ Baker Tie Back Sleeve 9 5,189’ Baker ZXP Liner Top Packer 10 5,196’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 11 6,000’ Paragon Packer w/ Bull Plug (Set 1/04/16) OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 510sx Class ‘L’ & 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 400sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 600’ MD Hole Angle Passes 50 Deg. @ 2,500’ Max Hole Angle in Tubing = 67 deg. 66 Deg. @ Sliding Sleeve 4,667’ TREE & WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger. CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23168-00-00 Drilled and Completed by Doyon 14 - 8/4/2003 Tubing Patch Se w/ E-line – 11/15/2008 Tubing Replacement / Caliper Casing Doyon 16 – 3/18/2010 Slickline Installed 4.5” X-Lock Equalizing Device Med Excluder – 7/5/2013 Pulled the Excluder Screen – 10/9/2013 CT Packer & Plug set – 1/5/2016 NOTE: 2.65’ Blast Rings Below Tubing Hanger Baker 4-1/2” Float Shoe @ 9,143’. (866’ of Rat Hole) Damaged Screen 6,756’-6,764’ Damaged Screen 6,042’ Restricted Blank Pipe6,127’-6,146’ _____________________________________________________________________________________ Revised By: TDF 12/31/2024 PROPOSED Milne Point Unit Well: MPU S-08 Last Completed: 3/18/2010 PTD: 203-123 12 FLUSH TUBING EVERY TIME WITH DIESEL, POOR ACTION WHILE PULLING PUMP. TD =10,009’(MD) / TD = 4,077’(TVD) 20” Orig. DF Elev. = 72.45’ / Orig. GL Elev.= 38.6’ Doyon 14 7-5/8” 3 9 & 10 5 4 10-3/4” TOC @ ±4,606’ 2 7 8 6 11 Tubing Punch ±4,699’ 7-5/8” TOC @ ±3,604’ 1 11 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 112' 0.355 10-3/4" Surface 45.5 / L-80 / BTC 9.950 Surface 2,776’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 5,284’ 0.0459 4” Production Liner 9.5/ L-80/ IBT 3.548 5,182 9,143’ 0.0122 TUBING DETAIL 4-1/2” Tubing 12.6/ 13Cr-80/ TC-II 3.958 Surface 4,755’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,024’ Camco 4.5” x 1” w/ BK Latch Side-pocket KGB-2 GLM 2 4,657’ Weatherford Gauge Mandrel 3 4,667’ 4.5” HES ‘XD’ Dura Sliding Sleeve – 3.813” ID, Opens Down w/ Rev. Circ. Jet Pump 4 4,679’ 4.5’ Weatherford Snorkel Sub 5 4,706’ 7-5/8” x 4.5” Baker Premier Packer – 3.870” ID 6 ±4,718’’ Interventionless Cement Retainer 7 4,742’ 4.5” HES XN-Nipple -3.813” x 3.725” No Go 8 4,754’ WLEG – Bottom @ 4,755’ 9 5,182’ Baker Tie Back Sleeve 10 5,189’ Baker ZXP Liner Top Packer 11 5,196’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 12 6,000’ Paragon Packer w/ Bull Plug (Set 1/04/16) OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 510sx Class ‘L’ & 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 400sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 600’ MD Hole Angle Passes 50 Deg. @ 2,500’ Max Hole Angle in Tubing = 67 deg. 66 Deg. @ Sliding Sleeve 4,667’ TREE & WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger. CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23168-00-00 Drilled and Completed by Doyon 14 - 8/4/2003 Tubing Patch Se w/ E-line – 11/15/2008 Tubing Replacement / Caliper Casing Doyon 16 – 3/18/2010 Slickline Installed 4.5” X-Lock Equalizing Device Med Excluder – 7/5/2013 Pulled the Excluder Screen – 10/9/2013 CT Packer & Plug set – 1/5/2016 NOTE: 2.65’ Blast Rings Below Tubing Hanger Baker 4-1/2” Float Shoe @ 9,143’.(866’ of Rat Hole) Damaged Screen 6,756’-6,764’ Damaged Screen 6,042’ Restricted Blank Pipe6,127’-6,146’ Milne Point ASR Rig 1 BOPE 2025 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 Blin d11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 RECEIVED STATE OF ALASKA AllikA OIL AND GAS CONSERVATION COM SION [-LB 0 2 1016 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations U ❑ Pull Tubing U Install Patches Fracture Stimulate , Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ ; Plug for Redd! ❑ 3rforate New Pool ❑ Repair Well 0 R&R Jet Pump Cl Other: CT Fill Clean-out 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development El Exploratory ❑ 203-123 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23168-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109/ADL0380110 MILNE PT UNIT SB S-08 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 10,009 feet Plugs measured 6,000 feet true vertical 4,077 feet Junk measured N/A feet 4,706,5,189& Effective Depth measured 6,000 feet Packer measured 6,000 feet 3,839,3,982& true vertical 4,024 feet true vertical 4,024 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,776' 10-3/4" 2,776' 2,439' 3,580psi 2,090psi Production 5,284' 7-5/8" 5,284' 4,000' 6,890psi 4,790psi Liner 3,961' 4" 9,143' 4,006' 7,910psi 6,590psi Perforation depth Measured depth See Attached Schematic SCAMINEV1 t,'w,i" £ v,7 ' :- c;- True 'eTrue Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr-80/IBT 4,755' 3,858' Premier Packer Liner Top Packer Packers and SSSV(type,measured and true vertical depth) Paragon Packer 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 0 180 0 Subsequent to operation: 3 24 392 2,594 231 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory!: Development Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-521 Contact Stan Porhola Email sporhola athilcorp.com Printed Name Bo York Title Operations Engineer Signature ,,* - R0 'j i r Phone 777-8345 Date 2/1/2016 ��--!` Form 10-404 Revised 5/2015 Submit Original Only 0_/2.-ell RBDMS Ltd FEB 0 4 2016 • Milne Well: Point MPU S-08Unit II 0 SCHEMATIC Last Completed: 3/18/2010 Mean,Alaska,LLC PTD: 203-123 TREE&WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.DF Elev.=72.45'/Orig.GL Elev.38.6'Doyon 14 Tubing Hanger.CIW"H"BPV Profile Li' OPEN HOLE/CEMENT DETAIL 2O''r20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 510sx Class'L'&275sx Class'G'in a 13-1/2"Hole 7-5/8" 400sx Class"G"in 9-7/8"Hole CASING DETAIL 1 ff t Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface 112' 0.355 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,776' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 5,284' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 5,182 9,143' 0.0122 TUBING DETAIL l. 4-1/2" Tubing 12.6/13Cr-80/TC-II 3.958 Surface 4,755' 0.0152 WELL INCLINATION DETAIL i '` KOP@600'MD Hole Angle Passes 50 Deg.@ 2,500' Max Hole Angle in Tubing=47 deg. € 66 Deg.@ Sliding Sleeve 3,823' JEWELRY DETAIL No Depth Item 110-3/4"11 1 2,024' Camco 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM ' 2 4,657' Weatherford Gauge Mandrel 3 4,667' 4.5"HES'XD'Dura Sliding Sleeve-3.813"ID,Opens Down w/Rev.Circ.Jet Pump 4 4,679' 4.5'Weatherford Snorkel Sub 5 4,706' 7-5/8"x 4.5"Baker Premier Packer-3.870"ID 6 4,742' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 7 4,754' WLEG—Bottom @ 4,755' 8 5,182' Baker Tie Back Sleeve 9 5,189' Baker ZXP Liner Top Packer s 10 5,196' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 6,000' Paragon Packer w/Bull Plug(Set 1/04/16) 7 fri 1) GENERAL WELL INFO toTi ' API:50-029-23168-00-00 i Drilled and Completed by Doyon 14 -8/4/2003 " Tubing Patch Sew/E-line—11/15/2008 2 Tubing Replacement/Caliper Casing Doyon 16-3/18/2010 vg 4" Slickline Installed 4.5"X-Lock Equalizing Device Med Excluder—7/5/2013 ® 3 a" i' v Pulled the Excluder Screen—10/9/2013 4 CT Packer&Plug set—1/5/2016 r ' NOTE: i 0 2.65'Blast Rings Below Tubing Hanger v5 i r 6 '; si 7 Ar 1 -7) ( ' ' Damaged Screen 6,042' 7-5/8"` 10 $&9 Damaged Screen 6,756'-6,764' AL7 Ng Baker 4-1/2"Float Shoe @ Ng 9,143'.(866'of Rat Hole) TD=10,009'(MD)/TD=4,077'(TVD) Restricted Blank Pipe 6,127'-6,146' Revised By:STP 2/01/2016 S • Hilcorp Alaska, LLC tlileorpAlaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPS 08 Coil 50-029-23168-00-00 203-123 12/28/2015 1/5/2016 x PS- 8 t irk" a i,y,.. wp:r �„it;_ a, -* _ s; „ir 12 23 15- ednesda .'� 1 y �III��I �i��l� �k ,1\11,2o/ 413 Operations to Repo urrsday rt. /15 u �� I; No Operations to Report. 12/25/15-Friday �i,la,�p,,; a i� _ 'y r" No Operations to Report. 12/26/15-Saturday dai -,, ;i;,' _ = � No Operations to Report. '1112/27/15-Sund4W/;, E ".. �I��Rlollii �l l"' �li ' 9r No Operations to Report. i2/4111.01L-Monday ��I,�� ^�r��G Hold safety meeting discuss SLB JSA. Fire equipment.RD SLB CTU#4 from S-05 and move to S-08. Rig up. 290 bbls of 150 degree water in upright. Ordered 290 bbls of safe lube. AOGCC 24 hr notification sent 12/26/15 @ 20:41. Witness waived by Lou Grimaldi on 12/27/15 @ 15:34.Start BOPE test. Full body low PT. 336 psi end 334psi. High PT on full body. 4570 psi 10 minutes end 4530 psi. Low PT top set B/S. 260 psi end 10 minutes 251 psi. High top set B/S 4631 psi. 4589psi. Second low 300 10 minutes 294 psi. 2nd set high 4538 psi.10 minutes @ 4505 psi. Pipes low 290 psi.10 minutes 278 psi. High PT Pipe rams. 4557 psi. 4508 psi. Push 5k. Pull 10k slips good. BOP test complete.Blow down pop off well. Install night cap. Set injector head on deck. Wellsite secure. Crews off location. 1. i^ o�3x 12/29/15-Ttae ay �w Hold safety meeting. Review SLB JSA. Fire Equipment. Pick injector head. Stab lubricator. Attempt to install UTIM. Wrong mount bar. Make up shifting BHA. 2.0"CC,2.125 DFCV,2.125,Jars,2.125"Disco,B042 shifting tool. Shoulder facing up. (close sleeve). Stab on well. Low PT 250,High 3500 psi.Open master swab 23.5. 300 psi WHP. Gas cap. Bleed down. Small stream of fluid and then gas hits. IA shows 50 psi. 170 psi whp. RIH wt @ 4000'5k. Pick up weight at 4500'15k.Pressure test annulus to 3500 psi. Start PT 3530 psi @ 0930. 09:41m,3487 psi. 13 psi loss over 10 minutes. 10:00 hrs 3445 psi. Bleed down IA. Master swab close 23.5 turns. UTIM(Universal Tubing Interface Module)mount bar on location. Rig up and calibrate UTIM.Blow down stack. Pop off. Make up Drift Run BHA. PT stack 250/3500 psi. MHA 2.125, 2.125"Jars,2.125 disco,2.125 xrv,2.125"weight bar,2.125 x over,3.25' nozzle. Total BHA length 16.26'.Master swab open,RIH. 250 psi WHP. Stack weight at 6663'. Pick up weight 19.5k. Clean. Tagged it again 6663'but popped through. Weight broke back. Made it to 6686'stacking. Picking back up to see if we can pass through again. Picked 4k over coming through 6663'. Stack weight at 6657'. Stack weight at 6707'. Stack 5k. Pick up. stacking hard at 6707'. 6652'overpull 6k. Run back in from 6624'.Stack hard 6707'. Pick up 100'. RIH stack at 6707'. Pick up come online with water down the CT. 3800 psi circ pressure made it past 6707'without a bobble. Shut down pump at 6755'. Immediately stacked 5k. Pick up to 6680'. RIH pumping 1.5 bbls/min. Stack hard at 6755',and 6759'. Picked up to 6620'. No overpulls. Head back down.RIH wt 6700'is 4k. Stack hard at 6765'. Stack at 6787'. 8k down. 6830'. Stacking 5k. Making a little hole. Stack 6837', 6841'. Pick up and RIH we seem to make depth. Pick up stack to 6848'. Pick up RIH stack to 6867'. 5k don. POOH. 6710'10k overpull. 6700'over pull 10k. 30k. Sticky 6680'. Pull to 40k @ 6663'. RIH then pick up clean. Very strange. Pull heavy 6616' w . Pulling heavy 6490'.Pull heavy 6362'. 10k over. Shut down pump. Attempt to POOH. 6239'pull 10k heavy. Park in tubing tail. Let well stabilize. RIH stack weight at 5323.8'. POOH to surface. At surface. Master swab closed 23.5 turns. Blow down. Pop off well.Pop off nozzle. Send pictures to town. Set down weights and pick ups looked like mechanical at first. Later we thought it could be fill due to amount of stacks and overpulls. Good indication on nozzle that there is damaged liner. Set down injector head. Discuss plan forward with town. Send emails and phone calls to Baker and Weatherford. Wellsite secure. Crews off location. 89 bbls of safe lube pumped.120 bbls of seawater pumped for cleanout. SITP 0 psi. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 5-08 CTU 50-029-23168-00-00 203-123 12/28/15 1/5/16 D ily C perations: i e "° �kna - Pa'U 1t 'I iW 12/30/2015-Wednesday SLB clean unit. Address maintenance concerns. Cut 100' of pipe. 12/31/2015-Thursday Pick injector head and 30' lubricator. Make up 2.375" CC, pull test 30k. Make up 2.375" DFCV, 2.375" G Force Jars, 2.375" TJ disconnect. Low PT MHA 250psi and 4,500psi. Good PT. Bleed down. Make up 2.375" circ sub, 2.375" X-treme Motor(Max flow rate 120 GPM), 2.375" Centralizer/String reamer, 3.37"Turbo Scale Mill.Total BHA length 25.87'. Stab on well. Low PT 250psi/3,500psi. Good PT. Circulate freeze protect to 50 bbl tank. Master swab open 23.5 turns. RIH. Online with seawater to displace 60/40. 52psi whp. 23.5 bbls away. Coil pressure increased. Looks like ice plug. Online with warm fluid down back side. Pumped 50 bbls of 110 degree water down back side to warm up coil. Pressure still climbing at 5,300'. POOH. Attempt to freeze protect coil while pooh. 25 bbls down coil. 3,600psi. Pressure dropped @ 4,200'. Ice plug broke free. Continue with operation. 5,300' saw a bump in coil pressure. RIH at 30 ft/min. Stop at 5,412'. Perform weight check. 22k. RIH WT @ depth 5,100 lbs. Online at 1.75 bbls/min. 2,600psi. 5,820' stack 4k. Circ pressure increase. Pick up increase rate 2 bbls/min. RIH slow. 3,400psi circulating pressure. Stack weight at 5,826'. Motor stalled. RIH to 5,828'. Could be chasing metal chunk down hole. Motor work 5,835'. 3,700psi. Stack weight 5,922'. Stack and motor work at 5,934'. Stacking 5,947.8'. PU RIH tag 5,948.7'. 800 lbs motor work. No weight breaking off. PU to 5,844'. Down on pump attempt to RIH. Stack at 5,955'. Stacking down 4k at 5,960'. 800psi motor work. But no weight breaking back. PU wt break back. RIH to 5,965'. Making some hole. Set down 2k at 6,018'. Making hole.Stacking 6,061.5'. RIH to 6,098'. Stack 6,103'. Pick up RIH stack 6,113'. Pull heavy 32k. Keep picking up and RIH gaining 6-10' every time. Feels like we are pushing something down hole.4th time stacking at 6,135'. Heavy over pull 38k. 8k over @ 6,136'. Pull heavy again. Down on pump. Reset jars. Attempt OOH jar lick. 28k normal up. Pick up 20k over to 50k. Wait on jars. Still stacking at 6,136'. Broke through.Stack at 6,143'. Continued attempts at making it past 6,143'. Motor work increase but weight will not break back. Stack 10k down and still no ROP. Continue to attempt to make it past 6,143'.Attempt dry runs. Stack 12k down. Changed pump rates from 1, 1.5, 2 bbls/min. NO luck. Mill may be worn down. POOH to surface.At surface. Master swab closed. Bleed down. Pop off 420 bbls of seawater pumped for milling operation. Break down motor and mill. Set injector head on back deck. Install night cap. Location walk around complete. Location secure. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-08 CTU 50-029-23168-00-00 203-123 12/28/15 1/5/16 Daily Operation$: ,1114101 a iiCt'n h 6 1/1/2015- Friday Review rigging up tools. Use of little jerks. 265 IUR 325 OUR. 100 bbls in return tanks. Pick injector head. Make up tools. Stabbed on well. Lined up with 60/40 for PT. Low PT 250/3,500psi. Good test. Bleed down to 50 bbl tank. Online with seawater from OUR to circulate out 60/40. BHA OD 3.13" CC, DFCV, G-Force Jars,TJ DISCO, DCS, xover,Venturi. 20.26'. Open master swab 23.5 turns. RIH Wt chk at 5k 8,000 lbs. RIH stack weight at 5,175'. Right at liner top. PU. S/O. RIH stack 5k down. PU. RIH pumping 2 bbls min 3,200psi. Work pipe up and down. Stack 10k down. RIH 100 ft/min. Multiple attempts at various pump rates. Pressure up pump and dump coil. NO luck making through liner top with cut lip guide. Tagged up at surface. Blow down pop off. Lots of small metal shavings and two larger 1" long by 1/4"-1/2" wide chunks of metal. Making up motor and mill. Stabbbed on well. 250/3,500psi. Master swab open 23.5 turns. RIH. Pumping safe lube at .3 bbls/min down back side. 19k up @ 5,000' made it past 5,175'with motor and mill. Not pumping. No set down weight. RIH wt @ 5,350' 8k. 5,657' stack 4k popped right back. 5,800'-5,815' stack weight and breaks back. Hard stack 5,815'. No break back. PU wt 22k clean. Online ct, 2.1 bbls/min 3,170 psi. 5,810' stack and motor work. 3,780 psi. PU clean 23.5k. Pulling heavy 28k. 5,800' RIH. Stack weight. 5,815.5'. No weight break back. Not milling off. PU, 24k break over. Stack @ 5,833'. 10k down. PU 30k. RIH, bobbles 30 ft/min made it to 5,879'. PU to 5,765'. Drop pump to .5 bbls/min. RIH 60 ft/min. Making new hole not pumping. 5,898' stack 10k. Clean sailing from 5,879'-5,898'. Stack 10k. Pull to 5,775'. RIH from 5,775' @ 60 ft/min .5 bbls/min. Making hole.Stacking at 5,939'. Made 52' without bobbles or pumping. Possible friction bite due to corkscrew tubing.The faster we RIH the less weight bobbles and deeper we get. PU to 5,850'. RIH at 65 ft/min. Pick up to 5,750'. Online with mill 2 bbls/min. RIH 35 ft/min. 7,600 lbs RIH wt @ 5,790'. Making hole. Stack weight 5,970'. Pull wt 22k clean. 5,969.8' stack 2k. Weight broke back 3,800psi. 700psi motor work. Slack off to 5,971.4' no increase in motor work. Still 800 differential. PU. 5,934'. RIH 40 ft min min rate .3 bpm. Making hole 6,080'.40 ftm. Saw bobble at 6,130'. 6,146' stacking weight. 800psi motor work. No weight or pressure break back. PU 50'. Hit it again. RIH. Stack again at 6,145'. 26k wt. PU to 6,100'. Online 2 bpm 3,100 psi. Stack weight at 6,146.2'. PU to 6,094'. Online 1 bbl.min. RIH @ 80 fpm. Stack @ 6,146'. No luck. PU 26k. Continue with different attempts to make hole at 6,146'. No luck. Good 800psi motor work but not breaking back weight or dropping in pressure. POOH to surface.Tagged up. Master swab closed 23.5 turns. Bleed down. 192 bbls pumped for milling run. Rig down tools. Cut off connector.Trim 100' of pipe.Vac truck loaded 290 bbls seawater in outside upright. Pulling off return tank. Chain inspection. Change packoffs. SDFN. Location secure. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-08 CTU 50-029-23168-00-00 203-123 12/28/15 1/5/16 Daily Operations -27e 44, 1/2/2015-Saturday Discuss JSA and job procedure. Pull test coil connector 20k. Make up MHA. Low PT 250/3,500psi. Bleed down.Stabbed on well. PT 250/3,500psi. Open master swab. RIH. BHA as follows: 2.0" CC, 2.13" DFCV, 2.13"Jars, 2.13"TJ DISCO, 2.13" Circ Sub, 2.13" Extreme Mud Motor, 2.90"Tapered Mill. 19.20'. Enter liner top at 5,182'. Didn't see any bobbles. RIH wt @ 5,500' 7k. 20 up wt. Clean sailing pumping at .5 bmp. 5,900'. Didn't see anything from 6,130'-6,146'. Cont RIH. 7,000'. PU weight 27k. Clean. Cont RIH. Stack weight at 7,424'. PU 29k clean. Online with sea water 1.5 bbls/min. 2,250psi free spin. 7,421.2' stall motor. Ran back in slow. Didn't see motor work. Broke something loose. Cont RIH. 8,000' wt check 28k. Clean. RIH.Stack at 8,058'. 5k down weight broke back. Stack at 8,081' motor work. RIH at 1.5 bbls min 30 fpm. 8,130'. Stack weight and stall motor at 8,405'. RIH stack weight at 8,424'. PU 32k. 8,430' stack weight stall motor. PU clean. Stack weight at 8,644'. Stall motor. 8,727' motor work. RIH past 8,190'without pumping.Tagged 9,080'. PU come online to bottoms up and back ream. 28k clean up wt. Online 1.5 bbls min. Reaming ooh tight spot 6,673'. Pulling heavy. POOH.Tagged up master swab closed. 335 bbls. Pop off well. Break down motor and mill. Make up below circ sub. 2.13 trq-Knuckle, 2" x over, 2.63 venturi. Stab on well. PT 250/3,500psi. Open 23.5 turns. RIH. PU wt at 6,000' 21k. Continue at 1.5 bbls minute. Didn't see liner top on way in. RIH weights look really clean. 6,122'. RIH wt 6,300'. 7,440' swapped to 60/40 @ 428 on totalizer. 9,000'. POOH. Close master and swab 23.5 turns. Blow down. Pop off. Break down tools. Metal chunks, rubber, metal shavings in Venturi.Venturi tube full. Break down tools. Install night cap. SDFN.478 bbls of seawater pump. 1/3/2015-Sunday Hold safety meeting. Discuss JSA. Review and discuss job procedure and BOP reconfiguration. Remove p-subs from BOP's. Change pack offs. Cut 100' of pipe. Pick 35' of lubricator. Make up 2.125" CC, DFCV,Jars, Disco. Pull test to 25k. Pressure test MHA 250/3,500psi. Make up CCL/Gamma Ray PDS memory tools with 2-7/8" carrier. Install 2.875" DJN. Stab on well. Re-pressure test stack to 250/4,500psi for 10 minutes. 272-265 for 10 minutes. 4,615psi-4,560psi after 10 minutes. Bleed down. Open well 23.5 turns. RIH. Corrected to RKB. Input Coil depth of 22'. Stacking weight at 6,315'. PU 21k. Clean. Not able to make it past 6,315'. Mechanical counter says 6,127'. Could have slipped on counter. Counters off 145'. Parked at 6,304' (Mechanical 6,127'). Wait 5 minutes start logging. Pick up to 6,125' Mechanical 6,302' Electronic. Paint white flag at depth. Wait 5 minutes. PU to 6,175' electronic, 5,998' mechanical. Paint reg flag. Wait 5 minutes. Put 6,100' electronic, 5,923' mechanical. Paint yellow flag. Wait 5 minutes. Log up to 4,500' at 40 fpm. Wait 5 minutes. POOH at 80 ft/min. Tagged up at surface. -47.9'. Close master swab 23.5 turns. Blow down pop off. 136 bbls pumped. Break down memory tools. Retrieve Data. Good data. Install night cap. SDFN. �� Hilcorp Alaska, LLC C W~~kUy Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-08 CTU 50'029'23168-80'08 203-123 12/28/15 1/5/16 Daily Operations: ' . 1/4/2015- Monday Fire equipment. Hold safety meeting. Discuss iSA and job procedures. Review BOPE test procedure. Pick injector head. Break down MHA. Install nozzle on coil connector. Stab on well. 24 Hr AOGCC witness notification sent 1/3/16 @ 17:35. Witness waived by Brian Bixby on 1/3/16 @ 17:38 hrs. Start BOPE test. FB Low 269psi 10min end 266psi. High pt full body 4,6l8psi 10 minutes 4,585psi top set b/s 293psi 10 minutes 285psi Hig pt start 4,600psi end 4,540 psi. Low pt 2nd set 28UpsiEnd 26Spdhigh ptsecond set 4^631psi 4541psi. Good test. RIH for pipe rams push 5k pull 10k. Low pt pipe rams 260psi end 256psi. High pt pipe rams.4531psi. End 4,517psi. Bleed down blow down. Pop off. BOPE test complete. Make up BHA. Pressure test MHA at disco 258/3,500psi Circulate 60/40 to recovery tank. BHA: 2" CC, 2.13" DFCV, 2.15"Jars, 2.13" T] DISCO, I.U6" Xover, Z75" HYD setting tool, Z7" setting adapter, 3.11" Paragon packer. End ofcoil toMiddle of � � element 19.49' Total BHA length 22.40' RIH. VVTchk @ 5,100' 20K. RIH. Stack weight at 6,116' Parked at flag CT depth �/a� reads 6,161.6'. Corrected EOP depth at flag is 6,113.19' Packer BHA from EOP to Center of element 19.49' Correct depth to 6,132.68 . Launch 1/2 in ball. Pick up to 6,008' corrected Depth. Pump 30 bbls at 1.6 bbls/min.Audibly confirmed ball over goosneck. Dropped rate to .8 bb|s/min. 800psi. 3,500psi Packer set. Pick up. 21k clean ' tag | Tagged plug 6008' Stacked3kdovvn. � surface.__�� turns. Bleed down pop off. 182 bbls. Setting adapter left down hole on top of Paragon Packer. 2.4" OD. l2" inlength. Pictures sent to town. Break down tools. Instal 1.5" K4Tx1'5/8" sucker rod. Instal B042 shifting tool. Set down 20' lubricator.Walk around cnmp|ete� SDFN� 1/5/2015-Tuesday Fire equipment. Hold safety meeting. Discuss JSA and job procedure. Pick injector head. BHA: 2" CC, 2.125" DFCV, 2.125" Jars, 2.12S"T] HydDisco, Z" drain sub,4.01" BO42shifting tool. Stab nnwell. Low PT2S0psihigh PT3'5U8psiBleed down to 50 bbl tank. Open master swab 23.5 turns. RIH. RIH WT @ 4,300' isS,608|bs.VVHP building while RIH to 191psi. Pump up |Ato808psitohelp see when sleeve opens. VVTcheck 4,SUU' 1Sk. Clean. RIH to shift sleeve open. Ran past sleeve. IA pressure. 800psi Didn't see any weight stack or pressure drop off. 4,850' PU through tubing. No overpull. Could be ice plug in IA or pin could be sheared. Attempting to thaw IA with 80 degree seawater. Bleed down. Bleed 800psi off IA. No signs of gas. Pressure up IA to 3,000psi. Continue to circulate 80 degree seawater down tubing to thaw IA. 114 bbls pumped. Bleed down IA. Pressure up to 2,350psi with 60/40. Online down back side to warm tubing. Pump 30 bbls of 60/40 down tubing. 225 bbls of 80 degree seawater circulated to warm up backside. Master swab closed 23.5 turns. Blow down stack. Pop off. Break down tools. Stab on well. Online with N2 blow coil dry. 320 gallons of N2 pumped. Rig down N2. Rig down CTU 4. 225 bbls of seawater pumped. 320 gallons of N2 pumped. Return well to Pad operator. Coil unit parked onedge ofpad.4.S"tubing freeze protected with 30bb|oof68/48. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, January 04, 2016 11:04 AM To: 'Stan Porhola' Cc: Ted Kramer; Bo York Subject: RE: Change to Sundry 315-738 (MPU S-08 PTD 203-123) Set Plug, No Patches Stan, Thanks for update... unfortunate that there is substantial damage to the liner. You proposal to set a packer/plug at 6000 ft to isolate lower section of 4.5" liner is approved. Regards, Guy Schwartz2016 Sr. Petroleum Engineer r��N Ep MAY 0 2 AOGCC �^ 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Monday, January 04, 2016 9:48 AM To: Schwartz, Guy L(DOA) Cc: Ted Kramer; Bo York Subject: Change to Sundry 315-738 (MPU S-08 PTD 203-123) Set Plug, No Patches Guy, During our mill run we encountered tight hole at 6,143'CTM in a section of blank pipe with a 3.37" mill on 2.0"coil tubing in well MPU S-08. We were able to make it thru the restriction with a 2.90" mill and tagged PBTD to 9,080' MD. A subsequent run with a 2.90" nozzle and 2.875" GR/CCL logging tool tagged up at 6,127' CTM (same section of blank pipe). We feel it will be unlikely we will be able to run our 3.11" OD packers for the lower patch so we will plan to isolate this interval with a retrievable packer/plug. The upper patch was located to isolate a single joint of screen that is located from 6,008'to 6,046'. However,the upper patch will only leave a single joint of screen open below the patch if a plug is set above the restriction at 6,127'CTM.The expense of running the upper patch to isolate the damaged screen to keep only 1 joint of screen does not justify the expense. Therefore,we will plan to isolate both damaged screens and the restricted blank pipe with a single packer/plug set at+/- 6,000'. 1 • • See attached proposed well schematic update if we run the packer as a plug in its new location at+1-6,000'. Let me know if you have any questions or concerns. Regards, Stan Porhola Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 • Milne Point Unit Well: MPU S-08 PROPOSED Last Completed: 3/18/2010 Hilcorp Alaska,LLC PTD: 203-123 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.OF Elev.=72.45'/Orig.GL Elev.=38.6'Doyon 14 20" Conductor 92/H-40 N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,776' j7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 5,284' 20" 4" Production Liner 9.5/L-80/I8T 3.548 5,182 9,143' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/TCII 3.958 Surface 4,755' JEWELRY DETAIL t No Depth Item 1 2,024' Camco 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 4,657' Weatherford Gauge Mandrel 3 4,667' 4.5"HES'XD'Dura Sliding Sleeve-3.813"ID,Opens Down w/Rev.Circ.Jet Pump 4 4,679' 4.5'Weatherford Snorkel Sub 5 4,706' 7-5/8"x 4.5"Baker Premier Packer—3.870"ID 6 4,742' 4.5"HES XN-Nipple 3.813"x 3.725"No Go 7 4,754' WLEG—Bottom @ 4,755' 8 5,182' Baker Tie Back Sleeve 9 5,189' Baker ZXP Liner Top Packer 10 5,196' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 ±6,000' Packer set for Isolation WELL INCLINATION DETAIL 10.3/4"4 0 KOP @ 600'MD Hole Angle Passes 50 Deg.@ 2,500' Max Hole Angle in Tubing=47 deg. 66 Deg.@ Sliding Sleeve 3,823' OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 510sx Class'L'&275sx Class'G'in a 13-1/2"Hole 7-5/8" 400sx Class"G"in 9-7/8"Hole WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-Il T&B k' Tubing Hanger.CIW"H"BPV Profile GENERAL WELL INFO 2 ?i API:50-029-23168-00-00 Drilled and Completed by Doyon 14 -8/4/2003 3 Tubing Patch Se w/E-line—11/15/2008 4 Tubing Replacement/Caliper Casing Doyon 16—3/18/2010 t %9 Slickline Installed 4.5"X-Lock Equalizing Device Med Excluder—7/5/2013 ; . Pulled the Excluder Screen—10/9/2013 +; NOTE: 2.65'Blast Rings Below Tubing S� 5 g Hanger 6 1. 7 Damaged Screen 6,042' 7-5/8'•F`' to 88`s Damaged Screen 6,756'-6,764' ` 11 ---� gm Baker 4-1/2"Float Shoe @ 9,143'.(866'of Rat Hole) TD=10,009 (M))/ID=4,07T(TVD) Restricted Blank Pipe 6,127'-6,146' Revised By:STP 1/04/2016 (BCW' ,'y's • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, December 30, 2015 9:42 AM To: 'Stan Porhola' Cc: Ted Kramer; Bo York Subject: RE: Change to Sundry 315-738 (MPU S-08 PTD 203-123) Mill & Drift run Stan, Thanks for the update on progress...You have approval to modify the sundry procedure for S-08 as outlined below. If milling out restriction is not successful then setting a packer/plug is acceptable alternative to shut off water. Make sure to update the MOC form also. Regards, Guy Schwartz Sr. Petroleum Engineer SCANNED JUL 2 5 2016 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Wednesday, December 30, 2015 8:40 AM To: Schwartz, Guy L(DOA) Cc: Ted Kramer; Bo York Subject: Change to Sundry 315-738 (MPU S-08 PTD 203-123) Mill & Drift run Guy, During our cleanout run with a 3.25"wash nozzle,we started stacking weight at 6,663'CTM. We fought down to 6,867' CTM and had some drag(10k)while pulling back to the tubing tail at 4,754' MD.We ran back down and stacked weight at 5,324' CTM. When we came out of hole we saw significant drag/scratches on the wash nozzle (see attached picture). This metal would likely damage the packers we plan to run in this well for our patches. The plan forward would be to run a mill to+1-7,000' CTM and make a follow up drift run to+/-7,000'CTM to confirm no metal damage. If the mill and drift runs are successful, we would continue with the cleanout run as in Step#7 of the approved sundry. However, if indications are that we would likely damage the packers for the lower patch,we would shorten up our cleanout run and would plan to change from running the lower patch and instead set one of the packers w/a bull plug at +/-6,300' CTM to isolate the lower end of the lateral that is in the Nc sand to minimize sand/water production (in lieu of the patch).This would leave open the Nb sand in the heel of the lateral. 1 • See attached proposed well schematic update if we run the packer as a plug instead of a patch (the plug and patches are all removable). Let me know if you have any questions or concerns. Regards, Stan Porhola l Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 • 0 Milne Point Unit . , . II Well: MPU S-08 PROPOSED Last Completed: 3/18/2010 Hilcorp Alaska,LLC PTD: 203-123 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=72.45'/Orig.GL Elev.38.6'Doyon 14 20" Conductor 92/H-40 N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,776' 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 5,284' 20 j4" Production Liner 9.5/L-80/1BT 3.548 5,182 9,143' TUBING DETAIL 4-1/2" 1 Tubing 12.6/13Cr-80/TCII 3.958 Surface 4,755' JEWELRY DETAIL 1 No Depth Item 1 2,024' Camco 4.5"x 1"w/BK Latch Side pocket KGB-2 GLM f ' 2 4,657' Weatherford Gauge Mandrel 3 4,667' 4.5"HES'XD'Dura Sliding Sleeve-3.813"ID,Opens Down w/Rev.Circ.Jet Pump 4 4,679' 4.5'Weatherford Snorkel Sub 5 4,706' 7-5/8"x 4.5"Baker Premier Packer-3.870"ID 6 4,742' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 7 4,754' WLEG-Bottom @ 4,755' 8 5,182' Baker lie Back Sleeve 9 5,189' Baker ZXP Liner Top Packer 10 5,196' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 ±6,000' Top Patch Upper Packer 12 ±6,090' Top Patch Lower Packer 13 ±6,300' Packer set for Isolation WELL INCLINATION DETAIL ID-3/4'4 6 KOP @ 600'MD Hole Angle Passes 50 Deg.@ 2,500' Max Hole Angle in Tubing=47 deg. t 66 Deg.@ Sliding Sleeve 3,823' i OPEN HOLE/CEMENT DETAIL I ' 20" 260sx of Arctic Set(Approx)in 42"Hole '! 10-3/4" 510sx Class'L'&275sx Class'G'in a 13-1/2"Hole 7-5/8" 400sx Class"G"in 9-7/8"Hole WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.CIW"H"BPV Profile GENERAL WELL INFO 2 API:50-029-23168-00-00 3 Drilled and Completed by Doyon 14 -8/4/2003 Milt 4 Tubing Patch Se w/E-line-11/15/2008 Tubing Replacement/Caliper Casing Doyon 16-3/18/2010 1` Slickline Installed 4.5"X-Lock Equalizing Device Med Excluder-7/5/2013 Pulled the Excluder Screen-10/9/2013 a* ''' NOTE: 5 2.65'Blast Rings Below Tubing Hanger 6 as 1,61 1 7-5/8"'.'` 10 $&9 30/ �` 11 12 13 I� 11s 'd Baker 4-1/2"Float Shoe @ \ �� Ns 9,143'.(866'of Rat Hole) TD=10,009'(MD)/TD=4,077'(1VD) 'r Revised By:STP 12/30/2015 OF T� i • //7711,4's THE STATE Alaska Oil and Gas ALASKA Conservation Commission r _ -- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC Q10 3 ia3 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-08 Sundry Number: 315-738 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • °P' iD7R1,-4--74-- Cathy I. Foerster Chair DATED this/�• day of December, 2015 Encl. aCt t7 116 R$O"sem 0 • RECEIVED • STATE OF ALASKA DEC 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION . 2110 wr APPLICATION FOR SUNDRY APPROVALS )GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well El Install Patches' Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ r Change Approved Program Q, Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑, Other. CT Fill Clean-out D. 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number td Hilcorp Alaska,LLC - Exploratory ❑ Development El` 203-123 • 3.Address: Stratigraphic LI Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23168-00-00 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 SB S-08 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0380109 I ADL03801 10 ' MILNE POINT/SCHRADER BLUFF OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): - 10,009 • 4,077 . 10,009 _ 4,077 1,307 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' N/A N/A Surface 2,776' 10-3/4" 2,776' 2,439' 3,580 psi 2,090 psi Intermediate Production 5,284' 7-5/8" 5,284' 4,000' 6,890 psi 4,790 psi Liner 3,961' 4" 9,143' 4,006' 7,910 psi 6,590 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic 4-1/2" 12.6/13CR-80/TC-II 4,755' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Premier Pkr/ZXP Liner Top Pkr and N/A 4,706(MD)/3,839(TVD)&5,189(MD)/3,982(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑� 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑✓ Exploratory ❑ Stratigraphic I- I Development�]^ Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 12/16/2015 Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact STAN PORHOLA 7 Email sporhola(cr�hilcorp.com Printed Name BO YORK Title OPERATIONS MANAGER SignaturePhone 907-777-8345 Date 12/8/2015 COMMISSION USE ONLY Conditions of appr al: Notify Commission so that a representative may witness Sundry Number: c,fv `I5 -•732 Plug Integrity ❑ BOP Test [ Mechanical Integrity Test EILocation Clearance 117Other: 41- '-15bo /Si. & MeG$(-11 pp C 3Sao103 c.4.-43 Se j .A— ) 44- T ' c s1- ccs ;i ^n Post Initial Injection MIT Req'd? Yes LiNo ❑ 3.5-4T6 Li C 7 / > !e ,t.G '� k11�� Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0 L11O tf Ti:03DMS li APPROVED BY _�� Approved by: i ?6ii_1/ _ COMMISSIONER THE COMMISSION Date: �& "'`/l�GRoie641012 �� TM1Z1f6/� Submit Form and Form 10-403 vised 11/2015 for 12 mont s fromthe dateof approval. Attachments in Duplicate iz-�3 t b �t c 0/%1 • • Well Prognosis Well: MPU S-08 Ililcurp Alaska,LL Date: 12/08/2015 Well Name: MPU S-08 API Number: 50-029-23168-00 Current Status: SI Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: December 16th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-123 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,707 psi @ 4,000' TVD (Last BHP measured 12/31/2012) Maximum Expected BHP: 1,707 psi @ 4,000' TVD (No new perfs being added) Max. Potential Surf Pressure: 1,307 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU S-08 was drilled in 2003 using Doyon 14 and completed as a single-lateral in the Schrader Bluff N sand with a Jet Pump. The completion was pulled and changed out in 2010 using Doyon#16 to replace the 4.5" L-80 tubing with 4.5" 13 Chrome VAM-TOP connections. Notes Regarding Wellbore Condition • Max angle 95.0° @ 6,390'. Deviation at pump is 66.0°. • Casing last tested to 4,200 psi for 30 min down to 4,706' on 3/16/2010. • Jet Pump currently inactive. • Borax log in 2015 found holes in 4.0" 9.5# liner at 6,756'-6,764' and 6,042'. Objective: The purpose of this work is to pull the existing Jet Pump, cleanout the lateral, sei: 2 patches (each patch has an upper and lower packer and spacer pipe)across holes in the 4.0" liner and run a new Jet Pump. Brief Procedure: Coiled Tubing Procedure: ***THIS ISA CHANGE TO SUNDRY 315-521*** 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. 2. Pressure test BOPE to 4,500 psi Hi 250 Low, 5 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. --� 3. Contingency: If jet pump set previously on slickline. a. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump +/-4,667' MD. POOH. 4. RIH w/2.00" coil w/shifting tool and spot tools below sliding sleeve at+/-4,667' MD. 5. Bullhead filtered 8.5 ppg seawater down annulus (at least 1 casing volume, 122.5 bbl), lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. 6. Shift sliding sleeve closed at+/-4,667' MD. Test casing to 3,500 psi for 10 min. POOH. 7. RIH w/2.00" coil w/3.0"to 3.4" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-9,143' MD. POOH. •111 • Well Prognosis Well: MPU S-08 Ililcor')Alaska,LL) Date: 12/08/2015 a. Min ID is 3.423" (4.0" 9.5#Tubing Drift ID)thru Liner. '? b. Circulate out fill using 8.5 ppg seawater w/friction reducer. c. Contingency: If unable to circulate fluid to surface without significant losses (<50% returns). 0 Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 8 RIH w/2.00" coil w/GR/CCL memory logging tool and drift BHA and log 4" liner from +/-7,000' MD to+/-5,750' MD. POOH. (Utilize GR/CCL to correlate to PDS caliper log dated 8/02/2014). 9. PLAN FOR LOWER PATCH: 10. RIH w/2.00" coil w/4.0" 9.5# Paragon II packer and set at+/-6,795' MD. POOH. a. Lower hole in 4.0" liner is from 6,756'-6,764' MD. 1 b. Screen #35 collars at 6,754' to 6,791'. P 11. RIH w/2.00" coil w/latch, 15'joint of 1-1/2"tubing, and PBR (polished bore receptacle). Stab into Paragon II packer at+/-6,795' MD. POOH. 12. RIH w/2.00" coil w/ latch, 15'joint of 1-1/2" tubing, and PBR (polished bore receptacle). Stab into PBR at+/-6,780' MD. POOH. 13. RIH w/2.00" coil w/latch, 15'joint of 1-1/2" tubing, and Upper Paragon II packer. Stab into PBR at +/-6,765' MD. Packer to be set at+/-6,750'. POOH. 4. PLAN FOR UPPER PATCH: 15. RIH w/2.00" coil w/4.0" 9.5# Paragon II packer and set at+/-6,050' MD. POOH. a. Upper hole in 4.0" liner is at 6,042' MD. . 1/ b. Screen #38 collars at 6,009' to 6,046'. ff 6. RIH w/2.00" coil w/latch, 15'joint of 1-1/2"tubing, and PBR (polished bore receptacle). Stab into Paragon II packer at+/-6,050' MD. POOH. 17. RIH w/2.00" coil w/ latch, 15'joint of 1-1/2" tubing, and PBR (polished bore receptacle). Stab into PBR at+/-6,035' MD. POOH. 18. RIH w/2.00" coil w/latch, 15'joint of 1-1/2"tubing, and Upper Paragon II packer. Stab into PBR at +/-6,020' MD. Packer to be set at+/- 6,005'. POOH. 19. RIH w/2.00" coil w/shifting tool and shift sliding sleeve open at+/-4,667' MD. POOH. ,j f:( 20. RIH w/2.00" coil w/RXN running tool and jars to set Jet Pump at+/-4,667' MD. ,5 , a. Confirm proper shear pins set in X-lock to be sheared with the proper force applied. 21. PU above jet pump and start circulation of power fluid to confirm jet pump set. a. Contingency: If pump not set, re-pin and attempt to set again in sliding sleeve profile. 22. POOH w/coil. LD RXN running tool and jars. 23. RD Coiled Tubing and ancillary equipment. 24. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Nitrogen Operations Procedure 5. Fill Cleanout w/Nitrogen Diagram 'n • Milne Point Unit Well: MPU S-08 SCHEMATIC Last Completed: 3/18/2010 Ililcarp Alaska,LLC PTD: 203-123 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=72.45'/Orig.GL Elev.38.6'Doyon 14 20" Conductor 92/H-40 N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,776' k7-5/8" Intermediate29.7/L-80/BTC M6.875 Surface 5,284' 4" Production Liner 9.5/L-80/IBT 3.548 5,182 9,143' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/TCII 3.958 Surface 4,755' JEWELRY DETAIL No Depth Item 1 2,024' Camco 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 4,657' Weatherford Gauge Mandrel 3 4,667' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down w/Rev.Circ.Jet Pump 4 4,679' 4.5'Weatherford Snorkel Sub 5 4,706' 7-5/8"x 4.5"Baker Premier Packer—3.870"ID 6 4,742' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 7 4,754' WLEG—Bottom @ 4,755' 8 5,182' Baker Tie Back Sleeve 9 5,189' Baker ZXP Liner Top Packer 10 5,196' Baker 7-5/8"x 5-1/2"HMC Liner Hanger WELL INCLINATION DETAIL KOP@600'MD Hole Angle Passes 50 Deg.@ 2,500' Max Hole Angle in Tubing=47 deg. 10-3/4"4 I► 66 Deg.@ Sliding Sleeve 3,823' OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 510sx Class'L'&275sx Class'G'in a 13-1/2"Hole 7-5/8" 400sx Class"G"in 9-7/8"Hole WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.CIW"H"BPV Profile GENERAL WELL INFO 5, $wlt ' API:50-029-23168-00-00 e Drilled and Completed by Doyon 14 -8/4/2003 Al Tubing Patch Sew/E-line—11/15/2008 2 p Tubing Replacement/Caliper Casing Doyon 16-3/18/2010 1i -, Slickline Installed 4.5"X-Lock Equalizing Device Med Excluder-7/5/2013 111 3 4' ?` i' Pulled the Excluder Screen—10/9/2013 '4 4 % A I NOTE: (t 2.65'Blast Rings Below Tubing Hanger It e r e 6 k' 7 M. i 7.5/8„ ILK.. 8&9 lc IP ft or I Baker 4-1/2"Float Shoe @ 9,143'.(866'of Rat Hole) NM TD=10,009'(MD)/TD=4,077(TVD) Revised By:STP 12/08/2015 'n • Milne Point Unit Well: MPU S-08 PROPOSED Last Completed: 3/18/2010 Ililcarp Alaska,LLC PTD: 203-123 CASING DETAIL Size Type Wt/Grade/Conn ID Top 8tm Orig.DF Elev.=72.45'/Orig.GL Elev.=38.6'Doyon 14 20" Conductor 92/H-40 N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,776' 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 5,284' V 4" Production Liner 9.5/L-80/IBT 3.548 5,182 9,143' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/TCII 3.958 Surface 4,755' JEWELRY DETAIL No Depth Item 1 2,024' Camco 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 4,657' Weatherford Gauge Mandrel 3 _ 4,667' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down w/Rev.Circ.Jet Pump 4 4,679' 4.5'Weatherford Snorkel Sub 5 4,706' 7-5/8"x 4.5"Baker Premier Packer—3.870"ID 6 4,742' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 7 4,754' WLEG—Bottom @ 4,755' 8 5,182' Baker Tie Back Sleeve 9 5,189' Baker ZXP Liner Top Packer 10 5,196' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 ±6,000' Top Patch Upper Packer 12 ±6,090' Top Patch Lower Packer 13 ±6,710' Bottom Patch Upper Packer 14 ±6,800' Bottom Patch Lower Packer WELL INCLINATION DETAIL 10-3/4'4 1 KOP @ 600'MD Hole Angle Passes 50 Deg.@ 2,500' Max Hole Angle in Tubing=47 deg. 66 Deg.@ Sliding Sleeve 3,823' OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 510sx Class'L'&275sx Class'G'in a 13-1/2"Hole 7-5/8" 400sx Class"G"in 9-7/8"Hole WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-Il T&B Tubing Hanger.CIW"H"BPV Profile • GENERAL WELL INFO 2 " API:50-029-23168-00-00 mom Drilled and Completed by Doyon 14 -8/4/2003 IB. s Tubing Patch Se w/E-line—11/15/2008 goo Tubing Replacement/Caliper Casing Doyon 16—3/18/2010 Slickline Installed 4.5"X-Lock Equalizing Device Med Excluder—7/5/2013 Pulled the Excluder Screen—10/9/2013 a° NOTE: • 5 2.65'Blast Rings Below Tubing Hanger 6 , j, sr 1 7 7-5/8"'• 10 8&9 .:5_819 11 12 13 14 --di.-- Baker 4-1/2"Float Shoe @ r® _ 9,143'.(866'of Rat Hole) TD=10,009'(MD)/TD=4,077(1VD) Revised By:STP 12/08/2015 0 II Milne Point Unit COIL BOPE MPU S-08 11/30/2015 11,1-..j. \L,.A.,.11I MPU S-08 20 X 10% X 7% X 4% Coil Tubing BOP Lubricator to injection head I 117 2.00"Single Stripper _ 1 0E11 Blind/Shea• 1/1610 ! Bh / indShear ,IiFt �a � l` irmm �•I,I,IBlind/Shear■= =■Blind/Shear l,IuI.1 r- _ Slip =� Slip 1 1■I1 011111=1=, =® Pipe 11114 Olk Crossover spool 4 1/1610M X41/16 5M _ Pump-In41/16 Mb .� °� ['I: 11 1502 Union 11111111 Manual Gate Manual Gate �,• 2 1/8 5M 2 1/8 5M Valve,Swab,WKM-M, ; 4 1/16 5M FE ~.ray \yiv 34\t‘q:0 6S�� J \ �i i \l'a N1�1 Valve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic Valve,Lower Master,WKM-M, :t/ 4 1/16 5M FEy Tubing Adapter,4 1/16 5M 1 ,i STANDARD WELL PROCEDURE I!HHemp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • 1- x 2 S F2 a co 5 et + •yti.. > '�A Q N O awo • "6 , Foa E. O W K W C Uk�U Q3o 3 3 a /4 N W S 4I AZZO� D r ----T y;x W W a 0. ❑ g r Z Z (. '`5 > d c r 0 I g ' Y L u MI ii 01. TIM N c 1 7 ,,, i in m a a � � T 11 1.1 1�11y�]11 11111111 1111 r Y111111zo p p W y Z i O O O O 5 IG 0 2a V Y Z a F J J Y J m m 8 N 211 21 i •," � OF Tyi� • • w,I/7,' THE STATE Alaska Oil and. Gas - STA of Conservati®n Commission LAs KA .,_ _ „_:._:4„,. i4„,__,_.,:_:.,__ oit, 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Z, % Fax: 907.276.7542 O�"ALAS1C NV ki SCAC ;AN 4 www.aogcc.alaska.gov Stan Porhola1 a3 Operations Engineer Q0 3 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-08 Sundry Number: 315-521 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Li-/-4 t /"z-‘, Cathy P. Foerster 34 Chair DATED this 'day of November, 2015 Encl. RBDMS POV 12 US • • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 5 2015 APPLICATION FOR SUNDRY APPROVALS ( 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ( ' Install Patches ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑Q Re-enter Susp Well ❑Dther. Remove/Replace Jet Pump 1] 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q " 203-123 3.Address: Stratigraphic ❑ Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23168-00-00 • 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 0 ✓ MILNE PT UNIT SB S-08 • 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0380109IADL0380110 , MILNE POINT/SCRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,009' 4,077 _ 10,009' 4,077 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,776' 10-3/4" 2,776' 2,439' 3,580psi 2,090psi Intermediate 5,284' 7-5/8" 5,284' 4,000' 6,890psi 4,790psi Liner 3,961' 4" 9,143' 4,006' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 4.5" 12.6#/13Cr80/TC-II 4,755 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Premier Pkr/ZXP Liner Top Pkr and N/A •4,706(MD)/3,839(TVD)&5,189(MD)/3,982(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development ❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/29/2015 Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola c(�hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature k ,,` , - Phone 777-8412 Date 8/25/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: M._ 2 t Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other. V L1 J(2�cd ed,-7 ie--21 / (pvsP z2 2 p52.) RBDMII0OV 12 2Q15 Spacing Exception Required? Yes ❑ No El Subsequent Form Required: /0— goy' APPROVED BY Approved by: ,�4 _ C MMISSIONER THE COMMISSION Date: //-3-/s �j OpRidGANAt SubForm ane Form 10-403 Revised 5/2015 for 12 months from the date of approval. Attachmentss in Duplicate • • Well Prognosis Well: MPU S-08 Hikora Alaska,Lb Date:8/11/2015 Well Name: MPU S-08 API Number: 50-029-23168-00 Current Status: SI Oil Well [Jet Pump] Pad: S-Pad Estimated Start Date: September 29th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-123 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,707 psi @ 4,000' TVD (Last BHP measured 12/31/2013) Maximum Expected BHP: 1,707 psi @ 4,000' TVD (No new perfs being added) Max. Allowable Surf Pressure: 222 psi (Based on SBHP taken 12/31/2013 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU S-08 was drilled in 2003 using Doyon 14 and completed as a single-lateral in the Schrader Bluff N sand with a Jet Pump. The completion was pulled and changed out in 2010 using Doyon #16 to replace the 4.5" L-80 tubing with 4.5" 13 Chrome VAM-TOP connection. Notes Regarding Wellbore Condition • Max angle 95.0° @ 6,390'. Deviation at pump is 66.0°. • Casing last tested to 4,200 psi for 30 min down to 4,706' on 3/16/2010. • Jet Pump currently inactive. • Borax log in 2015 found holes in 4.0" 9.5# liner at 6,756'-6,764' and 6,042'. Objective: The purpose of this work/sundry is to pull the existing Jet Pump, cleanout the lateral, set 2 patches (each patch has an upper and lower packer and spacer pipe) across holes in the 4.0" liner and run a new Jet Pump. Brief Procedure: Coiled Tubing Procedure: ,p45r 1. MIRU Coiled Tubing, PT BOPE to,z)J2giasilli 250 Low. 2. RIH w/2.00" coil w/3.5" wash nozzle and cleanout to top of Jet Pump+/-4,667' MD. POOH. a. Min ID is 3.813" thru Sliding Sleeve. 3. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump+/-4,667' MD. POOH. 4. RIH w/2.00" coil w/3.5" wash nozzle to sliding sleeve at+/-4,667' MD. 5. Bullhead filtered 8.4 ppg produced water down annulus, lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. POOH. 6. RIH w/2.00" coil w/shifting tool and shift sliding sleeve closed at+/-4,667' MD. POOH. 7. RIH w/2.00" coil w/3.0" wash nozzle and cleanout to PBTD at+/-9,143' MD. POOH. a. Min ID is 3.725" thru XN Nipple. b. Min ID is 3.548" (3.423" Drift)thru 4.0" liner. 8. RIH w/2.00" coil w/4.0" 9.5# Paragon II packer and set at+/-6,800' MD. POOH. • • Well Prognosis Well: MPU S-08 Rikor„Ala.ka,LL Date:8/11/2015 a. Lower hole in 4.0" liner is from 6,756'-6,764' MD. , toc 9. RIH w/2.00" coil w/4.0" 9.5# Paragon II packer, spacer pipe, and anchor latch 10. Land latch in lower packer and set upper packer at+/-6,710' MD. POOH. 11. RIH w/2.00" coil w/4.0" 9.5# Paragon II packer and set at+/-6,090' MD. POOH. �,„oa a. Upper hole in 4.0" liner is from 6,042' MD. 12. RIH w/2.00" coil w/4.0" 9.5# Paragon II packer, spacer pipe, and anchor latch. 13. Land latch in lower packer and set upper packer at+/-6,000' MD. POOH. 14. RIH w/2.00" coil w/shifting tool and shift sliding sleeve open at+/-4,667' MD. POOH. 15. RIH w/2.00" coil w/GS running tool and run Jet Pump+/-4,667' MD. 16. PU to+/-4,650' MD. Displace well over to 8.4 ppg produced water. a. Estimated volume (w/o coil in hole) is 70 bbl. 17. POOH w/coil. LD GS running tool. P41,4- 18. RD Coiled Tubing. 19. Turn well over to production. I • Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic • • Milne Well: Point MPU S-08Unit SCHEMATIC Last Completed: 3/18/2010 Ililcorp Alaska,LLC PTD: 203-123 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=72.45'/Orig.GL Elev.38.6'Doyon 14 20" Conductor 92/H-40 N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,776' 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 5,284' 20 e 4" Production Liner 9.5/L-80/IBT 3.548 5,182 9,143' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/TCII 3.958 Surface 4,755' JEWELRY DETAIL 1 No Depth Item 1 2,024' Camco 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 4,657' Weatherford Gauge Mandrel ' 3 4,667' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down w/Rev.Circ.Jet Pump 4 4,679' 4.5'Weatherford Snorkel Sub 5 4,706' 7-5/8"x 4.5"Baker Premier Packer—3.870"ID 6 4,742' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 7 4,754' WLEG—Bottom @ 4,755' 8 5,182' Baker Tie Back Sleeve 9 5,189' Baker ZXP Liner Top Packer 10 5,196' Baker 7-5/8"x 5-1/2"HMC Liner Hanger WELL INCLINATION DETAIL KOP @ 600'MD Hole Angle Passes 50 Deg.@ 2,500' Max Hole Angle in Tubing=47 deg. 10-3/4"4 1 66 Deg.@ Sliding Sleeve 3,823' OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 510sx Class'L'&275sx Class'G'in a 13-1/2"Hole 7-5/8" 400sx Class"G"in 9-7/8"Hole 1 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-IIT&B Tubing Hanger.CIW"H"BPV Profile GENERAL WELL INFO ' API:50-029-23168-00-00 Drilled and Completed by Doyon 14 -8/4/2003 Tubing Patch Se w/E-line—11/15/2008 t 2 54 Tubing Replacement/Caliper Casing Doyon 16—3/18/2010 44 V, 141 3 .'y Slickline Installed 4.5"X-Lock Equalizing Device Med Excluder-7/5/2013 f* im4 Pulled the Excluder Screen—10/9/2013 V NOTE: I'8 12.65'Blast Rings Below Tubing Hanger 4 45 1q a 6 7 75/8„' 10 &9 I/4r f Baker 4-1/2"Float Shoe @ 9,143'.(866'of Rat Hole) TD=10,009'(MD)/TD=4,077'(TVD) Revised By:TDF 8/24/2015 • Milne Point Unit • Well: MPU S-08 PROPOSED Last Completed: 3/18/2010 flilcoru Alaska,LLC PTD: 203-123 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=72 45'/Orig.GL Elev.=38 6'Doyon 14 20" Conductor 92/H-40 N/A Surface 112' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,776' 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 5,284' 20 4" Production Liner 9.5/L-80/IBT 3.548 5,182 9,143' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/TCI I 3.958 Surface 4,755' JEWELRY DETAIL 1 No Depth Item 1 2,024' Camco 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 4,657' Weatherford Gauge Mandrel 3 4,667' 4.5"HES`XD'Dura Sliding Sleeve—3.813"ID,Opens Down w/Rev.Circ.Jet Pump 4 4,679' 4.5'Weatherford Snorkel Sub 5 4,706' 7-5/8"x 4.5"Baker Premier Packer-3.870"ID 6 4,742' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 7 4,754' WLEG—Bottom @ 4,755' 8 5,182' Baker Tie Back Sleeve 9 5,189' Baker ZXP Liner Top Packer 10 5,196' Baker 7-5/8"x 5-1/2"HMC Liner Hanger r— 11 ±6,000' Top Patch Upper Packer ) ,yS' P ,,,fr E 12 ±6,090' Top Patch Lower Packer / 13 ±6,710' Bottom Patch Upper Packer S S 14 ±6,800' Bottom Patch Lower Packer WELL INCLINATION DETAIL 103/4"4 1 KOP @ 600'MD Hole Angle Passes 50 Deg.@ 2,500' Max Hole Angle in Tubing=47 deg. 66 Deg.@ Sliding Sleeve 3,823' OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 510sx Class'L'&275sx Class'G'in a 13-1/2"Hole 7-5/8" 400sx Class"G"in 9-7/8"Hole WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.CIW"H"BPV Profile GENERAL WELL INFO 2 API:50-029-23168-00-00 Drilled and Completed by Doyon 14 -8/4/2003 ��i 3 Tubing Patch Se w/E-line—11/15/2008 • 4 Tubing Replacement/Caliper Casing Doyon 16—3/18/2010 Slickline Installed 4.5"X-Lock Equalizing Device Med Excluder—7/5/2013 Pulled the Excluder Screen—10/9/2013 ;• NOTE: 5 2.65'Blast Rings Below Tubing Hanger 6 7 7.5/8" 10 %\ &9` 11 12 13 14 m m m m Baker 4-1/2"Float Shoe @ ea--za 9,143'.(866'of Rat Hole) TD=10,009'(MD)/TD=4,077'(1VD) Revised By:TDF 8/25/2015 • Milne Point Unit COIL BOPE MPU S-08 08/11/2015 Ililrorp 1Da.ks',I.IA. MPU S-08 20 X10''% X7%X4% Coil Tubing BOP 7vLubricator to injection head 1 71 ift-r 1.75"Tandem Stripper I Gam, El JIull Blind/ShearL1/1610 _ ,I,'.1 ■ I _■Blind/Shear l 0.111.1 il M% elind/Shear = • • Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, November 02, 2015 11:28 AM To: Schwartz, Guy L(DOA) Subject: FW: S-08 CTU patches in 4" liner PTD 203-123 Guy, Just got confirmation that the pipe will actually be 1.900" 3.64#, not the 2-1/16" OD pipe. Stan From: Stan Porhola Sent: Monday, November 02, 2015 11:25 AM To: 'Schwartz, Guy L(DOA)' Subject: RE: S-08 CTU patches in 4" liner PTD 203-123 Guy, The new design for the patch will be roughly 30'-35' long pieces of 2-1/16" 3.25#. We should have adequate lubricator to run the patch since it will be run in sections that have a latch at the bottom and a PBR at the top. No plan for separate ram coverage even though the coil rams will be for 2"coil so they will be fairly close to the OD of the 2-1/16" stick pipe. Stan From: Schwartz, Guy L (DOA) [mailto:guv.schwartz@alaska.gov] Sent: Thursday, August 27, 2015 9:51 AM To: Stan Porhola Subject: S-08 CTU patches in 4" liner PTD 203-123 Stan, CT is going thru tubing to set a two patches in the 4" liner according to your procedure. The patches are 90ft long. How are you going to lubricate that much spacer pipe in to the well with CT. ?or just plan on having well dead and run in with equipment with open wellhead? Will there be ram coverage for the spacer pipe? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gpv). 1 Image p, ¿ject Well History File coJer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a.03 - L;23 Well History File Identifier Organizing (done) o Two-sided 1IIIIIII1 " 11111111 o Rescan Needed 1111111111111111111 R~CAN V Color Items: o Greyscale Items: DIGITAL DATA ~ettes, No. S o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: é Maria) o Other:: Date: 'I I ~ 0 O~.e;' /s/ \y~ 1111111111111111111 !J t11 Project Proofing Scanning Preparation BY: éMaria ) Date: I ~ 1,/ oS- î X 30 =, [PO + ;;J..Ó = TOTAL PAGES SO I . (Count does not include cover sheet) '/Vl~ Date: 1:;- r ()~ç Isl "I II II /s/ BY: ( Maria) Production Scanning Stage 1 Page Count from Scanned File: Cð (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ('Maria) Date: f~/11oC NO wJJ BY: /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ II1I11I1I111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked I11111I1I1111111111 10/6/2005 Well History File Cover Page.doc • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 S ` FEB 2 4 ' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ca03 _ 13 333 West 7 Avenue Anchorage, Alaska 99501 pC Do �1 Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 --j MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS-16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS-22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS-27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS-28 , 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS-29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 _ 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 03/25/10 Schtumh~rger ~a ~ ~..'~ .~.,.' N0.5481 Alaska Data & Consulting Services Company: State of Alaska q (~ (~` ~ :('s ~ (>• 2525 Gambell Street, Su0e 400 Alaska Oil & GaS Cons Comm ! S I~~ i- sl' eJ Anchorage, AK 99503-2636 Attn: Christine Mahnken ATTN: Bath 333 West 7th Ave, Suite 100 Anchorage, AK 99501 qt .- b d'c+ ° , Well Job # Log Description Date BL Color CD ~~'S ~~ ~a,.r 03-37 07-23B V-123 09AKA0188 09AKA0078 BBKA-00002 OH MWD/LWD EDIT - 1 OH MWD/LWD EDIT CH EDIT PDC SCMT 02/14/10 01/10/10 01/15/10 2 2 1 1 1 04-42 08-12A X-04 8148-00099 AP3O-00081 BBSK-00012 INJECTION PROFILE .- PRODUCTION PROFILE - LDL - 03/23!10 03/21/10 -03/14/10 1 1 1 1 1 1 03-28 14-11 A 15-318 89RH-00017 83S0-00050 AP3O-00082 PRODUCTION LOG PERF RECORD & FL 1 G BHP LDL 03/19/10 /20/10 03/22/10 1 1 1 1 1 1 03-10 14-07 03-11 12-26 P 89RH-00018 8148-00098 89RH-00019 ANHY-00121 INJEC ION PROFILE -Q PERF RECORD & FLOWING BHP INJECTION PROFILE PRODUCTION PROFILE G - 03/21/10 03/22/10 03/22/10 03!76/10 1 1 1 1 1 1 1 1 2-22 BBSK-00011 USIT CORROSION DATA 03/11/10 1 1 P2-22 BBSK-D0011 USIT CEMENT DATA r 03/11/10 1 1 03-28 89RH-00017 CBL - 8 03/19/10 1 1 15-30A BSJN-00045 SCMT - - ~ - 03/22/10 1 1 MPS-08 BBUO-00009 USIT .- 03/12/10 1 1 PLEASE ACKNOWI Ffl(:F wac ctor pv cir_uru r•_ nun eer„ounv. ...,~ ........ -.,......._ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 _. _ ...... . 900 E. Benson Blvd. - - Alaska Data & Consulting Services 2525 Gambell Street, Suee 400 Anchorage, AK 99503-2838 • • t~ ~n~,, ` 1 STATE OF ALASKA ~ ~~~~~~ ALAS IL AND GAS CONSERVATION COMMI N REPOR OF SUNDRY WELL OPERATIONS APR 0 5.2010 1. Operations Performed: KNI ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re - ~~~ ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: .Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 203-123 3. Address: ^ Service ^ Stratigraphic API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23168-00-00 7. Property Designation: ~fi 8. Well Name and Number: ~. ~ ADL 380110 '~' ~ (~ MPS-08 9. Field /Pool(s): Milne Point Unit / Schrader Bluff Oil Pool 10. Present well condition summary Total depth: measured 10009' feet true vertical 4077' feet Plugs (measured) None Effective depth: measured 10009' feet Junk (measured) None true vertical 4077' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 2741' 10-3/4" 2776' 2438' 5210 2480 Intermediate 5252' 7-5/8" 5284' 4000' 6890 4790 Production Liner 3961' 4-1 /2" x 4" 5182' - 9143' 3980' - 4006' Perforation Depth: Measured Depth: Sand Screen: 9293' - 9059' True Vertical Depth: 4013' - 4006' Tubing (size, grade, measured and true vertical depth): 4-1 /2", 12.6# 13Cr80 4755' 3858' Packers and SSSV (type, measured and true vertical depth): 7-5/8" x 4-1/2" Baker Premier packer 4706' 3839' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~~s ~~~ay ~ ~ ~ ~ ~ ~~ ~ ~~ ~r Y, 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 342 91 576 1,397 218 Subsequent to operation: 388 64 518 3,170 235 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ®Development ^ Service ® Dail Re ort of Well O erations y p p ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact David Bjork, 564-5683 N/A Printed Name Terrie Hubble Title Drillin Technologist Prepared ey NamelNumber. S' nature Phone 564-4628 Date ~g ~~ Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 r Submit Original Only RBDAAS aPR 0 6 ~~ c~~`~ ~ `'~'~' ~~.~r'c~ • MPS-08, Well History (Pre Rig Workover) Date Summary 01/30/10 RAN 2.64" CENT, 3-1/2" GS CORE W/EO PRONG. EO PLUG Q 4,813' MD. RAN 3-1/2" GR (steel), PULLED XXN-PLUG BODY FROM 4,813' MD. RAN KJ, 2.64" CENT, S. ABSOBER, DUAL SPARTEK GAUGES. 15 MIN GRADIENT STOP C~3 4,763' SLM (4,794' MD). 3 HR BHP STOP Q 5,118' SLM (5,149' MD). ATTEMPTED TO SET AND XXN PLUG W/FILL EXTENSION IN XN NIPPLE C~3 4813' MD. WORKED FOR 1 HR. PINS CAME BACK BARELY TOUCHED. 01/31/10 LRS DISPLACED TBG W/75 BBLS OF DIESEL 120°. SET 2.81" XXN-PLUG W/ 16" FILL EXT.(8-7/64" equalizing ports, 40" lih, 2.80" no-go. T/IA=50/250) IN XN C~3 4,813' MD. LRS CMIT-IA TO 2,000 PSI. (passed). WELL LEFT S/I, TURN OVER TO DSO. JOB COMPLETE. 02/01/10 T/I/0=S1/300/0 MIT-OA (FAILED) Pumped a total of 10 bbls diesel down OA. Injection rate of 1 bpm Q 1140 psi. Pressure lost 510 psi in 15 min and falling. Notified opertor, Tag well w/Info. WHP=S1/300/0 02/08/10 T/IA/OA= SI/320/0 Temp=warm PPPOT-T (PASS) PPPOT-IC (PASS) (Pre Rig) PPPOT-T RU 1 HP BT onto THA test void psi bled to 0 psi. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycled and torqued "ET Style" all were in good working condition PPPOT-IC RU 2 HP BT onto IC test void 0+ psi bled to 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle and torqued LDS "ET style" all were in good working condition. "*" All LDS ran out 1.0" ran in and then torqued'*' 02/09/10 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 0/200/0, RU ELINE FOR TUBING CUT. 02/10/10 POWER JET CUT 3-1/2" TUBING AT 4760' WITH 2.50" SCP POWER CUTTER. DEPTH REFERENCED TO TUBING TALLY DATED 8/2/2003. POSITIVE SURFACE INDICATION OF FIRE. CONFIRMED CUTTER FIRED AFTER POOH. FINAL T/I/O = 0/300/0 JOB COMPLETE, WELL SHUT- IN ON DEPARTURE. 02/24/10 Freeze protect Flowline. Pump 3 bbls 60/40 meth, 3 bbls diesel and 3 bbls 60/40 meth down flowline. Bleed flowline to zero. Tag well, notified operator. 02/27/10 T/I/0=20/250/50 MIT-TxIA to 1000 psi PASSED (Pre RWO). Pump 17.1 bbls diesel down Tbg to reach test pressure. 1 st 15 min Tx IA loss 0/0 psi. 2nd 15 min Tx lA loss 0/0 psi for a total loss in 30 min 0/0. Bleed Tx IA down w/ 17.1 bbls diesel returned. FWHP=20/250/50. Page 1 of 1 BP EXPLORATION Page 1-,of 13' Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 .Date From - To Hours Task Code NPT Phase Description of Operations 3/7/2010 05:00 - 06:30 1.50 MOB P PRE PJSM, BRIDAL UP, RD FLOOR EQUIPMENT. 06:30 - 07:30 1.00 MOB P PRE PJSM, LAY DERRICK OVER 07:30 - 08:30 1.00 MOB P PRE PJSM, MOVE OFF WELL, CLEAN LOCATION AROUND WELL. 08:30 - 09:00 0.50 MOB P PRE TROUBLESHOOT SMOKE IN SCR ROOM. CLEANED OUT EXHAUST BLOWER VENT PACKED WITH SNOW. 09:00 - 09:30 0.50 MOB P PRE CONTINUE TO STAGE RIG IN MIDDLE OF PAD. 09:30 - 11:00 1.50 MOB P PRE PJSM, INSTALL BOPS OF TRAVELING STAND, INSTALL REAR BOOSTER. 11:00 - 12:00 1.00 MOB P PRE PJSM, MOVE RIG TO FRONT SIDE OF DS - 03 PAD. 12:00 - 00:00 12.00 MOB P PRE MOVE RIG FROM DS - 03 TOWARD MPS-08. --1600-hrs, RIG AT ICE ROAD ON DS-17. --1800-hrs, RIG AT GUARD SHACK ON OTHER SIDE OF ICE ROAD. --2200-hrs, RIG AT OXBOW ROAD INTERSECTION ON THE SPINE ROAD. 3/8/2010 00:00 - 00:00 24.00 MOB P PRE MOVE RIG FROM DS - 03 TOWARD MPS-O8. --0300-hrs, RIG AT GC1 INTERSECTION. --0530-hrs, RIG AT RIG AT FRONTIER CORNER --1000-hrs, RIG NEAR EAST KUPARUK BRIDGE --1400-hrs, RIG AT W-PAD ACCESS. --1600-hrs, RIG 3-MI FROM MILNE POINT ACCESS ROAD. --1900-hrs, RIG STARTED DOWN MILNE POINT ACCESS ROAD --2230-hrs, RIG PASSING TEXACO PAD ON MILNE POINT ACCESS ROAD. --2330-hrs, RIG TURNED ON TO S-PAD ACCESS ROAD. 3/9/2010 00:00 - 06:00 6.00 RIGU P PRE MOVE RIG TO S-PAD --0030-hrs, SPOT RIG IN MIDDLE OF S-PAD. --0045-hrs, RD REAR BOOSTER WHEELS, REMOVE SNOW, PLACE BOP STACK ON RIG. --0200-hrs, PJSM, RAISE DERRICK. --0330-hrs, CONTINUE WITH SNOW REMOVAL AND PAD PREP. --0500-hrs, PLACE RIG MATS AROUND WELL. 06:00 - 09:30 3.50 RIGU P PRE WORK RIG INTO POSITION TO GET UP ON RIG MATS. LOWER THE BACK WINDWALLS IN ORDER TO CROWD CLOSER TO THE WELLHOUSES TO THE EAST OF THE THREE WELLS EXPOSED FOR THE RIG ACCESS. --0710-hrs, CALL AOGCC WITH UPDATE FOR IMPENDING INITIAL BOP TEST FOR DOYON 16 ON MPS-08 RWO. --0715-hrs, CHUCK SCHEVE, AOGCC INSPECTOR RETURNED CALL AND WAIVED STATE'S RIGHT TO WITNESS THE BOP TEST. --0800-hrs, CONTINUE TO WORK RIG INTO POSITION WITH PAD OPERATOR, TOOLPUSHER, AND WSL OBSERVING. DO NOT FINISH POSITIONING RIG DUE TO SCHEDULED MANDATORY ATTENDANCE AT MILNE POINT ATP MEETING AT 1000-hrs. 09:30 - 12:00 2.50 MOB P PRE BOTH CREWS ATTEND MILNE POINT ATP MEETING IN MILNE POINT GYM. ALSO IN ATTENDANCE WERE RIG WELDER AND WSL. 12:00 - 17:30 5.50 RIGU P PRE PRE-TOUR AND PJSM FOR DAY CREW TO COMPLETE F'flflt0tl: 4/S/'LU1V 1U:5`J:IU AM • BP EXPLORATION Operations Summary. Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Event Name: WORKOVER Start: 3/2/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Page 2 of 13 ~' Spud Date: 7/21/2003 End: 4/30/2010 Date From - To Hours Task Code NPT Phase Description ofi Operations 3/9/2010 12:00 - 17:30 5.50 RIGU P PRE THE RIG POSITIONING. --1230-hrs, CREW CHANGE AND RESUME RIG POSITIONING. --SPOT CUTTINGS TANK, GENERATOR MODULE, ULSD FUEL TRAILER, AND MUD PUMP MODULE #2. --R/U CELLAR. WELLS SUPPORT PERSONNEL PUMP OPEN THE SURFACE SAFETY VALVE. --BRING ON HOT SEAWATER. --ACCEPT RIG AT 1700-hrs. 17:30 - 20:00 2.50 WHSUR P DECOMP LOAD WELLS SUPPORT LUBRICATOR IN PIPE SHED AND BRING TO RIG FLOOR. --R/U LUBRICATOR ON TREE. --TEST LUBRICATOR TO 500 PSI. GOOD TEST. --PULL BPV WITH LUBRICATOR WITH NO PRESSURE UNDER BPV. --RD LUBRICATOR. --RU AND CHECK SUCTION LINES ON PUMPS. 20:00 - 23:30 3.50 WHSUR P DECOMP PJSM ON CIRCULATING OUT DIESEL FROM WELL. --FILL LINES AND INSPECT. --PRESSURE TEST LINES TO 3500 PSI. GOOD TEST. --0 PSI ON TUBING, 0 PSI ON IA. --BEGIN CIRCULATING DOWN TUBING TAKING RETURNS OUT OF IA. --PUMPING AT 5 BPM WITH 0 PSI AND NO RETURNS FOR 17 BBLS. --AT 17 BBLS AWAY PRESSURE INCREASED TO 180 PSI SEEING RETURNS AT 25 BBLS AWAY. --PUMP 20 BBL HI-VIS SWEEP. --CIRCULATE AT 5 BPM FOR THE TUBING VOLUME AND INCREASE TO 7 BPM AND 370 PSI FOR THE REMAINDER OF THE CIRCULATION. --SWEEP BACK IN 208 BBLS PUMPED. PUMPED A TOTAL OF 275 BBLS STILL SEEING DIESEL STRUNG OUT IN RETURNS BUT A WT OF 8.4 PPG HEAVY. --SHUT DOWN PUMPS FOR 30 MIN. MONITORING WELL. --BRING ON PUMPS ON AT 7 BPM AND 450 PSI AND CIRCULATE 150 BBLS TILL FLUID STARTED GLEANING UP, CONTINUE CIRCULATING A TOTAL OF 272 BBLS AND SHUT DOWN PUMPS TO MONITOR WELL. WELL STATIC. 23:30 - 00:00 0.50 WHSUR P DECOMP R/U TO SET TWC. --BLOW DOWN CIRCULATION LINES. --SUCK OUT TREE. 3/10/2010 00:00 - 02:00 2.00 WHSUR P DECOMP INSTALL TWC. --TEST TWC TO 3500 PSI ABOVE AND 1000 PSI FROM BELOW. GOOD TEST. --BLOW DOWN LINES. --RIG DOWN TEST EQUIPMENT. --BARRIERS ARE TESTED TWC AND PX PLUG AT 4813'. 02:00 - 04:00 2.00 WHSUR P DECOMP PJSM ON NIPPLE DOWN TREE. --N/D TREE AND ADAPTER FLANGE. --TEST FIT 4-1/2" HANGER X-OVER WITH 7-1/2 TURNS. 04:00 - 09:00 5.00 BOPSU P DECOMP PJSM FOR N/U BOPE. --N/U 13-5/8" ADAPTER SPOOL. Printed: 4/5/2010 10:59:10 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description ofi Operations 3/10/2010 04:00 - 09:00 5.00 BOPSU P DECOMP --N/U BOPE WITH 2-7/8" X 5" VBRS. 09:00 - 15:00 6.00 BOPSU P DECOMP PJSM for BOP TESTING. ALSO DISCUSSED DROPPED OBJECT AT ANOTHER RIG AND A WELL CONTROL EVENT AT ANOTHER RIG. AOGCC INSPECTOR, CHUCK SCHEVE WAIVED WITNESS AT 0715-hrs, 3-09-2010. --TEST BOPE TO 250-psi LOW, 3500-psi HIGH. TEST VBRS WITH 4" AND 4-1/2" TEST JOINTS. TEST THE ANNULAR WITH THE 4" TEST JOINT TO 250-psi AND 3500-psi. -ALL TESTS PASS. ALL TESTS WITNESSED BY WSL MIKE ROONEY AND TOOL PUSHER BOB LUPTON. 15:00 - 15:30 0.50 BOPSU P DECOMP RD ALL BOPE TEST EQUIPMENT. --BLOW DOWN CHOKE AND KILL MANIFOLD. --RD CHART RECORDER. 15:30 - 16:30 1.00 CLEAN P DECOMP PICKUP DUTCH RISER AND INSTALL. -RILDS. -PU LUBRICATOR AND TEST TO 500 PSI. -GOOD TEST. -PULL TWC WITH NO PRESSURE UNDER TWC. 16:30 - 17:00 0.50 CLEAN P DECOMP LAY DOWN LUBRICATOR AND TWC. -BOLDS. -RD DUTCH RISER. 17:00 - 18:00 1.00 CLEAN P DECOMP INSPECT TOP DRIVE. -PULL COOLING FAN COVER AND REPAIR. 18:00 - 19:00 1.00 CLEAN P DECOMP MAKE UP HANGER XO. -SUCK OUT STACK. -RIH AND MAKE UP XO TO HANGER WITH 8 TURNS. -BOLDS. -PULL TO 80K AND HANGER CAME FREE. PULL TO 105K AND BREAK OVER TO 100K STRING WEIGHT. -PULL BUSHINGS. -PULL HANGER ABOVE RIG FLOOR. 19:00 - 20:00 1.00 CLEAN P DECOMP BREAK CIRCULATION WITH 8 BPM AND 270 PSI -CIRCULATE BOTTOMS UP. -RETURNS ARE CRUDE AND DIRTY SEAWATER DUMPING RETURNS OUT TO CUTTINGS TANK. -DUMPED 150 BBLS OF DIRTY SEAWATER. -MONITOR WELL. WELL STATIC. 20:00 - 00:00 4.00 CLEAN P DECOMP PJSM FOR POH WITH 4-1/2" 12.6#, L-80, IBT TUBING. -R/U EQUIPMENT. -M/U FLOOR VALVE. -TERMINATE I-WIRE. -UD TUBING HANGER. -POH UD 4-1/2" TUBING FROM 4760' TO 2560'. -NO EXTERNAL CORROSION ISSUES NOTED AS OF YET. 3/11/2010 00:00 - 06:00 6.00 CLEAN P DECOMP PJSM FOR POH WITH 4-1/2" 12.6#, L-80, IBT TUBING FROM 2560'. -JOINTS 54, 56, 58 OUT OF THE HOLE WERE NOTED TO HAVE SPOTS OF CORROSION IN MIDDLE OF JOINTS. THESE SECTIONS WERE CUT OUT TO BE SENT FOR INSPECTION. -JOINT 61 SHOWS SIGNS BUT WAS NOT CUT AS NO PENETRATION OF CORROSION AS OF YET. -JOINTS 63, 64 SHOWS CORROSION PENETRATION, ~~ Printed: 4/5/2010 10:59:10 AM BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17!2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To' 'Hours Task Code. NPT Phase Description of Operations 3/11/2010 100:00 - 06:00 6.001 CLEAN P 06:00 - 07:00 1.00 CLEAN P 07:00 - 07:30 0.50 CLEAN P 07:30 - 08:30 1.00 CLEAN P 08:30 - 09:00 09:00 - 11:00 0.50 CLEAN P 2.00 CLEAN N 11:00 - 16:00 5.001 CLEAN I P 16:00 - 16:30 0.501 CLEAN P 16:30 - 17:30 I 1.001 CLEAN I P DECOMP COLLAR BETWEEN 63, 64 WAS CORRODED ON ONE SIDE. SOME OF THE I-WIRE CLAMPS SHOWED CORROSION. SECTIONS WERE CUT FROM BOTH THESE JOINTS. -AI I CORROSION WAS LOCATED ON ONE SIDE OF PIPE. -CONTINUE SEEING CORROSION PITTING ON ALL JOINTS. -JOINTS 87 - 93 STILL SIGNS OF CORROSION BUT NOT AS MUCH AS ON THE EARLIER JOINTS. -I-WIRE PARTED UNDER CLAMP WHEN CLAMP WAS REMOVED. PULLED WIPER RUBBER AND REMOVED 3 CLAMPS FROM STACK. -CONTINUE POH WITH TBG. -JOINTS 94 - 112 SHOWING WORSE AND DEEPER PITTING THAN JOINTS 87 - 93. -0500 Hrs, JOINT #112 OUT OF HOLE. -HOLES IN JOINTS 63, 64, AND 98. ALL THE REST JUST CORROSION PITTED. -ALL CONNECTIONS GOOD ON I-WIRE. NO CORROSION AND NO BREAKS. -RECOVERED 1 GLM ASSY, DISCHARGE PRESSURE GAUGE, SLIDING SLEEVE, JET PUMP GAUGE SENSOR, X-NIPPLE, 3-1/2" CUT JOINT 4.66' LONG FLARED TO 4". -TOTAL OF 63 CANNON CLAMPS RECOVERED. DECOMP CLEAR AND CLEAN RIG FLOOR. LOAD OUT THE SCHLUMBERGER / CAMCO SPOOLER. DECOMP P/U AND INSTALL 9-1/8" WEAR RING. BRING 7-5/8" SCRAPER BHA COMPONENTS TO RIG FLOOR. DECOMP PJSM. P U AND M/U 7-5/8" CASING SCRAPER BHA: 4-3/4" BULLNOSE, 7.2" OD SCRAPER FOR 7-5/8" CASING, 2-ea BOOT BASKETS, BIT SUB, BUMPER SUB, AND 6-ea 4-3/4" DRILL COLLARS. DECOMP RIH TO 243'. RREP DECOMP CHANGE OUT RETURN SPRINGS ON SKATE HYDRAULIC HOSE REEL. DECOMP PJSM. CONTINUE RIH WITH 7-5/8" CASING SCRAPER BHA. --1235-hrs, RIH WITH JOINT #45. --1305-hrs, #60 RIH. --1330-hrs, #75 RIH. --1450-hrs, #120. --1505-hrs, #135. --1535-hrs, TAC, STl IR AT 4759'. MAKE 5-ea YO-YO SCRAPES FROM 4632' TO 4727'. --CIRCULATE BOTTOMS UP, 8-BPM AT 850-psi, AND SEE CLEAR SEAWATER ACROSS THE SHAKERS THROUGH THE FIRST 130-140-Bbls (144-Bbls DP x 7-5/8", 29.7# ANNULAR VOLUME), THEN GET THICK, OILY FLUID FOR 10+Bbls, FOLLOWED BY THICKER PARAFFIN-LIKE GUNK FOR ANOTHER 3-4-Bbls, THEN RETURNS CLEAN UP. DECOMP MONTIOR WELL -WELL STATIC. --PUMP DRY-JOB. --BLOW DOWN TOP DRIVE. DECOMP PULL OUT OF HOLE. --POH FROM 4752' TO 212' STANDING BACK DRILL PIPE IN DERRICK. Printed: 4/5/2010 10:59:10 AM • BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To .Hours Task Code NPT Phase Description of Operations 3/11/2010 17:30 - 19:00 1.50 CLEAN P DECOMP STAND BACK DRILL COLLARS IN DERRICK. --LAY DOWN SCRAPER BHA. --EMPTY BOOT BASKETS, RECOVERED 1 SMALL PIECE OF BROKEN CANNON CLAMP AND 1 PIN FROM CANNON CLAMP. 19:00 - 20:30 1.50 CLEAN P DECOMP PJSM FOR PICKING UP E-LINE TOOLS. SWS, CREW, WSL AND PDS HANDS DISCUSS THE HAZARDS OF RIGGING UP E-LINE. --MOBILIZE E-LINE AND PDS TOOLS TO RIG FLOOR. --TOOL STRING CONSISTS OF: ROLLER, 2 KNUCKLES, ADAPTER, ROLLER BAR, GAMMA RAY, COLLAR LOCATOR, PDS TOOLS CONSISTING OF WLSA, WL, WLKJ, UW_UMT, PKJ, PRC_4, UW_MTT, PRC_4 UW_BP. --PDS TOOL LENGTH = 28.37', OVERALL TOOL LENGTH = 58.37' 20:30 - 00:00 3.50 EVAL P DECOMP RIH WITH E-LINE. -RIH TO 4756' E-LINE MEASUREMENT AND LIGHTLY ~ G~~ ~; TOP OF TUBING STUB. ~ -BEGIN LOGGING UP WITH FINGER CALIPER AND MTT ~~ ~m~ TOOLS. 3/12/2010 00:00 - 01:00 1.00 EVAL P DECOMP CONTINUE TO LOG OUT OF WELL WITH FINGER CALIPER TOOL AND MTT. -0100-Hrs, ON SURFACE WITH FINGER CALIPER TOOL AND MTT TOOLS. 01:00 - 02:00 1.00 EVAL P DECOMP RD TOOLS -RU USIT LOG TOOLS 02:00 - 07:30 5.50 EVAL P DECOMP RIH WITH USIT LOG TOOLS TO 4150'. -HI-RES - LOG OUT TO 2670'. -RIH TO TOP OF STUB AND LOG OUT. SPINNER MOTOR PROBLEM IN USIT TOOL; REVERSE ROTATION AND START LOGGING AT 4725'. 07:30 - 08:30 1.00 EVAL P DECOMP R/D SCHLUMBERGER AND FIND TWO SMALL CHUNKS (1" X 3") OF CANNON CLAMP AND A CANNON CLAMP PIN IN THE CENTRALIZER FINGERS OF THE USIT TOOL. --0745-hrs, CONTINUE R/D SCHLUMBERGER. 08:30 - 12:30 4.00 WHSUR P DECOMP PULL WEAR RING. HOLD PJSM TO CHANGE OUT THE 7-5/8" PACKOFF. FMC TECH M/U PACKOFF RUN/PULL TOOL AND INSTRUCT CREW TO RIH AND PULL PACKOFF. BOLDS. PULL PACKOFF FREE WITH 23K-Ibs; BRING TO RIG FLOOR AND BREAK OFF PACKOFF. P/U NSW PACKOFF AND RIH• R O IR OK-Ihs W HT TO LL. RILDS. --1030-hrs, TEST PACKOFF TO 5000-psi, BUT BLEEDS TO 3500-psi. BLEED OFF ALL PRESSURE. E-MAIL THE USIT LOG TO ADW RWO ENGINEER. --1130-hrs, PULL PACKOFF TO INSPECT. CLEAN UP PACKOFF, FIND NO DAMAGE. CLEAN THE HANGER AND MANDREL WITH WATER LINE AND RIG VACUUM LINE. --1145-hrs, ADW RWO ENGINEER CALLS WITH THE DECISION TO CONTINUE THE RWO AS PLANNED. --1200-hrs, RE-RUN PACKOFF. SET DOWN 20K-Ibs. RILDS, AND TEST TO 5000-psi. TEST HELD SOLID 12:30 - 13:00 0.50 WHSUR P DECOMP P/U AND INSTALL 9-1/8" ID WEAR RING. Printed: 4/5/2010 10:59:10 AM BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Event Name: WORKOVER Start: 3/2/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Spud Date: 7/21/2003 End: 4/30/2010 Date From. - To Hours Task Code NPT Phase Description of Operations 3/12/2010 13:00 - 16:30 3.50 CLEAN P DECOMP PJSM. M/U PACKER MILLING BHA: PACKER MILL W/ 2-13/16" STINGER, 4-ea BOOT BASKETS, BIT SUB, BUMPER SUB, OIL JARS AND 9-ea 4-3/4" DRILL COLLARS. --1400-hrs, MAKE LATE DAY CREW CHANGE. --CONTINUE RIH WITH DP FROM DERRICK. 16:30 - 00:00 7.50 CLEAN P DECOMP ESTABLISH SLOW PUMP RATES: --PUMP #1 - 31 STROKES @ 110 psi. - 39 STROKES ~ 190 psi. --PUMP #2 - 30 STROKES @ 150 psi. - 41 STROKES ~ 290 psi. --ESTABLISH PARAMETERS: --S/O WT 93K, P/U WT 110K. --ROTATING WT 101K AT 80 RPM WITH 4.5 K FREE TO. --RIH AND TAG TOP OF STUB AT 4752'. BEGIN MILLING ON TBG STUB AT 4 BPM AND 310 PSI, 1-4 K WOB. ADUSTING PARAMETERS, ATTEMPTING TO DRY DRILL AND ADJUST PUMP RATES. --AT 2100-Hrs. DRILLED DOWN TO 4754'. --2230-Hrs. DRILLED DOWN TO 4755'. PUMP 20 BBL HI-VIS SWEEP SEEING MEDIUM AMOUNT OF METAL IN RETURNS. --0000-Hrs. AT 4755' HAVING DRILLED OFF 3' OF 4.9' OF TUBING STUB PRIOR TO DRILLING ON PACKER. 3/13/2010 00:00 - 08:00 8.00 CLEAN P DECOMP CONTINUE MILLING ON TBG STUB AT 4755'. PUMP RATE OF 4.5 BPM AND 360 PSI. ROTATING AT 110 RPM WITH 7-8K TO, 10-15K WOB. --0100-Hrs. DEPTH OF 4756'. MILLING ON PACKER. _ . --0200-Hrs. DEPTH OF 4757'. PUMP 20 BBL HI-VIS SWEEP SEEING SMALL AMOUNT OF METAL IN RETURNS. --0300-Hrs. DEPTH OF 4758'. --0500-Hrs. DEPTH OF 4759'. --0640-Hrs, LOSE RETURNS. P/U TO GET DYNAMIC LOSS RATE OF 315-BPH AT 8-1/2-BPM AND 1060-psi, WITH RETURNS AT SURFACE. SLOW PUMP RATE TO 6-1/2-BPM TO KEEP HOLE FULL. WILL USE 40-BPH CONSTANT HOLE FILL. --0715-Hrs, RESUME MILLING OPERATIONS, ANDS., DROPS FREE AT 0730-Hrs. --0730-Hrs, CHASE PACKER DOWNHOLE WITH SINGLES FROM PIPE SHED. --0750-Hrs, P/U JOINT #153, CONTINUE RIH AND SOFT TAG AT 5125'. THE TAILPIPE LENGTH (43'0) PLUS PACKER LENGTH (4.04') PLUS RKB DIFFERENCE BETWEEN DOYON 16 AND DOYON 14 (8.27') PLACES THE TOP OF THE 5-1/2" ZXP LINER AT 5180' VERSUS THE AS-RUN LINER TOP AT 5182'. DECIDE TO POH RATHER THAN RISK DAMAGE TO THE LINER TOP WITH THE WLEG OF THE TAILPIPE. 08:00 - 11:00 3.00 CLEAN P DECOMP PJSM TO POH AND S/B DP IN DERRICK. WSL ASKED THE FILLIN HAND IF HE SAW ANYTHING THE CREW COULD IMPROVE UPON OR ANYTHING THAT CAUSES HIM CONCERNS ABOUT SAFETY OR EFFICIENCY. HE SAID "NO, THESE ARE GOOD GUYS TO WORK WITH." Printed: 4/5/2010 70:59:10 AM • BP EXPLORATION Page 7 of 13 Operations Summary 'Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2010 ~ 08:00 - 11:00 3.00 ~ CLEAN ~ P 11:00 - 12:00 I 1.001 CLEAN I P 12:00 - 15:30 I 3.501 CLEAN I P 15:30 - 21:00 5.501 CLEAN ~ P 21:00 - 21:30 0.50 CLEAN P 21:30 - 00:00 2.50 CLEAN P 13/14/2010 100:00 - 01:00 I 1.001 CLEAN I P DECOMP --0810-Hrs, POH AND S/B DP IN DERRICK. --0930-Hrs, STAND #40 S/B IN DERRICK. --1030-Hrs, CLEANOUT BOOT BASKETS AND GET 2-1/2-gals OF METAL SHAVINGS AND DEBRIS. B/O AND UD MILL. MILL SHOWS ESTIMATED 35% WEAR. DECOMP CLEAR AND CLEAN RIG FLOOR. MAKE CREW CHANGE. HOLD PJSM FOR M/U AND RIH WITH THE PACKER SPEAR BHA. SPEAR BHA: 2-7/8" ITCO SPEAR WITH 2.933" GRAPPLE, SPEAR EXTENSION, XO, BUMPER SUB, OIL JARS, PUMP-OUT SUB, XO, AND 9-EA 4-3/4" DRILL COLLARS. DECOMP RIH PACKER PLUCKING BHA ON DP FROM DERRICK. USE CONSTANT HOLE FILL OF 40-BPH. STOP AND FILL DP EVERY 15-STANDS AND TAKES 12-Bbls TO FILL PLACING THE FLUID LEVEL INSIDE DP AT -1110'. --1350-Hrs, STAND #35 RIH. --1415-Hrs, STAND #51. STOP AND GET PARAMETERS: P/U WT 121 K-Ibs, S/O WT 95K-Ibs, 3-BPM, 560-psi. --1430-Hrs, REDUCE PUMP RATE TO 2-BPM, 120-psi. SLOWLY RIH AND SEE PRESSURE INCREASE TO 430-psi WHILE SETTING DOWN 15K-Ib. P/U AND PRESSURE DROPS TO 120-psi. SET BACK DOWN 15K-Ibs AND PRESSURE INCREASES TO 430-psi. P/U AND PRESSURE DROPS TO 220-psi AND STAYS THERE. SET DOWN TO 18K-Ibs WEIGHT ON THE PACKER. P/U TO VERIFY AND SEE DRAG OF 2K-Ibs AND CONTINUE TO POH TO GET FULL STAND ABOVE RIG FLOOR. --1515-Hrs, BREAK OFF STAND AND DROP DART TO OPEN PUMP-OUT SUB. CHASE DART AT 3-BPM. SEE PUMP-OUT SUB OPEN WITH ABOUT 2000-psi. DECOMP PJSM. POH AND UD DP. --1715-Hrs, UD DP JOINT #45. --1800-Hrs, UD #75. --2000-Hrs, UD DP JOINT 145. --2100-Hrs, P/U SPEAR ASSY ABOVE RIG FLOOR WITH NO -- THE GRAPPLE TAPE WAS INTACT INDICATING SPEAR HAD NOT ENTERED THE FISH. THE NOSE OF THE SPEAR SHOWED WEAR, INDICATING THE SPEAR WAS ATTEMPTING TO PUSH UNDER THE SIDE OF THE FISH. THIS PLUGGED THE JET, CAUSING AN INCREASE IN PRESSURE AS IF THE SPEAR WERE IN THE FISH. DECOMP CLEAR AND CLEAN RIG FLOOR. DECOMP DISCUSS OPTIONS WITH TOWN ENGINEER AND RWO SUPERINTENDANT. -PLAN ON ADDING STABILIZER ABOVE THE SPEAR AND ABOVE THE JARS TO CENTRALIZE THE SPEAR IN THE 65 DEGREE SECTION. -LOADING DP IN THE PIPE SHED AND STRAPPING. -WAITING ON TOOLS FROM BAKER. DECOMP PICK UP BHA FOR FISHING PACKER:,2-7/8" ITCO SPEAR WITH 2.933" GRAPPLE, SPEAR EXTENSION, XO, STABILIZER, BUMPER SUB, OIL JARS, STABILIZER, Printed: ais~zotu to:SaauAm • • BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase. Description of Operations 3/14/2010 00:00 - 01:00 1.00 CLEAN P DECOMP 01:00 - 03:00 2.00 CLEAN N HMAN DECOMP 03:00 - 04:00 1.00 CLEAN P DECOMP 04:00 - 10:30 6.50 CLEAN P DECOMP 10:30 - 12:00 1.50 FISH P DECOMP PUMP-OUT SUB, XO, AND 6-EA 4-3/4" DRILL COLLARS. -MAINTAIN 40 BPH CONSTANT HOLE FILL. WHILE REMOVING LIFT SUB FROM DRILL COLLARS, THE DRILLER WENT INTO THE DOG HOUSE TO GET A CUP OF COFFEE. A FLOOR HAND WENT TO THE DRILLING CONSOLE TO MOVE THE BAILS OUT OF THE WAY IN ORDER TO REMOVE THE LIFT SUB. HE HIT THE LINK TILT AND THE LINK TILT WENT TOO FAR AND TWISTED THE DRILLER'S-SIDE BAIL AND GOT IT INTO A BIND. THE DRILLER IMMEDIATELY SHUT DOWN THE OPERATION AND NOTIFIED THE WSL AND TOOLPUSHER. ALL HANDS WERE GATHERED INTO THE DOG HOUSE TO DISCUSS THE INCIDENT. THE DRILLER MENTIONED THAT NO ONE WAS TO TOUCH ANY CONTROL UNLESS AUTHORIZED TO DO SO. HE HANDLED THE SITUATION PROFESSIONALLY AND THEN THEY WENT INTO A HAZARD ASSESSMENT ON HOW TO CORRECT THE PROBLEM. THEYFREED THE BAIL WITHOUT INCIDENT. THEY THEN PERFORMED A TOP DRIVE INSPECTION TO MAKE SURE NOTHING ELSE WAS DAMAGED. DAYLIGHT SAVINGS TIME. -MOVE CLOCKS 1 HOUR AHEAD. RIH PICKING UP DRILL PIPE. --0700-Hrs, JOINT #81 RIH. --0700-0730-Hrs, WSL ATTENDED WEEKLY HOUSEKEEPING STAFF SAFETY MEETING. THE LEAD COOK DISCUSSED THE NEW WRITTEN PROCEDURE SHE DEVELOPED FOR MEAL PREPARATION AND THE OPERATION AND SAFE-KEEPING OF THE KITCHEN EQUIPMENT DURING A RIG MOVE. --0800-Hrs, JOINT #105 RIH. --1015-Hrs, P/U FIRST OF TWO STANDS OF DP M/U PREVIOUSLY AND S/B IN DERRICK FOR THE FISHING OPERATION. 1030-Hrs, P/U THE 2ND OF TWO STANDS OF DP THAT HAD BEEN M/U AND S/B IN THE DERRICK EARLIER. GET SLOW PUMP PARAMETERS: #1--3-BPM AT 420-psi, 4-BPM AT 1220-psi; #2--2.6-BPM AT 680-psi, 4.0-BPM AT 1130-psi. P/U WEIGHT WITH NO PUMP IS 125K-Ibs AND S/O WEIGHT IS 93K-Ibs. 1040-Hrs, RIH WITH PUMP RATE AT 3.9-BPM AT 1220-psi. MAKE 6 ATTEMPTS TO SLOWLY LOWER THEN P/U TO WASH ANY DEBRIS AWAY FROM THE TOP OF THE PACKER. INCREASE RATE TO 4.1-BPM AT 1620-psi. STACK OUT WITH 8K-Ibs WITH NOSE ONLY A FEW (ESTIMATED) INCHES INTO THE PACKER AND SEE PRESSURE INCREASE TO 1950-psi. INCREASE WEIGHT TO 10K-Ibs AND HOLD BRAKE, WATCHING THE WEIGHT SLOWLY FALL. DECREASE PUMP RATE TO 1.9-BPM, 1300-psi AND CONTINUE PUTTING 10K-Ibs ON FISH AND THE STRING DROPS DOWN TO THE NO-GO; DECREASE PUMP RATE TO 1-BPM, 1280-psi. --1110-Hrs, P/U AND SEE WEIGHT INCREASE TO 128K-Ibs. Printed: 4/5/2010 10:59:10 AM • BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date .From - To Hours Task Code NPT Phase Description of Operations 13/14/2010 110:30 - 12:00 I 1.501 FISH I P 12:00 - 18:00 I 6.001 FISH I P 18:00 - 20:00 I 2.001 FISH I P 20:00 - 00:00 I 4.00 3/15/2010 100:00 - 01:00 I 1.001 RUN 01:00 - 01:30 I 0.501 RU DECOMP START PUMP AND BRING UP TO 2.5-BPM AT 800-psi. P/U TO 130K-Ibs AND IT APPEARS THAT WE HAVE A FISH. CONTINUE TO P/U AND PULL TO 160K-Ibs AND JARS GO OFF. SET BACK DOWN TO VERIFY AND SEE THE FISH STACK OUT THEN SLIDE THROUGH THE TITE SPOT. --1130-Hrs, P/U AND SEE THE TITE SPOT, BUT PULL THROUGH WITH 160-170K-Ibs. --1140-psi, BLOW DOWN THE KILL LINE AND PREPARE TO POH AND UD DP. DECOMP BREAK OFF FIRST JOINT AND DROP PUMP-OUT SUB DART, CHASING AT 3-BPM. DROP BACK TO 1-1/2-BPM AFTER 85-Bbls PUMPED AND ONLY140-Bbls REMAINING IN PITS. CALL TO CHECK ON ROUND-TRIPPING TRUCK STATUS, AND NORDIC 2 RIG IS BETWEEN DOYON 16 AND THE TRUCK. CALL NABOBS 4ES AND WSL RELEASES A TRUCK-LOAD OF SEAWATER WHICH ARRIVES 15-MINUTES LATER. --DECIDE TO POH UNTIL WE FIND WET STRING, THEN M/U TO TOP-DRIVE AND OPEN THE PUMP-OUT SUB. --1400-Hrs, DP STARTED COMING WET; STOP AND MAKE UP TO TOPDRIVE AND PUMP DART ONTO PUMP-OUT SUB SEAT TO OPEN WITH 2-Bbls, OPENING THE PORTS AT 1980-psi. --1545-Hrs, ONE TRUCKLOAD OF 120E SEAWATER AND ONE TRUCK WITH AMBIENT TEMP SEAWATER ARRIVE. --1605-Hrs, JOINT #125 UD. --1615-Hrs, RELEASE THE AMBIENT TEMP LOAD TO GO TO NABOBS 4ES. SEAWATER ONSITE: 280-Bbls IN PITS AND 290-Bbl LOAD ON VAC TRUCK. DECOMP LD/ DRILL COLLARS. -BACK OUT AND UD SPEAR. -PJSM FOR PUNCHING AND UD FISH. -UD PACKER ASSY. AT 14.93' IN LENGTH._ -UD TAIL PIPE ASSY WITH WLEG AND XN NIPPLE. PUNCHING ALL JOINTS ABOVE XN NIPPLE - 37.28'. -CUT 6" SECTION OF 3.5" TUBING 6" ABOVE THE XN NIPPLE TO SUBMIT FOR CORROSION TESTING, DUMP ALL DEBRIS FROM ON TOP OF XXN PLUG FOR CORROSION TESTING. RUNCMP PJSM FOR P/U TUBING RUNNING EQUIPMENT. -PULL WEAR RING. -P/U SPOOLING UNIT FOR I-WIRE. -P/U TONGS AND TOOLS. -INSPECT SIZE OF ELEVATORS FOR RUNNING 4-1/2" TUBING. -CONTINUOUS HOLE FILL OF -40 BPH. RUNCMP CONTINUE TO RIG UP EQUIPMENT TO RUN TUBING. -RU SPOOLER AND SHEAVE. RUNCMP PJSM FOR RUNNING TUBING. -DISCUSSION WITH CREW, WSL, BAKER, WEATHERFORD ON HAZARDS OF RUNNING THE COMPLETION AND THE ASSOCIATED HAZARDS CREATED BY THE I-WIRE SPOOL. THE HANDS DISCUSSED THE DROPPED OBJECTS Printed: 4/5/2010 10:59:10 AM • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase 3/15/2010 01:00 - 01:30 0.50 BUNCO P RUNCMP 01:30 - 03:00 1.501 RUNCONIP RUNCMP 03:00 - 04:30 1.501 RUNCON7P RUNCMP 04:30 - 09:30 I 5.00 ~ RUNCOf~1P ~ ~ RUNCMP Description of Operations PROGRAM, INSPECTING EQUIPMENT SUCH AS ELEVATORS PRIOR TO USE. THE WEATHERFORD HANDS DISCUSSED THEIR PROGRAM OF RUNNING THE I-WIRE AND THE TESTING THAT THEY WOULD HAVE TO PERFORM. BAKER HAND DISCUSSED THE ASSOCIATED RISK AND RUNNING SPEED OF HIS EQUIPMENT. ALL MEMBERS BROUGHT AN ISSUE TO THE PREJOB THAT WAS DISCUSSED AND THE HAZARDS WHERE MITIGATED. WSL INSTRUCTED THAT THE DRILLER WAS NOT TO ANSWER THE RADIO FOR SPOC DUTIES WHILE RUNNING IN HOLE WITH I-WIRE, AND TO ENSURE HIS FOCUS STAYED ON THE HAZARDS OF WORKING IN TANDEM WITH THE WEATHERFORD HANDS. RUN IN HOLE WITH 4-1/2" 12.6# 13Cr-80 VAM TOP TUBING. -RIH WITH WLEG AND XN NIPPLE. -RIH WITH PACKER. -RIH WITH SNORKEL SUB, SLIDING SLEEVE, AND GAUGE MANDREL. WEATHERFORD HANDS RU ON SNORKEL SUB AND RUN STAINLESS STEEL LINES TO GAUGE MANDREL. -THESE LINES WHERE TESTED. -ADD 2 STAINLESS STEEL BANDS AROUND STAINLESS STEEL LINES COUPLINGS WITH NOTCHES CUT OUT FOR LINES TO KEEP STAINLESS LINE IN NOTCH AREA OF COLLAR. RUN IN HOLE WITH 4-1/2", 12.6#, 13Cr-80, VAM TOP TUBING. --0430 Hrs.- RIH WITH JOINT #1. --0700-Hrs, #25 RIH. CHECK I-WIRE EVERY 10-JOINTS AND IT IS STILL COMMUNICATING TO SURFACE. --0745-Hrs, #29 RIH. WEATHERFORD CHECKING I-WIRE AND THE PRESSURE FUNCTION OF THE INLET OR FORMATION PRESSURE GAGE IS RELAYING 12.6-psia. CONTINUE TROUBLESHOOTING. WEATHERFORD CALLED MAIN OFFICE IN TEXAS AND THEY SAID THAT THERE MAY BE AIR TRAPPED IN THE CAPILLARY TUBE CONNECTING ONE OF THE GAGES TO THE SNORKEL SUB. WSL CONFER WITH ADW RWO ENGINEERING TEAM TO DETERMINE COURSE OF ACTION. --0830-Hrs, THE TENTATIVE PLAN IS TO PUMP DOWN THE TUBING TO CHECK FOR PRESSURE INCREASES IN THE GAGES. BAKER COMPLETIONS WANTS PRESSURE LIMITED TO 500-psi. --0900-Hrs, PUMP DOWN THE TUBING 3-BPM, 30 psi. SEE PRESSURE IN THE GAGE SENSING PRESSURE ABOVE THE SLIDING SLEEVE (PUMP DISCHARGE) INCREASE FROM 211-psia TO 340-psia, WHEREAS THE GAGE SENSING PRESSURE FROM BELOW THE PUMP DID NOT CHANGE FROM FLUTTERING AROUND 12.5-psia. --0915-Hrs, CALL ADW RWO ENGINEERING AND GET APPROVAL TO POH TO CHECK THE CAPILLARY TUBING AND CONNECTIONS. ALSO WILL TRY TO PUMP THROUGH Printed: 4/5/2010 10:59:10 AM • BP EXPLORATION Operations-Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Event Name: WORKOVER Start: 3/2/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours I Task Code NPT Phase 3/15/2010 04:30 - 09:30 5.00 BUNCO RUNCMP 09:30 - 12:00- 2.50 BUNCO RUNCMP 12:00 - 14:00 2.00 BUNCO DFAL RUNCMP 14:00 - 00:00 10.00 BUNCO RUNCMP Page 11 _of 13 Spud Date: 7/21/2003 End: 4/30/2010 Description of Operations THE CAPILLARY TUBING TO CHECK FOR OBSTRUCTIONS. --0930-Hrs, SLOWDOWN THE KILL LINE AND PREPARE TO POH. HOLD PJSM WITH WEATHERFORD TECHNICIANS, BP TRAINEE, BAKER COMPLETIONS TECH, DOYON CASING TECH, RIG CREW, CH2MHILL TRUCK PUSHER, AND WSL. COVER REASON FOR AND THE NEW STEPS FOR THE CHANGE IN DIRECTION OF THE PROGRAM. ALSO COVER DROPPED OBJECTS, THE REDUCED SPEED NECESSARY FOR THE POWER TONGS, AND THE CARE NEEDED IN LAYING DOWN THE TUBING USING THREAD PROTECTORS AND SINGLE JOINT ELEVATORS. --1200-Hrs, SNORKEL SUB AND GAGE MANDREL ASSEMBLY AT RIG FLOOR. USE HOT WATER TO TEST THE TEMPERATURE GAGE FEATURE OF BOTH GAGES WITH IDENTICAL RESULTS. WEATHERFORD TECHS REMOVE THE CAPILLARY TUBE FROM THE fNLET SENSOR PORT AND THE CORRESPONDING GAGE. WEATHERFORD TECHS ATTEMPT TO PUMP HYDRAULIC FLUID THROUGH THE TUBE WITH NO SUCCESS. HOOK UP AIRLINE AND AIR STARTS TO PASS THROUGH THE LINE. H/U THE ENERPAC PUMP AND PUMP HYDRAULIC FLUID THROUGH THE LINE UNTIL IT FLOWS FREELY WITH NO BACK PRESSURE AND A STRONG, STEADY FLOW, CLEANING OUT WHATEVER MAY HAVE BEEN INSIDE THE TUBING. --1330-Hrs, WEATHERFORD REASSEMBLES CAPILLARY TUBING TO THE SENSOR PORT AND THE GAGE. --WEATHERFORD TECH EXPLAINED POSSIBLE REASON FOR BLOCKAGE IN CAPILLARY TBG. TBG WAS CUT AND PURGED IN HOUSTON, TX. THEN ROLLED UP AND SHIPPED TO THE SLOPE. IT WAS NOT REPURGED PRIOR TO ASSY. AND RIH. PJSM. RIH WITH 4-1/2", 12.6#, 13Cr80, VAM TOP TUBING. TORQUE TURN ALL CONNECTIONS TO 4,440-ft-Ibs USING JET LOBE SEAL GUARD. --1500-Hrs, 5-JOINTS RIH. MAKE CHECK OF THE I-WIRE COMMUNICATION AND THE READINGS SHOW GOOD COMMUNICATION. --1530-Hrs, #15 RIH. COMMS CHECK--EXCELLENT COMMUNICATION. --1615-Hrs, #25 RIH. PRESSURE CHECK: PUMP DISCHARGE LOCATION 144.7-psi, INTAKE LOCATION 145.3-PSI, AND THE TEMPERATURES ARE 70-F AND 71-F, RESPECTIVELY. --1645-Hrs, #35 RIH. DISCHARGE PRESSURE AND TEMPERATURE, 307.8-psi / 65-F; INTAKE PRES /TEMP, 307.6-psi / 65-F. --1730-Hrs, #45 RIH. DISCHARGE P / T, 470.6-psi / 61-F; INTAKE P / T, 469.8-psi / 61-F. --1820-Hrs, #55 RIH. DIS P/T, 617.94-psi / 61-F; INT P/T, 618.26-psi / 61-F. F'flflt8tl: 4/S/"LUIU lU:S9aU HM • • BP EXPLORATION Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Event Name: WORKOVER Start: 3/2/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date I From - To I Hours I Task I Code I NPT I Phase 3/15/2010 114:00 - 00:00 I 10.001 RUN 3/16/2010 00:00 - 01:00 ~ 1.00 ~ RU 01:00 - 01:30 0.501 RU 01:30 - 03:30 I 2.001 RU 03:30 - 04:00 I 0.501 RU 04:00 - 08:30 I 4.501 RUN INCREASE PRESSURE WITH TEST PUMP TO 4500 PSI. --PRESSURE DROPPED 150 PSI IN 15 MIN. BLEED TBG OFF AND PRESSURE BACK UP TO 4500 PSI ONCE AGAIN CONTINOUS FOR 20 MINUTES DROPPING 100 PSI WITH NO SIGN OF GOING FLAT. BLEED AIR OFF OF TBG AND PRESSURE BACK UP. STILL PRESSURE WAS DROPPING. BLEED OFF AND BACK OUT LANDING JOINT. REDOPE AND RETOROUE LANDING JOINT. PRESSURE BACK UP Page 12 of 13 ~ Spud Date: 7/21/2003 End: 4/30/2010 Description of Operations RUNCMP --1855-Hrs, #65 RIH. DIS P/T, 734.65-psi / 60-F; INT P/T, 735.46-psi / 60-F. --1930-Hrs, #75 RIH. DIS P/T, 870.06-psi / 59-F; INT P/T, 870.87-psi / 59-F. --2010-Hrs, #85 RIH. DIS P/T, 1010.22-psi / 58-F; INT PlT, 1010.70-psi / 58-F. --2045-Hrs, #95 RIH. DIS P/T, 1152.34-psi / 59-F; INT PlT, 1152.75-psi / 59-F. --2120-Hrs, #105 RIH. DIS P/T,1286.84-psi / 59-F; INT P/T, 1287.44-psi / 59-F. --2205-Hrs, #118 RIH. DIS P/T, 1394.58-psi / 61-F; INT P/T,1395.21-psi/61-F. --MAKE UP HANGER AND LANDING JOINT. --CONTINUOUS HOLE FILL OF ~ 40 BPH. RUNCMP CONTINUE TO TERMINATE I-WIRE. --STRIP I-WIRE AND RUN THROUGH STAINLESS STEEL TUBING. --RUN STAINLESS STEEL TUBING THROUGH HANGER AND TEST I-WIRE. --TEST SWEDGE TO 5000K ON HANGER FOR 5 MIN.-GOOD TEST. RUNCMP LAND TUBING HANGER, _ --DRAIN STACK AND LAND TUBING HANGER 22' IN. --RILDS. --UP WT IS 98K, DOWN WT IS 82K. --118 CLAMPS USED AND 4 STAINLESS STEEL BANDS USED ON I-WIRE. RUNCMP PJSM FOR REVERSE CIRCULATING IN CORROSION INHIBITOR. --RU TO CIRCULATE DOWN THE ANNULIST AND UP THE TUBING. --PRESSURE TEST LINES TO 3500 PSI. -GOOD TEST. --REVERSE CIRCULATE 100 BBLS OF 120 DEGREE SEAWATER AT 3 BPM 0-psi, NO RETURNS. --REVERSE CIRCULATE 130 BBLS OF 120 DEGREE SEAWATER AND CORROSION INHIBITOR AT 3 BPM 0-psi AND NO RETURNS. RUNCMP TEST I-WIRE FOR ONE LAST TIME PRIOR TO DROPPING BALL AND ROD. --1425.89-psi AT 64 DEGREE, 1426.32-psi AT 64 DEGREE. --BREAK OF 1502 AND HOSE. --DROP BALL AND ROD. --HOOK 1502 BACK UP AND HOSE. RUNCMP FILL TUBING WITH 10 BBLS. Printed: 4/5/2010 10:59:10 AM ,~ i • BP EXPLORATION Page 13 of 13 Operations Summary-Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: WORKOVER Start: 3/2/2010 End: 4/30/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 3/16/2010 104:00 - 08:30 I 4.501 RUN 08:30 - 10:00 I 1.501 BOPSUR P 10:00 - 14:30 ~ 4.50 ~ BOPSUf~ P 14:30-21:00 ~ 6.50~WHSURIP 21:00-21:30 0.501 WHSURIP 21:30 - 00:00 I 2.501 WHSUR I P 3/17/2010 100:00 - 03:30 I 3.501 WHSUR I P 03:30 - 04:30 I 1.001 WHSUR I P 04:30 - 06:00 I 1.501 WHSUR I P RUNCMP TO 4500 PSI. HOLD AND CHART FOR 30 MIN. -GOOD TEST. BLEED TUBING DOWN TO 2500 PSI. PRESSURE UP IA TO 4200 PSI AND CHART FOR 30 MIN. -GOOD TEST. --BLEED PRESSURE DOWN ON TUBING AND DCK SHEARED AT 1500 PSI. --CIRCULATED IN BOTH DIRECTIONS AT 3 BPM AND 600 PSI. WHDTRE BLOW DOWN LINES AND DRAIN ROPE STACK. --SET TWC. --TEST TWC FROM ABOVE TO 3500 PSI FOR 10 MIN. - GOOD TEST. --TEST TWC FROM BELOW TO 1000 PSI FOR 10 MIN. -GOOD TEST. WHDTRE PJSM FOR ND ROPE STACK. --BLOW DOWN LINES AND DRAIN STACK. --REMOVE TURNBUCKLES AND RISER. --CHANGE OUT BLIND RAMS. --ND BOPE STACK. --STAND BACK BOPE STACK. --CHANGE OUT SAVER SUB TO 4-1/2" IF. WHDTRE ND ADAPTER FLANGE. --PREP WELL HEAD AND I-WIRE, INSTALL SBS SEAL. --NU ADAPTER FLANGE. --TEST I-WIRE. -GOOD TEST. --TEST ADAPTER FLANGE TO 5000 PSI FOR 30 MIN. - GOOD TEST. --NU TREE AND TEST TO 5000 PSI. -GOOD TEST. WHDTRE RU DSM LUBRICATOR AND TEST TO 500 PSI. -GOOD TEST. --P L TWC AND LD LUBRICATOR ON RIG FLOOR. WHDTRE PJSM WITH LITTLE RED AND RIG CREWS. --RU LINES TO LRS. --PRESSURE TEST LINES TO 3500 PSI. -GOOD TEST. --LINE UP AND LRS REVERSED IN 80 BBLS OF 80 DEGREE DIESEL FREEZE PROTECT AT 2 BPM AND 600 PSI. WHDTRE ALLOW WELL TO U-TUBE. -1 HOUR INTO U-TUBE, 80 PSI ON GAUGE. -2 HOURS INTO U-TUBE, 40 PSI ON GAUGE. -3 HOURS INTO U-TUBE, 20 PSI ON GAUGE. -3.5 HOURS INTO U-TUBE, 20 PSI ON GAUGE. IA WAS OPEN AND PRESSURE BLEED IMMEDIATLY DOWN AND NO DIESEL WAS LOST. -BLOW DOWN LINES. WHDTRE RU DSM LUBRICATOR AND TEST TO 500 PSI. -GOOD TEST. -LD LUBRICATOR. -TEST BPV TO 1000 PSI. GOOD TEST. WHDTRE RIG DOWN ALL EQUIPMENT AND SECURE TREE. **************RIG RELEASED AT 0600 HRS******************* Printed: 4/5/2010 10:59:10 AM Tree: 4-1/16" - 5M FMC Wellhead: 11" x 4.5" 5M Gen 6 w/ 4.5" TCII T&B Tubing Hanger CIW "H" BPV profile 20" x 34" insulated, 215 #/ft A-53 112` 2.65` Blast rings below tubing hanger 10 3/4" 45.5 #/ft L-80 BTC 2776` 7 5/8" 29.7# L-80 BTC-M casing ( drift ID = 6.75", cap = .02s2 BPF w/ tbg. ) 4.5" 12.6# 13Cr-80 TCII tubing ( ID = 3.958", cap = .0152 BPF ) Reverse Circulation" Jet Pump Configuratir Baker Tie Back Sleeve 5182` Baker ZXP Liner Top Packer 5189' Baker 7 5/8" x 5 1/2" HMC Liner Hanger 5196` Orig. KB~ = 72.45' (Doyon 14) Orig. GL. .= 38.60' (Doyon 14) KOP @ 600' Hole angle passes 50 degrees @ 2500' Max angle in tubing = 47 degree 66 degrees at sliding sleeve (3843' TVD) P 4.5" Weatherford Gauge Mandrel 4,657` 4.5" HES "XD" Dura sliding sleeve 4,667` 3.813" ID (Opens down ) Snorkel Sub -Weatherford 4.5" 4,679` 7 5/8" x 4.5" Baker Premier Pkr. (3.870" ID) 4,706' 4.5" HES XN-Nipple (3.725" No Go) 4,742' (3.813" pkg. bore) 4.5" WLEG 4,754` 7 5/8" HES Float Collar 5198` l` - s 1/s" Hole td @ 10,009' 7 5/8" HES Float Shoe 5284' N Lateral 701ts 4", 9.5 #/ft. Screened Liner & Blanks 866' of L-80 IBT (5293' - 9059') rat hole Btm. Baker 4 1/2" Guide Shoe 9143' DATE REV. BY COMMENTS MILNE POINTppUNIT 8/04/03 MDO Drilled and completed by Doyon 14 WELL S-~(7 11/15/08 Hulme Tbg patch set with EL. API NO: 50-029-23168-00 MPS-08 0 Camco 4.5" x 1" w/ BK latch 2024' side ocket KBG-2 GLM BP EXPLORATION (AKA ~ \ Reservoir Fluid / ~~~'~~~~~~~~ N0. 5310 ~~ h, e~~ r r r; ~ t-,r;r~t~ ~laska Data & Gonsulting Services ~/ aa $~y~; ~~~~. . % t u a~.- Company: State of Alaska 2525 Gambell Street, Suite 400 "`~` ~~~ "~ Alaska Oil & Gas Cons Comm Anchorage, AV( 99503-2838 Attn: Christine Mahnken ~sTrN: Beth 333 West 7th Ave, Suite~ 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 07/14/09 Z-20 P2-31 AP3~-00043 AZCM-00029 SBHP SURVEY - LDL L~ ~ 06/17/09 06/17/09 1 1 1 1 12-03 AY1M-00022 SBHP SURVEY O6/15/09 1 1 ~-1481 AYQQ-00036 TEMP SURVEY & BHP - 06/23/09 1 ~ N-46 AP3Q-00042 SBHP SURVEY ` ~ ~ 06/16/09 1 ' V-QS,. ,.. 11999053 USIT 10/12/08 1 1 .,~" N-11C AP3Q-00042 SBHP SURVEY O6/16/09 1 ~ `'- T3-12 AY3J-00030 LDL _ O6/12/09 1 1 L1-30 AVY5-00049 PRODUCTION PROFILE Lla ..- (~ 06/22l09 1 1 17-07~ AYQQ-00031 SBHP SURVEY "y / '3C5 06l11/09 1 1 OS-25B AP3Q-00040 SBHP SURVEY ~ 06/11/09 1 1 ~-27A AXBD-00028 MEM INJ PROFILE 06/1?J09 1 1 11-36 614B-00066 CROSSFLOW & IBP ~ 06/23/09 1 1 Z°21e~ B14B-00065 SBHP SURVEY ' O6/21/09 1 1 ~-7~ AYTU-00043 PROD PROFILE -~ 06/08/09 1 1 ~-25 AWLB-00018 LDL V~~ ~°~- 05/28/09 1 1 02-3318 AYTU-00033 USIT ` ~ OS/19l09 1 1 P2-07 AVYS-00051 PRODUCTION PROFILE ~~ ~ 06/25/09 1 1 13-03 AWLB-00020 LDL e 06/01/09 1 1 3-i7FlK30 B2NJ-00008 MEM INJ PROFILE 06/15l09 1 1 MPS-O8 AYS4-00080 LDL O6/15/09 1 1 13-12 AViH-00019 LDL ~ 07/05/09 1 1 01-25 AYTU-00046 USIT - ~~ 06/28/09 1 1 W-39,4 AWLB-00023 STATIC TEMP SURVEY ~ ~ O6/26/09 1 1 ~-35 AYTO-00022 SBHP SURVEY ~ 06/29l09 1 1 Z-16 AV1H-00017 SBHPSURVEY f (} 06/29/09 1 1 18-20 B581-00004 LDL ~ 06/27/09 1 1 Z-29 AVY5-00053 SBMP SURVEY ~'~ ~~ ~,)P~~~ ~'~ ~ 07/03/09 1 1 L5-09 AYQQ-00032 , RST ~ I~- ~ O6/13/09 1 1 07-10A oi eneo nrv~in~ui GIl!_C ~G 61JJ-00022 /~CIAT ., MCNL - bI ~ 05/26/09 1 -------- - -. _._....._...._..~..,.............~....~~ ~....~~ ~v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. y Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • ~ y • . 04/06/09 S~hlumbe~g~r NO. 5162 Alaska Data & Consulting Services Company• State o1 Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ g ~ ~^ '; ~ t -t,s~, `ate ~~° ~i•. ~~ ~U~ ~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i \Ncli I..w u MPS-08 AY3J-00018 -- -- LDL 03/23/09 uV VVIVI VV 1 04-22A B1JJ-00003 MEM L L 03/24/09 1 1 15-15C BOOR-00004 MEM PROD & INJ PROFILE _ ~ ~- ' 1 03/15/09 1 1 4-04lT-26 AP3O-00028 _ USIT 03/21/09 1 1 P-06B AY3J-00016 INJECTION PROFILE 03/30/09 1 1 E-05A BiJJ-00003 CH EDIT PDC-GR (JEWELRY LOG) / 9 _ 02/08/09 1 06-14A BOOR-00004 CH EDIT PDC-GR (JEWELRY LOG) - '-~- 02/21/09 1 F-33A 40018553 OH MWD/LWD EDIT _ a(o 01/25/09 2 1 F-33A PBi 40018553 OH MWD/LWD EDIT _ f j ~ 01/14/09 2 1 v~ r+v ....v •.~w~a~ .mow c.r. u. J~V11~119q MIYV nGi VIl1Yi1YV! VIYC liVr'T CNI.A 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Str et, Suite 400 Anchorage, AK -2838 ATTN: Beth -~~ Received by: i APR 0 1 2~ ~~~ STATE OF ALASKA ~~'09 ALAS~OIL AND GAS CONSERVATION COMMON Alaska Oil ~- Gas Cons. Con+ia~•~---~~ REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Abandon ~ Repair Well ~_ Plug Perforations ~ Stimulated Other ~ TUBING PATCH Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ 4.5# BAKER "KB" Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' - Exploratory ~~~ 203-1230 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-23168-00-00 7. KB Elevation (ft): 9. Well Name and Number: 72.46 KB - MPS-08 - 8. Property Designation: 10. Field/Pool(s): ADLO-380110 MILNE POINT Field/ SCHRADER BLFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 10009 " feet Plugs (measured) None true vertical 4077.46 - feet Junk (measured) None Effective Depth measured 10009 ~ feet true vertical 4077.46 feet Casing Length Size MD TVD Burst Collapse Conductor 112 20" 215# A-53 Surface - 112 Surface - 112 Surface 2776 10-3/4" 45.5# L-80 35 - 2776 35 - 2438 5210 2480 Production 5284 7-5/8" 29.7# L-80 32 - 5284 32 - 4000 6890 4790 Liner 3961 4-1/2"X4" 12.6# 9.5# 5182 - 9143 3980, - , Q6 d t? L ~~~~ '~ E o f.: a~•~ ' Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-112" 12.6# L-80 SURFACE - 4753' 3-1/2" 9.2# L-80 4573' - 4818' 4-1 /2" BAKER SINGLE PATCH 2692' - 2712' Packers and SSSV (type and measured depth) 4-1/2" BAKER "KB" PATCH 2692' 4-1/2" BAKER "KB" PATCH 2712' 7-5/8"X4-1/2" BAKER PREMIER PKR 4765' 0 0 12. Stimulation or cement squeeze summary: ~ ` `~,~ ~ i ~ Intervals treated (measured): ` ~ ~~ ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 24 12 0 141 Subsequent to operation: 115 13 0 235 14. Attachments: 15. Well Class. after proposed work: Copies of Logs and Surveys Run Exploratory Development ' ' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ ~ WINJ WDSPL 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 3/31/2009 MPS-08 203-123 PERF ATTACHMENT • Sw Name O ration Date Pert O ration Code Meas De th To Meas De h Base Tvd De th To Tvd De th Base MPS-08 8/1/03 OH 9,143. 10,009. 4,008.08 4,077.46 MPS-08 8/1/03 SL 8,108. 8,144. 4,000.42 4,000.81 MPS-08 8/1/03 SL 8,045. 8,082. 3,989.15 4,000. MPS-08 8/1/03 SL 7,982. 8,020. 3,997.7 3,998.55 MPS-08 8/1/03 SL 8,169. 8,206. 4,000.37 3,999.5 MPS-08 8/1/03 SL 7,917. 7,955. 3,886.72 3,997.21 MPS-08 8/1/03 SL 7,781. 7,829. 3,986.52 3,996.54 MPS-08 8/1/03 SL 7,727. 7,764. 3,995.69 3,996.37 MPS-08 8/1/03 SL 7,662. 7,700. 3,994.76 3,895.14 MPS-08 8/1/03 SL 7,855. 7,892. 3,896.52 3,996.54 MPS-08 8/1/03 SL 7,599. 7,637. 3,995.56 3,994.98 MPS-08 8/1/03 SL 8,233. 8,271. 3,998.72 3,998.3 MPS-08 8/1/03 SL 8,360. 8,398. 3,998.78 3,998.86 MPS-08 8/1/03 SL 8,932. 8,970. 4,005.13 4,005.34 MPS-08 8/1/03 SL 8,808. 8,845. 4,002.3 4,003.47 MPS-08 8/1/03 SL 8,745. 8,782. 4,001.08 4,001.85 MPS-08 8/1/03 SL 8,297. 8,334. 3,998.23 3,998.33 MPS-08 8/1/03 SL 8,680. 8,717. 3,899.17 4,000.31 MPS-08 8/1/03 SL 8,551. 8,588. 3,997.87 3,998.33 MPS-08 8/1/03 SL 8,487. 8,524. 3,897.5 3,997.59 MPS-08 8/1/03 SL 8,423. 8,461. 3,998.3 3,897.69 MPS-08 8/1/03 SL 8,615. 8,652. 3,998.58 3,998.76 MPS-08 8/1/03 SL 8,996. 9,033. 4,005.66 4,005.97 MPS-08 S/1/03 SL 7,534. 7,572. 3,986.43 3,995.93 MPS-08 8/1/03 SL 7,394. 7,432. 3,998.51 3,987.54 MPS-08 8/1/03 3L 5,849. 5,886. 4,021.4 4,021.72 MPS-08 8/1/03 SL 5,769. 5,807. 4,018.51 4,020.18 MPS-08 8/1/03 Sl 5,690. 5,727. 4,016.05 4,016.93 MPS-08 8/1/03 SL 5,928. 5,866. 4,027.83 4,022.71 MPS-08 8/1/03 SL 5,609. 5,847. 4,014.4 4,015.1 MPS-08 8/1/03 SL 5,452. 5,488. 4,010.39 4,011.59 MPS-08 8/1/03 SL 5,372. 5,409. 4,008.36 4,008.28 MPS-08 8/1/03 SL 5,293. 5,331. 4,007.01 4,004.69 MPS-08 8/1/03 SL 5,530. 5,567. 4,012.9 4,013.8 MPS-08 8/1/03 SL 7,470. 7,508. 3,996.83 3,996.66 MPS-08 8/1/03 SL 6,009. 6,046. 4,023.91 4,024.94 MPS-08 8/1/03 SL 6,340. 6,376. 4,015.77 4,013.43 MPS-08 8/1/03 SL 7,314. 7,351. 3,998.31 3,998.8 MPS-08 8N/03 SL 7,234. 7,272. 3,896.97 3,987.59 MPS-08 8/1/03 SL 7,156. 7,193. 3,996.33 3,996.57 MPS-08 8/1/03 SL 6,088. 6,126. 4,026.3 4,027.46 MPS-08 8/1/03 SL 7,075. 7,113. 3,986. 3,986.12 MPS-08 8/1/03 SL 6,918. 6,953. 3,996. 3,995.85 MPS-08 8/1/03 SL 6,836. 6,874. 3,895.72 3,995.96 MPS-08 8/1/03 SL 6,758. 6,794. 3,995.57 3,995.53 MPS-08 8/1/03 SL 6,895. 7,033. 3,995.83 3,995.93 MPS-08 8/1/03 3L 9,059. 9,096. 4,008.14 4,006.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE L~ MPS-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/23/2009; T/I/0=250/400/0. (Freeze protect for E-line/patch) Freeze protect tbg w/ 10 f bbls 60/40 meth for E-line toset tbg patch. FWHP=250/400/0. 3/23/2009~WELL SHUT IN ON ARRIVAL 1WELL BROUGHT ONLINE BY DSO SHORTLY AFTER SPOTTING IN INITIAL T/I/O/= 250/400/0 WELL INJECTING 4600 BPD POWER FLUID WITH 4000 BPD RETURN UP '- 4715', PE v nT n7AA1 D !SET 4.5" BAKER KB PATCH (ELEMENTS AT 2692' AND 2712') PATCH 'TOTAL LENGTH= 26' JOB CONT'D ON 24-MAR-09 *""REPLACEMENT FOR DELETED WSR**" 3/24/2009 ASRC Test Unit #5, Start 6 hour test, **"Job in Progress**' 3/24/2009' CONT'D FROM 03-23-09 RIGGED DOWN E-LINE FINAL T/I/O = 250/400/0 WELL SHUT IN ON DEPARTURE, TURNED OVER TO DSO 3/25/2009jASRC Test Unit #5, End 6 hour test, Rig down, ***Job Complete""* FLUIDS PUMPED BBLS 1 diesel 11 METH 12 Total • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ,~ ~, , ~ r. ~ ~ ~r Y r'~ ~ ; L,. 4' ~ s:. ~. ~~~~ '- RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ x65-1 r~. ~1 ~ 63~ and ProActive Dia nostic Services, Inc. X03 "" ! a 3 ~ ~ d 3 g Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907) 245-8952 1) Leak Detection -WLD 14.Oct-08 L-114A 1 Color Log / EDE 50-029-23032-01 ;~ 2) Leak Detection -WLD 14-0ct-08 MPS-08 1 Color Log / EDE _.50-029-23.168-00 Signed : Date Print Name: ~~~~~( cse_ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~^+~S~~7C.~SS3~~~~=i~13~57]~3"iCa~,,.~t3333 WEBSITE:'r!isni',"i,'1',°_~7:~Dd'4j'Oa'i.~flZ~? ~_ C:\Documenfs and Settings\Owner\Desktap\Transcctit_BP.doc ~, • -,6.., MICROFILMED 03/01/2008 DO NOT PLACE ~.T. , ~~ ~~. -, -' -~ mar ~* ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ) ) WELL LOG TRANSMITTAL JD'j~ I ~-~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1"5135 RE: M\VD Formation Ev,aluation Logs MPS-08 & MPS-08 PB 1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPS-08 & MPS-08 PB1: ~C~NNIE.t,~1 l\I\ì¡\H 0 ~:jj 2JJGb LAS Data & Digital Log Images: 50-029-23168-00,70 1 CD Rom ~ :r!ØøfD& ;;t~ DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031230 Well Name/No. MILNE PT UNIT SB 5-08 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23168-00-00 MD 10009 TVD 4077 Completion Date 8/2/2003 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: MWD, GR, IFR, CASANDRA, RES, ABI, PWD Logl Electr Data Digital Dataset Log Log Run ~ Med/Frmt Number Name Scale Media No I ED D --1f 842 I nd uction/Resistivity 1,2,3 !:f 11842 LIS Verification 1,2,3 i pt 11843 LIS Verification 1,2,3 !-.ed D Directional Survey Final ip Directional Survey Final ~ Directional Survey Final ¿ D Directional Survey Final ! Rpt Directional Survey Final I ED----Q Lis j.j.842 I nduction/Resistivity ~~ Lis 1--1"843 I nd uctionlResistivity '--- Well Cores/Samples Information: Interval Name Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y & Chips Received? Y 1 N ----- Analysis Y 1 N Received? Daily History Received? Formation Tops Comments: Current Status 1-OIL UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint ~ Interval OHI Start Stop CH Received Comments 68 10008 Open 8/29/2003 GR, EWR4, ROP 68 1 0008 Open 8/29/2003 GR, EWR4, ROP 68 5651 Open 8/29/2003 GR, EWR4, ROP 823 5651 Open 8/29/2003 MWD, PDF & PTT data files 0 823 Open 8/29/2003 Gyro 823 5651 Open 8/29/2003 PB1 5333 1 0009 Open 8/29/2003 MWD, PDF & PTT data files 5333 1 0009 Open 8/29/2003 \ 68 9955 Open \ 8/29/2003 MWD: GR, EWR4, ROP 68 5597 / MWD: GR, EWR4, ROP Open/ 8/29/2003 ---- Sample Set Number Comments ~/N Ò'/N DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031230 Well Name/No. MILNE PT UNIT 5B 5-08 Operator BP EXPLORATION (ALASKA) INC MD 10009 TVD 4077 Completion Date 8/2/2003 Completion Status 1-01L Current Status 1-01L Compliance Reviewed By: I,~ Date: API No. 50-029-23168-00-00 UIC N J 7 No if l..J.),~ .~ -" MPS-08 Test Production Data ) Subject: MPS-08 Test Production Data Date: Wed, 3 Sep 2003 17:42:07 -0500 From: "Hubble, Terrie L" <HubbleTL@BP.com> To: "Bob Fleckenstein (E-mail)..<bob_fleckenstein@admin.state.ak.us> CC: "Tom Maunder (E-mail)..<Tom_Maunder@admin.state.ak.us> Hi Bob, Sorry for the erroneous information. Here is what I actually should have in those fields... Date of Test: 08/29/03 Hours Tested: 6 Test Period Oil: 2,369 Test Period Gas: 401 Test Period Water: -0- GaR: 169 24 Hour Oil: 9,476 24 Hour Gas: 1,604 24 Hour Water: -0- Thanks to both of your for catching the error. Terrie Hubble GPB Drilling & Wells 564-4628, MB7-5, Cube 718 1 of 1 ;lc?' -I À> 9/3/2003 2:54 PM ~. } STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMiSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 IFR, CASANDRA, RES, ABI, PWD CASING, LINER AND CEMENTING RECORD ':';'I;::'.IIi"I$¡;JiIJ1¡~GI~I~eß;¡;H~II',I:llli:I:';;1 "I':::'I:'I':'110A~;II.:¡I:I:,'I:,¡I~'~i:,leOT,;rO:~I":'1,1' Surface 112' 35' 2776' 32' 5284' 5182' 9143' 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: 3349' NSL, 35' WEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 1755' NSL, 4064' WEL, SEC. 07, T12N, R11E, UM Total Depth: 930' NSL, 3277' WEL, SEC. 06, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565976, y- 6000018' Zone- ASP4 TPI: x- 566748 y- 5998431 Zone- ASP4 Total Depth: x- 567476 L y- 6002892· Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, 22. ,i':~II',9ÅSlfi.I,q':'I¡"I::¡I:::~:1 ' ¡"".': SI1?~,1 1",:::111'1: 20" 10-3/4" 7-5/8" 4-1/2" x 4" 92# 45.5# 29.7# 12.6# x 9.5# H-40 L-80 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4",9.5#, L-80 Sand Screens MD TVD MD TVD 9293' - 9059' 4013' - 4006' One Other 5. Date Comp., Susp., or Aband. 8/2/2003 . 6. Date Spudded 7/22/2003 7. Date 1. D. Reached 7/30/2003 8. Elevation in feet (indicate KB, OF, etc.) KBE = 72.46' 9. Plug Back Depth (MD+TVD) 10009 ¡ + 4077' Ft 10. Total Depth (MD+TVD) 10009 . + 4077' Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-123 13. API Number 50- 029-23168-00-00 14. Well Number M PS-08 15. Field and Pool Milne Point Unit / Schrader Bluff 16. Lease Designation and Serial No. ADL 380110 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 42" 260 sx Arctic Set (Approx.) 13-1/2" 510 sx Class 'L', 275 sx Class 'G' 13-1/2" 400 sx Class 'G' 6-1/8" Uncemented Sand Screen Liner SIZE 4-1/2", 12.6#, L-80 3-1/2",9.2#, L-80 DEPTH SET (MD) 4753' 4818' PACKER SET (MD) 4754' ;Iii.· ......". r-.... ¡ ...,...., I 11:. f þ I ì ~."", ¡.II ' hj l· J ',..< ~ t· ~1 ' ! \- lj ...~'i.H '1\\1"\_ CONTINUED ON REVERSE SIDE DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 130 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): August 27,2003 Hydraulic Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBl~ðé:t1. GAS-MCFÁf)l WATER-BBl 8/24/2003 2 TEST PERIOD + ~ &FV ~I -0- Flow Tubing Casing Pressure CALCULATED + OIL-BB~'I1b GAS-MCF/t£:4 WATER-BBl Press. 24-HoUR RATE 17,732 ßR-- ~ -0- 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". CHOKE SIZE GAS-all RAø I ~ 9 (JfJt-, OIL GRAVITY-API (CORR) ~~~.{¿;;:, It~f\ ß\.. ~ ... ,{~" Ph ~ ~\Q) ¡'-' \,.' ,. ~ t? \.1 Sf? o ¡ ~ ~ t~~:':OO'~'~~ None , ,,",-c ~.lo" ,~; ~ '2 ' .~·2·D./'; 0-- '-~ .~____.___ I Form 10-407 Revised 2/2003 NAME GEOLOGIC MARKE ~) MD 4463' 4500' 4585' 5130' 5224' 5297' 6090' 6271' 6368' 6664' 8503' 9102' 9324' 9502' 9797' 9878' 29. ") FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. TVD Top of Ugnu Zone C1 3724' None Top of Ugnu Zone B 3744' Top of Ugnu Zone BLower 3787' SBF2-NA 3968' SBF24-MF 3989' SBF1·NB 4002' SBF12 4026' SBEF-NC 4021' SBE4-NC 4014' SBF12 3998' SBF1-NB 3997' SBF1-NB 4006' SBF1-NB 4015' SBF1-NB 4025' SBF12 4052' SBE4-NC 4062' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble ~~ ~~ Title Technical Assistant Date oq·O~·O~ MPS-08 203-123 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number P . Drilling Engineer: Matt Green, 564-5581 ermlt 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. 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 2/2003 ORIGINAL Legal Name: Common Name: Test Date 7/24/2003 7/27/2003 FIT FIT MPS-08 MPS-08 Test Type Test Depth (TMD) 2,803.0 (ft) 5,310.0 (ft) Test Depth (TVD) 2,437.0 (ft) 4,000.0 (ft) EMW 11.56 (ppg) 11.69 (ppg) AMW 8.80 (ppg) 8.80 (ppg) Surface Pressure 350 (psi) 600 (psi) Leak Off Pressure (BHP) 1 ,464 (psi) 2,429 (psi) ~/ ~ Printed: 8/4/2003 9:09:26 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/21/2003 7/22/2003 7/23/2003 7/24/2003 MPS-08 MPS-08 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 7/22/2003 Rig Release: 8/2/2003 Rig Number: Spud Date: 7/21/2003 End: From - To Hours Task Code NPT Phase Description of Operations 22:00 - 22:30 0.50 MOB P PRE Skid rig floor from drlg position to move position 22:30 - 23:00 0.50 MOB P PRE Move rig from S-06i to S-08 - Spot over well 23:00 - 00:00 1.00 MOB P PRE Skid rig floor from move position to drlg position - Shim rig - Rig up 00:00 - 03:00 3.00 DRILL P SURF Accept rig @ 00:00 hrs 7/21/2003 - Nipple up Riser to divertor- Nipple up flowline - (Set rock washer - berm same while loading pipe shed) - Load 4" drill pipe - 5" hwdp in shed - mixing spud mud 03:00 - 08:30 5.50 DRILL P SURF Picking up 4" drill pipe from shed - Standing back in derrick - Stand back total of 109 stands in derrick for drilling to TO on S-08 08:30 - 10:30 2.00 DRILL P SURF Change out 4" handling equipment to 5" handling equipment - PU 5" HWDP - 6" flex dc's - 8" flex dc's - stand back in derrick 10:30-11:30 1.00 DRILL P SURF Clear rig floor - PU small bha tools up beaver slide 11:30-13:00 1.50 DRILL P SURF PJSM - Make up bit to motor - mwd - orient same - con't make up BHA assy 13:00 - 13:30 0.50 DRILL P SURF Rig up Gyro equipment - Function test divertor - Accumulator test - Witness of test waived by Chuck Scheeve with AOGCC 13:30 - 14:00 0.50 DRILL P SURF Pre spud meeting with all personnel - Fill stack with mud check for surface leaks 14:00 - 00:00 10.00 DRILL P SURF Drill from 112' to 1060' - WOB 20K to 40K - RPM 80 Tq on 5K - off 1 K - GPM 400 PP on 1530 - off 1230 - PU 98K - SO 98K- Rot 98K 00:00 - 11 :30 11.50 DRILL P SURF Directional drill 13 1/2" surface hole from 1 060' to 2783' - (rig down Gyro survey equipment @ 00:30hrs) - 11 :30 - 13:00 1.50 CASE P SURF Circ three bottoms up , with 100 rpms. 500 gals min, 2350 psi 13:00 - 14:30 1.50 CASE P SURF Pump out to HWDP @ 816 14:30 - 15:30 1.00 CASE P SURF Trip back to bottom @ 2783 15:30 - 17:30 2.00 CASE P SURF Circ three bottoms up , with 100 rpms. 500 gals min, 2350 psi 17:30 - 19:30 2.00 CASE P SURF Pump out to HWDP @ 816 19:30 - 22:00 2.50 CASE P SURF Tripping out laying down BHA, clear floor 22:00 - 23:00 1.00 CASE P SURF Rig up to run csg., PJSM 23:00 - 00:00 1.00 CASE P SURF Running 10 3/445.5# L-80 csg 00:00 - 03:00 3.00 CASE P SURF Running 10 3/445.5# L-80 csg, tight spot 2250 to 2330 worked and circ tru., finish going to bottom no problems land with 115,000# on landing ring, shoe @ 2776, float @ 2705, total jts run 67 03:00 - 03:30 0.50 CASE P SURF Rig down Franks tool, rig up cementing head 03:30 - 05:00 1.50 CASE P SURF Circ two csg vol., thin mud for cement job, PJSM 05:00 - 07:00 2.00 CEMT P SURF Cement with Halliburton, pump 10 bbls water, test lines to 3500 psi. pumped 10 bbls water, 50 bbls NSCI spacer mixed @ 10.2, one gal dye in spacer, drop bottom plug on fly, mixed and pumped 510 sx Class L, 377 bbls @ 10.7, tail with 275 sxs. Class G, 56 bbls mixed @ 15.8 mixed and pumped @ 8 bbls min., kicked out top plug with 30 bbls water, displace with rig pumps 10 bbls min 230 bbls mud, bump plug with 1000 psi over circ. pressure to 1750 psi, float held, 69 bbls of good cement to surface 07:00 - 08:00 1.00 CEMT P SURF Rig down cement head, Flush diverter, laydown landing jt 08:00 - 09:00 1.00 CEMT P SURF Nipple down Diverter 09:00 - 10:00 1.00 CEMT P SURF Nipple up FMC 11" 5,000psi casing head, 11 "x11" tubing head test 1 000 psi for 1 0 min. 10:00 -11 :30 1.50 CEMT P SURF Nipple up 13 5/8 5,000# BOP stack Printed: 8/4/2003 9:09:40 AM ) ) Operations Summary Report Legal Well Name: MPS-08 Common Well Name: MPS-08 Spud Date: 7/21/2003 Event Name: DRILL +COMPLETE Start: 7/22/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/2/2003 Rig Name: DOYON 14 Rig Number: - To Hours Task Code NPT Phase Description of Operations 7/24/2003 11:30 -15:30 4.00 CEMT P SURF Rig up and test BOPS and Manifold to 250/3500, 5 min. per test, test Annular 250/2500 psi, 5 min. per test, the right to witness test was wavier by John Crisp AOGCC 15:30 - 16:00 0.50 CEMT P SURF Pickup BHA #2 16:00 - 17:00 1.00 CEMT P SURF Trip in to 2650 17:00 - 18:00 1.00 CEMT P SURF Circ and test csg to 2,500psi for 30 min. 18:00 - 20:30 2.50 CASE P SURF String up new drill line 20:30 - 21 :30 1.00 CEMT P SURF Drill float and shoe and new hole to 2803 21 :30 - 22:00 0.50 CEMT P SURF Circ. bottoms up 22:00 - 22:30 0.50 CEMT P SURF Fit test with 350 psi 8.8 mud wt 2437 TVD= 11.5 EMW 22:30 - 23:00 0.50 CEMT P SURF Displace hole with new mud 23:00 - 00:00 1.00 DRILL P INT1 Slug pipe and trip out for motor 7/25/2003 00:00 - 02:00 2.00 DRILL P INT1 Picking up Bha #3 FGXIVC with 3x15 1 x10, 7" Sperry drill with 1.5 bend, stab,float sub, 6314 GR/RES, 6.75 DM, 6.75 HOC,stab,3 flex dC,stab, 12 HWDP,jars,5 HWDP 02:00 - 03:00 1.00 DRILL P INT1 Trip to bottom, tested MWD with motor out of CSG 03:00 - 00:00 21.00 DRILL P INT1 Directional drill from 2803' to 5067' with 430 gpm 2420 psi, 80 rpms, AST 11.41 ART 2.16 7/26/2003 00:00 - 05:00 5.00 DRILL P INT1 Directional drill from 5067' to 5290'TD with 430 gpm 2420 psi, 80 rpms 05:00 - 07:30 2.50 CASE P INT1 Circ, three bottoms up with 100 rpms 450 gals min, 2000 psi 07:30 - 09:30 2.00 CASE P INT1 POH to shoe @ 2738 with full drilling rate 09:30 - 11 :00 1.50 CASE P INT1 Trip to bottom 11 :00 - 13:30 2.50 CASE P INT1 Circ, three bottoms up with 100 rpms 485 gals min, 2000 psi clay balls came back @ 2500 ps. 13:30 - 15:00 1.50 CASE P INT1 POH to shoe @ 2738 with full drilling rate 15:00 - 16:00 1.00 CASE P INT1 POH to hwp 16:00 - 18:00 2.00 CASE P INT1 Lay down BHA 18:00 - 19:30 1.50 CASE P INT1 Change out top rams to 7 5/8 , test doors to 1500 psi 19:30 - 20:30 1.00 CASE P INT1 Rig up to run 7 5/8 csg, PJSM 20:30 - 23:00 2.50 CASE P INT1 Picking up 7 5/8 29.7# L-80 Btc-Mod csg to 2,750' 23:00 - 00:00 1.00 CASE P INT1 Circ. csg with 60 spm for 2400 ps 7/27/2003 00:00 - 02:30 2.50 CASE P INT1 Picking up 7 5/8 29.7# L-80 Btc-Mod csg to 5,284 Total of 129 jts, float 5198' shoe 5284', PU/wt 175,000, SolWt 125,000 02:30 - 03:00 0.50 CASE P INT1 Rig down Franks tool, rig up cement head 03:00 - 04:00 1.00 CASE P INT1 Circ and reciprocate csg., thin mud for cement job.,PJSM 04:00 - 05:30 1.50 CEMT P INT1 Cement with Halliburton with 5 bbls water,test lines to 3500psi, 15 bbls water,30 bbls Alpha spacer mixed @ 10.2,drop bottom plug,mix and pumped 400sxs. Class wI 3% Kcl+2% Cal seal + .5% Lap, 87 bbls slurry mixed @ 15.6, drop top plug, kicked out with 30 bbls water, displace with rig pump 208 bbls mud @ 6 bbls min.500 psi, full returns tru out job, bump plug with 1000# over circ. pressure, total 1500 psi, floats held. reciprocate csg till just before plug bump. 05:30 - 06:00 0.50 CEMT P INT1 Rig down, cement head 06:00 - 07:00 1.00 CEMT P INT1 Change out bales and elevators, Set packoff and test to 5000psi for 10 min. 07:00 - 09:00 2.00 CEMT P INT1 Change out top rams from 7 5/8 to 2 7/8x5" variables, test door seals to 3500psi, install wear ring 09:00 - 10:30 1.50 CASE P INT1 Picking up BHA #4 Fm2643 PDC with 3/13 jets, 4 3/4 Sperry drill with 1.5 bend,float sub,4 3/4 DGR & EWD,4 3/4 DM, 43/4 PWD, 4 3/4 TM,3 flex collars,jars,xo Printed: 8/4/2003 9:09:40 AM ) ) ) BPEXPLORATION Operations SUrnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-08 MPS-08 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 7/22/2003 Rig Release: 8/2/2003 Rig Number: Spud Date: 7/21/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/27/2003 10:30 - 12:00 1.50 CASE P INT1 Change out saver sub. on top drive 12:00 - 12:30 0.50 CASE P INT1 PJSM, Surface test MWD 12:30 - 14:00 1.50 CASE P INT1 Trip in to 5,114' 14:00 -15:00 1.00 CASE P INT1 Circ one drill pipe voL, Test Csg to 3,500psi for 30 min. 15:00 - 16:30 1.50 CEMT P INT1 Drill cement float and shoe and 20 ft of new hole to 5310 16:30 -17:00 0.50 CASE P INT1 Circ bottoms up 17:00 - 17:30 0.50 CASE P INT1 FIT test with 8.8 mud wt 600 psi tvd 4000= EMW 11.6 17:30 - 18:30 1.00 CASE P INT1 Displace well with 9.4 ppg Flo-Pro mud, @ 250 gals min. 1800psi 18:30 - 00:00 5.50 DRILL P PROD1 Directional drill 5310 to 5570' with 250 gals min.2400 psi 80 rpms 7/28/2003 00:00 - 03:30 3.50 DRILL P PROD1 Directional drill 5570 to 5651' with 250 gals min.2400 psi 80 rpms, Lost 700 psi drilling, lost 300 psi on slow pump rate 03:30 - 04:00 0.50 DRILL N DFAL PROD1 Pumped slow and pull into csg @ 5284 04:00 - 04:30 0.50 DRILL N DFAL PROD1 Pressure test pumps and mud lines, ok 04:30 - 06:00 1.50 DRILL N DFAL PROD1 Pulling out of hole, pulling pipe wet, looking for washout 06:00 - 07:00 1.00 DRILL N DFAL PROD1 Stand back BHA, found we had left the bit and bottom 12' of motor with ABI in hole 07:00 - 08:30 1.50 DRILL N DFAL PROD1 Test, read and unload MWD 08:30 - 10:00 1.50 DRILL N DFAL PROD1 Pick up new bit and motor 10:00 - 12:00 2.00 DRILL N DFAL PROD1 Trip into 5306, test MWD @ 2,809 12:00 - 13:00 1.00 DRILL N DFAL PROD1 Open hole side track well @ 5350 to 5400' 13:00 - 00:00 11.00 DRILL P PROD1 Directional drill 5400' to 6212' with 250 gals min.1950 psi 80 rpms, AST 5.66 ART 2.58 TO 4,500 7/29/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill 6212' to 8906' with 250 gals min. 2300 psi 80 rpms,AST 3.59 ART 9.5 7/30/2003 00:00 - 20:00 20.00 DRILL P PROD1 Directional drill 8906' to 1 0009'TD with 250 gals min. 2580 psi, 80 rpms AST 4.42 ART 10 TO 7200 ECD 12.1 20:00 - 22:30 2.50 CLEAN P COMP Circ. three bottoms up with 100 rpms and 250 gpm 2580 psi 22:30 - 00:00 1.50 CLEAN P COMP Pumping out with full drilling rate, hole was knotty from 8470 to 8250 7/31 /2003 00:00 - 03:30 3.50 CLEAN P COMP Pumping out to csg shoe @ 5284 with full drilling rate, hole was little knotty from 8470 to 8250, overpull and packing off. coming tru side track @ 6450 to 6350 rotate and it cleared up, 03:30 - 05:30 2.00 CLEAN P COMP Check for flow,slug pipe, POH to BHA 05:30 - 06:30 1.00 CLEAN P COMP Laying down BHA 06:30 - 11 :00 4.50 CLEAN P COMP Pull wear, Test BOPs and Manifold to 250/3500 psi for 5 min per test, test annular 250/2500 5 min. per test, the right to witness test was wavier by Lou Grimaldi AOGCC, install wear ring 11:00 -13:30 2.50 CLEAN P COMP Pick up holeopener, trip in to 5210' 13:30 - 15:00 1.50 CLEAN P COMP Cut drilling line and service topdrive 15:00 - 16:30 1.50 CLEAN P COMP Trip in to 9162' liner setting depth with no problems 16:30 - 19:00 2.50 CLEAN P COMP Circ four bottoms up with 120 rpms 250 gals min. 2000 psi 19:00 - 21 :30 2.50 CLEAN P COMP Displace hole with 20 bbls spacer, 160 bbls 9.5 brine, 580 bbls 9.5 solid free Flo-Pro , pumped brine @ 3 bbls min and 25 rpms with brine in open hole, pumped Flo-Pro 6 bbls min and 120 rpms after brine got into csg. 21 :30 - 00:00 2.50 CLEAN P COMP Pumping to csg shoe @ 5284 with full drilling rate 8/1/2003 00:00 - 01 :00 1.00 CLEAN P COMP Circ. bottoms up @ shoe 5284 01 :00 - 02:30 1.50 CLEAN P COMP Tripping out to BHA 02:30 - 03:00 0.50 CLEAN P COMP Laying down BHA 03:00 - 04:00 1.00 CASE P COMP Rig up to pick up Screen Liner, PJSM Printed: 8/4/2003 9:09:40 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-08 MPS-08 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 7/22/2003 Rig Release: 8/2/2003 Rig Number: Spud Date: 7/21/2003 End: Date From- To Hours Task Code NPT Phase Description of Operations 8/1/2003 04:00 - 09:00 5.00 CASE P COMP Picking up Screen Liner total of 47 4"screens and 584" Blanks , 3 4.5" blanks, Baker hanger and ZXP packer 09:00 - 11 :30 2.50 CASE P COMP Tripping in with liner to 9148' tag up on bridge, liner P/U 140K S/O 75K 11 :30 - 13:00 1.50 CASE P COMP Drop ball and set hanger with 2,000 psi,set packer with 3200 psi, shear ball with 4600 psi, test back side and packer with 1500 psi Liner top @ 5182', shoe @ 9143' 13:00 - 16:30 3.50 CASE P COMP Tripping out with liner running tools, lay down 162 jts of pipe 16:30 - 18:00 1.50 RUNCOrvP COMP Pickup Johnny Wacker, Trip in to 5,150' 18:00 - 19:30 1.50 RUNCOrvP COMP Displace well with 8.8 Nacl, 290 bbls Rpms 120, 10 bbls min. 1400 psi, follow by 9.2 Nacl, 425 bbls RPMs 120 10 bbls min. with 1300 psi, with one drum of corrosion inhibitor 19:30 - 21 :30 2.00 RUNCOrvP COMP Tripping out with Johnny Wacker, laying down excess pipe 21 :30 - 23:00 1.50 RUNCOrvP COMP Clear floor, rig up to run Tubing, count tubing, PJSM 23:00 - 00:00 1.00 RUNCOI'Vf\J DFAL COMP Picking up tail pipe, Baker packer, Packer started turning when we was making up jt, checked packer, layed packer down 8/2/2003 00:00 - 03:00 3.00 RUNCOI'Vf\J DFAL COMP Wait on new Baker packer 03:00 - 09:00 6.00 RUNCOrvP COMP Picking up Baker S-3 packer and 4.5 tubing, total 112 jts. 4.5" 12.6# L-80 IBT 09:00 - 10:30 1.50 RUNCOrvP COMP Make up hanger with TWC install and run i-wire though hanger, test and land hanger, wire line guide 4817, xn nipple 4812, packer 4765, x nipple 4754, gauge sensor 4738, sliding sleeve 4715, pressure gauge 4704, glm 2080 10:30 - 11 :30 1.00 RUNCOrvP COMP Test TWC with 300psi, Nipple down Bops 11 :30 - 12:00 0.50 RUNCOrvP COMP Nipple up FMC 11' X 41/165,000# adapter flange 12:00 - 13:30 1.50 RUNCOrvP COMP Nipple up 4 1/16 CIW Tree, test adaper to 5000psi, and body test tree to 5,000 psi 13:30 - 14:30 1.00 RUNCOrvP COMP Pull TWC, Drop ball and rod 14:30 - 16:30 2.00 RUNCOrvP COMP Test lines to 5,000 set packer with 4,000 psi and test tubing for 30 min., bleed back to 2500 psi and pressure test annulus to 4500 psi for 30 min., bleed back and shear DCK valve with 2500 psi 16:30 - 18:30 2.00 RUNCOrvP COMP Freeze protect annulus with 47 bbls of diesel, freeze protect 10 3/4 X 7 5/8 with 83 bbls diesel with HB&R, secure tree 18:30 - 0.00 RUNCOrvP COMP Rig Release for rig move Printed: 8/4/2003 9:09:40 AM ) ') a()3- J;j3 22-Aug-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS_08 PB1 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' M 0 (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) RECEIVED AUG 2 9 2003 AJaaka œ & Gas Cont. Commia8ion AndtOl!fle Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-OBPB1 Gyro .--- Job No. AKF00002567095, Surveyed: 28 July, 2003 Survey Report 21 August, 2003 Your Ref: API 500292316870 Surface Coordinates: 6000017.67 N, 565975.59 E (70024' 37.7510" N, 149027' 45.9888" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 1000017.67 N, 65975.59 E (Grid) Surface Coordinates relative to Structure: 45.93 N, 369.02 W (True) Kelly Bushing: 72.46ft above Mean Sea Level Elevation relative to Project V Reference: 72.46ft Elevation relative to Structure: 72.46ft 5~1 ·,-,y-5UI! DR I L.:.L ING ···SERV<. C::SS A Halliburton Company Survey Ref: svy1246 BP EXPLORA TION (ALASKA) INC. Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -72.46 0.00 274.00 0.000 0.000 201.54 274.00 454.00 0.000 0.000 381 .54 454.00 634.00 3.000 186.000 561.46 633.92 725.00 3.900 186.000 652.29 724.75 823.00 4.800 196.000 750.01 822.47 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08PB1 Gyro Your Ref: API 500292316870 Job No. AKF00002567095, Surveyed: 28 July, 2003 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (°/1 o Oft) 0.00 N 0.00 E 6000017.67 N 565975.59 E 0.00 Tolerable Gyro 0.00 N 0.00 E 6000017.67 N 565975.59 E 0.000 0.00 0.00 N 0.00 E 6000017.67 N 565975.59 E 0.000 0.00 4.69 S 0.49 W 6000012.98 N 565975.14 E 1.667 -4.47 10.13 S 1.06W 6000007.53 N 565974.61 E 0.989 -9.68 ~ 17.39 S 2.54W 6000000.26 N 565973.20 E 1.198 -16.90 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB. Northings and Eastings are relative to SHL. 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 SHL and calculated along an Azimuth of 24.240° (True). Magnetic Declination at Surface is 25.433°(22-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 823.00ft., The Bottom Hole Displacement is 17.57ft., in the Direction of 188.322° (True). Survey tool program for MPS-OBPB1 Gyro Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) .~ 0.00 0.00 823.00 822.47 Tolerable Gyro 21 August, 2003 - 14:01 Page 2 of 2 DrillQuest 3.03.02.005 ) ) r9cr3 -Ø3 22-Aug-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS_08 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 5,333.38 I MD Window / Kickoff Survey: 5,350.00' MD (if applicable) . Projected Survey: 10,009.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 2 9 2003 Alaska Qi'¡ & Gas Cons. Gommi3!ÏOn Äl1rt1nrN1P. Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-OB '-" Job No. AKZZ0002567095, Surveyed: 30 July, 2003 Survey Report 21 August, 2003 Your Ref: API 500292316800 Surface Coordinates: 6000017.67 N, 565975.59 E (70024' 37.7510" N, 149027' 45.9888" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 - Surface Coordinates relative to Project H Reference: 1000017.67 N, 65975.59 E (Grid) Surface Coordinates relative to Structure: 45.93 N, 369.02 W (True) Kelly Bushing: 72.46ft above Mean Sea Level Elevation relative to Project V Reference: 72.46ft Elevation relative to Structure: 72.46ft srt-"I ·.....y-5LJ1'l b R ILL ff\n::;"-sfe RV I c:e 5 A Halliburton Company Survey Ref: svy1252 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-OB Your Ref: API500292316BOO Job No. AKZZ0002567095, Surveyed: 30 July, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) 5333.38 87.280 73.550 3932.35 4004.81 1584.37 S 793.80 E 5998440.38 N 566783.36 E -1118.78 Tie On Point 5350.00 88.090 71.970 3933.03 4005.49 1579.45 S 809.66 E 5998445.44 N 566799.17 E 10.676 -1107.78 Window Point 5386.02 86.910 69.870 3934.60 4007.06 1567.68 S 843.67 E 5998457.50 N 566833.07 E 6.683 -1083.09 5429.58 87.040 69.550 3936.90 4009.36 1552.60 S 884.47 E 5998472.94 N 566873.74 E 0.792 -1052.59 5479.58 88.400 65.060 3938.89 4011.35 1533.33 S 930.55 E 5998492.62 N 566919.65 E 9.376 -1016.10 ~ 5525.73 88.090 60.890 3940.30 4012.76 1512.37 S 971.63 E 5998513.94 N 566960.54 E 9.056 -980.12 5579.87 89.320 52.700 3941 .53 4013.99 1482.76 S 1016.88 E 5998543.95 N 567005.53 E 15.293 -934.54 5622.76 88.950 49.120 3942.17 4014.63 1455.72 S 1050.16 E 5998571 .28 N 567038.57 E 8.390 -896.22 5674.72 88.700 38.250 3943.24 4015.70 1418.21 S 1085.98 E 5998609.11 N 567074.06 E 20.921 -847.31 5719.15 88.640 37.870 3944.27 4016.73 1383.24 S 1113.37 E 5998644.32 N 567101.13 E 0.866 -804.18 5771.37 87.220 30.210 3946.16 4018.62 1340.03 S 1142.56 E 5998687.79 N 567129.94 E 14.909 -752.79 5815.26 87.900 28.110 3948.03 4020.49 1301.74 S 1163.92 E 5998726.27 N 567150.97 E 5.025 -709.11 5864.96 89.570 20.210 3949.13 4021.59 1256.44 S 1184.24 E 5998771.74 N 567170.88 E 16.242 -659.46 5911.16 89.880 18.120 3949.35 4021.81 1212.80 S 1199.41 E 5998815.51 N 567185.66 E 4.573 -613.45 5964.87 88.270 8.260 3950.22 4022.68 1160.58 S 1211.65 E 5998867.84 N 567197.44 E 18.598 -560.80 6007.71 88.520 6.720 3951 .42 4023.88 1118.13 S 1217.23 E 5998910.34 N 567202.65 E 3.640 -519.80 6057.06 88.270 3.160 3952.80 4025.26 1068.99 S 1221.48 E 5998959.52 N 567206.46 E 7.229 -473.25 6104.16 87.710 2.420 3954.46 4026.92 1021.97 S 1223.77 E 5999006.55 N 567208.34 E 1.970 -429.44 6155.18 91 .730 1.330 3954.70 4027.16 970.99 S 1225.44 E 5999057.54 N 567209.56 E 8.164 -382.27 6197.83 93.830 3.850 3952.64 4025.10 928.44 S 1227.36 E 5999100.11 N 567211.1 0 E 7.686 -342.68 6249.85 93.270 2.520 3949.41 4021.87 876.60 S 1230.25 E 5999151.97 N 567213.53 E 2.770 -294.23 6293.83 94.450 2.470 3946.45 4018.91 832.76 S 1232.16 E 5999195.82 N 567215.05 E 2.685 -253.4 7 6345.87 93.210 359.500 3942.98 4015.44 780.85 S 1233.05 E 5999247.74 N 567215.49 E 6.173 -205.77 .~ 6389.75 95.010 0.150 3939.83 4012.29 737.09 S 1232.91 E 5999291.50 N 567214.97 E 4.360 -165.92 6441.81 94.010 0.200 3935.74 4008.20 685.19 S 1233.07 E 5999343.40 N 567214.67 E 1.923 -118.53 6486.43 93.460 359.280 3932.83 4005.29 640.67 S 1232.87 E 5999387.92 N 567214.07 E 2.398 -78.02 6537.76 92.960 359.860 3929.96 4002.42 589.42 S 1232.48 E 5999439.16 N 567213.23 E 1.491 -31.44 6582.93 90.800 1.610 3928.48 4000.94 544.28 S 1233.06 E 5999484.30 N 567213.41 E 6.153 9.95 6631.62 93.150 2.360 3926.80 3999.26 495.65 S 1234.75 E 5999532.94 N 567214.67 E 5.066 54.98 6678.98 92.410 2.390 3924.50 3996.96 448.39 S 1236.71 E 5999580.22 N 567216.21 E 1.564 98.89 6729.10 90.430 2.880 3923.26 3995.72 398.34 S 1239.01 E 5999630.29 N 567218.07 E 4.070 145.47 6775.12 90.060 2.990 3923.06 3995.52 352.38 S 1241.37 E 5999676.27 N 567220.02 E 0.839 188.34 6827.45 89.630 4.420 3923.20 3995.66 300.16 S 1244.75 E 5999728.51 N 567222.94 E 2.854 237.34 6871.35 89.630 3.770 3923.49 3995.95 256.38 S 1247.89 E 5999772.33 N 567225.69 E 1 .481 278.56 6921.11 90.310 4.940 3923.51 3995.97 206.76 S 1251.66E 5999821.97 N 567229.03 E 2.720 325.35 21 August, 2003 - 14:05 Page 2 of 5 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-OB Your Ref: API500292316BOO Job No. AKZZ0002567095, Surveyed: 30 July, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) (0/100ft) 6966.41 90.060 9.520 3923.37 3995.83 161.83 S 1257.36 E 5999866.95 N 567234.33 E 10.125 368.66 7016.23 89.810 8.490 3923.42 3995.88 112.63 S 1265.16 E 5999916.22 N 567241.70 E 2.127 416.73 7062.53 89.940 8.030 3923.52 3995.98 66.81 S 1271.81 E 5999962.10 N 567247.94 E 1.032 461.24 7112.26 89.750 9.130 3923.66 3996.12 17.64 S 1279.23 E 6000011.33 N 567254.93 E 2.245 509.12 7158.69 89.690 10.280 3923.89 3996.35 28.13 N 1287.06 E 6000057.17 N 567262.35 E 2.480 554.06 .~ 7208.75 89.510 9.880 3924.24 3996.70 77.41 N 1295.82 E 6000106.53 N 567270.68 E 0.876 602.60 7254.59 89.010 8.810 3924.83 3997.29 122.64 N 1303.26 E 6000151.82 N 567277.72 E 2.576 646.89 7303.24 89.010 10.670 3925.67 3998.13 170.58 N 1311.49 E 6000199.83 N 567285.52 E 3.823 693.99 7350.15 89.380 10.470 3926.33 3998.79 216.69 N 1320.10 E 6000246.01 N 567293.72 E 0.897 739.56 7401.09 91.670 8.370 3925.86 3998.32 266.93 N 1328.43 E 6000296.33 N 567301.61 E 6.099 788.80 7446.73 90.990 7.970 3924.80 3997.26 312.10 N 1334.92 E 6000341 .55 N 567307.70 E 1.728 832.64 7496.90 90.250 7.660 3924.26 3996.72 361.80 N 1341.74 E 6000391.31 N 567314.08 E 1.599 880.76 7542.31 90.740 7.330 3923.87 3996.33 406.82 N 1347.66 E 6000436.38 N 567319.60 E 1.301 924.25 7592.73 90.800 7.680 3923.19 3995.65 456.80 N 1354.25 E 6000486.42 N 567325.75 E 0.704 972.53 7638.07 90.930 7.550 3922.50 3994.96 501.74 N 1360.25 E 6000531 .40 N 567331.36 E 0.405 1015.97 7689.63 89.070 6.360 3922.50 3994.96 552.91 N 1366.50 E 6000582.63 N 567337.15 E 4.283 1065.19 7733.98 88.640 5.870 3923.39 3995.85 597.00 N 1371.22 E 6000626.76 N 567341.48 E 1.470 1107.34 7785.24 89.880 6.590 3924.05 3996.51 647.95 N 1376.78 E 6000677.76 N 567346.59 E 2.797 1156.08 7830.29 90.060 7.260 3924.08 3996.54 692.68 N 1382.21 E 6000722.53 N 567351.63 E 1.540 1199.09 7876.26 90.000 6.850 3924.05 3996.51 738.30 N 1387.86 E 6000768.20 N 567356.87 E 0.901 1243.00 7915.41 89.440 5.090 3924.24 3996.70 777.23 N 1391.93 E 6000807.17 N 567360.60 E 4.718 1280.18 7976.81 88.890 3.770 3925.14 3997.60 838.44 N 1396.67 E 6000868.42 N 567364.80 E 2.329 1337.94 8022.05 88.580 3.690 3926.14 3998.60 883.57 N 1399.62 E 6000913.57 N 567367.35 E 0.708 1380.30 '~ 8072.57 88.700 2.090 3927.34 3999.80 934.01 N 1402.16 E 6000964.03 N 567369.45 E 3.175 1427.34 8117.85 89.440 3.440 3928.07 4000.53 979.23 N 1404.35 E 6001009.27 N 567371.23 E 3.400 1469.47 8169.05 90.930 3.660 3927.91 4000.37 1030.33 N 1407.52 E 6001060.40 N 567373.95 E 2.942 1517.36 8213.25 91.910 3.660 3926.81 3999.27 1074.43 N 1410.34 E 6001104.52 N 567376.38 E 2.217 1558.73 8265.06 90.190 3.880 3925.86 3998.32 1126.12 N 1413.74 E 6001156.23 N 567379.33 E 3.347 1607.26 8306.42 90.120 3.140 3925.75 3998.21 1167.40 N 1416.28 E 6001197.53 N 567381.50 E 1.797 1645.94 8359.65 88.700 4.460 3926.30 3998.76 1220.51 N 1419.80 E 6001250.67 N 567384.56 E 3.642 1695.81 8405.09 91.420 6.600 3926.25 3998.71 1265.73 N 1424.18 E 6001295.93 N 567388.53 E 7.616 1738.85 8455.97 90.740 6.800 3925.29 3997.75 1316.25 N 1430.12 E 6001346.50 N 567394.02 E 1.393 1787.35 8500.05 89.940 6.730 3925.03 3997.49 1360.02 N 1435.31 E 6001390.32 N 567398.83 E 1.822 1829.40 8551 .49 89.200 5.800 3925.41 3997.87 1411.15 N 1440.92 E 6001441 .50 N 567403.99 E 2.310 1878.32 8593.30 89.380 5.780 3925.93 3998.39 1452.75 N 1445.14 E 6001483.13 N 567407.84 E 0.433 1917.98 21 August, 2003 - 14:05 Page 3 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-OB Your Ref: API500292316BOO Job No. AKZZ0002567095, Surveyed: 30 July, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) 8647.49 89.880 7.500 3926.28 3998.74 1506.57 N 1451 .40 E 6001537.00 N 567413.63 E 3.305 1969.63 8693.02 88.090 7.130 3927.09 3999.55 1551.72 N 1457.20 E 6001582.20 N 567419.03 E 4.015 2013.18 8743.84 88.520 7.470 3928.59 4001.05 1602.11 N 1463.66 E 6001632.64 N 567425.04 E 1.078 2061.77 8789.11 89.200 6.820 3929.49 4001.95 1647.02 N 1469.28 E 6001677.60 N 567430.27 E 2.078 2105.03 8838.48 87.840 5.770 3930.77 4003.23 1696.07 N 1474.70 E 6001726.70 N 567435.25 E 3.480 2151.99 ~ 8885.58 88.830 5.740 3932.14 4004.60 1742.91 N 1479.42 E 6001773.58 N 567439.55 E 2.103 2196.64 8936.43 89.940 5.500 3932.68 4005.14 1793.51 N 1484.40 E 6001824.23 N 567444.09 E 2.233 2244.82 8982.21 89.200 4.770 3933.03 4005.49 1839.11 N 1488.49 E 6001869.86 N 567447.78 E 2.271 2288.08 9031.81 89.690 5.720 3933.51 4005.97 1888.50 N 1493.03 E 6001919.28 N 567451.88 E 2.155 2334.97 9078.18 89.510 5.760 3933.83 4006.29 1934.63 N 1497.67 E 6001965.46 N 567456.11 E 0.398 2378.95 9128.19 90.740 5.450 3933.72 4006.18 1984.40 N 1502.55 E 6002015.27 N 567460.55 E 2.536 2426.33 9174.55 88.520 6.270 3934.02 4006.48 2030.52 N 1507.28 E 6002061.42 N 567464.88 E 5.105 2470.32 9224.16 86.790 5.150 3936.05 4008.51 2079.84 N 1512.21 E 6002110.78 N 567469.37 E 4.153 2517.32 9270.63 86.040 5.120 3938.96 4011.42 2126.03 N 1516.37 E 6002157.01 N 567473.12 E 1.615 2561.14 9319.91 86.600 359.490 3942.12 4014.58 2175.15 N 1518.34 E 6002206.15 N 567474.66 E 11 .457 2606.74 9365.92 86.600 358.910 3944.85 4017.31 2221.07 N 1517.70 E 6002252.06 N 567473.61 E 1.258 2648.36 9415.86 87.530 1.130 3947.41 4019.87 2270.94 N 1517.72 E 6002301.93 N 567473.19 E 4.814 2693.84 9461.90 86.480 359.670 3949.81 4022.27 2316.92 N 1518.04 E 6002347.91 N 567473.10 E 3.903 2735.89 9515.30 85.050 1.640 3953.76 4026.22 2370.16 N 1518.65 E 6002401.16 N 567473.24 E 4.550 2784.69 9556.87 84.620 0.390 3957.50 4029.96 2411.56 N 1519.38 E 6002442.56 N 567473.61 E 3.168 2822.74 9607.44 84.680 0.180 3962.21 4034.67 2461.91 N 1519.63 E 6002492.91 N 567473.41 E 0.430 2868.75 9653.58 85.370 0.890 3966.22 4038.68 2507.87 N 1520.06 E 6002538.87 N 567473.44 E 2.142 2910.84 9704.08 85.300 1.600 3970.32 4042.78 2558.19 N 1521.15 E 6002589.20 N 567474.09 E 1.408 2957.17 ~ 9749.74 83.880 1 .490 3974.63 4047.09 2603.63 N 1522.38 E 6002634.65 N 567474.91 E 3.119 2999.11 9799.42 83.450 1.680 3980.11 4052.57 2652.99 N 1523.75 E 6002684.01 N 567475.84 E 0.945 3044.67 9844.93 83.070 1 .460 3985.45 4057.91 2698.17 N 1524.98 E 6002729.20 N 567476.68 E 0.963 3086.38 9896.61 83.010 0.840 3991.71 4064.17 2749.46 N 1526.01 E 6002780.50 N 567477.26 E 1.196 3133.57 9942.08 83.260 0.850 3997.15 4069.61 2794.59 N 1526.68 E 6002825.64 N 567477.52 E 0.550 3175.00 10009.00 83.260 0.850 4005.00 4077.46 2861.04 N 1527.66 E 6002892.10 N 567477.92 E 0.000 3235.99 Projected Survey 21 August, 2003 - 14:05 Page 4 of 5 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-OB Your Ref: API 500292316800 Job No. AKZZ0002567095, Surveyed: 30 July, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB. Northings and Eastings are relative to SHL. 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 SHL and calculated along an Azimuth of 24.240° (True). Magnetic Declination at Surface is 25.434°(22-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10009.00ft., The Bottom Hole Displacement is 3243.35ft., in the Direction of 28.1 00° (True). -" Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5333.38 5350.00 10009.00 4004.81 4005.49 4077.46 1584.37 S 1579.45 S 2861.04 N 793.80 E 809.66 E 1527.66 E Tie On Point Window Point Projected Survey Survey tool program for MPS-OB Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) .~ 0.00 823.00 0.00 823.00 822.47 10009.00 822.47 Tolerable Gyro (MPS-08PB1 Gyro) 4077.46 AK-6 BP _IFR-AK (MPS-08PB1) 21 August, 2003 - 14:05 Page 5 of 5 DrillQuest 3.03.02.005 ) ) 803-/;) 3 22-Aug-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS_08 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 5,333.38' MD Window / Kickoff Survey: 5,350.00' MD (if applicable) Projected Survey: 10,009.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) RECEIVED AUG 2 9 2003 Alaska Qi¡ & Gas Cons. Commiseion Anchorage Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-OB MWD -- Job No. AKMW0002567095, Survey Report 21 August, 2003 Your Ref: API 500292316800 Surface Coordinates: 6000017.67 N, 565975.59 E (70024' 37.7510" N, 149027' 45.9888" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ^-. Surface Coordinates relative to Project H Reference: 1000017.67 N, 65975.59 E (Grid) Surface Coordinates relative to Structure: 45.93 N, 369.02 W (True) Kelly Bushing: 72.46ft above Mean Sea Level Elevation relative to Project V Reference: 72.46ft Elevation relative to Structure: 72.46ft =¡ ...........,.,y-5U1! b R It.:. L í ^NGmS'e^R^Vic^ES A Halliburton Company Survey Ref: svy1253 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-OB MWD Your Ref: API500292316BOO Job No. AKMWOO02567095, BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) e/100ft) 5333.38 87.280 74.120 3932.36 4004.82 1582.69 S 785.97 E 5998441.98 N 566775.51 E -1120.46 Tie On Point 5350.00 88.090 71.970 3933.03 4005.49 1577.858 801.86 E 5998446.97 N 566791.35 E 13.814 -1109.53 Window Point 5386.02 86.910 70.110 3934.60 4007.06 1566.168 835.89 E 5998458.96 N 566825.28 E 6.111 -1084.89 5429.58 87.040 69.860 3936.90 4009.36 1551.278 876.76 E 5998474.21 N 566866.02 E 0.646 -1054.54 5479.58 88.400 65.330 3938.89 4011.35 1532.23 8 922.94 E 5998493.65 N 566912.03 E 9.452 -1018.22 ..--- 5525.73 88.090 61.230 3940.30 4012.76 1511 .50 S 964.13 E 5998514.75 N 566953.03 E 8.905 -982.40 5579.87 89.320 52.840 3941 .53 4013.99 1482.07 S 1009.50 E 5998544.57 N 566998.14 E 15.658 -936.94 5622.76 88.950 49.570 3942.18 4014.64 1455.21 8 1042.92 E 5998571.73 N 567031.32 E 7.672 -898.72 5674.72 88.700 38.680 3943.25 4015.71 1417.97S 1079.03 E 5998609.29 N 567067.11 E 20.960 -849.95 5719.15 88.640 38.380 3944.28 4016.74 1383.22 8 1106.70 E 5998644.28 N 567094.47 E 0.688 -806.90 5771.37 87.220 30.480 3946.17 4018.63 1340.228 1136.19 E 5998687.54 N 567123.57 E 15.361 -755.58 5815.26 87.900 28.710 3948.04 4020.50 1302.09 8 1157.84 E 5998725.86 N 567144.89 E 4.317 -711.93 5864.96 89.570 20.790 3949.13 4021.59 1257.008 1178.63 E 5998771.13 N 567165.27 E 16.282 -662.28 5911.16 89.880 18.630 3949.36 4021.82 1213.51 8 1194.21 E 5998814.75 N 567180.47 E 4.723 -616.23 5964.87 88.270 8.450 3950.23 4022.69 1161.378 1206.76 E 5998867.00 N 567192.56 E 19.186 -563.53 6007.71 88.520 7.070 3951 .43 4023.89 1118.948 1212.54 E 5998909.48 N 567197.97 E 3.272 -522.47 6057.06 88.270 4.400 3952.81 4025.27 1069.868 1217.47 E 5998958.60 N 567202.47 E 5.432 -475.69 6104.16 87.710 3.970 3954.46 4026.92 1022.92 8 1220.91 E 5999005.58 N 567205.49 E 1 .499 -431.47 6155.18 91.730 2.790 3954.71 4027.17 972.00 S 1223.92 E 5999056.52 N 567208.04 E 8.212 -383.81 6197.83 93.830 6.180 3952.64 4025.10 929.54 S 1227.25 E 5999099.01 N 567211.00 E 9.342 -343.73 6249.85 93.270 3.620 3949.42 4021.88 877.81 S 1231.68 E 5999150.77 N 567214.98 E 5.028 -294.74 6293.83 94.450 3.520 3946.46 4018.92 834.02 S 1234.41 E 5999194.59 N 567217.32 E 2.693 -253.69 6345.87 93.210 1.260 3942.98 4015.44 782.14 S 1236.58 E 5999246.48 N 567219.03 E 4.945 -205.50 .--- 6389.75 95.010 1.720 3939.84 4012.30 738.39 S 1237.71 E 5999290.24 N 567219.78 E 4.233 -165.14 6441.81 94.010 1.250 3935.74 4008.20 686.51 S 1239.06 E 5999342.13 N 567220.67 E 2.121 -117.28 6486.43 93.460 0.240 3932.84 4005.30 641.99 S 1239.64 E 5999386.65 N 567220.85 E 2.573 -76.44 6537.76 92.960 0.930 3929.96 4002.42 590.75 S 1240.16 E 5999437.90 N 567220.92 E 1.658 -29.50 6582.93 90.800 2.880 3928.48 4000.94 545.63 S 1241.66E 5999483.03 N 567222.02 E 6.441 12.25 6631.62 93.150 3.000 3926.80 3999.26 497.04 S 1244.16 E 5999531.64 N 567224.09 E 4.833 57.59 6678.98 92.410 2.960 3924.51 3996.97 449.80 S 1246.62 E 5999578.90 N 567226.13 E 1.565 101.67 6729.10 90.430 3.970 3923.26 3995.72 399.798 1249.65 E 5999628.94 N 567228.72 E 4.434 148.52 6775.12 90.060 3.960 3923.07 3995.53 353.88 8 1252.83 E 5999674.87 N 567231.49 E 0.804 191.68 6827.45 89.630 4.740 3923.21 3995.67 301.708 1256.80 E 5999727.09 N 567235.00 E 1.702 240.89 6871 .35 89.630 3.930 3923.49 3995.95 257.928 1260.11 E 5999770.89 N 567237.93 E 1.845 282.17 6921.11 90.310 5.430 3923.52 3995.98 208.33 8 1264.17 E 5999820.51 N 567241.56 E 3.310 329.05 21 August, 2003 - 14:06 Page2of5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-OB MWD Your Ref: API500292316BOO Job No. AKMWOO02567095, BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) 6966.41 90.060 9.000 3923.37 3995.83 163.40 S 1269.86 E 5999865.50 N 567246.85 E 7.900 372.36 7016.23 89.810 9.440 3923.43 3995.89 114.22 S 1277.85 E 5999914.74 N 567254.39 E 1.016 420.48 7062.53 89.940 8.550 3923.53 3995.99 68.49 S 1285.08 E 5999960.53 N 567261.23 E 1.943 465.15 7112.26 89.750 9.430 3923.66 3996.12 19.37 S 1292.86 E 6000009.72 N 567268.57 E 1.810 513.13 7158.69 89.690 8.240 3923.89 3996.35 26.50 N 1299.99 E 6000055.66 N 567275.29 E 2.566 557.89 ~ 7208.75 89.510 9.760 3924.24 3996.70 75.94 N 1307.82 E 6000105.16 N 567282.68 E 3.057 606.19 7254.59 89.010 9.180 3924.83 3997.29 121.16 N 1315.36 E 6000150.44 N 567289.83 E 1.670 650.51 7303.24 89.010 10.380 3925.67 3998.13 169.09 N 1323.62 E 6000198.45 N 567297.67 E 2.466 697.61 7350.15 89.380 11.310 3926.33 3998.79 215.16N 1332.45 E 6000244.59 N 567306.08 E 2.133 743.24 7401.09 91.670 9.210 3925.86 3998.32 265.28 N 1341.52 E 6000294.79 N 567314.71 E 6.099 792.66 7446.73 90.990 8.680 3924.81 3997.27 310.35 N 1348.61 E 6000339.92 N 567321.41 E 1.889 836.67 7496.90 90.250 7.760 3924.26 3996.72 360.00 N 1355.78 E 6000389.63 N 567328.14 E 2.353 884.89 7542.31 90.740 7.740 3923.87 3996.33 404.99 N 1361.91 E 6000434.68 N 567333.87 E 1.080 928.43 7592.73 90.800 7.950 3923.19 3995.65 454.94 N 1368.79 E 6000484.68 N 567340.31 E 0.433 976.79 7638.07 90.930 7.620 3922.51 3994.97 499.85 N 1374.93 E 6000529.65 N 567346.05 E 0.782 1020.27 7689.63 89.070 6.340 3922.51 3994.97 551.03 N 1381.20 E 6000580.88 N 567351.86 E 4.379 1069.51 7733.98 88.640 6.140 3923.39 3995.85 595.10 N 1386.02 E 6000625.00 N 567356.29 E 1.069 1111.68 7785.24 89.880 7.510 3924.06 3996.52 646.00 N 1392.11 E 6000675.94 N 567361.94 E 3.605 1160.58 7830.29 90.060 8.600 3924.08 3996.54 690.60 N 1398.42 E 6000720.60 N 567367.85 E 2.452 1203.85 7876.26 90.000 8.320 3924.06 3996.52 736.07 N 1405.18 E 6000766.12 N 567374.21 E 0.623 1248.08 7915.41 89.440 6.290 3924.25 3996.71 774.90 N 1410.16 E 6000805.00 N 567378.85 E 5.379 1285.53 7976.81 88.890 5.070 3925.14 3997.60 835.99 N 1416.24 E 6000866.14 N 567384.39 E 2.179 1343.73 8022.05 88.580 5.090 3926.14 3998.60 881.04 N 1420.24 E 6000911.22 N 567387.99 E 0.687 1386.46 '~ 8072.57 88.700 2.460 3927.34 3999.80 931.43 N 1423.57 E 6000961.64 N 567390.87 E 5.210 1433.77 8117.85 89.440 4.310 3928.07 4000.53 976.63 N 1426.24 E 6001006.86 N 567393.15 E 4.400 1476.08 8169.05 90.930 4.560 3927.91 4000.37 1027.67 N 1430.20 E 6001057.93 N 567396.65 E 2.951 1524.25 8213.25 91.910 4.570 3926.81 3999.27 1071.72 N 1433.71 E 6001102.01 N 567399.78 E 2.217 1565.85 8265.06 90.190 4.630 3925.86 3998.32 1123.35 N 1437.87 E 6001153.68 N 567403.48 E 3.322 1614.64 8306.42 90.120 3.920 3925.75 3998.21 1164.59 N 1440.95 E 6001194.95 N 567406.20 E 1.725 1653.51 8359.65 88.700 5.320 3926.30 3998.76 1217.65 N 1445.24 E 6001248.03 N 567410.02 E 3.746 1703.65 8405.09 91.420 7.600 3926.25 3998.71 1262.79 N 1450.35 E 6001293.22 N 567414.73 E 7.810 1746.91 8455.97 90.740 8.230 3925.29 3997.75 1313.18N 1457.36 E 6001343.67 N 567421.29 E 1.822 1795.73 8500.05 89.940 7.630 3925.03 3997.49 1356.83 N 1463.44 E 6001387.38 N 567426.98 E 2.269 1838.03 8551 .49 89.200 6.660 3925.42 3997.88 1407.87 N 1469.83 E 6001438.47 N 567432.93 E 2.372 1887.20 8593.30 89.380 7. 500 3925.94 3998.40 1449.36 N 1474.99 E 6001480.00 N 567437.72 E 2.055 1927.14 21 August, 2003 - 14:06 Page 3 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-OB MWD Your Ref: API500292316BOO Job No. AKMWOO02567095, BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 8647.49 89.880 8.650 3926.29 3998.75 1503.01 N 1482.60 E 6001533.72 N 567444.85 E 2.314 1979.19 8693.02 88.090 8.670 3927.09 3999.55 1548.01 N 1489.45 E 6001578.78 N 567451.31 E 3.932 2023.04 8743.84 88.520 8.860 3928.60 4001.06 1598.21 N 1497.19 E 6001629.05 N 567458.61 E 0.925 2071.99 8789.11 89.200 7.840 3929.50 4001.96 1643.00 N 1503.77 E 6001673.88 N 567464.78 E 2.708 2115.52 8838.48 87.840 7.520 3930.77 4003.23 1691.90 N 1510.36 E 6001722.85 N 567470.95 E 2.830 2162.83 .~ 8885.58 88.830 7.320 3932.14 4004.60 1738.59 N 1516.44 E 6001769.59 N 567476.61 E 2.144 2207.90 8936.43 89.940 7.170 3932.69 4005.15 1789.03 N 1522.85 E 6001820.08 N 567482.58 E 2.203 2256.52 8982.21 89.200 6.770 3933.03 4005.49 1834.47 N 1528.41 E 6001865.57 N 567487.73 E 1.837 2300.24 9031.81 89.690 8.100 3933.51 4005.97 1883.65 N 1534.83 E 6001914.80 N 567493.72 E 2.858 2347.71 9078.18 89.510 7.100 3933.83 4006.29 1929.61 N 1540.96 E 6001960.82 N 567499.44 E 2.191 2392.14 9128.19 90.740 6.720 3933.73 4006.19 1979.26 N 1546.98 E 6002010.51 N 567505.02 E 2.574 2439.88 9174.55 88.520 7.080 3934.02 4006.48 2025.28 N 1552.55 E 6002056.58 N 567510.18 E 4.851 2484.13 9224.16 86.790 6.250 3936.05 4008.51 2074.51 N 1558.30 E 6002105.86 N 567515.50 E 3.867 2531.38 9270.63 86.040 5.200 3938.96 4011.42 2120.65 N 1562.92 E 6002152.05 N 567519.72 E 2.773 2575.36 931 9.91 86.600 0.550 3942.13 4014.59 2169.76 N 1565.39 E 6002201.17 N 567521.75 E 9.485 2621.14 9365.92 86.600 359.660 3944.85 4017.31 2215.69 N 1565.47 E 6002247.10 N 567521.43 E 1.931 2663.06 9415.86 87.530 0.900 3947.41 4019.87 2265.56 N 1565.72 E 6002296.97 N 567521.23 E 3.101 2708.63 9461.90 86.480 0.240 3949.82 4022.28 2311.53 N 1566.18 E 6002342.95 N 567521.29 E 2.693 2750.74 9515.30 85.050 2.550 3953.76 4026.22 2364.77 N 1567.47 E 6002396.19 N 567522.11 E 5.078 2799.81 9556.87 84.620 0.840 3957.50 4029.96 2406.15 N 1568.70 E 6002437.58 N 567522.97 E 4.225 2838.05 9607.44 84.680 0.590 3962.22 4034.68 2456.49 N 1569.32 E 6002487.93 N 567523.15 E 0.506 2884.21 9653.58 85.370 1.070 3966.22 4038.68 2502.45 N 1569.99 E 6002533.89 N 567523.41 E 1.819 2926.40 9704.08 85.300 2.440 3970.33 4042.79 2552.76 N 1571.53 E 6002584.21 N 567524.51 E 2.707 2972.90 .~ 9749.74 83.880 2.310 3974.63 4047.09 2598.18 N 1573.42 E 6002629.65 N 567525.99 E 3.123 3015.09 9799.42 83.450 2.680 3980.11 4052.57 2647.51 N 1575.56 E 6002678.99 N 567527.71 E 1.139 3060.95 9844.93 83.070 2.440 3985.45 4057.91 2692.66 N 1577.58 E 6002724.16 N 567529.33 E 0.986 3102.95 9896.61 83.010 1.860 3991.72 4064.18 2743.92 N 1579.51 E 6002775.44 N 567530.80 E 1.120 3150.48 9942.08 83.260 1.650 3997.15 4069.61 2789.04 N 1580.89 E 6002820.57 N 567531.78 E 0.716 3192.19 - 10009.00 83.260 1.650 4005.01 4077.47 2855.47 N 1582.80 E 6002887.01 N 567533.11 E 0.000 3253.55 Projected Survey 21 August, 2003 - 14:06 Page 4 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08 MWD Your Ref: API 500292316800 Job No. AKMW0002567095, BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB. Northings and Eastings are relative to SHL. 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 SHL and calculated along an Azimuth of 24.240° (True). Magnetic Declination at Surface is 25.434°(22-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10009.00ft., The Bottom Hole Displacement is 3264.81ft., in the Direction of 29.000° (True). .~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5333.38 5350.00 10009.00 4004.82 4005.49 4077.47 1582.69 S 1577.85 S 2855.47 N 785.97 E 801.86 E 1582.80 E Tie On Point Window Point Projected Survey Survey tool proqram for MPS-OB MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) ...~ 0.00 823.00 0.00 823.00 822.47 10009.00 822.47 Tolerable Gyro (MPS-08PB1 Gyro) 4077.47 MWD Magnetic (MPS-08PB1 MWD) 21 August, 2003 - 14:06 Page 5 of 5 DrillQuest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS_08 PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 5,651.00' MD (if applicable) ') &03 '-J a3 22-Aug-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 2 9 2003 AlasK8 Œ~ & Gas Com;. CommiMion AI1ci1orøge Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-OBPB1 ~ Job No. AKZZ2567095, Surveyed: 28 July, 2003 Survey Report 21 August, 2003 Your Ref: API 500292316870 Surface Coordinates: 6000017.67 N, 565975.59 E (70024'37.7510" N, 149027'45.9888" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 1000017.67 N, 65975.59 E (Grid) Surface Coordinates relative to Structure: 45.93 N, 369.02 W (True) Kelly Bushing: 72.46ft above Mean Sea Level Elevation relative to Project V Reference: 72.46ft Elevation relative to Structure: 72.46ft srt=tr"r"Y-5U1'1 DRILLrNG ·--SERVlcefs A Halliburton Company Survey Ref: svy1250 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08PB1 Your Ref: API 500292316870 Job No. AKZZ2567095, Surveyed: 28 July, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Off) 823.00 4.800 196.000 750.01 822.47 17.39 S 2.54W 6000000.26 N 565973.20 E -16.90 AK-6 BP _IFR-AK 948.23 7.920 201.040 874.45 946.91 30.48 S 7.09W 5999987.13 N 565968.77 E 2.529 -30.70 1044.39 10.690 205.810 969.34 1041.80 44.70 S 13.35 W 5999972.86 N 565962.64 E 2.988 -46.24 1140.60 13.800 203.860 1063.35 1135.81 63.23 S 21.88 W 5999954.25 N 565954.27 E 3.261 -66.63 1236.05 16.500 204.710 1155.48 1227.94 85.96 S 32.15 W 5999931 .43 N 565944.20 E 2.838 -91.58 ~ 1332.08 20.840 200.460 1246.44 1318.90 114.36 S 43.83 W 5999902.92 N 565932.77 E 4.733 -122.27 1428.60 26.210 199.860 1334.90 1407.36 150.52 S 57.08 W 5999866.65 N 565919.84 E 5.569 -160.69 1524.83 29.030 201.470 1420.16 1492.62 192.25 S 72.85 W 5999824.79 N 565904.44 E 3.031 -205.21 1621.35 31.810 195.830 1503.40 1575.86 238.53 S 88.37 W 5999778.37 N 565889.33 E 4.126 -253.78 1716.10 29.690 201.290 1584.84 1657.30 284.44 S 103.70 W 5999732.33 N 565874.40 E 3.698 -301.93 1812.56 31 .940 206.880 1667.69 1740.15 329.47 S 123.92 W 5999687.12 N 565854.59 E 3.773 -351.30 1908.76 35.840 210.150 1747.54 1820.00 376.54 S 149.58 W 5999639.82 N 565829.34 E 4.474 -404.75 2005.36 34.840 209.350 1826.34 1898.80 425.05 S 177.31 W 5999591.07 N 565802.04 E 1.141 -460.37 2101.63 37.790 214.460 1903.92 1976.38 473.36 S 207.49 W 5999542.50 N 565772.29 E 4.388 -516.81 2197.35 43.360 217.330 1976.60 2049.06 523.71 S 244.05 W 5999491.82 N 565736.18 E 6.136 -577.73 2293.19 47.270 218.970 2043.99 2116.45 577.26 S 286.15 W 5999437.90 N 565694.55 E 4.257 -643.85 2389.12 48.700 218.810 2108.20 2180.66 632.74 S 330.90 W 5999382.03 N 565650.29 E 1 .496 -712.81 2484.70 50.1 00 219.280 2170.40 2242.86 689.10 S 376.61 W 5999325.27 N 565605.08 E 1.512 -782.96 2579.79 49.370 215.820 2231 .86 2304.32 746.60 S 420.83 W 5999267.38 N 565561.37 E 2.880 -853.55 2675.53 47.030 211.620 2295.69 2368.15 805.91 S 460.47 W 5999207.73 N 565522.25 E 4.082 -923.91 2724.57 46.220 210.830 2329.37 2401.83 836.39 S 478.95 W 5999177.08 N 565504.04 E 2.025 -959.29 2862.99 41.750 204.810 2428.98 2501.44 921.21 S 523.94 W 5999091.87 N 565459.80 E 4.419 -1055.10 2958.14 40.200 196.540 2500.87 2573.33 979.45 S 546.00 W 5999033.44 N 565438.27 E 5.924 -1117.26 .~ 3054.27 37.810 189.000 2575.61 2648.07 1038.34 S 559.45 W 5998974.43 N 565425.34 E 5.524 -1176.48 3150.90 35.740 182.650 2653.04 2725.50 1095.81 S 565.39 W 5998916.91 N 565419.90 E 4.477 -1231.32 3246.67 34.720 173.540 2731 .32 2803.78 1150.89 S 563.61 W 5998861.85 N 565422.17 E 5.585 -1280.82 3343.36 34.180 166.470 2811.08 2883.54 1204.68 S 554.16 W 5998808.14 N 565432.10 E 4.172 -1325.98 3439.16 35.930 158.630 2889.54 2962.00 1257.05 S 537.61 W 5998755.92 N 565449.11 E 5.039 -1366.94 3535.69 34.880 151.070 2968.26 3040.72 1307.60 S 513.92 W 5998705.58 N 565473.24 E 4.663 -1403.31 3631.63 33.700 145.870 3047.54 3120.00 1353.66 S 485.71 W 5998659.78 N 565501.85 E 3.291 -1433.72 3727.81 33.140 139.900 3127.84 3200.30 1395.87 S 453.80 W 5998617.85 N 565534.14 E 3.467 -1459.11 3824.70 34.890 130.790 3208.20 3280.66 1434.26 S 415.73 W 5998579.80 N 565572.54 E 5.556 -1478.49 3919.89 37.630 123.810 3284.98 3357.44 1468.23 S 370.95 W 5998546.22 N 565617.63 E 5.202 -1491.08 4015.79 41.1 00 119.590 3359.13 3431.59 1500.10 S 319.19 W 5998514.81 N 565669.67 E 4.568 -1498.89 4111.74 43.870 116.910 3429.88 3502.34 1530.73 S 262.10 W 5998484.68 N 565727.02 E 3.448 -1503.38 21 August, 2003 - 14:04 Page2of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08PB1 Your Ref: API 500292316870 Job No. AKZZ2567095, Surveyed: 28 July, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) e/100ft) 4208.71 48.280 115.170 3497.14 3569.60 1561.35 S 199.35 W 5998454.62 N 565790.04 E 4.728 -1505.53 4304.40 52.390 112.950 3558.21 3630.67 1591.33 S 132.09 W 5998425.24 N 565857.56 E 4.651 -1505.26 4400.43 53.900 108.890 3615.82 3688.28 1618.73 S 60.34 W 5998398.47 N 565929.55 E 3.730 -1500.79 4496.64 57.720 102.430 3669.92 3742.38 1640.09 S 16.24 E 5998377.79 N 566006.32 E 6.825 -1488.82 4593.05 62.000 97.250 3718.34 3790.80 1654.25 S 98.34 E 5998364.35 N 566088.54 E 6.424 -1468.03 ~ 4688.44 66.390 94.770 3759.86 3832.32 1663.20 S 183.72 E 5998356.15 N 566173.99 E 5.163 -1441.14 4785.01 68.650 91.350 3796.79 3869.25 1667.94 S 272.80 E 5998352.20 N 566263.12 E 4.023 -1408.89 4881.33 71.400 86.800 3829.70 3902.16 1666.45 S 363.28 E 5998354.49 N 566353.57 E 5.278 -1370.38 4977.21 74.580 84.080 3857.75 3930.21 1659.15 S 454.65 E 5998362.61 N 566444.88 E 4.284 -1326.20 5073.03 76.230 79.500 3881.91 3954.37 1645.89 S 546.40 E 5998376.67 N 566536.50 E 4.935 -1276.45 5168.73 76.100 76.200 3904.80 3977.26 1626.34 S 637.22 E 5998397.02 N 566627.15 E 3.351 -1221.33 5219.17 78.880 75.660 3915.73 3988.19 1614.37 S 684.98 E 5998409.41 N 566674.81 E 5.610 -1190.81 5272.82 80.200 74.650 3925.47 3997.93 1600.85 S 735.98 E 5998423.38 N 566725.68 E 3.079 -1157.55 5303.10 83.190 74.080 3929.84 4002.30 1592.78 S 764.83 E 5998431.71 N 566754.46 E 10.049 -1138.34 5333.38 87.280 73.550 3932.35 4004.81 1584.37 S 793.80 E 5998440.38 N 566783.36 E 13.619 -1118.78 5367.80 88.950 70.270 3933.49 4005.95 1573.69 S 826.50 E 5998451.35 N 566815.96 E 10.688 -1095.61 5398.54 89.070 69.030 3934.02 4006.48 1563.00 S 855.31 E 5998462.29 N 566844.68 E 4.052 -1074.04 5429.58 90.250 64.520 3934.20 4006.66 1550.76 S 883.83 E 5998474.78 N 566873.08 E 15.018 -1 051 . 17 5464.02 90.120 60.280 3934.09 4006.55 1534.81 S 914.34 E 5998491.00 N 566903.46 E 12.317 -1024.10 5495.25 90.560 56.120 3933.91 4006.37 1518.36 S 940.88 E 5998507.68 N 566929.85 E 13.395 -998.20 5525.56 91.730 52.760 3933.30 4005.76 1500.74 S 965.53 E 5998525.52 N 566954.34 E 11 .736 -972.02 5651.00 91.730 52.760 3929.51 4001.97 1424.86 S 1065.35 E 5998602.28 N 567053.48 E 0.000 -861.85 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 RKB. Northings and Eastings are relative to SHL. 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 SHL and calculated along an Azimuth of 24.240° (True). Magnetic Declination at Surface is 25.434°(22-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 5651.0Oft., The Bottom Hole Displacement is 1779.10ft., in the Direction of 143.215° (True). 21 August, 2003 - 14:04 Page 30f4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08PB1 Your Ref: API 500292316870 Job No. AKZZ2567095, Surveyed: 28 July, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5651.00 4001.97 1424.86 S 1065.35 E Projected Survey .~ Survey tool program for MPS-OBPB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 823.00 0.00 822.47 823.00 5651.00 822.47 Tolerable Gyro (MPS-08PB1 Gyro) 4001.97 AK-6 BP _IFR-AK (MPS-08PB1) .~ 21 August, 2003 - 14:04 Page 4of4 DrillQuest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ') &0:3 -íC)3 22-Aug-03 Re: Distribution of Survey Data for Well MPS_08 PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 5,651.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 2 9 2003 Alaska or: & Gas Cons. Commilekm Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-OBPB1 MWD -' Job No. AKMW0002567095, Surveyed: 28 July, 2003 Survey Report 21 August, 2003 Your Ref: API 500292316870 Surface Coordinates: 6000017.67 N, 565975.59 E (70024' 37.7510" N, 149027' 45.9888" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~' Surface Coordinates relative to Project H Reference: 1000017.67 N, 65975.59 E (Grid) Surface Coordinates relative to Structure: 45.93 N, 369.02 W (True) Kelly Bushing: 72.46ft above Mean Sea Level Elevation relative to Project V Reference: 72.46ft Elevation relative to Structure: 72.46ft sr....' ......y-5iLJr1 DR 1 a...: L'I NG "'SER,,\,rc:es A Halliburton Company Survey Ref: svy1251 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08PB1 MWD Your Ref: AP/500292316870 Job No. AKMW0002567095, Surveyed: 28 July, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) e/100ft) 823.00 4.800 196.000 750.01 822.47 17.39 S 2.54W 6000000.26 N 565973.20 E -16.90 MWD Magnetic 948.23 7.920 201.720 874.46 946.92 30.44 S 7.18W 5999987.16 N 565968.68 E 2.539 -30.71 1044.39 10.690 206.520 969.34 1041.80 44.58 S 13.62 W 5999972.97 N 565962.37 E 2.989 -46.24 1140.60 13.800 204.390 1063.35 1135.81 63.02 S 22.34 W 5999954.46 N 565953.81 E 3.266 -66.64 1236.05 16.500 205.900 1155.48 1227.94 85.59 S 32.97 W 5999931.80 N 565943.38 E 2.859 -91.57 ~ 1332.08 20.840 201.160 1246.44 1318.90 113.80 S 45.09 W 5999903.48 N 565931.50 E 4.784 -122.28 1428.60 26.210 200.680 1334.90 1407.36 149.78 S 58.83 W 5999867.38 N 565918.09 E 5.567 -160.72 1524.83 29.030 202.120 1420.16 1492.62 191.30 S 75.13 W 5999825.72 N 565902.15 E 3.011 -205.28 1621.35 31.810 196.430 1503.40 1575.86 237.41 S 91 .15 W 5999779.46 N 565886.54 E 4.145 -253.90 1716.10 29.690 201.850 1584.84 1657.30 283.16 S 106.95 W 5999733.58 N 565871.14 E 3.681 -302.10 1812.56 31. 940 207.150 1667.69 1740.15 328.05 S 127.49 W 5999688.51 N 565851.00 E 3.654 -351.47 1908.76 35.840 210.370 1747.54 1820.00 375.01 S 153.35 W 5999641 .32 N 565825.55 E 4.462 -404.91 2005.36 34.840 210.110 1826.34 1898.80 423.28 S 181.50W 5999592.80 N 565797.84 E 1.047 -460.48 2101.63 37.790 214.700 1903.92 1976.38 471.34 S 212.09 W 5999544.48 N 565767.67 E 4.165 -516.86 2197.35 43.360 217.230 1976.60 2049.06 521.66 S 248.70 W 5999493.84 N 565731.51 E 6.067 -577.77 2293.19 47.270 218.230 2043.98 2116.44 575.53 S 290.41 W 5999439.60 N 565690.28 E 4.147 -644.01 2389.12 48.700 218.260 2108.19 2180.65 631.50 S 334.53 W 5999383.24 N 565646.66 E 1.491 -713.16 2484.70 50.100 219.180 2170.39 2242.85 688.11 S 379.92 W 5999326.23 N 565601.76 E 1.637 -783.43 2579.79 49.370 215.880 2231.86 2304.32 745.63 S 424.12 W 5999268.32 N 565558.07 E 2.757 -854.02 2675.53 47.030 211.750 2295.68 2368.14 804.88 S 463.86 W 5999208.73 N 565518.86 E 4.038 -924.36 2724.57 46.220 210.750 2329.36 2401.82 835.35 S 482.35 W 5999178.09 N 565500.63 E 2.219 -959.74 2862.99 41.750 205.640 2428.96 2501.42 919.91 S 527.88 W 5999093.13 N 565455.85 E 4.121 -1055.53 2958.14 40.200 197.170 2500.86 2573.32 977.86 S 550.68 W 5999034.98 N 565433.57 E 6.056 -1117.73 .~ 3054.27 37.810 189.520 2575.60 2648.06 1036.60 S 564.72 W 5998976.12 N 565420.05 E 5.588 -1177.06 3150.90 35.740 182.970 2653.02 2725.48 1094.03 S 571.08 W 5998918.64 N 565414.19 E 4.586 -1232.03 3246.67 34.720 173.750 2731.31 2803.77 1149.11 S 569.56 W 5998863.57 N 565416.20 E 5.650 -1281.64 3343.36 34.180 166.770 2811.07 2883.53 1202.95 S 560.34 W 5998809.82 N 565425.89 E 4.120 -1326.94 3439.16 35.930 158.760 2889.53 2961.99 1255.37 S 543.99 W 5998757.54 N 565442.71 E 5.134 -1368.03 3535.69 34.880 151.170 2968.25 3040.71 1305.98 S 520.41 W 5998707.15 N 565466.74 E 4.681 -1404.49 3631.63 33.700 145.870 3047.53 3119.99 1352.05 S 492.24 W 5998661.32 N 565495.31 E 3.345 -1434.94 3727.81 33.140 139.860 3127.83 3200.29 1394.25 S 460.31 W 5998619.41 N 565527.61 E 3.489 -1460.31 3824.70 34.890 130.640 3208.19 3280.65 1432.57 S 422.18 W 5998581 .42 N 565566.08 E 5.616 -1479.60 3919.89 37.630 123.770 3284.97 3357.43 1466.48 S 377.34 W 5998547.92 N 565611.22 E 5.145 -1492.10 4015.79 41 .100 119.550 3359.12 3431.58 1498.31 S 325.56 W 5998516.54 N 565663.28 E 4.568 -1499.87 4111.74 43.870 117.040 3429.87 3502.33 1528.99 S 268.49 W 5998486.37 N 565720.61 E 3.384 -1504.42 21 August, 2003 - 14:05 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08PB1 MWD Your Ref: API 500292316870 Job No. AKMW0002567095, Surveyed: 28 July, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured 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) C/100ft) 4208.71 48.280 115.250 3497.13 3569.59 1559.728 205.80 W 5998456.19 N 565783.57 E 4.738 -1506.70 4304.40 52.390 113.680 3558.20 3630.66 1590.19 S 138.76 W 5998426.32 N 565850.88 E 4.477 -1506.96 4400.43 53.900 109.570 3615.81 3688.27 1618.478 67.35 W 5998398.67 N 565922.54 E 3.768 -1503.42 4496.64 57.720 103.230 3669.90 3742.36 1640.82 8 8.95 E 5998376.99 N 565999.03 E 6.741 -1492.48 4593.05 62.000 97.020 3718.33 3790.79 1655.37 8 90.96 E 5998363.17 N 566081.17 E 7.120 -1472.07 -" 4688.44 66.390 95.020 3759.85 3832.31 1664.34 8 176.34 E 5998354.95 N 566166.63 E 4.974 -1445.20 4785.01 68.650 91.670 3796.78 3869.24 1669.53 S 265.40 E 5998350.55 N 566255.73 E 3.968 -1413.37 4881.33 71.400 85.590 3829.71 3902.17 1667.328 355.84 E 5998353.56 N 566346.14 E 6.583 -1374.23 4977.21 74.580 84.020 3857.76 3930.22 1659.01 8 447.13 E 5998362.67 N 566437.36 E 3.668 -1329.17 5073.03 76.230 78.920 3881.92 3954.38 1645.25 8 538.80 E 5998377.25 N 566528.90 E 5.431 -1278.98 5168.73 76.100 75.920 3904.81 3977.27 1625.01 S 629.48 E 5998398.28 N 566619.40 E 3.047 -1223.30 5219.17 78.880 74.950 3915.73 3988.19 1612.63 S 677.13 E 5998411.09 N 566666.94 E 5.822 -1192.44 5272.82 80.200 74.650 3925.47 3997.93 1598.798 728. 04 E 5998425.37 N 566717.73 E 2.521 -1158.93 5303.10 83.190 74.550 3929.84 4002.30 1590.84 S 756.93 E 5998433.58 N 566746.54 E 9.880 -1139.82 5333.38 87.280 74.120 3932.36 4004.82 1582.69 8 785.97 E 5998441.98 N 566775.51 E 13.581 -1120.46 5367.80 88.950 70.270 3933.49 4005.95 1572.178 818.72 E 5998452.79 N 566808.17 E 12.186 -1097.43 5398.54 89.070 67.620 3934.02 4006.48 1561.13S 847.40 E 5998464.08 N 566836.75 E 8.628 -1075.59 5429.58 90.250 65.030 3934.21 4006.67 1548.678 875.83 E 5998476.80 N 566865.06 E 9.169 -1052.55 5464.02 90.120 60.770 3934.10 4006.56 1532.99 8 906.48 E 5998492.75 N 566895.57 E 12.375 -1025.67 5495.25 90.560 56.860 3933.91 4006.37 1516.828 933.19 E 5998509.15 N 566922.14 E 12.599 -999.96 5525.56 91 .730 53.520 3933.30 4005.76 1499.528 958.07 E 5998526.67 N 566946.86 E 11.674 -973.97 5651.00 91 .730 53.520 3929.52 4001.98 1424.98 S 1058.88 E 5998602.10 N 567047.02 E 0.000 -864.61 Projected 8urvey --- All data is in Feet (U8 8urvey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB. Northings and Eastings are relative to 8HL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (U8 8urvey). Vertical 8ection is from SHL and calculated along an Azimuth of 24.240° (True). Magnetic Declination at Surface is 25.434°(22-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 5651.00ft., The Bottom Hole Displacement is 1775.33f1., in the Direction of 143.384° (True). 21 August, 2003 - 14:05 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-08PB1 MWD Your Ref: API 500292316870 Job No. AKMW0002567095, Surveyed: 28 July, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5651.00 4001.98 1424.98 S 1058.88 E Projected Survey --- Survey tool program for MPS-OBPB1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 823.00 0.00 822.47 823.00 5651.00 822.47 Tolerable Gyro (MPS-08PB1 Gyro) 4001.98 MWD Magnetic (MPS-08PB1 MWD) -~/ 21 August, 2003 - 14:05 Page 4 of 4 DrillQuest 3.03.02.005 ) ') t)03 --/:9 3 ~ IlZL/óZ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 33 3 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 August 28, 2003 RE: MWD FOffi1ation Evaluation Logs MPS-08, AK-MW-2567095 1 LIS fOffi1atted Disc with verification listing. API#: 50-029-23168-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. i\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: ?5 iye¡-Q3 Sign;t~Ç\~~.~~ RECEIVED AUG 2 9 2003 Aja~~8 '::If: & Gas CAîfìS. C\~OO~ ,~dlCfttge ~~~rY\~ ) ) !Jæ- Jé)3 ~·'18Lf3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation CorruTI. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 28, 2003 RE: MWD Formation Evaluation Logs l\1PS-08 PB 1, AK-MW-2567095 1 LIS formatted Disc with verification listing. API#: 50-029-23168-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: ~"cYq -08 Signed*\~~~ RECEIVED AUG 29 2003 Ala!ka Of: & Ca8l~n£. CŒnm~ .J\nQh~ RE: MPS-08 ) Subject: RE: MPS-08 Date: Mon, 14 Jul2003 10:40:42 -0500 From: "Green, Matt D" <GreenMD@BP.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, You are absolutely correct. The top of cement for the production casing should be 3,664-ft MD (500-ft above the top Ugnu). Good catch. Hope all is going well. Cheers, Matt. -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl Sent: Friday, 11 July 2003 3:56 PM To: Green, Matt D Subject: MPS-08 Matt, I was looking at MPS-08 and had a question. For your production casing cement you indicate a planned TOC of 5900' md. This is below the casing setting depth. Would you check on this. Based on the formation tops you give in the table on the next page, I think the TOC should be somewhere around 3660'. Thanks. Tom Maunder 1 of 1 7/14/20037:51 AM ) ') FRANK H. MURKOWSKI, GOVERNOR A1tASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH 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 1\1PS-08 BP Exploration (Alaska) Inc. Permit No: 203-123 Surface Location: 3349' NSL, 35' WEL, SEC. 12, T12N, R10E, UM Bottomhole Location: 1478' NSL, 3267' WEL, SEC. 06, T12N, RIlE, 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 trom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ¡Çd- ~~ Randy ~edrich Commissioner BY ORDER ~¥ THE COMMISSION DATED this r day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section Hole 42" 13-1/2" 9-7/8" 6-1/8" ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory a Stratigraphic Test B Development Oil o Service 0 Development Gas []J Single zone....Jþ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 72' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380110 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-08 9. Approximate spud date July 24, 2003 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10573' MD / 4007' TVD o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Maximum surface 1313 psig, At total depth (TV D) 3930' / 1706 psig Setting Depth T of Bottom MD TVD MD TVD Surface Surface 112' 112' Surface Surface 2769' 2442' Surface Surface 5225' 3993' 5125' 3978' 10573' 4007' ky~ 1 a. Type of work B Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 565976, Y = 6000018 3349' NSL, 35' WEL, SEC. 12, T12N, R10E, UM At top of productive interval x = 566850, Y = 5998450 1773' NSL, 3962' WEL, SEC. 07, T12N, R11E, UM At total depth x = 567480, Y = 6003440 1478' NSL, 3267' WEL, SEC. 06, T12N, R11E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL380109, 1500' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 550' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weiaht Grade COUDlina 20" 92# H-40 Weld 10-3/4" 45.5# L-80 BTC 7-5/8" 29.7# L-80 BTC 4-1/211 12.7# L-80 BTC 91 Lenath 112' 2769' 5225' 5448' Quantity of Cement (include staae data) ,260 sx Arctic Set (Approx.) 504 sx Class 'L', 261 sx Class 'G' 402 sx Class 'G' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition. summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Su rface Intermediate Production Liner F) Ir=~' E '\\¡¡,-C JUL 1 0 ?"":1 Perforation depth: measured true vertical i~;3Sk;Ej Oil & G3$ Cor: fmchor8L,:} 20. Attachments B Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report B 20 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Green, 564-5581 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the fop.oing is true and c~rrect to the best of my knowledge . Signed Pat Archey ,~ (" L (":-tv Title Senior Drilling Engineer . .... ,':;'I,',' ......"',·...;_:¡,·::::,¿:\/,:·.}f:~/i¡!·)/::..~tg·iP~~$tÞÞif._.,:Qíllr::,\··:>i:'?',:,'~::;·S~,:¡.':'··:: /,.. I Permit Number ..., ~ API Numb~ ~ S2/ / 6 .~ 7~~ro~a'Pate See cover letter 2.63 -I ~ 50- 02-," - L..--J fo Õ -~ /' !'¡ D3 for other reauirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes Øo Hydrogen Sulfide Measures 0 Yes ~No Directional Survey Required ~Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: ~~s,,\Sa\>·~~ ,('3 I ?y order of Approved By {~Á /: ~ ~ \ 0 art~~N ^ ~he commission Form 10-401 Rev. 12-01-81 r(rOl Date -¡ //CJ/o 3 Date 711~~3 Submit In Triplicate ) ) Milne Point MPS-08 Well Permit IWell Name: I MPS-08 Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Single Lateral Producer "NB" Surface Location: 19311 FNL, (33491 FSL);351 FE~' (52451 FWL), SEC. 12, T12N, R1 O~" E=565975.59 N=60000~ 7.67 3506' FNL, (17731 FSL-r;" 3962' FEL, (8261 FWL), SEC. 7, T12N, R11 E /' E=566850 N=5998450 Z=3930' TVDss 3802' FNL, (14781 FSL1; 3267' FEL;(15001 FWL), SEC. 6, T12N, R11 E ,,' E=567480 N=6003440 Z=3935' TVDss Target Location: TOP "NB" Target Location: BHL "NB" Well TD I AFE Number: I I Estimated Start Date: 124 Jul2003 I MD: 110,573 I I TVD: 14,007 I I Rig: I Doyon 14 I OperatinQ days to complete: 113.3 1 Max Inc: 191 I I KOP: 1550 1 1 KBE:172 Well Design (conventional, slim hole, etc.): Conventional Grass Roots Lateral ./ Producer I Objective: I Schrader NB Sand / Mud Program: 13-1/2" Surface Hole Mud Properties: Density (ppçJ) Funnel visc YP HTHP 8.6 - 9.0 75 -150 25 - 60 N/A Spud - LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.5 < 8 < 12 9-7/8" Intermediate Hole Mud Properties: Density (pPQ) Funnel visc YP HTHP 9.0 - 9.3 75 -150 25 - 60 N/A LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 6.125-in Production Hole Mud Properties: KCL-CaC03 Flo-Pro Density (ppQ( Funnel visc YP HTHP pH API Filtrate LG Solids 8.6 - 10.0 40 - 55 22 - 27 <10 8.0 - 8.5 4 - 6 < 8 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 ) ) Milne Point MPS-08 Well Permit Cement Program: Casin~ Size 110-3/4" 45.5-lb/ft L-80 BTC Surface Casing Basis 175% excess over gauge hole in permafrost interval 400/0 excess over gauge hole below permafrost Total Cement Volume: 427 -bbl Wash 20-bbl water Spacer 50-bbl 10.2-lb/ÇJal Alpha Spacer Lead 373-bbl, 504-sx 10.7 Ib/gal Class L - 4.15 ft~/sx (cement to surface) Tal 54-bbl, 261-sx 15.8 Ib/gal Prem G - 1.15 fe/sx , .........1......... .................... ..... .......~..m (!~E~~!~il?~?,?~~=!~ ~.º~........mm..................... ............ ....... .......... ..... ........... ............... ....u ....... .................. .....m .m. .. n;¡t'Ä~.~::"».>~,:~~$:::J:,:,:,:,~~:''',:,:,:,:~,r,_<mM.:,:,:,~¥f'::~:{.~4~~~,Wï4:::::~é~~::~~::,::¡:~~~~.~::¡:*%~:~:;K:::~<,~~:~,:~~~j.g,::i@,~~~~~ý¡m.:x_.~~~dGm:~!%,,~,:,r%%i_~~~::_:::::;~~,~~:~"~<\\!:;,~~~~~::~:,~~~~~:,~::.<::i:~:::',:,:,:~,~,M:':(':,~:,Û_¡;;:M::::~:~:~::,:iM::f,w¡*:~;:~i(~~,::~~, Temp BHST ~ 55°F from SOR, BHCT 60°F estimated by Halliburton Casin~ Size 17-5/8 29.7-lb/ft L-80 BTC Intermediate Casing Basis 400/0 excess over gauge hole. Lead 500-ft MD above top of Ugnu. Total Cement Volume: 88-bbl Wash 5-bbl water S acer Lead 30-bbI10.2-lb/. al AI ha S acer AI ha 87-bbl, 402-~15: al Prem G -1.22 ft /sx (top of lead t - ~ <o~ '-{ · 'P<t' Q. ~\\ ~ 1\ BHST "'.80° (om son, HCT 70°F estimated by m--<rf'!\ Halliburton Temp 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 IFRlCASANDRA Cased Hole: N/A 6-1/8"Section Open Hole: MWD/GRlRESrABl/PWD IFRlCASANDRA 2 ') ) Milne Point MPS-08 Well Permit Formation Markers: Formation Tops Base Permafrost Top UQnu Middle UQnu NA NB MDrkb (ft) 1910 4164 4661 5115 5392 TVDrkb (ft) 1822 3547 3832 3977 4002 Pore Pressure Estimated EMW (psi) (Ib/gal)* 1509 1633 1696 1706 8.35 8.35 8.35 8.35 / CasingITubing Program: Hole Csg/ WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Weld 112' 0 112-ft / 112-ft 13-1/2" 1 0-3/4" 45.5# L-80 BTC 2769' 0 2769' / 2442' 9-7/8" 7-5/8" 29.7# L-80 BTC 5225' 0 5225' / 3993' 6-1/8" 4-1/2" 12.7# L-80 BTC 10573' 5125' / 3978' 10573'/4007' NB *The 20" casing is insulated Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13-1/2" 0-2,769' M ill tooth 3-15 & 1-1 0 2 9-7/8" 2,769 - 5,225' M ill tooth 3-15 & 1-1 0 3 6-1/8" 5,225' - TD Secu rity 3-12 FM2643 3 -) ) Milne Point MPS-08 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. Intermediate and Production Intervals · Planned completion fluid: 1,706-psi @ 3,930-ft TVDss - Top of NB-sand 1 ,313-psi @ surface (Based on BHP and a full column of gas from TD @ 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 3,500-psi high. An FIT to 11 .5-lb/gal will be made on the 7-5/8" casing shoe. 62.2-bbl with 9.2-lb/gal mud and FIT of 11.5-lb/gal @ 10-3/4" casing shoe. 9.2-lb/gal NaCI I 6.8-lb/gal Diesel · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Integrity test: · Kick tolerance: Drilling Hazards & Contingencies: Hydrates · Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+1- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Pretreat 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 item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). 4 ') ') y Milne Point MPS-08 Well Permit Pad Data Sheet · Please read the S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults · A 90-ft DTW fault is predicted in the Ugnu at 4380-ft MD. · Multiple small (5 to 35-ft) faults are predicted in the NB lateral. Hydrogen Sulfide · MPS Pad is not designated as an H2S Pad. Anti-collision Issues · MPS-12 must be minor risk based at 1 :200 to pass anti-collision issues. 5 ) ") Milne Point MPS-08 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 as per directional plan. 3. Case and cement 1 0-3/4" surface casing. 4. ND diverter, NU BOPE and test. 5. Perform FIT. 6. Drill 9-7/8" hole to land in top of the NB-sand as per directional plan. 7. Case and cement 7-5/8" intermediate casing. Freeze protect 7-5/8" x 10-3/4" annulus. 8. Drill out shoe and 20-ft new formation and perform FIT. 9. Drill 6-1/8" NB-sand lateral as per directional plan. 10. Run 5" uncemented sand screens and hang off 100-ft inside 7-5/8" casing. 11. Displace drilling mud to brine. 12. Run 4-1/2" jet pump completion as per schematic. 13. Land tubing hanger and test. 14. Set BPV. 15. ND BOP. 16. I nstall and test tree. 17. Pull BPV. 18. Test 7-5/8" x 4-1/2" annulus. 19. Freeze protect thru GLM. 20. Install BPV and secure well. 21. RD/MO. 6 yHOt-.O~I:=LJ COMt-'LI:= Ilor .-Q,1 jæl~ 20" 92 Ibltt, H-40 Welded /f(:- ~:; Insulated Diesel Freeze protect to 500' MD TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 6 11 ", 5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger 1121 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collapse: 2,480 psi 9.7-lblgal NaCI with corroa;o/ inhibitor as packer fluid Jet Pump Installed in Sliding Sleeve Post rig! 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi 7.625" Casing Shoe @ 5,225' MD; 3,993' TVD Well Inclination @ Shoe = 84 Degrees DATE REV. BY COMMENTS ~ ~III ') KB. ELEV =72.0' Cellar Box ELEV = 38.6' .. 42" Hole 4-1/2" x 1" Gas Lift Mandrel @ 2,200' MD; 2,045' TVD, 13-1/2" hole 4-1/2",12.6 Ib/tt, L-80, IBT-M Coupling aD: 5.2" Drift/ID: 3.833" Burst: 8,430, 80% 6,744 psi Collapse: 7.500. 80%=6.000 psi .... 10-3/4"@ 2,769' MD, 2,442' TVDrkb 'BIW 1- Wire Phoenix Pressure Gauge (3.850" 10, W/BIW 1- wire down to lower sensor) Phoenix Pressure Gauge (2.840" 10) 7-5/8" x 4-1/2" Premier Packer ISet @ 5,000' MD 3-1/2" HES 'XN' nipple 2.750" 10 No Go W/RHC ball & rod Wireline Entry Guide 9-7/8" Hole ~ 5" Sand Screen Liner W/Baker HR-ZXP liner hanger --- - - - - - - - - - - -- NB Horizontal 6-1/8" hole 110,573' MD/4,007' TVD 1 Milne Point Unit WFI I : MPS-08 API NO: BP Exploration (Alaska) I I I r I I /... I I I r I I r __I I . L I I r I I ~ I I Q I ~~~~ J / x;:J'Q. .-- _T_ - - _T_ - - _T_ - - _T_ J , ~ / -.., NOTES: 1. DATE OF SURVEY: JANUARY 3-4, 2003. 2. REFERENCE FIELD BOOK: MP03-01 PAGES 01-11. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. S f !I Î ~ f t j -34 -33 -31i -29i _27 _25 _24i -23 -21i _19i _17 _15i _13i _ 11 MPS-08f9i MP~6 7i MPS-04 5__ 3 _2 _ 1 ) I I ~ I I J I I I 1 I I ~ I I J .l SteT - - - 1- ---.. ::::-:..:.. 12 TI2 II SteT "1' . '!' RIOt TI2N, R7¡f- . . I I I ~ 22 21 I - Z-c!Jlla I 30 SlE 29 28 PLANT ) 15·00'00" GRID - . 34 ··...i-PAD T13N T12N 2 35 3r~ 32 33 " . ~ '.~1 6 5 PROJECT~ S-PAD I~ 12 7 8 9 10 MPU S-PAD 11 Ww 13 ~;: 18 c::c:: LEGEND 14 17 16 15 4- . AS-BUILT CONDUCTOR EXISTING CONDUCTOR VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 04, 2003. LOCATED WITHIN PROTRACTED SEC. 7, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINA TES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-04 Y=6,OOO,033.25 N= 2,236.82 70·24'37.899" 70.4105275· 38.3' 3,364' FSL X= 566,033.83 E= 6,914.48 149·27'44.278" 149.4622994· 4,758' FEL LOCATED WITHIN PROTRACTED SEC. 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-06 Y= 6,000,025.19 N= 2,236.71 70·24'37.822" 70.4105061· 38.5' 3,357' FSL X= 566,004.15 E= 6,883.72 149·27'45.150" 149.4625417" 6' FEL MPS-08 Y=6,OOO,017.67 N= 2,236.84 70·24'37.751" 70.4104864· 38.6' 3,349' FSL X= 565,975.59 E= 6,854.18 149·27'45.989" 149.4627747" 35' FEL ~ ~ t I " ! § t ~ 1 ì 0 1/12/03 ISSUED fOR INfORMAl1ON ~ NO. DATE REVISION F. ROb' DRAWN: Obp COTTON 1 -- . CHECKED: AWSON 11 "".: DATE: 12/11/02 DRAWING: MILNE POINT UNIT S-P AD FRB03 MPS 01-00 SHEET: 1 ffi~~[JJ[t;o JOB NO: SCALE: AS-BUILT CONDUCTORS JJC RFA (HCNDtS AND LAND SI.IR'tEYORS WELLS MPS-04, MPS-06 & MPS-08 1 Of 1 801 ¥lEST FÆ'IUD LAN( 1"= 160' BY CHK ANCHOAACt. N..Jt3(A "~ CÜJl,WANY DETAILS REFERENCE INF01U.l,'\110N BP AmQÇO CASING DETAILS No. TVD MD Name Size I 2442.00 2768.49 103/4" 10.750 2 3992.88 5225.18 7" 7,625 3 4007.00 10572.51 4112" 4.500 FORMATION TOP DETAILS No, TVDPath MDPath Formarion I 3977.00 511530 SBF2-NA 2 3997,00 5268.60 NAMF 3 4002.00 5392.27 SBFI-NB 4 4007.00 10572.51 SBFl-NBR Start Dk 15°/100' : 550' MD. 550'TVD / Start Dj, 3'tJOO' : 683.33' MD. 683.3'TVD 1000 '¡:¡' ~ Co Co Ë "" & ~ 2000 " '€ " > ~ Start Dir 5.09'/[00': 1666.67' MD, J6J4,67"TVD EndDir: 1827J5'MD, 1750.2'TVD StartDir45'/100': 194827' MD, J850.J9'TVD ': 2656,76' MD, 2361.89'TVD 3000 400G -2GGG -IOGG o lOGO 2000 Vertical Section at 24.24' [WOOft/in] SURVEY PROGRAM Pian: MPSc-()8 wpO& (Nan MPS-08iPlan Mf'$-08J O'-"ptJ¡ I'm Ikpth Tü $urv"y!Plan h'(l1 Üemoo By; Kio'il AHeu D¡:l1e; 611712003 Date: Date: 3.tüO IOOO.{)) WOO,OO 1057251 "Irw.wv WELL DETA1LS NaUl<: -'fi-W Northing E<I$Üug Latitude Lo¡:¡gimd.v Slot P!¡¡uM1'$·08 43JJ7 -36930 60oo017J8 565975.37 7(f'24'37J52N i49Q27'45.995W NiA TARGET DETAILS N¡¡¡n;, Northing Ea~1i¡¡g Simp;: SECTION DETAILS Sec MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSec I 33,00 O.GG 0.00 33.0G 0.00 0,00 0.00 0,00 G.OO 2 550,00 0,00 0,00 550.00 0,00 0,00 0.00 0,00 0.00 3 683.33 2,00 200.00 683.30 -2,19 -0,80 1.50 200.00 -232 4 1616,67 30.00 200.00 1571.59 -241.54 -87,91 3.00 0.00 -25633 5 1666,67 31.00 200,00 1614,67 -26538 -96,59 2.00 360,00 -281.64 6 1827.35 34,21 214.00 1750.20 -341.85 -136,07 5,09 72.94 -367.57 7 1948.27 34,21 214,00 1850.19 -398.21 -J74,09 0,00 0.00 -434.58 8 2204.47 45,73 214,69 2046.20 -533,82 ,266,89 4.50 2.47 -59633 9 2656.76 45,73 214.69 2361.89 ,800.14 ,45L23 0.00 0.00 ,9J4,85 10 5392,27 90,00 75,00 4002.00 ,1575.59 860,83 4.50 ,129.44 -1083.27 ¡¡ 5412,27 90,00 75,00 4002,00 -1570.42 880,15 0,00 0,00 -1070,62 12 6039,65 90.56 359,72 3998,39 -1106,86 1234,03 12.00 -89.42 -502,64 13 6692,83 90.56 359,72 3992,00 -453,71 1230.79 0,00 0.00 91.59 14 6826,61 89.2J 7.63 3992,27 -32032 1239.35 6,00 99,67 216.74 15 7541.41 89.21 7,63 4002.11 388,09 1334.22 0,00 0,00 901.64 16 7574,06 9L17 7.53 4002,00 420.45 133852 6.00 -2.72 932.92 17 8309,81 91.17 7.53 3987,00 1149,70 1434,98 0.00 0,00 1637.47 18 8368.73 89.65 4,34 3986.58 1208.29 1441.07 6.00 -115.41 1693.40 19 9257.18 89,65 4.34 3992,00 2094.18 1508.33 0.00 0,00 2528.80 20 9311.58 89.34 1.09 3992.48 2148.50 1510,91 6.00 -95.47 2579,39 21 10572.5 J 89.34 1.09 4007,00 3409.12 1534,95 0.00 0,00 3738,74 Target MPS-08 TI Wp 7 MPS-08 T2 Wp 7 MPS-08 T3 Wp 7 MPS-08 T4 Wp 7 MPS-08 T5 Wp 7 MPS-08 T6 Wp 7 MPS-08 wp08 3000 I I I 4000 I ¡ ¡ ! ¡ ¡ ¡ COMPAJ~\' DETAILS REFERENCE INFtìRMATJON SURVEY PROGRAM Plan: MPS-Q8 wp08 œlM MP$·OS/Plan MP.s~08) BPAm';><.:<> );..>pth Fm DJ,;'Ptl1 T~1 SurveyiT'b\n 1'\)oJ Created By: Ken AlJen ('hí..'Ç.ki;'d~ R;;::vk-wed: DJ;ìI~~; 6Jt7/2003 33.00 WOO.OO lOOOJ){J W5725J Date: N<¡tW -Ni8 ~Ei·W Northing EMling. Latirmk {.oJ1.gitmk Slo! PI\J.I1MI'S·(J8 43J!7 ~3693() 6()OOOj7.78 56597537 7(P24'37,752N J49Q2T45.995W NfA 5000- TARGET DETAilS Nartk.' TV!) ~NÍ'.s: -òEf·W NMhiug l~s\Íug Sbapi;1" 4000- SECTION DETAJLS Sec MD me Azi TVD +N/-S +E/-W DLeg TFace VSec Target , MPS-08 wp08 J 33,00 0,00 0.00 33,00 0,00 0,00 0,00 0,00 0,00 2 550,00 0,00 0,00 550,00 0,00 0.00 0,00 0,00 0,00 3 68333 2,00 200,00 683.30 -2.19 -0.80 150 200,00 -2.32 4 16J6,67 30,00 200,00 J571.59 -241.54 -87,9J 3,00 0.00 -256.33 5 J666.67 31.00 200,00 J6J4,67 -26538 -9659 2.00 360.00 ·281.64 6 J82735 34.21 2J4,00 J 750,20 -341.85 -136.07 5,09 72.94 -36757 7 1948.27 34.2J 2J4,OO 1850,J9 -39JUI -J74,09 0,00 0,00 -43458 3000 8 2204.47 45.73 2J4.69 2046,20 -533,82 -266.89 450 2.47 -596.33 9 2656,76 45,73 214,69 2361.89 -8QOJ4 -451.23 0,00 0,00 -9J4,85 10 ~~li~i 90.00 75,00 4002,00 -157559 860,83 4,50 -129.44 -1083,27 MPS-08 TJ Wp 7 11 90,00 75,00 4002,00 -1570.42 880,15 0.00 0,00 -J070,62 12 6039.65 90.56 359,72 3998.39 -[j06,86 1234.03 J2,00 -89.42 -502,64 13 6692.83 90.56 359,72 3992,00 -453,71 J230,79 0,00 0,00 91.59 MPS-08 T2 Wp 7 J4 6826.6 I 89,21 7,63 3992.27 -32032 1239.35 6,00 99,67 216,74 : 931 1.58' MD, 3992.48' TVD J5 7541.41 89.21 7.63 4002.11 388.09 1334.22 0,00 0,00 901.64 16 7574,06 91.l7 7.53 4002.00 420.45 1338.52 6,00 -2.72 932,92 MPS.Q8 T3 Wp 7 'is' : 9257.18' MD, 3992TVD 17 8309.81 91.l7 7.53 3987,00 IJ49,70 1434,98 0.00 0,00 1637.47 MPS.Q8 T4 Wp 7 ~ 7 18 8368,73 89.65 4.34 398658 1208.29 1441,07 6.00 -IJ5AJ 1693.40 g 2000 19 9257.l8 89.65 4.34 3992,00 2094,18 1508.33 0,00 0,00 2528.80 MPS-08 T5 Wp 7 S 20 931 U8 89.34 1.09 3992A8 2148.50 1510.91 6.00 -95.47 2579.39 ±: 21 10572.51 89.34 1.09 4007,00 3409,12 1534,95 0,00 0,00 3738,74 MPS-08 T6 Wp 7 ~ ~ CASlNG DETAILS FORMA nON TOP DET AJLS :E: ':5 No, TVD MD Name Size No, TVDPath MDPath Formation 0 '" 1000 1 2442.00 2768.49 103/4" 10,750 1 3977.00 5115.30 SBF2-NA 2 3992.88 5225,18 7" 7,625 2 3997,00 5268,60 NAMF 3 4007.00 10572,51 4 Jl2" 4.500 3 4002,00 5392.27 SBn -NB 4 4007,00 10572.51 SBFI·NBR : 7574.06" MD, 4002' TVD , 6QII00': 7541.41' MD, 4002,1 I'TVD 08 T3 Wp 7 0 : 6826,61' MD, 3992.27' TVD 6"/100' ; 6692,83' MD, 3992TVD T2 Wp 7 -1000 : 6039.65' MD, 399839' TVD Dir 12°/100': 5412.27' MD, 4002'TVD End Dir : 5392,27' MD, 4002' TVD -2000 -2000 -1000 o 1000 West(-)/East(+) [IOOOftlinJ , I I 2000 ¡ ¡ ¡ I 1 ¡ I I I I 3000 [ ! t I j ¡ I I I ' 4000 I I I ! ') ) BP KW A Planning Report MAP m· Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: M pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-08 Slot Name: Well Position: +N/-S 43.07 ft Northing: 6000017.78 ft Latitude: 70 24 37.752 N +E/- W -369.30 ft Easting : 565975.37 ft Longitude: 149 27 45.995 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-08 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: S-Pad Dev Height 72.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/29/2001 Declination: 26.21 deg Field Strength: 57481 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 24.24 Plan: MPS-08 wp08 Date Composed: 2/26/2003 New targets from Dee. . . Version: 27 Principal: Yes Tied-to: From Well Ref. Point Casing Points <l\ìID; >',ftC' 2768.49 2442.00 5225.18 3992.88 10572.51 4007.00 10.750 7.625 4.500 \:lIøle$iz¢ · t:';. in: 12.250 8.500 6.125 103/4" 7" 41/2" Formations "MD< ' :··'{fì ,TVD ft 0.00 3977.00 3997.00 4002.00 4007.00 0.00 '::ForÎtiatlo"s>' /::»ip·.Angleri' Dip/D1re¢tlon 'M ,deg::d~g 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5115.30 5268.60 5392.27 10572.51 NB SBF2-NA NAMF SBF1-NB SBF1-NBR SBE4-NC Targets Map Map <-- . Latitude:. .--> <-.,. Longltude-> Name Description TVD +N/-S +EI-W Northing Easting Deg· Min· See Deg Min.· Sec Dip. Dir. ft ft ft ft ft MPS-08 HardLine 72.00 -3354.99 4841.65 5996706.00 570846.00 70 24 4.741 N 149 25 24.147 W -Polygon 1 72.00 -3354.99 4841.65 5996706.00 570846.00 70 24 4.741 N 149 25 24.147 W -Polygon 2 72.00 -3361 .26 -10525.47 5996564.00 555481.00 70 24 4.622 N 149 32 54.366 W MPS-08 T 4 Wp 7 3987.00 1149.70 1434.98 6001180.00 567400.00 70 24 49.058 N 149 27 3.928 W MPS-08 T2 Wp 7 3992.00 -453.71 1230.79 5999575.00 567210.00 70 24 33.289 N 149 27 9.922 W MPS-08 T5 Wp 7 3992.00 2094.18 1508.33 6002125.00 567465.00 70 24 58.346 N 149 27 1.772 W ) ') BP KW A Planning Report MAP t €~th ~ti'~1d }"~It~:' . Þ)V4J:' Þ\YiJI, Targets MPS-08 Geo-Poly 4002.00 -1575.59 860.83 5998450.00 566850.00 70 24 22.256 N 149 27 20.769 W -Polygon 1 4002.00 -1707.42 499.62 5998315.00 566490.00 70 24 20.960 N 149 27 31.354 W -Polygon 2 4002.00 -872.72 1112.07 5999155.00 567095.00 70 24 29.168 N 149 27 13.403 W -Polygon 3 4002.00 1005.62 1328.69 6001035.00 567295.00 70 24 47.641 N 149 27 7.045 W -Polygon 4 4002.00 2035.37 1372.79 6002065.01 567330.00 70 24 57.768 N 149 27 5.747 W -Polygon 5 4002.00 3410.18 1414.94 6003440.00 567360.00 70 25 11.289 N 149 27 4.503 W -Polygon 6 4002.00 3407.97 1664.96 6003440.00 567610.00 70 25 11.267 N· 149 26 57.172 W -Polygon 7 4002.00 2053.31 1605.98 6002085.00 567563.00 70 24 57.944 N 149 26 58.910 W -Polygon 8 4002.00 804.19 1486.93 6000835.00 567455.00 70 24 45.660 N 149 27 2.407 W -Polygon 9 4002.00 -888.46 1421.97 5999142.00 567405.00 70 24 29.013 N 149 27 4.321 W -Polygon 10 4002.00 -1599.07 1253.68 5998430.00 567243.01 70 24 22.025 N 149 27 9.257 W MPS-08 T3 Wp 7 4002.00 420.45 1338.52 6000450.00 567310.00 70 24 41.886 N 149 27 6.760 W MPS-08 T1 Wp 7 4002.00 -1575.59 860.83 5998450.00 566850.00 70 24 22.256 N 149 27 20.769 W MPS-08 T6 Wp 7 4007.00 3409.12 1534.95 6003440.00 567480.00 70 25 11.279 N 149 27 0.984 W Plan Section Information I¡itl AZìñit +E/-W ~: QL;~;~: iL BU!Jd ;, It: :'f,F+TÈO f .dØg· d~9;i~ . o rt ThV; ~eg/1 @:9~?::~(¡!g~~ OOft>;, QOft!¡fö;'d~gt 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 0.00 550.00 0.00 0.00 550.00 0.00 0.00 0.00 0.00 0.00 0.00 683.33 2.00 200.00 683.30 -2.19 -0.80 1.50 1.50 0.00 200.00 1616.67- 30.00 200.00 1571.59 -241.54 -87.91 3.00 3.00 0.00 0.00 1666.67 31.00 200.00 1614.67 -265.38 -96.59 2.00 2.00 0.00 360.00 1827.35- 34.21 214.00 1750.20 -341.85 -136.07 5.09 2.00 8.71 72.94 1948.27 34.21 214.00 1850.19 -398.21 -174.09 0.00 0.00 0.00 0.00 2204.47 45.73 214.69 2046.20 -533.82 -266.89 4.50 4.50 0.27 2.47 2656.76- 45.73 214.69 2361.89 -800.14 -451.23 0.00 0.00 0.00 0.00 5392.27 - 90.00 75.00 4002.00 -1575.59 860.83 4.50 1.62 -5.11 -129.44 MPS-08 T1 Wp 7 5412.27 _ 90.00 75.00 4002.00 -1570.42 880.15 0.00 0.00 0.00 0.00 6039.65 - 90.56 359.72 3998.39 -1106.86 1234.03 12.00 0.09 -12.00 -89.42 6692.83 . 90.56 359.72 3992.00 -453.71 1230.79 0.00 0.00 0.00 0.00 MPS-08 T2 Wp 7 6826.61 ~ 89.21 7.63 3992.27 -320.32 1239.35 6.00 -1.01 5.91 99.67 7541.41 89.21 7.63 4002.11 388.09 1334.22 0.00 0.00 0.00 0.00 7574.06 91.17 7.53 4002.00 420.45 1338.52 6.00 5.99 -0.28 -2.72 MPS-08 T3 Wp 7 8309.81-. 91.17 7.53 3987.00 1149.70 1434.98 0.00 0.00 0.00 0.00 MPS-08 T 4 Wp 7 8368.73 .- 89.65 4.34 3986.58 1208.29 1441.07 6.00 -2.58 -5.42 -115.41 9257.18 89.65 4.34 3992.00 2094.18 1508.33 0.00 0.00 0.00 0.00 MPS-08 T5 Wp 7 9311.58 89.34 1.09 3992.48 2148.50 1510.91 6.00 -0.57 -5.97 -95.47 10572.51-;- 89.34 1.09 4007.00 3409.12 1534.95 0.00 0.00 0.00 0.00 MPS-08 T6 Wp 7 Survey MD Incl Azlm TVD SysJ'VD VS D1.S. l'FO Toól/Comment ft deg deg ft ft ft··. degf100ft deg 33.00 0.00 0.00 33.00 -39.00 6000017.78 565975.37 0.00 0.00 0.00 CB-GYRO-SS 72.00 0.00 0.00 72.00 0.00 6000017.78 565975.37 0.00 0.00 0.00 MPS-08 HardLine 100.00 0.00 0.00 100.00 28.00 6000017.78 565975.37 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 128.00 6000017.78 565975.37 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 228.00 6000017.78 565975.37 0.00 0.00 0.00 CB-GYRO-SS 400.00 0.00 0.00 400.00 328.00 6000017.78 565975.37 0.00 0.00 0.00 CB-GYRO-SS 500.00 0.00 0.00 500.00 428.00 6000017.78 565975.37 0.00 0.00 0.00 CB-GYRO-SS 550.00 0.00 0.00 550.00 478.00 6000017.78 565975.37 0.00 0.00 0.00 CB-GYRO-SS 600.00 0.75 200.00 600.00 528.00 6000017.47 565975.26 -0.33 1.50 0.00 CB-GYRO-SS 683.33 2.00 200.00 683.30 611.30 6000015.59 565974.59 -2.32 1.50 0.00 CB-GYRO-SS 700.00 2.50 200.00 699.96 627.96 6000014.97 565974.38 -2.97 3.00 360.00 CB-GYRO-SS ) ) BP KW A Planning Report MAP Survey 800.00 5.50 200.00 799.71 727.71 6000008.40 565972.05 -9.93 3.00 0.00 CB-GYRO-SS 900.00 8.50 200.00 898.95 826.95 5999996.91 565967.98 -22.08 3.00 0.00 CB-GYRO-SS 1000.00 11.50 200.00 997.42 925.42 5999980.54 565962.19 -39.40 3.00 0.00 MWD+IFR+MS 1100.00 14.50 200.00 1094.84 1022.84 5999959.34 565954.68 -61.83 3.00 0.00 MWD+IFR+MS 1200.00 17.50 200.00 1190.96 1118.96 5999933.36 565945.49 -89.31 3.00 360.00 MWD+IFR+MS 1300.00 20.50 200.00 1285.50 1213.50 5999902.68 565934.62 -121.78 3.00 0.00 MWD+IFR+MS 1400.00 23.50 200.00 1378.21 1306.21 5999867.37 565922.13 -159.13 3.00 0.00 MWD+IFR+MS 1500.00 26.50 200.00 1468.83 1396.83 5999827.54 565908.03 -201.27 3.00 360.00 MWD+IFR+MS 1600.00 29.50 200.00 1557.11 1485.11 5999783.30 565892.36 -248.09 3.00 0.00 MWD+IFR+MS 1616.67 30.00 200.00 1571.59 1499.59 5999775.50 565889.60 -256.33 3.00 0.00 MWD+IFR+MS 1666.67 31.00 200.00 1614.67 1542.67 5999751.58 565881.14 -281.64 2.00 360.00 MWD+IFR+MS 1700.00 31.54 203.10 1643.16 1571.16 5999735.44 565874.92 -298.92 5.09 72.94 MWD+IFR+MS 1800.00 33.56 211.79 1727.49 1655.49 5999687.65 565850.51 -352.50 5.09 70.29 MWD+IFR+MS 1827.35 34.21 214.00 1750.20 1678.20 5999674.78 565842.34 -367.57 5.09 62.95 MWD+IFR+MS 1900.00 34.21 214.00 1810.28 1738.28 5999640.71 565819.80 -407.83 0.00 180.00 MWD+IFR+MS 1948.27 34.21 214.00 1850.19 1778.19 5999618.08 565804.82 -434.58 0.00 180.00 MWD+IFR+MS 2000.00 36.54 214.17 1892.37 1820.37 5999593.13 565788.26 -464.09 4.50 2.47 MWD+IFR+MS 2100.00 41.04 214.45 1970.30 1898.30 5999541.10 565753.41 -525.75 4.50 2.33 MWD+IFR+MS 2204.47 45.73 214.69 2046.20 1974.20 5999481.68 565713.23 -596.33 4.50 2.11 MWD+IFR+MS 2300.00 45.73 214.69 2112.88 2040.88 5999425.09 565674.80 -663.60 0.00 0.00 MWD+IFR+MS 2400.00 45.73 214.69 2182.67 2110.67 5999365.86 565634.57 -734.03 0.00 0.00 MWD+IFR+MS 2500.00 45.73 214.69 2252.47 2180.47 5999306.62 565594.34 -804.45 0.00 0.00 MWD+IFR+MS 2600.00 45.73 214.69 2322.27 2250.27 5999247.39 565554.11 -874.87 0.00 0.00 MWD+IFR+MS 2656.76 45.73 214.69 2361.89 2289.89 5999213.76 565531.27 -914.85 0.00 0.00 MWD+IFR+MS 2700.00 44.52 212.55 2392.40 2320.40 5999188.11 565514.53 -945.07 4.50 230.56 MWD+IFR+MS 2800.00 41.87 207.23 2465.32 2393.32 5999128.56 565480.92 -1013.13 4.50 232.07 MWD+IFR+MS 2900.00 39.50 201.36 2541.17 2469.17 5999069.00 565454.58 -1078.25 4.50 235.95 MWD+IFR+MS 3000.00 37.44 194.92 2619.49 2547.49 5999009.82 565435.68 -1140.04 4.50 240.40 MWD+IFR+MS 3100.00 35.78 187.91 2699.80 2627.80 5998951.36 565424.35 -1198.12 4.50 245.45 MWD+IFR+MS 3200.00 34.54 180.38 2781.59 2709.59 5998894.00 565420.64 -1252.13 4.50 251.08 MWD+IFR+MS 3300.00 33.80 172.48 2864.37 2792.37 5998838.08 565424.59 -1301.73 4.50 257.23 MWD+IFR+MS 3400.00 33.58 164.37 2947.62 2875.62 5998783.96 565436.16 -1346.63 4.50 263.77 MWD+IFR+MS 3500.00 33.88 156.28 3030.83 2958.83 5998731.95 565455.29 -1386.54 4.50 270.52 MWD+IFR+MS 3600.00 34.70 148.42 3113.48 3041.48 5998682.39 565481.86 -1421.21 4.50 277 .26 MWD+IFR+MS 3700.00 36.01 140.97 3195.08 3123.08 5998635.58 565515.71 -1450.45 4.50 283.75 MWD+IFR+MS 3800.00 37.74 134.05 3275.11 3203.11 5998591.81 565556.62 -1474.05 4.50 289.83 MWD+IFR+MS 3900.00 39.84 127.70 3353.08 3281.08 5998551.35 565604.34 -1491.89 4.50 295.37 MWD+IFR+MS 4000.00 42.26 121.92 3428.51 3356.51 5998514.45 565658.58 -1503.84 4.50 300.33 MWD+IFR+MS 4100.00 44.95 116.68 3500.94 3428.94 5998481.33 565719.01 -1509.84 4.50 304.69 MWD+IFR+MS 4200.00 47.85 111.93 3569.91 3497.91 5998452.20 565785.25 -1509.84 4.50 308.48 MWD+IFR+MS 4300.00 50.93 107.60 3635.01 3563.01 5998427.24 565856.89 -1503.86 4.50 311.76 MWD+IFR+MS 4400.00 54.16 103.65 3695.83 3623.83 5998406.60 565933.50 -1491.92 4.50 314.58 MWD+IFR+MS 4500.00 57.50 100.01 3752.00 3680.00 5998390.41 566014.59 -1474.09 4.50 316.98 MWD+IFR+MS 4600.00 60.95 96.64 3803.17 3731.17 5998378.78 566099.68 -1450.50 4.50 319.03 MWD+IFR+MS 4700.00 64.47 93.48 3849.03 3777.03 5998371.76 566188.23 -1421.27 4.50 320.76 MWD+IFR+MS 4800.00 68.05 90.51 3889.28 3817.28 5998369.41 566279.70 -1386.61 4.50 322.20 MWD+IFR+MS 4900.00 71.69 87.69 3923.70 3851.70 5998371.74 566373.53 -1346.71 4.50 323.40 MWD+IFR+MS 5000.00 75.37 84.98 3952.05 3880.05 5998378.74 566469.14 -1301.82 4.50 324.37 MWD+IFR+MS 5100.00 79.07 82.36 3974.17 3902.17 5998390.35 566565.93 -1252.22 4.50 325.14 MWD+IFR+MS 5115.30 79.64 81.97 3977.00 3905.00 5998392.53 566580.80 -1244.24 4.50 325.72 SBF2-NA 5200.00 82.80 79.81 3989.93 3917.93 5998406.52 566663.31 -1198.22 4.50 325.79 MWD+IFR+MS 5268.60 85.37 78.08 3997.00 3925.00 5998420.19 566730.14 -1158.81 4.50 326.12 NAMF 5300.00 86.54 77.30 3999.22 3927.22 5998427.14 566760.68 -1140.15 4.50 326.30 MWD+IFR+MS ) ) BP KW A Planning Report MAP Survey iìmi ~··.·a~g 5392.27 90.00 75.00 4002.00 3930.00 5998450.00 566850.00 -1083.27 4.50 326.36 MPS-08 T1 Wp 7 5400.00 90.00 75.00 4002.00 3930.00 5998452.07 566857.45 -1078.38 0.00 0.00 MWD+IFR+MS 5412.27 90.00 75.00 4002.00 3930.00 5998455.35 566869.27 -1070.62 0.00 0.00 MWD+IFR+MS 5425.00 90.02 73.47 4002.00 3930.00 5998458.91 566881.49 -1062.43 12.00 270.58 MWD+IFR+MS 5450.00 90.05 70.47 4001.98 3929.98 5998466.86 566905.19 -1045.62 12.00 270.58 MWD+IFR+MS 5475.00 90.08 67.47 4001.96 3929.96 5998476.03 566928.44 -1027.86 12.00 270.58 MWD+IFR+MS 5500.00 90.11 64.47 4001.92 3929.92 5998486.41 566951.18 -1009.21 12.00 270.57 MWD+IFR+MS 5525.00 90.14 61.47 4001.87 3929.87 5998497.97 566973.34 -989.71 12.00 270.57 MWD+IFR+MS 5550.00 90.16 58.47 4001.80 3929.80 5998510.66 566994.87 -969.42 12.00 270.56 MWD+IFR+MS 5575.00 90.19 55.47 4001.72 3929.72 5998524.4 7 567015.71 -948.39 12.00 270.56 MWD+IFR+MS 5600.00 90.22 52.47 4001.63 3929.63 5998539.35 567035.79 -926.68 12.00 270.55 MWD+IFR+MS 5625.00 90.25 49.47 4001.53 3929.53 5998555.26 567055.07 -904.36 12.00 270.54 MWD+IFR+MS 5650.00 90.28 46.47 4001.41 3929.41 5998572.16 567073.49 -881.48 12.00 270.52 MWD+IFR+MS 5675.00 90.30 43.47 4001.29 3929.29 5998589.99 567090.99 -858.10 12.00 270.51 MWD+IFR+MS 5700.00 90.33 40.47 4001.15 3929.15 5998608.72 567107.54 -834.29 12.00 270.49 MWD+IFR+MS 5725.00 90.35 37.47 4001.00 3929.00 5998628.29 567123.09 -810.12 12.00 270.48 MWD+IFR+MS 5750.00 90.38 34.47 4000.84 3928.84 5998648.65 567137.60 -785.64 12.00 270.46 MWD+IFR+MS 5775.00 90.40 31.47 4000.67 3928.67 5998669.74 567151.01 -760.93 12.00 270.44 MWD+IFR+MS 5800.00 90.42 28.47 4000.49 3928.49 5998691.50 567163.31 -736.06 12.00 270.42 MWD+IFR+MS 5825.00 90.44 25.47 4000.30 3928.30 5998713.87 567174.45 -711.10 12.00 270.40 MWD+IFR+MS 5850.00 90.46 22.47 4000.11 3928.11 5998736.80 567184.40 -686.10 12.00 270.38 MWD+IFR+MS 5875.00 90.48 19.47 3999.90 3927.90 5998760.21 567193.14 -661.14 12.00 270.35 MWD+IFR+MS 5900.00 90.49 16.47 3999.69 3927.69 5998784.06 567200.64 -636.30 12.00 270.33 MWD+IFR+MS 5925.00 90.51 13.47 3999.4 7 3927.47 5998808.26 567206.89 -611.63 12.00 270.30 MWD+IFR+MS 5950.00 90.52 10.47 3999.25 3927.25 5998832.75 567211.86 -587.20 12.00 270.28 MWD+IFR+MS 5975.00 90.54 7.47 3999.01 3927.01 5998857.47 567215.54 -563.09 12.00 270.25 MWD+IFR+MS 6000.00 90.55 4.47 3998.78 3926.78 5998882.35 567217.92 -539.35 12.00 270.22 MWD+IFR+MS 6025.00 90.56 1.47 3998.54 3926.54 5998907.32 567218.99 -516.06 12.00 270.19 MWD+IFR+MS 6039.65 90.56 359.72 3998.39 3926.39 5998921.97 567219.02 -502.64 12.00 270.16 MWD+IFR+MS 6100.00 90.56 359.72 3997.80 3925.80 5998982.31 567218.18 -447.73 0.00 0.00 MWD+IFR+MS 6200.00 90.56 359.72 3996.82 3924.82 5999082.28 567216.80 -356.76 0.00 0.00 MWD+IFR+MS 6300.00 90.56 359.72 3995.85 3923.85 5999182.26 567215.42 -265.79 0.00 0.00 MWD+IFR+MS 6400.00 90.56 359.72 3994.87 3922.87 5999282.24 567214.04 -174.81 0.00 0.00 MWD+IFR+MS 6500.00 90.56 359.72 3993.89 3921.89 5999382.21 567212.66 -83.84 0.00 0.00 MWD+IFR+MS 6600.00 90.56 359.72 3992.91 3920.91 5999482.19 567211.28 7.14 0.00 0.00 MWD+IFR+MS 6692.83 90.56 359.72 3992.00 3920.00 5999575.00 567210.00 91.59 0.00 0.00 MPS-08 T2 Wp 7 6700.00 90.49 0.14 3991.93 3919.93 5999582.16 567209.93 98.12 6.00 99.67 MWD+IFR+MS 6750.00 89.98 3.10 3991.73 3919.73 5999632.14 567210.90 144.27 6.00 99.68 MWD+IFR+MS 6800.00 89.48 6.05 3991.96 3919.96 5999682.01 567214.44 191.35 6.00 99.69 MWD+IFR+MS 6826.61 89.21 7.63 3992.27 3920.27 5999708.45 567217.38 216.74 6.00 99.68 MWD+IFR+MS 6900.00 89.21 7.63 3993.28 3921.28 5999781.26 567226.48 287.06 0.00 0.00 MWD+IFR+MS 7000.00 89.21 7.63 3994.65 3922.65 5999880.47 567238.87 382.87 0.00 0.00 MWD+IFR+MS 7100.00 89.21 7.63 3996.03 3924.03 5999979.68 567251.27 478.69 0.00 0.00 MWD+IFR+MS 7200.00 89.21 7.63 3997.41 3925.41 6000078.89 567263.66 574.51 0.00 0.00 MWD+IFR+MS 7300.00 89.21 7.63 3998.78 3926.78 6000178.10 567276.06 670.33 0.00 0.00 MWD+IFR+MS 7400.00 89.21 7.63 4000.16 3928.16 6000277.31 567288.45 766.14 0.00 0.00 MWD+IFR+MS 7500.00 89.21 7.63 4001.54 3929.54 6000376.52 567300.85 861.96 0.00 0.00 MWD+IFR+MS 7541.41 89.21 7.63 4002.11 3930.11 6000417.60 567305.98 901.64 0.00 0.00 MWD+IFR+MS 7550.00 89.73 7.60 4002.19 3930.19 6000426.12 567307.04 909.87 6.00 357.28 MWD+IFR+MS 7574.06 91.17 7.53 4002.00 3930.00 6000450.00 567310.00 932.92 6.00 357.28 MPS-08 T3 Wp 7 7600.00 91.17 7.53 4001.47 3929.47 6000475.73 567313.17 957.76 0.00 0.00 MWD+IFR+MS 7700.00 91.17 7.53 3999.43 3927.43 6000574.95 567325.40 1053.52 0.00 0.00 MWD+IFR+MS ) ) BP KW A Planning Report MAP li~t;t:I:[ Survey Ñiitri . ;¥~¡g'.'.. 7800.00 91.17 7.53 3997.39 3925.39 6000674.17 567337.64 1149.28 0.00 0.00 MWD+IFR+MS 7900.00 91.17 7.53 3995.36 3923.36 6000773.39 567349.87 1245.04 0.00 0.00 MWD+IFR+MS 8000.00 91.17 7.53 3993.32 3921.32 6000872.61 567362.10 1340.80 0.00 0.00 MWD+IFR+MS 8100.00 91.17 7.53 3991.28 3919.28 6000971.83 567374.33 1436.56 0.00 0.00 MWD+IFR+MS 8200.00 91.17 7.53 3989.24 3917.24 6001071.05 567386.57 1532.32 0.00 0.00 MWD+IFR+MS 8309.81 91.17 7.53 3987.00 3915.00 6001180.00 567400.00 1637.47 0.00 0.00 MPS-08 T 4 Wp 7 8350.00 90.13 5.36 3986.54 3914.54 6001219.96 567404.16 1675.73 6.00 244.59 MWD+IFR+MS 8368.73 89.65 4.34 3986.58 3914.58 6001238.64 567405.58 1693.40 6.00 244.57 MWD+IFR+MS 8400.00 89.65 4.34 3986.77 3914.77 6001269.83 567407.67 1722.80 0.00 0.00 MWD+IFR+MS 8500.00 89.65 4.34 3987.38 3915.38 6001369.60 567414.36 1816.83 0.00 0.00 MWD+IFR+MS 8600.00 89.65 4.34 3987.99 3915.99 6001469.36 567421.04 1910.86 0.00 0.00 MWD+IFR+MS 8700.00 89.65 4.34 3988.60 3916.60 6001569.13 567427.73 2004.89 0.00 0.00 MWD+IFR+MS 8800.00 89.65 4.34 3989.21 3917.21 6001668.89 567434.42 2098.91 0.00 0.00 MWD+IFR+MS 8900.00 89.65 4.34 3989.82 3917.82 6001768.66 567441.11 2192.94 0.00 0.00 MWD+IFR+MS 9000.00 89.65 4.34 3990.43 3918.43 6001868.42 567447.80 2286.97 0.00 0.00 MWD+IFR+MS 9100.00 89.65 4.34 3991.04 3919.04 6001968.19 567454.49 2381.00 0.00 0.00 MWD+IFR+MS 9200.00 89.65 4.34 3991.65 3919.65 6002067.95 567461.17 2475.03 0.00 0.00 MWD+IFR+MS 9257.18 89.65 4.34 3992.00 3920.00 6002125.00 567465.00 2528.80 0.00 0.00 MPS-08 T5 Wp 7 9300.00 89.41 1.78 3992.35 3920.35 6002167.76 567466.91 2568.72 6.00 264.53 MWD+IFR+MS 9311.58 89.34 1.09 3992.48 3920.48 6002179.34 567467.10 2579.39 6.00 264.55 MWD+IFR+MS 9400.00 89.34 1.09 3993.50 3921.50 6002267.74 567468.00 2660.69 0.00 0.00 MWD+IFR+MS 9500.00 89.34 1.09 3994.65 3922.65 6002367.72 567469.03 2752.63 0.00 0.00 MWD+IFR+MS 9600.00 89.34 1.09 3995.80 3923.80 6002467.70 567470.05 2844.58 0.00 0.00 MWD+IFR+MS 9700.00 89.34 1.09 3996.95 3924.95 6002567.68 567471.07 2936.52 0.00 0.00 MWD+IFR+MS 9800.00 89.34 1.09 3998.10 3926.10 6002667.66 567472.09 3028.46 0.00 0.00 MWD+IFR+MS 9900.00 89.34 1.09 3999.26 3927.26 6002767.63 567473.12 3120.41 0.00 0.00 MWD+IFR+MS 10000.00 89.34 1.09 4000.41 3928.41 6002867.61 567474.14 3212.35 0.00 0.00 MWD+IFR+MS 10100.00 89.34 1.09 4001.56 3929.56 6002967.59 567475.16 3304.29 0.00 0.00 MWD+IFR+MS 10200.00 89.34 1.09 4002.71 3930.71 6003067.57 567476.19 3396.24 0.00 0.00 MWD+IFR+MS 10300.00 89.34 1.09 4003.86 3931.86 6003167.55 567477.21 3488.18 0.00 0.00 MWD+IFR+MS 10400.00 89.34 1.09 4005.01 3933.01 6003267.53 567478.23 3580.13 0.00 0.00 MWD+IFR+MS 10500.00 89.34 1.09 4006.16 3934.16 6003367.51 567479.26 3672.07 0.00 0.00 MWD+IFR+MS 10572.51 89.34 1.09 4007.00 3935.00 6003440.00 567480.00 3738.74 0.00 0.00 MPS-08 T6 Wp 7 p055087 DATE 6/9/2003 /'....-.-..... -----~ INVOICE / CREDIT MEMO DESCRIPTION --J-- INV# CK060403G PERMIT TO DRILL =EE .- ?...-~- '-..... . . (ilE: Þ.Tr¡\CHeD CHECK IS IN PAYIV1ENY FOR ITEMS DESCRIBED ABOVE. ,~. ~ -~.--- ~~ ..t"~J~ SP EXPLORATION) (ALASKA) INC. PRUDHOE BAY UNIT eo BOX oj 966"12 Ai'JCHORI\GE, Af< 995i9~6612 PAY: -- TO THE ORDER OF: B. p ~~~. u,... .. .. . :: ~l .,¡f,. ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 l~__.__.___._~__~~_____.__ --~~...-~--~- - -~---_._-~~~---_..._~---.._----_._.---~_._-_._---..-_.-. - f;:::!~ GROSS -~-L NATIONAL CITY BANK Ashland, Ohio ____ DATE: ____w__ June 9, 2003 III 0 5 SOB 7 118 ;: 0 ~ ~ 2 0 :i B g S I: o. 2 7 B g b 110 -~-~..~----- __._____ _~.___n ____ _ __..__. _DATE__ ____º!:!ê~~~\!º.~___ 6/9/2003 055087 VENDOR DISCOUNT --~==J_~ _~~_-=-~=~ï~i~~: ~ - ~ :111 UU ~._.- --- --- --.--. "-- .. .. -- .. -~---- ~--,-------. - r-' t ~~-_._~- ----_._~ -----.._-- ~~--- . 56-38.2. 412 NouP 055087 CONSOLlDAïED COMMEflC/ill. fI(~CüU~JT .~ . _~__!~lí:L~~'~LI. I **~*::~~_1 O~'~?~~*_~*~:I NOT VAL'k.j'~~>':~ ~~_~v~~· r.::·;·:···~· ~'.: . - ~ ~___I ) ) TRANSMIT AL LETTER CHECK'LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BEINCLUDEDINT~NSNUTTALLE~~~~ WELL NAME ffi / {/ .:;; c 2S 2CJ3 '-/Z3 PTD# CHECK WIIA T APPLIES ADD-ONS (OPTIONS) MlJL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated In both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent UpOD issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing.. exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMlrCHECKLlSTi Company BP EXPLORATION (ál8.s.~AlliC ________________________ Well Name: MILNE POINT UNLLSJ3_____$.:.OlL__ ___ Program IlE;V Well bore seg PTD#: 2031230 Field & Pool MILNE POINT, SCHRAt:lER61FF OIL - 525140 Initial ClasslType __º_EY-.L1:...QLL.,__ GeoArea J390 Unit J_13.Z1t___ On/Off Shore -ºD_ Annular Disposal Administration 1 P~rll)itfe~ qttaçhe_d_ _ _ . . . . . . . . . . . . . .. . ,_ . .. . . . . . . . . . . . . _ . . . . . . . . . . . .Y~$ . . . . . _ . _ .. . . . . _ . . . ._ . . . . . . . . . . . . . ._ .. . . . . . . .. _ . . . . .. . . . . . . . . . . . . . . . ._ . _ _ . _ 2 .Leqs~ .n\..lIJ1P~r .appropriate _ .. . ._ . . . . . . _ _ _ _ . _ _ _ _ _ _ _ _ _ ., .Y ~$ _ . _ _ _ _ _ . _ _ _ _ _ _ _ __ . . _ .. _ _ . .. _ _ _ , .. .. . .. _ . . __ _ __ _ . . , 3 .U.nique well._n_arn~.and oumb.er _ _ _ . _ . _ _ _ . _ _ _ _ . .. . . .. . _ _ _ _ _ _ _ _ _ _ _ ........ .Y~$ _ . _ _ _ . .. _ .. . _ _ , , . . . . . _ . . . _ . _ _ .. ._ . . _ . . _ _ _ _ .. _ 4 .W~IIJQcat~d in_a.d.efil1e.d.pOQI. . . .. _ .. .. . . . . .. . _ _ .. . . . . . . . . . _ _ . _ . . . . . _ . .Y~$ . . . . . . . . . _ _ . . _ _ . _ . _ _ . .. _ . . _ . . . .. _ . _ . . . . _ _ . .. . __ _ . _ . . . ._ _ . .. _ _........_ 5 _W~IIJQcÇlt~çI pr.op~r .distançeJroJ11. qriJling I)l1it.b.ol)l1d~ry_ _ _ _ _ _ _ _ _ _ ._ _ _ _ _ _ _ Y~$ _ . _ _ . . _ . . _ . _ _ _ _ _ _ __ _ . _ _ _ _ . .. _ . . . _ _ .. . .. _ .. . . . . . . . . . . _ . . . . . _ . . . . ._ . . .. 6 _W~II JQCÇlt~çI pr.oper _d istan GeJroJ11. QtbeJ wells. _ _ .. . . , _ _ _ . . _ _ . . _ _ _ _ Y~s . . _ . . . . _ __ _ _ . _ _ _ . _ _ _ _. _ _ _ _ _ . _ 7 .S.uffiçiel1t .açreqg_e.ayqilpple in.drilJiOg unjt. . _ _ . . .. . . . . _ . . . _ . _ _ . _ _ _ . . . . _ . . . . .Y~$ _ . . . . .. . . _ . . . . . _ . . . . . _ _ . _ _ _ ._ _ . _ _ . . _ . ___ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . _ _ . 8 Jf.d~viªted, js. weJlpQre plaUl1c]u.ded . . _ _ _ _ . . . . . .. _ . . . . .. . . . . . . _ . . _ . _ _ . _ . _ Y~$ . . . . . . . . . . _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ ._ _ _ . _ _ _ _ . . _ _ _ . . _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ 9 ,Qp!:!r.ator Or)Jy- qff.eçt!:!d party _ _ _ _ . . . . . _ . . _ _ . _ . _ _ . _ _ . _ . . . .. . Y~$ _ . . . _ _ . _ _ . . _ . _ . _ . _ . _ _ _ . . _ . _ ._ . .. _ _ . . _ . _ . _ _ ._ . . . ._ 10 .Qp!:!r.ator bas.appropriate. b.onQ i.n JQrç~ . . . . . _ __ . . . . . . . . _ _ . . . _ . _ . _ . .. _.. Y.ß$ . . . . . . . . . . ., . . . . . . . . _ . . _ _ . . . _ . _ _ _ . . . . . . . . . . . . _ . . . . . . . . . . . . .. . . . . . _ . . . _ _ . . 11 P~(I1)itc.a(1 Þe i.s$ued wJtbQut ço.nserva.tiOI1 Qrder. ._ . . . . . . . . . .. . . .. . ._ ,. Y~$ _ . . . _ . . . . . .. . . . . . ._ . . _ . . . _ . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . ._ . . . _ . . . . _ _ 12 P.ßrmitc.a[1 Þe i.ssued wjtbQut qd.mil1i~tr.ati\le.approvaJ _ . _ . . . . . . . . . . _ . _ _ _ _ _ _ _ . _ . Y~s . _ _ . . .. . . . . _ _ . _ . . _ _ , _ . . . _ . _ . , _ . _ _ _ .. .. _ _ . _ _ _ _ _ ' .. ,. _ _ . . _ . . . . 7/10/2003 13 _C_ao permJtÞe apPJQv~d before .15-dqy.wajt. .. ..._.,..._....... _ . ._ . _ _ . . . .. . . Y~$.. . _ . . _ . . . . . . . . . . _ . . . . . .. . . . .. . ._ _ . . . . . .. _ _ . _ . . . . . . . . . . . . . _ . . . . _ 14 W~IIJQcat~dwiJhil1qreaqnd.strata~uthQrizedby-lojeGtiooOrd~r#(puUO#in.cor:nm~ots).(fQr. NA... _. _......... _... _ _......"........... ............. _............ _.. 15 .AJlw!:!l]s.witþifl.1(4.l1Jite.are.a.ofreyi!:!wjd~otified(For~ervjc.ß.w.eIJOI1IY-L... . _...... NA............. _... _ _.... _...,. _.. _... _. _.. _ _ _ _. ,.... _... _. _.. __ 16 Pr~-produ.ced.i[1jßctor; .duraljQn.ofprß-pro.ducti0I1I~ss.thqn3mon.ths.(fQr.sßr:vi.ceweltQnjy).. NA.................. _.............................................. _............. 17 .AGMP.F:in.ding.of ÇQn~i~te[1cy.h~s bee.nj~suedJor.tbis proiect. . .. . . . . . . . . . . . .. . . . . . NA . . . . . . . Wßlj drilled frQrr:! an existir:!9.p,ad.. . . . . . . . . . _ _ . .. . . . .. . . . . . . . _ . . . . . . . . . . . . . . _ . . .. .. . . . . 18 .C.oodu_ctor ~trin.9-prQvidßd _ _ _ _ . . . . . . . _ . _ _ _ _ .. . .. . . . . . . . . . . . . . . . .. . . . . . Y~s . . . . .. . . . . . . .. . . . . . . . . . . . . . .. . . .. . .. . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . 19 .S.urjqc.ß_ca~ing.PJQtec.ts..all...known.USQW~........._....... _.............. NA....... .Altaq.uifeJ~ex.er:npt~d~QÇfßj47..1.021b)(3).................................... _...... 20 .CMT.v.otadßQu.ate.to çirc.ul~te.ofl.cond.uctor.& surf.~g . . . . . . . . . . . . . . . _ . . . . . . . . .Y~s . . . .. . . .. . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . ,. .. . . . . . . . . . . . . . . . . . . . .. _ _ _ _ . . . . 21 _CMT.v.otad!:!Qu.ateJo tie-i.nJQng~triog to.surf ~g. _ . . . . _ .. .. . . _ . . . . . . . . . _ .. .. .. _ . .. No. . . . . . . . . . . . . . _ _ . . . . . . . . . . _ . . _ _ _ .. . .. . . . .. . . .. . .. . .. .. . .. . . . . . . .. . .. . . . . . . . . . _ . . . .. . . .. . 22 .CMT. wil! coyer .a]l .!<I)o.w.n .pro.ductiye bQri~Qn.s. . . . _ .. . . . . . . .. . _ . . . . . . . . . . . . . . . No.. .. _ . _ _ . . $Iotte.d Jioer ptao, I)e.d . _ . . . . . . . . . . . . . . . .. . . . . . . .. . . . . . .. . .. .. . . . . . . . . . . . . _ _ _ _ . . . . . 23 .C.asiog d~sig[1~ qd.eqlJa.t~ fpr C,.T., ß .&. p,ermafr.ost, _ . _ . . _ . . . . . . .. . . .. .. . . . _ . . _ . . Y~s . . . . . . . . . . . . . . . . . . _ _ . . . _ . _ . . . . . . . .. . . . . . . . .. . . . . . . . . . . .. . . _ . . .. _ _ _ _ . . . 24 AdequateJqn_kage.or re.serye pit. . . . . _ . _ _ . _ _ _ _ _ _ . . . _ . . _ _ . . _ . . _ . . . . . . . Y~s _ _ _ _ _ _ _ Rig js.e.quippe.d.with st~el.pit~.. NQ rßseJ'~e.pjtptanlJe.d, All wa~te to.Class JI.w.elJs.. . . . . . . . . . _ . . _ . . . . . . 25 Jf.a.re-.drill.. has.a. 1.0:4.03 fQr aba.ndonlT\eflt be~o apprQved . . . _ _ . . . . . . . .. . . . _ . . . . . NA . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . .. . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . ..' . _ , . . . . 26 Adequate.weIlQor~ $.eparatjon propo~ed. . _ _ . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . Y~s . . . . . . . Prp~imlty. analy~is p~rforll)e.d, No .clos~ app(oach. is~uß~ i.denti~ed.. . _ _ . _ _ ' . . _ . . _ . . . . . . . . . _ _ _ . .. . 27 Jf.diver:ter reqJ,Jired. dQes jt me!:!t reguJa.tiOl1s. . . . . . . . . . . . . . _ _ _ _ . . _ . . . . . . . _ _ _ Y~s _ _ . _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ _ . _ . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . _ . .. . . . . . . . . . . . . . _ _ Appr Date 28 .DrilJio9 fluid.p,rQg.ram schemati.c.& eq.uipJist.adequat~. . . _ . . . . . . . . _ .. _ _ _ . . . _ . . . . Y~s .. . _ _ . . . Maximum ßI:iP 8..35 EMW. .Plqnned mud weigh.t~ 8.6 -: 10..Q in reser:voi(.. . _ . . _ _ _ . _ _ _ . . . . . _ _ _ . . _ . . TEM 7/11/2003 29 .B.oPEs,.d.o .they me!:!t.reguJa.tiOI1 . . . _ _ . . _ .. _ _ _ _ . . . . . . . _ . _ . _ . . . . _ . . . . _ . . Y.ß$ . . .. . . . . . . . . . _ _ _ _ _ _ . . . . . . . . . . . . .. . . _ _ _ _ . _ _ _ _ . . . . _ _ . . _ . _ . . _ . . . . . . . . . _ _ . _ .. _ .. . . . 30 .B.oPE.pr~ss ra.tiOg qppropriate;.testto.(pu.t p~ig in.comments). _ _ _ _ _ _ _ _ . _ . _ . . _ . _ . _ Y~s _ _ . _ . _ _ CqlcuJa.t~d_MASP_ 1.3.13 p~i.. PlalJn.ed BOP.test press.ure.3.50Q psJ.. . .. . . _ . . . . . . . . . _ . _ . . . _ _ .. . . _ . .. 31 .c.hoke_manjfold ÇQmpJies. w/API.RP-53 (May 84). . _ . . .. _ . . _ . . _ . .. _ .. .. . _ . . _ _ . . . . .Y~s . _ . . _ . _ . _ . . . . . . . . _ _ . . . . .. . . . . . _ _ _ . . . . . _ . . _ . . _ _ _ . . _ _ . _ . _ . . . _ . . . . . . _ _ . _ .. 32 .WQrk will occ.ur withOIJt.operation .sbutdQ'Im. , _ . _ _ . _ _ . . . . . . . . . _ _ .. _ . . . . _ . . . . .Y~$ _ _ _ _ _ _ _ . . . . . . . _ . _ _ .. . . . . . . . . . . . _ . . . _ _ _ _ _ . _ . . _ _ _ . _ . . . . _ _ . _ . . _ . . . _ . . . .. _ .. 33 J~ pre~ence. Qf H2$ gas. p,rob.abl!:!. . _ . _ _ .. .. _ .. . _ _ _ . . . _ . . _ . . . . _ . . . . . . . . . . . N.o _ . . _ . . . . . . _ . _ . _ _ _ _ _ _ _ . _ . . . . . . _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ . . . . . _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ . 34 Meçl)a.nlCÇlI.coodjtion p{ W~II$ within AQR yerified. (for.s.ervicø w.ß1J QnJy). . .. . .. . . _ . . _ .. _ . NA . . _ . . _ _ _ . . . . . . . . . . . _ _ _ . _ . . . _ . _ . . . . . . . . . . . . _ _ . .. . . . . . . . . . _ _ . . . _ _ . . . .. _ _ .. . _ . .. . . Appr SFD ) Date Engineering ) Geology Appr SFD Date 7/10/2003 35 P.ßrrnitc.ao Þe i.ssued wlo. hydr:.ogen.s_utfide measJ,Jr:.es _ .. .. . _ . . . . . _ .. . . _ . . _ . . . _ _ _ _ Y.ßs _ . _ . . . . . _ . . . . _ . . . . . _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ . . .. . _ . _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ 36 D_ata.pres!:!otedon.pote.ntialoverpres.sure.zones... _ _.......... _... _. _... _... Y~s_ _ _.' _ .NQn.e.expe_ct..ed..Res.ervoirpress.ure.a_nticipate_d.i~8.35ppg.EMW;.will.be.d.rilJ~d.wit!1.8..6.-_10.Pppgmuc!.... _ _. 37 .S~i~r:nic.analysjs. Qf shaJlow gas.zoo~s. . . _ . . . . . . . . _ _ . _ . _ . . . . _ _ .. .. . . .. . _ . . . NA . . _ .. _ . .. .. . . . _ . . _ . . _ _ . . _ . . . . . . . _ . . _ . _ _ _ . _ _ _ _ . . . . . . . . . . . . . . . _ . _ . . _ _ _ . .. . _ 38 .S~abed _conditipo survey .(if off-~hpr:.e) .. _ . _ _ .. . .. _ _ _ _ . . . . . . _ .. _ . . . . . . . . . . . . . NA. _ .. _ . _ _ . . . .. . . .. .. .. _ . _ . . . . . . . _ . . . . . . . . . . . . . . . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ .. _ _ _ _ . _ _ . . _ _ _ _ _ 39 . CQnta.ct nam_e(p!1one.for.we!:!kly progre~s.rep-orts [explQratory .only). . . . . . .. .. . _ _ _ . . . . . NA . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . _ . . .. . _ . . . . . . . . . . . . . . _ . _ . . . . . . . . . _ _ _ _ .. _ . . . . _ . _ _ . Geologic Engineering Date Public Date orsoner.lI¡O;,'J Commissioner: Commissioner ~ ........G" ~ -) ~ \: -- '- "-- [J D ) ) Well H ¡story File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, infomlation of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. · ), . Sperry-Sun Drl~llng Servlces LIS Scan Utility ') !)ô3-/{} 5 -=# 113Lf3 $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 27 09:21:59 2003 Reel Header Service name........... . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/08/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........ ....... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-08 PB1 500292316870 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 27 -AUG- 03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW2567095 J. STRAHAN C. DIXON MWD RUN 2 AK-MW2567095 J. STRAHAN C. DIXON MWD RUN 3 AK-MW2567095 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3349 35 72.45 38.60 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.125 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 112.0 2776.0 5284.0 RECEIVED # AUG 29 2003 '~~'D ,y\ 0~ Al.a œ &. Gas COOß. CommiMn Anchorage REMARKS: ) ) 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED AT-BIT-INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/22/03. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1, 2, AND 3 REPRESENT WELL MPS-08 PB1 WITH API#: 50-029-23168-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5651'MD/4002'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name......... ... .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS 1 and clipped curves; all bit runs merged. .5000 START DEPTH 68.5 113.5 2757.0 2757.0 2757.0 2757.0 STOP DEPTH 5597.0 5651.0 5604.5 5604.5 5604.5 5604.5 RPX $ 2757.0 ) 5604.5 ') # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 68.5 2783.0 5290.0 MERGE BASE 2783.0 5290.0 5651.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 5651 2859.75 11166 68.5 5651 ROP MWD FT/H 1.63 2152.47 263.923 11076 113.5 5651 GR MWD API 7.86 124.47 66.1686 11058 68.5 5597 RPX MWD OHMM 0.16 2000 18.9806 5696 2757 5604.5 RPS MWD OHMM 0.19 2000 31.8316 5696 2757 5604.5 RPM MWD OHMM 0.07 2000 41.5282 5696 2757 5604.5 RPD MWD OHMM 0.1 2000 39.6668 5696 2757 5604.5 FET MWD HOUR 0.08 39.95 1.63202 5696 2757 5604.5 First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .5651 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 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...... .03/08/27 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ') header data for each bit run in separate files. 1 .5000 START DEPTH 68.5 113.5 STOP DEPTH 2738.5 2783.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 23-JUL-03 Insite 66.37 Memory 2783.0 112.0 2783.0 .0 50.1 TOOL NUMBER 155790 13.500 112.0 Spud Mud 9.55 109.0 9.0 300 9.8 .000 .000 .000 .000 .0 77.0 .0 .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): ) ) # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value........... . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 2783 1425.75 5430 68.5 2783 ROP MWD010 FT/H 28.45 1888.02 269.661 5340 113.5 2783 GR MWD010 API 18.21 123.89 64.0065 5341 68.5 2738.5 First Reading For Entire File......... .68.5 Last Reading For Entire File......... ..2783 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type............... .LO Next File Name... ....... .STSLIB.003 Physical EOF File Header Service name....... ..... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 3 header data for each bit run in separate files. 2 .5000 START DEPTH STOP DEPTH GR FET RPD RPM RPX RPS ROP $ ') 5250.5 5243.0 5243.0 5243.0 5243.0 5243.0 5290.0 2739.0 2757.0 2757.0 2757.0 2757.0 2757.0 2783.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing........... ......... .60 .1IN Max frames per record... ......... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 26-JUL-03 Insite 66.37 Memory 5290.0 2783.0 5290.0 33.1 78.9 TOOL NUMBER 155789 56933 9.875 2776.0 LSND 9.25 56.0 7.0 200 6.1 2.700 2.090 8.000 2.350 72.0 95.0 72.0 72.0 ) ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2739 5290 4014.5 5103 2739 5290 Rap MWD020 FT/H 1.63 2152.47 280.33 5014 2783.5 5290 GR MWD020 API 7.86 124.47 67.9814 5024 2739 5250.5 RPX MWD020 OHMM 2.19 2000 19.0331 4973 2757 5243 RPS MWD020 OHMM 2.14 2000 21.3604 4973 2757 5243 RPM MWD020 OHMM 2.16 2000 22.5709 4973 2757 5243 RPD MWD020 OHMM 2.28 2000 22.7396 4973 2757 5243 FET MWD020 HOUR 0.08 39.95 0.984917 4973 2757 5243 First Reading For Entire File.... ..... .2739 Last Reading For Entire File.......... .5290 File Trailer Service name............ .STSLIB.003 Service Sub Level Name.. . Version Number......... ..1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . La 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..... ..03/08/27 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 RPD RPM RPS RPX FET GR Rap 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5243.5 5243.5 5243.5 5243.5 5243.5 5251.0 5290.5 STOP DEPTH 5604.5 5604.5 5604.5 5604.5 5604.5 5597.0 5651.0 $ ) # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ..... .... ....0 Data Specification Block Type. ....0 Logging Direction.......... ...... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value...... ............... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 28-JUL-03 Insite 66.37 Memory 5651.0 5290.0 5651.0 80.2 91.7 TOOL NUMBER 65036 148574 6.125 5284.0 LSND 9.35 54.0 9.0 59000 4.0 .070 .060 .100 .090 75.0 85.8 70.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM RPD FET MWD030 MWD030 MWD030 OHMM OHMM HOUR ) ':I: 4 4 20 24 28 ') 1 1 1 68 68 68 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5243.5 5651 5447.25 816 5243.5 5651 Rap MWD030 FT/H 2.52 684.9 107.551 722 5290.5 5651 GR MWD030 API 32.67 97.77 69.6908 693 5251 5597 RPX MWD030 OHMM 0.16 2000 18.6198 723 5243.5 5604.5 RPS MWD030 OHMM 0.19 2000 103.856 723 5243.5 5604.5 RPM MWD030 OHMM 0.07 2000 171.922 723 5243.5 5604.5 RPD MWD030 OHMM 0.1 2000 156.097 723 5243.5 5604.5 FET MWD030 HOUR 0.38 38 6.083 723 5243.5 5604.5 First Reading For Entire File......... .5243.5 Last Reading For Entire File.......... .5651 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name. .......... ..LISTPE Date. . . .. . . . . .. . . . . . . . . . .03/08/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name..... ..... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/08/27 Origin. . . . . . . .. . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File S )1" perry-Sun Dr1~ 1ng Serv1ces LIS Scan Utility ') ~Q3- '<:93 Æ \\<gL(~ $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 27 09:54:41 2003 Reel Header Service name.... . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-08 500292316800 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 27-AUG-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW2567095 J. STRAHAN C. DIXON MWD RUN 2 AK-MW2567095 J. STRAHAN C. DIXON MWD RUN 3 AK-MW2567095 J. STRAHAN C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW2567095 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3349 35 72.45 38.60 RECEIVED # WELL CASING RECORD AUG 2 9 2003 OPEN HOLE CASING DRILLERS ~~ '-- '\. ~ · "C)I\~" 1 ,~,. Alaska on & Gas Cons. CommileiÐn Anchorage 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING ) BIT S.L£JE 13.500 9.875 6.125 (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 10.750 2776.0 7.625 5284.0 ) # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK, EFFECTED AT 5350'MD/4005'TVD IN THE MPS-08 PBl WELLBORE. THE SIDE TRACK WAS NECESSITATED DUE TO JUNK IN THE ORIGINAL WELLBORE AND FOR RESERVOIR QUALITY CONCERNS. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 3 & 4 ALSO INCLUDED AT-BIT- INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/22/03. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 4 REPRESENT WELL MPS-08 WITH API#: 50-029-23168-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10009'MD/4077'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.......... ...STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record..65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 ) ') and clipped curves; all bit runs merged. .5000 START DEPTH 68.5 113.5 2757.0 2757.0 2757.0 2757.0 2757.0 STOP DEPTH 9955.0 10008.5 9962.0 9962.0 9962.0 9962.0 9962.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 68.5 2783.0 5290.0 5350.0 MERGE BASE 2783.0 5290.0 5349.5 10008.5 # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction........ ........ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 10008.5 5038.5 19881 68.5 10008.5 ROP MWD FT/H 1.28 2286.38 245.188 19791 113.5 10008.5 GR MWD API 7.86 124.47 61.9411 19774 68.5 9955 RPX MWD OHMM 0.16 2000 26.2827 14411 2757 9962 RPS MWD OHMM 0.19 2000 86.4998 14411 2757 9962 RPM MWD OHMM 0.07 2000 109.081 14411 2757 9962 RPD MWD OHMM 0.1 2000 123.934 14411 2757 9962 FET MWD HOUR 0.08 39.95 0.953543 14411 2757 9962 ') ) First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .10008.5 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 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..... ..03/08/27 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 68.5 113.5 STOP DEPTH 2738.5 2783.0 # 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: 23-JUL-03 Insite 66.37 Memory 2783.0 112.0 2783.0 .0 50.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER 155790 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): Spud Mud 9.55 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: ) ') 109.0 9.0 300 9.8 .000 .0 .000 77.0 .000 .0 .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point... .......... .Undefined Frame Spacing.... ............. ... .60 .1IN Max frames per record.... ..... ... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 2783 1425.75 5430 68.5 2783 ROP MWD010 FT/H 28.45 1888.02 269.661 5340 113.5 2783 GR MWD010 API 18.21 123.89 64.0065 5341 68.5 2738.5 First Reading For Entire File...... ....68.5 Last Reading For Entire File......... ..2783 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.. ...... ...1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .v}/08/27 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 2739.0 2757.0 2757.0 2757.0 2757.0 2757.0 2783.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 5250.5 5243.0 5243.0 5243.0 5243.0 5243.0 5290.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 26-JUL-03 Insite 66.37 Memory 5290.0 2783.0 5290.0 33.1 78.9 TOOL NUMBER 155789 56933 9.875 2776.0 LSND 9.25 56.0 7.0 200 6.1 2.700 2.090 8.000 2.350 72.0 95.0 72.0 72.0 # ') ) REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value........ . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2739 5290 4014.5 5103 2739 5290 ROP MWD020 FT/H 1.63 2152.47 280.33 5014 2783.5 5290 GR MWD020 API 7.86 124.47 67.9814 5024 2739 5250.5 RPX MWD020 OHMM 2.19 2000 19.0331 4973 2757 5243 RPS MWD020 OHMM 2.14 2000 21.3604 4973 2757 5243 RPM MWD020 OHMM 2.16 2000 22.5709 4973 2757 5243 RPD MWD020 OHMM 2.28 2000 22.7396 4973 2757 5243 FET MWD020 HOUR 0.08 39.95 0.984917 4973 2757 5243 First Reading For Entire File......... .2739 Last Reading For Entire File.......... .5290 File Trailer Service name.......... ...STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 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 FET RPD RPM RPS RPX GR ROP $ ) 4 ') header data for each bit run in separate files. 3 .5000 START DEPTH 5243.5 5243.5 5243.5 5243.5 5243.5 5251.0 5290.5 STOP DEPTH 5349.5 5349.5 5349.5 5349.5 5349.5 5349.5 5349.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 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 28-JUL-03 Insite 66.37 Memory 5350.0 5290.0 5350.0 80.2 91.7 TOOL NUMBER 65036 148574 6.125 5284.0 FLO-PRO 9.35 54.0 9.0 59000 3.8 .070 .060 .100 .090 75.0 85.8 70.0 72.0 · .. ) Logglng Dlrectl0n................ . Down optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5243.5 5349.5 5296.5 213 5243.5 5349.5 ROP MWD030 FT/H 14.23 395 200.976 119 5290.5 5349.5 GR MWD030 API 32.67 85.18 51.4949 198 5251 5349.5 RPX MWD030 OHMM 0.16 2000 35.403 213 5243.5 5349.5 RPS MWD030 OHMM 0.19 2000 313.424 213 5243.5 5349.5 RPM MWD030 OHMM 0.07 2000 529.996 213 5243.5 5349.5 RPD MWD030 OHMM 0.1 2000 455.349 213 5243.5 5349.5 FET MWD030 HOUR 0.53 38 17.5755 213 5243.5 5349.5 First Reading For Entire File......... .5243.5 Last Reading For Entire File.......... .5349.5 File Trailer Service name......... ... .STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .03/08/27 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.... ...03/08/27 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 5 header data for each bit run in separate files. 4 .5000 VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ ") START ùJ::¡PTH 5350.0 5350.0 5350.0 5350.0 5350.0 5350.0 5350.0 STOP DEPTH 9962.0 9962.0 9962.0 9962.0 9955.0 10008.5 9962.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing........ ............ .60 .1IN Max frames per record........... ..Undefined Absent value... ..... ..... ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . ) 30-JUL-03 Insite 66.37 Memory 10009.0 5350.0 10009.0 83.0 94.5 TOOL NUMBER 65036 148574 6.125 5284.0 FLO-PRO 9.40 52.0 8.0 64000 4.4 .070 .060 .100 .090 75.0 93.5 70.0 72.0 Datum . f' . 1 '): b ) Specl lcatlon Bock su -type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5350 10008.5 7679.25 9318 5350 10008.5 ROP MWD040 FT/H 1.28 2286.38 212.818 9318 5350 10008.5 GR MWD040 API 19.39 114.79 57.6734 9211 5350 9955 RPX MWD040 OHMM 4.3 2000 29.9802 9225 5350 9962 RPS MWD040 OHMM 5.34 2000 116.376 9225 5350 9962 RPM MWD040 OHMM 5.73 2000 145.998 9225 5350 9962 RPD MWD040 OHMM 6.61 2000 170.833 9225 5350 9962 FET MWD040 HOUR 0.12 18.28 0.552838 9225 5350 9962 First Reading For Entire File......... .5350 Last Reading For Entire File....... ... .10008.5 File Trailer Service name........ .... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/27 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name....... ... .UNKNOWN Comments............. ... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments............. ... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF ) ) End Of LIS File