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193-048
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install tubing patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5,234 feet N/A feet true vertical 4,312 feet N/A feet Effective Depth measured 5,234 feet 4,615 feet true vertical 4,313 feet 3,703 feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 4,308' 3,449' Packers and SSSV (type, measured and true vertical depth)Baker SC-1R N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name:Chad Helgeson Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 1,130psi 2,020psi Burst 3,730psi 3,250psi 777-8343 13-3/8" 9-5/8" 7" 2,366' 3,957' 5,410psi WINJ WAG 2,736' 4,876' Surface Production Oil-Bbl 7,240psi dhaakinson@hilcorp.com 260 MILNE PT UNIT G-08A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 40 Gas-Mcf 260 Casing Pressure Tubing Pressure 34 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-372 232 Authorized Signature with date: David Haakinson 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 2040 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-048 50-029-22141-01-00 115' Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Plugs ADL025906 N/A measured 115' measured true vertical Packer Size N/A Casing Conductor Length 619 Operations Manager 0 Water-Bbl MD 115' 2,736' 4,876' TVD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:07 am, Sep 02, 2021 Chad Helgeson (1517) 2021.09.02 10:58:41 - 08'00' MGR11OCT2021 DSR-9/2/21 SFD 9/2/2021 RBDMS HEW 9/2/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP G-08A Slickline 50-029-22141-01-00 193-048 7/24/2021 7/24/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. DRIFT TBG WITH 2.06"" CENT, 1.75"" S-BAILER TO DISCHARGE HEAD AT 4138' SLM/4138' MD (no restrictions, bailer empty). SET CSV IN XN-NIP AT 4096' SLM/4096' MD, ATTEMPT TO MIT-T 1500psi WITH TRI-PLEX (unsuccessful). LRS ESTABLISH LEAK RATE AT .65 bpm @ 800psi, FIND LEAK WITH D&D HOLEFINDER BETWEEN 4050' & 4096' SLM. RUN LDL WITH ROPE AND FIND HOLE AT 4065' SLM WITH LRS RATE AT .65 bpm @ 800psi (tools grab and TBG psi climbs). MAKE 5 RUNS AND SET D&D PATCH FROM 4081' SLM TO 4040' SLM (OAL=531""). UPPER D&D SLIP STOP (OAL=18""), D&D PACKOFF 15' STINGER (OAL=208""), 20' STINGER (OAL=254""), D&D PACKOFF (OAL=25""), LOWER D&D SLIP STOP (OAL=26""). RDMO, CLOSE PERMIT W/PAD-OP, TAG WELL. 7/24/2021 - Saturday Hilcorp Alaska, LLC Weekly Operations Summary _____________________________________________________________________________________ Revised By: DH 9/1/2021 SCHEMATIC Milne Point Unit Well: MPU G-08A Last Completed: 11/04/15 PTD: 193-048 TD =5,234’(MD) / TD =4,312’(TVD) 2 13-3/8” TOC Est @ 3,900’ Orig. KB Elev.: 35’AGL (Nabors 27E) 7” 4 7 8 109 11 13 14 15 9-5/8” 1 3 17 16 Tubing Patch Top @ 4,040’ Btm @ 4,081' PBTD = N/A(MD)/ PBTD = N/A (TVD) 6 7”HOS Cementer @ 4,823’ 5 External Csg Packer @ 4,836’ 9 12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.615 Surface 115' 9-5/8" Surface 36 / K-55 / Btrc. 8.921 Surface 2,736’ 7" Production 26 / L-80 / Btrc 6.276 Surface 4,876’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf 4,308’ JEWELRY DETAIL No Depth Item 1 137’ GLM Camco 2-7/8” x 1” Side pocket KBMM 2 2,444’ Heat Trace 3 4,016’ GLM Camco 2-7/8” x 1” Side pocket KBMM 4 4,096’ 2.31” XN Nipple:2.25” No Go 5 4,138’ Discharge Head: FPDIS 6 4,139’ Pump: SXD 119 FLEX 10 7 4,162’ Gas Separator Intake 8 4,167’ Tandem Seal Section 9 4,179’ ESP Shroud, 5.5” 15.5# (Hanging off motor, suspending sand control screens) 10 4,179’ MSP1-325 Motor, 56HP, 1,745 Volt, 21 Amp 11 4,191’ Phoenix Sensor w/ 6 Fin Centralizer:Bottom @ 4,195’ 12 4,196’ 4.0” Bakerweld 8-Gauge Sand control screens (3 jts) :Bottom @ 4,308’ 13 4,615’ Packer: Baker Model – SC-1R w/ 4.0” ID 14 4,628’ Sliding Sleeve: Baker Model ‘S’ 4.38” ID 15 4,883’ Johnson Pre-Pack Single Screens 4.5” x 2-7/8” 12ga. 2.44” ID, 17 jts, 342’ Long 16 5,226’ Flapper Valve Assembly 17 5,227’ Baker V-Set Shoe w/ Check Valves - 2.0” ID OPEN HOLE DETAIL The 8.5” open hole was under-reamed to 12” below the 7” casing shoe from 4,870’ to 5,234’ (3,956’ to 4,312’ TVD.) “NA” sand top 4,882’MD/ 3,968’TVD. “OB” sand base 5,146’MD/ 4,226’TVD. OPEN HOLE / CEMENT DETAIL 20" 452 sx of Arcticset IV in 30” Hole 9-5/8" 900 sx Perm E, 300 sx Class ‘G’ in 12-1/4” Hole 7” 195 sx Premium “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 50 deg. @ 3,250’ MD Max Hole Angle through perforations = 19 deg. TREE & WELLHEAD Tree WKM 2-9/16” 5M Wellhead 11” 5M FMC w/ 11” x 2-7/8” FMC Tbg. Hngr., 2-7/8” 8rd Threads T&B. 2.5” CIW BPV profile GENERAL WELL INFO API: 50-029-22141-01-00 Sidetrack Completed by Nabors 27E - 7/22/1993 RWO & Multiple Gravel Packs – 4/4/1995 RWO w/ Nabors 4ES – 6/15/2000 RWO w/ Nabors 3S – 7/7/2008 RWO w/ ASR 1 – 11/03/2015 Tubing Patch – 7/24/2021 GRAVEL PACK DETAIL 4-1/2” OD x 2-7/8” pre-packed single screen liner surrounded by 22,000lbs of 20/40 sand. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install Tubing patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 5,240'N/A Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng David Haakinson COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025906 193-048 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22141-01-00 Hilcorp Alaska LLC Length Size 4,318' 4,300' 3,442' 1,162 N/A MILNE POINT / SCHRADER BLUFF OIL 115' 115' 6.5#/ L-80/ EUE 8rd TVD Burst 3,410' MD N/A 3,520psi 7,240psi 2,366' 3,957' 2,736' 4,876' See Schematic 115' 13-3/8" 9-5/8" 7" 2,736' 4,876' Authorized Signature: 7/24/2021 2-7/8" Perforation Depth MD (ft): See Schematic MILNE PT UNIT G-08A CO 477.05 SC-1R Packer and N/A 4,615MD / 3,703TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 3:15 pm, Jul 26, 2021 321-372 Chad Helgeson (1517) 2021.07.26 15:06:38 - 08'00' DLB 07/26/2021 X DSR-7/26/21MGR29JUL21 10-404 dts 7/30/2021 JLC 7/30/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.30 10:54:16 -08'00' RBDMS HEW 7/30/2021 Tubing Patch Well: MPU G-08 Date: 07-26-2021 Well Name:MPU G-08 API Number: 50-029-22141-00-00 Current Status:Shut In- ESP Producer Pad:G-Pad Estimated Start Date:July 24th, 2021 Wellwork unit:SL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:193-048 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 AFE Number:Job Type:Tubing Patch Current Bottom Hole Pressure:1,500 psi @ 3,382’ TVD Downhole Gauge (7/24/2021) |8.53 PPG Maximum Expected BHP:1,500 psi @ 3,382’ TVD 8.53 PPG MPSP:1,162 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 48° @ 2,800’ MD BPV Profile:2-1/2” CIW Type H Brief Well Summary: MPU producer G-08 was drilled and completed in 1993 as a Schrader Bluff producer. It has had a history of solids production and was shut in due to an apparent ESP shaft break in July 2017. After a review of the well in June 2021, it was determined that the ESP may not have been compromised and the tubing was tested, finding a leak with a rate of 0.65 BPM. Notes Regarding Wellbore Condition x Tubing leak confirmed at 4,065’ MD on 07-24-2021. x A tubing patch was set after the leak was found on 7-26-2021 due to the efficiency of the operation. o The well will remain shut in until the 10-403 is approved. Objective: x Set D&D tubing patch Procedure Slickline (completed on 7/24/21) 1. MIRU SL. PT lubricator to 200 psig low, 2,500 psig high. 2. RU LRS for pump support. 3. Set CAT-SV in XN Nipple @ 4,096’ MD. 4. Pressure Test Tubing to 1,500 psi. 5. RIH w/ D&D hole-finder to locate a tubing leak. Move up-hole to locate leak. 6. RIH w/ rope leak detect to leak interval and locate leak depth at 4,065’ MD. Note: Remainder of work was completed in single day due to materials on location and efficiency of operation. 7. Flag wire and POOH. 8. Pull CAT-SV from XN Nipple @ 4,096’ MD. Tubing Patch Well: MPU G-08 Date: 07-26-2021 9. Set D&D slip-stop at 4,081’ MD. 10. Set D&D Pack-off on top of slip-stop @ 4,080’ MD. 11. Set 35’ of stinger and spacer pipe across tubing leak @ 4,065’ MD. 12. Set Upper Pack off Assembly @ ±4,045’ MD. 13. Set D&D slip-stop on top of upper pack-off. 14. RDMO Slick-line and LRS. Leave well SI. Attachments: 1) Current Schematic 2) Proposed Schematic _____________________________________________________________________________________ Revised By: STP 12/17/2015 SCHEMATIC Milne Point Unit Well: MPU G-08A Last Completed: 11/04/15 PTD: 193-048 TD =5,234’(MD) / TD =4,312’(TVD) 2 13-3/8” TOC Est @ 3,900’ Orig. KB Elev.: 35’AGL (Nabors 27E) 7” 4 7 8 109 11 13 14 15 9-5/8” 1 3 17 16 PBTD =N/A(MD)/ PBTD = N/A (TVD) 6 7”HOS Cementer @ 4,823’ 5 External Csg Packer @ 4,836’ 9 12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.615 Surface 115' 9-5/8" Surface 36 / K-55 / Btrc. 8.921 Surface 2,736’ 7" Production 26 / L-80 / Btrc 6.276 Surface 4,876’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf 4,308’ JEWELRY DETAIL No Depth Item 1 137’ GLM Camco 2-7/8” x 1” Side pocket KBMM 2 2,444’ Heat Trace 3 4,016’ GLM Camco 2-7/8” x 1” Side pocket KBMM 4 4,096’ 2.31” XN Nipple:2.25” No Go 5 4,138’ Discharge Head: FPDIS 6 4,139’ Pump: SXD 119 FLEX 10 7 4,162’ Gas Separator Intake 8 4,167’ Tandem Seal Section 9 4,179’ ESP Shroud, 5.5” 15.5# (Hanging off motor, suspending sand control screens) 10 4,179’ MSP1-325 Motor, 56HP, 1,745 Volt, 21 Amp 11 4,191’ Phoenix Sensor w/ 6 Fin Centralizer:Bottom @ 4,195’ 12 4,196’ 4.0” Bakerweld 8-Gauge Sand control screens (3 jts) :Bottom @ 4,308’ 13 4,615’ Packer: Baker Model – SC-1R w/ 4.0” ID 14 4,628’ Sliding Sleeve: Baker Model ‘S’ 4.38” ID 15 4,883’ Johnson Pre-Pack Single Screens 4.5” x 2-7/8” 12ga. 2.44” ID, 17 jts, 342’ Long 16 5,226’ Flapper Valve Assembly 17 5,227’ Baker V-Set Shoe w/ Check Valves - 2.0” ID OPEN HOLE DETAIL The 8.5” open hole was under-reamed to 12” below the 7” casing shoe from 4,870’ to 5,234’ (3,956’ to 4,312’ TVD.) “NA” sand top 4,882’MD/ 3,968’TVD. “OB” sand base 5,146’MD/ 4,226’TVD. OPEN HOLE / CEMENT DETAIL 20" 452 sx of Arcticset IV in 30” Hole 9-5/8" 900 sx Perm E, 300 sx Class ‘G’ in 12-1/4” Hole 7” 195 sx Premium “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 50 deg. @ 3,250’ MD Max Hole Angle through perforations = 19 deg. TREE & WELLHEAD Tree WKM 2-9/16” 5M Wellhead 11” 5M FMC w/ 11” x 2-7/8” FMC Tbg. Hngr., 2-7/8” 8rd Threads T&B. 2.5” CIW BPV profile GENERAL WELL INFO API: 50-029-22141-01-00 Sidetrack Completed by Nabors 27E - 7/22/1993 RWO & Multiple Gravel Packs – 4/4/1995 RWO w/ Nabors 4ES – 6/15/2000 RWO w/ Nabors 3S – 7/7/2008 RWO w/ ASR 1 – 11/03/2015 GRAVEL PACK DETAIL 4-1/2” OD x 2-7/8” pre-packed single screen liner surrounded by 22,000lbs of 20/40 sand. _____________________________________________________________________________________ Revised By: TDF 7/26/2021 PROPOSED Milne Point Unit Well: MPU G-08A Last Completed: 11/04/15 PTD: 193-048 TD = 5,234’(MD) / TD =4,312’(TVD) 2 13-3/8” TOC Est @ 3,900’ Orig. KB Elev.: 35’AGL (Nabors 27E) 7” 4 7 8 109 11 13 14 15 9-5/8” 1 3 17 16 Tubing Patch Top @ ±4,045’ Btm @ ±4,080' PBTD = N/A(MD)/ PBTD = N/A (TVD) 6 7”HOS Cementer @ 4,823’ 5 External Csg Packer @ 4,836’ 9 12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.615 Surface 115' 9-5/8" Surface 36 / K-55 / Btrc. 8.921 Surface 2,736’ 7" Production 26 / L-80 / Btrc 6.276 Surface 4,876’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf 4,308’ JEWELRY DETAIL No Depth Item 1 137’ GLM Camco 2-7/8” x 1” Side pocket KBMM 2 2,444’ Heat Trace 3 4,016’ GLM Camco 2-7/8” x 1” Side pocket KBMM 4 4,096’ 2.31” XN Nipple:2.25” No Go 5 4,138’ Discharge Head: FPDIS 6 4,139’ Pump: SXD 119 FLEX 10 7 4,162’ Gas Separator Intake 8 4,167’ Tandem Seal Section 9 4,179’ ESP Shroud, 5.5” 15.5# (Hanging off motor, suspending sand control screens) 10 4,179’ MSP1-325 Motor, 56HP, 1,745 Volt, 21 Amp 11 4,191’ Phoenix Sensor w/ 6 Fin Centralizer:Bottom @ 4,195’ 12 4,196’ 4.0” Bakerweld 8-Gauge Sand control screens (3 jts) :Bottom @ 4,308’ 13 4,615’ Packer: Baker Model – SC-1R w/ 4.0” ID 14 4,628’ Sliding Sleeve: Baker Model ‘S’ 4.38” ID 15 4,883’ Johnson Pre-Pack Single Screens 4.5” x 2-7/8” 12ga. 2.44” ID, 17 jts, 342’ Long 16 5,226’ Flapper Valve Assembly 17 5,227’ Baker V-Set Shoe w/ Check Valves - 2.0” ID OPEN HOLE DETAIL The 8.5” open hole was under-reamed to 12” below the 7” casing shoe from 4,870’ to 5,234’ (3,956’ to 4,312’ TVD.) “NA” sand top 4,882’MD/ 3,968’TVD. “OB” sand base 5,146’MD/ 4,226’TVD. OPEN HOLE / CEMENT DETAIL 20" 452 sx of Arcticset IV in 30” Hole 9-5/8" 900 sx Perm E, 300 sx Class ‘G’ in 12-1/4” Hole 7” 195 sx Premium “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 50 deg. @ 3,250’ MD Max Hole Angle through perforations = 19 deg. TREE & WELLHEAD Tree WKM 2-9/16” 5M Wellhead 11” 5M FMC w/ 11” x 2-7/8” FMC Tbg. Hngr., 2-7/8” 8rd Threads T&B. 2.5” CIW BPV profile GENERAL WELL INFO API: 50-029-22141-01-00 Sidetrack Completed by Nabors 27E - 7/22/1993 RWO & Multiple Gravel Packs – 4/4/1995 RWO w/ Nabors 4ES – 6/15/2000 RWO w/ Nabors 3S – 7/7/2008 RWO w/ ASR 1 – 11/03/2015 GRAVEL PACK DETAIL 4-1/2” OD x 2-7/8” pre-packed single screen liner surrounded by 22,000lbs of 20/40 sand. STATE OF ALASKA ALO OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program Q Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑� Re-enter Susp Well❑ Other: ESP Change-out ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 193-048 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22141-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL025906 MILNE PT UNIT SB G-08A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JAN ® 6 2016 N/A MILNE POINT/SCHRADER BLUFF OIL v 11.Present Well Condition Summary: A )GCC Total Depth measured 5,234 feet Plugs measured N/A feet true vertical 4,312 feet Junk measured N/A feet Effective Depth measured 5,234 feet Packer measured 4,615 feet true vertical 4,312 feet true vertical 3,703 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 2,736' 9-5/8" 2,736' 2,366' 3,250psi 2,020psi Production 4,876' 7" 4,876' 3,957' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNEV' MAR 0 3 2016 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,259' 3,410' 4,615'MD Packers and SSSV(type,measured and true vertical depth) SC-1R N/A 3,703'TVD 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 0 220 0 Subsequent to operation: 481 107 1,040 200 202 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory❑ Development ID Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.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: 315-494&315-652 Contact Stan Porhola Email sporhola(C�hilcorp.com Printed Name Bo York t� v Title Operations Engineer Signature —� l%'"` t'+aµ S c,,,,, �C to/Phone 777-8345 Date 1/6/2016 / i–//–/CiP V(,RBDMS JAN 0 7 2016 im' ,,A Form 10-404 Revised 5/2015 Submit Original Only • III Milne Point Unit Well: MPU G-08A SCHEMATIC Last Completed: 11/04/15 Ilileorp Alaska,LLC PTD: 193-048 CASING DETAIL Orig.KB Elev.:35'AGL(Nabors 27E) Size Type Wt/Grade/Conn ID Top Btm 4 N v, k,... 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 115' rt.,. 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,736' 13-3/8" 7" Production 26/L-80/Btrc 6.276 Surface 4,876' 1 Y TUBING DETAIL R 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 4,308' 's, JEWELRY DETAIL No Depth Item 1 137' GLM Camco 2-7/8"x 1"Side pocket KBMM 2 2,444' Heat Trace 1"' 3 4,016' GLM Camco 2-7/8"x 1"Side pocket KBMM a `t4 4,096' 2.31"XN Nipple:2.25"No Go 't I9-5/8"' (, 2 5 4,138' Discharge Head:FPDIS 6 4,139' Pump:SXD 119 FLEX 10 7 4,162' Gas Separator Intake 8 4,167' Tandem Seal Section 9 4,179' ESP Shroud,5.5"15.5#(Handing off motor,suspending sand control screens) 10 4,179' MSP1-325 Motor,56HP, 1,745 Volt,21 Amp 11 4,191' Phoenix Sensor w/6 Fin Centralizer:Bottom @ 4,195' 12 4,196' 4.0"Bakerweld 8-Gauge Sand control screens(3 jts):Bottom @ 4,308' TOC Est@ 13 4,615' Packer:Baker Model-SC-1R w/4.0"ID 3,900' 14 4,628' Sliding Sleeve:Baker Model'V 4.38"ID ''''41171, 15 4,883' Johnson Pre-Pack Single Screens 4.5"x 2-7/8"12ga.2.44"ID,17 jts,342'Long 3 16 5,226' Flapper Valve Assembly 17 5,227 Baker V-Set Shoe w/Check Valves-2.0"ID ea 4 OPEN HOLE DETAIL a>: ..; The 8.5"open hole was under-reamed to 12"below the 7"casing shoe from 4,870'to 5,234'(3,956'to ' " 4,312'TVD.)"NA"sand top 4,882'MD/3,968'TVD."OB"sand base 5,146'MD/4,226'TVD. > it GRAVEL PACK DETAIL 06 to s. 4 1/2"OD x 2-7/8"pre packed single screen liner surrounded by 22,000Ibs of 20/40 sand. illi 1`«7 WELL INCLINATION DETAIL , it 8 KOP @ 500' .0 sac 7 9 Max Hole Angle=50 deg.@ 3,250'MD 10 Max Hole Angle through perforations=19 deg. , - 1,i1 OPEN HOLE/CEMENT DETAIL r' & f 11 20" 452 sx of Arcticset IV in 30"Hole ii 9-5/8" 900 sx Perm E,300 sx Class'G'in 12-1/4"Hole '11 a 7" 195 sx Premium"G"in 8-1/2"Hole 12 ,i., TREE&WELLHEAD Tree WKM 2-9/16"5M VWellhead 11"5M FMC w/11"x 2-7/8"FMC Tbg.Hngr., r I.4 ;13 2-7/8"8rd Threads T&B.2.5"CIW BPV profile 7 HOS Cementer t - @4,823' i' •.. ° X14 GENERAL WELL INFO External Cs9 ' API:50-029-22141-01-00 Packer©4,836 1'^ Sidetrack Completed by Nabors 27E -7/22/1993 7 ' t RWO&Multiple Gravel Packs -4/4/1995 RWO w/Nabors 4ES-6/15/2000 147 PIO 15 RWO w/Nabors 3S-7/7/2008 RWO w/ASR 1-11/03/2015 ' 16 i,a pax 17 TD=5,234'(MD)/TD=4,312'(TVD) PBTD=N/A(MD)/PBTD=N/A(ND) Revised By:STP 12/17/2015 . • Hilcorp Alaska, LLC Weekly Operations Summary Well Name _ Rig API Number Well Permit Number Start Date End Date MP G-08A Pumping 50-029-2214-01-00 193-048 10/26/15 11/3/15 Daily Operations: 10/21/2015 Wednesday No activity to report. 10/22/2015 -Thursday No activity to report. 10/23/2015 - Friday No activity to report. 10/24/2015 -Saturday No activity to report. 10/25/2015 -Sunday Notified AOGCC of right to witness rig inspection & bop test, Chuck Scheve on 10-25-2015 @ 1600 hrs 10/26/2015- Monday Rig up Little Red Services on MPG-08A. Pressure test surface lines to 3,000 psi. Pump 160 bbls of 9.4 filtered brine down tubing taking returns up annulus to flow back tank, monitored wellbore for 10 minutes, well was on slight vacuum, install Cameron BPV, rig down Little Red Services. Nipple down production tree. Nipple up BOP. Install BOP enclosure. Spot rig over well. Raise Derrick, spot pit module pipe skate and pipe ramps. Rigged up co man shack and rig crew change out shack. Install accumulator lines to Bop stack. Install Riser on hydril to rig floor. 10/27/2015-Tuesday Continue rigging up on MPG-08A, Insulate and heat trace koomey lines and all circulating lines, Inspect rig with AOGCC Chuck Scheve. Fill pits with 9.4 ppg brine water. Continue insulating koomey lines and prepping rig for approval from AOGCC to continue workover operations. Continue load and tally new 2-7/8" tbg on pipe racks, Received 60 joints of BTS-8 tbg, Continue working on Boiler. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-08A ASR 50-029-2214-01-00 193-048 10/26/15 11/3/15 Dafj ®aerations: 1100 10/28/2015 -Wednesday Continue to prep rig for RWO, circulated 15 bbls of 9.4 heated filtered brine down tubing returning to flow back tank to warm up wellbore. Continue winterizing around rig floor and rig. Pulling BPV& install TWC. 10/29/2015-Thursday Prep rig for RWO on MPG-08A. Rig up to test BOPs, fill BOP and circulate warm fluid throughout system.Test BOPS er, AOGCC requirements, tested 2-7/8" x 5" VBRs, Blind Rams, all choke valves, kill line manuals,floor safety valve, dart valve to 250 psi low and 3,000 psi high pressure, held for 5 minutes each test.Test witnessed by AOGCC Bob Noble. 10/30/2015-Friday Standby for AOGCC approval, maintain rig. Pull 2 way check. Circulate 2 tubing volumes @ 3bpm @ 500 psi.Troubleshoot Link tilt. Make up 2-7/8" Landing joint, back out lock down screws, pull tubing hanger and lay down. Max pull 41k out of tbg spool,free wt 31K fill hole with 9.4 brine, pulling 2-7/8" tbg heat trace line & ESP cable. Filling the hole every 15 Joints, pulled 2,515 ft heat trace cable & retrieved 385-6 ft Flat Guards& 39-3ft Flat Guards all 1,566 bands retrieved From guards. Pulling 2-7/8" tbg ESP cable & ESP clamps fill hole up with 9.4 brine @ 5 bbl. Retrived lasalle clamps= 32, Protectolizers=4,Armster Guards=2. Break down lay down SXD 140-P10 Pump, KMH-A Motor 55HP/1,259V/26A- Pump Mate sensor¢ralizer. 10/31/2015-Saturday Load out ESP assy. Load pipe racks with 2-7/8"tubing. Make up 6" Bit, casing scraper&X0.Trip in the hole picking up singles of 2-7/8" tubing to 4,615'. Reverse circulate 1 tubing volume @ 2 BPM. Blow lines down.Trip out of the hole laying down 2-7/8" tubing. Lay down bit, casing scraper&XO. Load 2-7/8" tubing on pipe racks pick up make up 7' storm packer on tubing.Trip in the hole with 7' storm packer to 4,600 ft.Set 7' storm packer @ 4,600 ft. Fill BOP stack with 9.4 brine, close annular test casing from 4,600 ft to surface @ 2,000psi 30 min-Charted.Trip out of the hole with 2-7/8" tubing. 11/1/2015 -Sunday Trip out of the hole laying down 2-7/8" tubing&test ackerr.Load &strap BHA, with 1.66" clean out string. Install stripping head on BOP. Make up BHA#3 clean out assy. 3 blade junk mill, mud motor,jars, circulation sub, MHA, XO, 18 Joints of 1.660 BTS-8 Small tubing. Change handling tools, trip in the hole with clean-out assembly on 2-7/8" tubing.Tagged top of screens @ 4,605 ft. Continued tripping inside of the screens tagged top of fill @ 4,844 ft. Rigged up circulating rubber mix and pump N-Vis sweeps as per Halliburton Procedure, wash and circulate through tigh spot from 4,844 ft.to 4,846 ft. ICP =750psi @ 50 spm, continue washing sand from 4,846 ft to 5,065 ft. Fcp=980psi @ 50 spm lost circulation @ 5,065 ft. Drop ball sheared. Circulation sub @ 1,010 psi, P/U 27k, S/0=21K @ 5,065 ft.Trip out of the hole laying down 2-7/8"tbg. 11/2/2015- Monday Trip out of the hole, lay down clean out BHA. Rig down ESP cable hose, rig up floor&tools for ESP assy. Make up sand control screens gas separator intake, pick up &service ESP assembly.Trip in the hole with ESP assembly on 2-7/8"Tubing. 53 jts to 1,876 ft, install heat trace cable. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-08A ASR 50-029-2214-01-00 193-048 10/26/15 11/3/15 Dai lyperat ions: `,11 11/3/2015-Tuesday Continue to trip in hole with ESP completion on 2-7/8"tubing attaching heat trace cable. Make up tubing hanger and install ESP penetrator& heat trace penetrator. Splice ESP pigtail for tubing hanger& heat trace pigtail for tubing hanger. Installed ESP penetrator to hanger, attempt to install heat trace penetrator hanger, heat trace cable is too short to install into tubing hanger, re-splice cable to fit. Install heat trace penetrator to tubing hanger land hanger RILDS P/U=39k 5/0=22k H/T teminator=1 red, Lassale clamps=40, Protecterlizers=1, A24=32 Heat Trace Guards Long=379 Short=78 Bands=5;Remove Landing Joint Install TWC in Hanger. Rigging down rig floor, pit module, peak trucks moved two trailers from G-08A to E-21 trucks moved pipe handler misc. equipment to E-Pad. • •Tg Alaska Oiland Gas 1)- 4. THE STATEw ofA Conservation Commission t>�2 LAsKAL 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS/°' Fax: 907.276.7542 www.aogcc.alaska.gov EtItt Stan Porhola Operations Engineer w "f Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB G-08A Sundry Number: 315-652 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, -4C77 Daniel T. Seamount, Jr. Commissioner DATED this 3 d day of October, 2015 Encl. t 10341�15 EIVED,. E. .,.. STATE OF ALASKA {)rT 5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS p ' �l±a��+�a� S 20 MC 25.280 �AL,J 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑✓ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program 0 Plug for Redrill❑ Perforate New Pool ❑ Repair Well 2 Re-enter Susp Well ❑ Other. ESP Change-out ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 2 % 193-048 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22141-01-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 477.05✓ Will planned perforations require a spacing exception? Yes ❑ No ❑Q / MILNE PT UNIT SB G-08A ° 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025906 ' MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): • 5,240 • 4,318 ' 5,226 - 4,300 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' Surface 2,736' 9-5/8" 2,736' 2,366' 3,520psi 2,020psi Intermediate Production 4,876' 7" 4,876' 3,957' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8" 6.5#/L-80/8RD 4,259 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SC-1R Packer and N/A • 4,615MD/3,703ND and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/24/2015 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 correct to the best of my knowledge. Contact Stan Porhola Email sporhola(a)hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ,e/ Phone 777-8412 Date i y I lic COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316- ( € 2 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Locationion Clearance ❑ Other: if- 3 ) ,1751. /,6 0� S e ( ;�.sf = i -'-> t (.. ./.eSf •.s zt'CJe)ie -s4=. ( +c Spacing Exception Required? Yes ElNo LI Subsequent Form R(eequired: to.--L/011 400 vt50 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / U '3G /15 /C.d ,'15 (:) RIG44stAstgalid ��'�'/' Submit Form and Form 10 3 Revised 5/2015for 12 months f 911,17/Approval. Attachments in Duplicate • • 14 Well Prognosis Well: MPU G-08A Hilcorp Alaska,Lb Date: 10/14/2015 Well Name: MPU G-08A API Number: 50-029-22141-01 Current Status: SI Oil Well [ESP] Pad: G-Pad Estimated Start Date: October 24th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 193-048 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: rt i r � 2--/91,)- Current , ,'Current Bottom Hole Pressure: _1x689 p i @ 4,000' TVD (Last BHP measured 4/25/2015) Maximum Expected BHP: psi ©4,000' ND (No new perfs being added)/ Max.Allowable Surf Pressure: 4-p r `.30 p s (Based on SBHP taken 4/25/2015 and water cut of 50% (0.385psi/ft)with an added safety factor S-Re- -""^"r"' of 1,000' ND of oil cap) Brief Well Summary: MPU G-08A was drilled in 1993 using Nabors 22E as a sidetrack of the original G-08 wellbore and completed with a gravel packed completion in the Schrader Bluff sands. The well has had multiple ESPs due to excessive solids production. Notes Regarding Wellbore Condition • Suspect failed screens in gravel pack causing excessive solids production. • Casing last tested to 2,000 psi for 30 min down to 4,836'on 7/17/1993. Obiective: The purpose of this work/sundry is to pull the failed ESP, cleanout fill inside the gravel pack completion and run a new ESP with screens hung off the bottom. Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines.Clear and level area around well. 3. RU Little Red Services Pump.Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Reverse circulate at least one casing volume with ppg sea water down casing,taking returns up tubing to 500 bbl returns tank. pr'y> 6. Pump at least one tubing volume of$15 ppg seawater down tubing. 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services Pump and reverse out skid. 9. RU crane.Set BPV. ND Tree. NU 11" BOPE. RD crane. 10. NU BOPE house.Spot mud boat. WO Rig Procedure: • IA U 0 • Well Prognosis je' Hilcorp Alaska,LL, Well: MPU G-08A a'•J Date: 10/14/2015 ppb'" '4' ii• 11. MIRU Hilcorp ASR#1 WO Rig, ancilla�y e-guipment and lines to 500 bbl returns tank. 'tr r� �: 12. Pull BPV. Bleed any pressure off tubing and casing. O 13. Kill well w/8.5 ppg seawater as needed.Set TWC. 14. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8"test joint. 15. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking P,Y anywhere at surface.) ��k �• d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. Co.v e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 16. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. Pull TWC. Bleed any pressure off tubing and casing. Kill well w/8.5 ppg seawater as needed. 18. MU 2-7/8" landing joint(EUE)and BOLDS. 19. Pull over string weight(approx. 25k PU)on tubing hanger to confirm free. LD tubing hanger. 20. POOH. Lay 2-7/8"tubing on the pipe rack(plan to re-run tubing). Lay down ESP. 21. MU 6-1/8" bit and casing scraper and RIH w/2-7/8"tubing. 22. Scrape 7" 26#casing down to+/-4,615' MD(SC-1R Packer). 23. POOH. Lay 2-7/8"tubing on the pipe rack. LD bit and casing scraper. 24. Remove old tubing from pipe rack, installing 2-7/8" EUE thread protectors(140 sets). 25. Place new tubing(2-7/8" EUE)on pipe rack and tally. 26. PU RTTS and RIH w/2-7/8"tubing(new tubing). 27. Set RTTS at+/-4,600' MD. Fill annulus w/8.5 ppg sea water. `.Qs; 28. Test casing to 2,000 psi for 30 min and chart. „�Lyr 29. Bleed off casing.Release RTTS. POOH. LD RTTS. Lay down 2-7/8"tubing. 30. MU 2-1/4" mill, 1-11/16" motor,jars and RIH 30 jts of w/1.660" 3.02#BTS-8 small tubing. 31. MU crossover from 1.660" BTS-8 x 2-7/8" EUE tubing. L. RA.4 C'''t-'?- 2 S C F, 2. RIH w/2-7/8"tubing and clean out fill to seal sub at 5,220' MD below screens. �G)C�t) f ja(..( a. Min ID is 2.000"at seal sub(5,220'). b. Min ID is 2.440"thru screens(17 jts). C�r� ` jw: �„{ P G, c. Min ID is 3.960" above screens. ) �-�� 3 33. Attempt to circulate fill out of hole.Take returns to 500 bbl returns tank. ,z.Z6 .s- a. Clrc 20-40 bbl hi-vis sweeps using 8.5 ppg sea water w/N-VIS at 2-4 lb/bbl. ,�?? 4 f`t u✓'n$ (1,-1- l'E 0....„,,,,3 4,./-6,-,._ h e.tA-5;A, (4 N II i • Well Prognosis Well: MPU G-08A Hilcorp Alaska,LL) Date:10/14/2015 34. POOH. Lay down 1.660"and 2-7/8"tubing on the pipe rack. LD mill, motor and jars. 35. PU new 475 series ESP and RIH with new 2-7/8"8RD EUE L-80 tubing. a. Run 2-7/8"XN profile, 2 ea GLMS, and heat trace to+/-2,500'. b. RU to use clamps to secure heat trace to tubing(ensure adequate clamps). c. Run 5-1/2"shroud around ESP motor. d. Hang off 3 jts of sand control screens below ESP motor shroud. Y 36. Set base of ESP at+/-4,250' (Pump intake around+/-4,170'). 37. Land tubing hanger. RILDS. Lay down landing joint. a. Note PU (Pick Up)and SO (Slack Off)weights on tally. 38. Set BPV.Test tubing hanger to 250/5,000 psi. 39. RD Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 40. RD mud boat. RD BOPE house. Move to next well location. 41. RU crane. ND BOPE. NU existing 2-9/16" 5,000#tree. Pull BPV. 42. Set TWC.Test tree to 250/5,000 psi. Pull TWC. RD crane. 43. Move 500 bbl returns tank and rig mats to next well location. 44. Replace IA&OA pressure gauges if removed (7" &9-5/8"). 45. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic III Milne Point Unit Well: MPU G-08A H . SCHEMATIC Last Completed: 7/7/2008 Mewl)Alaska,LLC PTD: 193-048 CASING DETAIL Orig.KB Elev.:35'AGL(Nabors 27E) Size Type Wt/Grade/Conn ID Top Btm i 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 115' II k 0 V [ 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,736' 13-3/8' 7" Production 26/L-80/Btrc 6.276 Surface 4,876' 11 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 4,259' '' JEWELRY DETAIL ? ,� A No Depth Item h 1 147' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 «, $ � 2 2,522' Heat Trace �' 6° 3 4,054' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 I' { 4 4,193' 2.31"XN Nipple:2.25"No Go 4'5/8,A } 2 5 4,212' Discharge Head:FPHVDIS 6 4,213' Pump:SXD 140-P10 7 4,230' Gas Separator Intake 8 4,236' Tandem Seal Section N 9 4,249' MSP Motor,S5HP, 1,259 Volt,26 amp 10 4,257' Pumpmate w/6 Fin Centralizer:Bottom @ 4,259' 11 4,615' Packer:Baker Model-SC-1R w/4.0"ID 12 4,628' Sliding Sleeve:Baker Model'S'4.38"ID 13 4,883' Johnson Pre-Pack Single Screens 4.5"x 2-7/8"12ga.2.44"ID,17 jts,342'Long 14 5,228' Flapper Valve Assembly 15 5,233' Baker V-Set Shoe w/Check Valves-2.0"ID OPEN HOLE DETAIL TCC Est @ t ' The 8.5"open hole was under-reamed to 12"below the 7"casing shoe from 4,870'to 5,234'(3,956'to 3,900' ''.......„,.......i,.� ? x 4,312'TVD.)"NA"sand top 4,882'MD/3,968'TVD."OB"sand base 5,146'MD/4,226'TVD. 3 }r GRAVEL PACK DETAIL C.- +II �,; 4-1/2"OD x 2-7/8"pre-packed single screen liner surrounded by 22,000lbs of 20/40 sand. 1 4P WELL INCLINATION DETAIL ..f. k- �� KOP @ 500' a '11 Max Hole Angle=50 deg.@ 3,250'MD L"" Max Hole Angle through perforations=19 deg. 6 OPEN HOLE/CEMENT DETAIL iI I_ 7 20" 452 sx of Arcticset IV in 30"Hole #" 8 9-5/8" 900 sx Perm E,300 sx Class'G'in 12-1/4"Hole 4 7" 195 sx Premium"G"in 8-1/2"Hole 4" V TREE&WELLHEAD *" h;9 Tree WKM 2-9/16"5M itl Wt rj 11"5M FMC w/11"x 2-7/8"FMC Tbg.Hngr., (: Wellhead 2-7/8"8rd Threads T&B.2.5"CIW BPV profile 110 GENERAL WELL INFO T HOS Cementer ►'.a ).".4. 11 API:50-029-22141-01-00 @4,8'13' ,'' /r 12 Sidetrack Completed by Nabors 27E -7/22/1993 - t/' ' RWO&Multiple Gravel Packs -4/4/1995 Extend Csg ,Y Packer©4,836' r.4- ' RWOw/Nabors4ES-6/15/2000 7' " ¢ -4` RWO w/Nabors 35-7/7/2008 w~ r a 13 �a. yt ' ititi. ;,i.', ,',"f41';14 'C: 15 1D=5,240'(MD)/TD=4,318'(TVD) PBTD=N/A(MD)/PBTD=N/A(TVD) Revised By:STP 7/21/2015 H . • Milne Point Unit Well: MPU G-08A PROPOSED SCHEMATIC Last Completed: Proposed Hi!corp Alaska,LLC PTD: 193-048 CASING DETAIL Orig.KB Elev.:35'AGL(Nabors 27E) ` Size Type Wt/Grade/Conn ID Top Btm hi 0 , p,'t 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 115' r 0 �� 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,736' 73/8 4 t ) 7" Production 26/L-80/Btrc 6.276 Surface 4,876' v. 1 * TUBING DETAIL *: 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 4,250' s " JEWELRY DETAIL a 4 No Depth Item 1 150' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 2 2,500' Heat Trace 3 4,000' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 4 4,184' 2.31"XN Nipple:2.25"No Go 2 5 4,203' Discharge Head:FPHVDIS 9-5/8"' il 6 4,205' Pump:SXD 140-P10 7 4,228' Gas Separator Intake 8 4,227' Tandem Seal Section 9 4,240' MSP Motor,55HP, 1,259 Volt,26 amp 10 4,248' Pumpmate w/6 Fin Centralizer:Bottom @ 4,250' 11 4,265' ESP Shroud,5.5"15.5#(Handing off motor,suspending sand control screens) .1 12 4,270' Sand control screens(3 jts) TOC Est @ 13 4,615' Packer:Baker Model-SC-1R w/4.0"ID 3,900 14 4,628' Sliding Sleeve:Baker Model'5'4.38"ID :ka 15 4,883' Johnson Pre-Pack Single Screens 4.5"x 2-7/8"12ga.2.44"ID,17 jts,342'Long y3 V 16 5,228' Flapper Valve Assembly }' 17 5,233' Baker V-Set Shoe w/Check Valves-2.0"ID R k„ 67, Ewa I » 4: OPEN HOLE DETAIL % ',Li, 8.5"open hole was under-reamed to 12"below the 7"casing shoe from 4,870'to 5,234'(3,956'to 4,312'TVD.)"NA"sand top 4,882'MD/3,968'TVD."OB"sand base 5,146'MD/4,226'TVD. GRAVEL PACK DETAIL s 4-1/2"OD x 2-7/8"pre-packed single screen liner surrounded by 22,000Ibs of 20/40 sand. 7 WELL INCLINATION DETAIL 8 KOP@500' Max Hole Angle=50 deg.@ 3,250'MD f9 skt° Max Hole Angle through perforations=19 deg. r Y OPEN HOLE/CEMENT DETAIL 10 20" 452 sx of Arcticset IV in 30"Hole 11 9-5/8" 900 sx Perm E,300 sx Class'G'in 12-1/4"Hole 7" 195 sx Premium"G"in 8-1/2"Hole 12 TREE&WELLHEAD Tree WKM 2-9/16"5M Wellhead 11"5M FMC w/11"x 2-7/8"FMC Tbg.Hngr., t MI 7'H06 Cementer t`13 2-7/8"8rd Threads T&B.2.5"CIW BPV profile @4,823' x F 14 GENERAL WELL INFO External Ow ' API:50-029-22141-01-00 Packer©4,836 Sidetrack Completed by Nabors 27E -7/22/1993 7" RWO&Multiple Gravel Packs -4/4/1995 RWO w/Nabors 4ES-6/15/2000 15 RWO w/Nabors 35-7/7/2008 16 17 • TD=5,240'(MD)/TD=4,318'(TVD) PBTD=N/A(M))/PBTD=N/A(TVD) Revised By:STP 8/10/2015 • • Milne Point 2015 ASR Rig 1 �{���� � }�� Knight Oil Tools BOP 11" BOPE \ Stripping Head 1 3.98' ° Shaffer ° i 11" - 5000 iii Iti 1111(1 fill 4.54' H C CI _Ujillprig H 2 7/8-5 variables !MI 11"-5000 Niiii LI_ - Blind * flhrFtLilThiilItt frttirfic 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves i i i j` i - IN; lirlil'L!1•11111ul1 2.00' � • „11,1Iti, �uI(*1IiOI il.ili.iilTi1111'! Manual Manual Manual HCR Updated 8/19/15 • • I v n (2,, o tc�3 Eno v, —-I F- -114---- _ -I N----I 1— —N- -N 74 —4 F 3 x x -I F— W a K6 I" n z v, n x §x A w 9x C m 11- 41:03- .. a x 3 > 073 A r W 3C A r m a C C I C Gni a x . 9 1y mm.. N I 1 . .in... A x _ lip7 2 t+ + 0- 7G 7c v , = Ao 9 m O xt i n 7 . - 5 c_ 2.m cm o - S .�'..1 m o • n m 0 c - 9 0 r_co _.„,i-.<,,,._ n 1 s 0 1c 'O m m C 3 i i 7 ID N • n •I'.. NC8 > O V ... W O ♦ O c O n v w • •n-. :p 2 r "o D to C., < ,-Ir, m C14 C:1 C9 ."' C2 ^+ Z c c. w w c to D Z g .o `° ,TR. tin n ;m z Z c N . ..0 w 0 ,, .tin Or x ' Cal tol V o P2- o C16 COgg m 0 I 0 N co OeRaZLg Z" "x w w c E o 1 o < `1 a '''1'; < m , rn n rn R- m n ti a d CP n. C T , va • Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, October 26, 2015 1:10 PM To: Schwartz, Guy L(DOA) Subject: RE: MPU G-08A (PTD 193-048) change to kill fluid type and density Guy, The new MASP is 430 psi.The new BHP is 1,915 psi @ 4,000'TVD. On the FCO rig up (step 31-33),the plan is to forward circulate. Currently working on the final touches for the flow diagram. The well site supervisors also mentioned it would be worthwhile to rig up slickline after step#29 to tag the fill instead of tagging up with the motor or doing a separate run with a mule shoe. Could you add this note between steps#29 and#30 to rig up slickline(rig up and test lubricator on top of BOPE to 250/3,000 psi) and tag the fill? Regarding the ESP shroud,the fluid path will be up the existing gravel pack,thru the hanging screens, between the shroud and motor and exit the top of the shroud, passed the seals and in the intake.The shroud is hung off the top of the motor.The goal of the shroud is to hang off screens for additional sand control. It is open on the top(a piece of 5.5" casing with a plain end top and 4 large set screws to anchor it to the top of the motor)and forces the flow of fluid passed the motor. Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, October 26, 2015 12:37 PM To: Stan Porhola Subject: RE: MPU G-08A (PTD 193-048) change to kill fluid type and density Stan, Still have this sundry in hand. Not approved yet.... I will make the change in KWF fluid. Please recalculate the MASP (Max Anticipated Surface Pressure) based on this new value also. We just had meeting today regarding startup of ASR1. Part of the new requirements will be a diagram of the FCO rig-up (step 31-33). Also more detail on the Fill clean out regarding fluid path (normal vs reverse). Are you making separate trip in with mule shoe etc.??? Also, in reviewing the sundry I am confused as to the placement of Shroud/hanging screen on the ESP motor. Shouldn't shroud extend over the intake in order to direct the flow of produced fluids properly. Guy Schwartz Sr. 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 1 • information.The unauthorized review,use disclosure of such information may violate statefederal 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:sporholaOhilcorp.com] Sent: Monday, October 26, 2015 10:37 AM To: Schwartz, Guy L(DOA) Subject: MPU G-08A (PTD 193-048) change to kill fluid type and density Guy, We got an updated static BHP survey on MPU G-08A(PTD 193-048)and it came back at 1,605 psi @ 4,206' MD(3,367' TVD).This equates to a 9.17 ppg EMW. We are planning to kill the well with Steps#5 and#6 on the revised sundry with 9.4 ppg NaCl brine. Let me know if you need any additional information. Regards, Stan Porhola i Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 • Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Friday, October 23, 2015 4:00 PM To: Regg,James B (DOA) Cc: Bo York; Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Restart at HAK ASR1 Understood. We will provide the inspectors at least 24 hours notice for the rig inspection. Stan From: Regg, James B (DOA) [mailto:jim.rega@alaska.gov] Sent: Friday, October 23, 2015 3:54 PM To: Stan Porhola Cc: Bo York; Schwartz, Guy L(DOA); DOA AOGCC Prudhoe Bay Subject: Restart at HAK ASR1 To reiterate our discussion this afternoon,AOGCC is authorizing Hilcorp to mobilize and rig up ASR1 at MPU G-08A(PTD 1930480). Per Sundry approval 315-494—supplemented with a revised work procedure on 10/15/2015— Hilcorp may proceed through Step 11,work you describe as necessary to install the rig winterization. AOGCC Inspection of the rig is required before proceeding beyond Step 11 of the supplemental work procedure. Please provide 24 hour notice to AOGCC Inspectors for the required rig inspection. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 1 • of T� Alaska Oil and Gas LAsKA. �w\�-\fyy,�s� THE STATE -I-.4 ��, of Conservation Commission - . = 333 West Seventh Avenue * ,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 � ALAS". Fax: 907.276 7542 c,COM p www.aogcc alaska.gov Stan Porhola E+ Operations Engineer ,r Hilcorp Alaska, LLC i a 3 �- - T 3800 Centerpoint Drive, Suite 1400 -` Anchorage, AK 99503 Re: Milne Point Unit, Schrader Bluff Oil, SB G-08A Sundry Number: 315-494 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, 116 Cathy P. Foerster L Chair DATED this 1¢'day of August, 2015 Encl. RECEIVED STATE OF ALASKA AUG 1 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION DO:S 8( 1 5 1 s APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ PuN Tubing Q ' Operations shutdown ❑ Suspend p Perforate ❑ Other Stimulate ❑ Atter Casing 0 Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well Q• Re-enter Susp Well ❑ Other. ESP Change-out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Or Number Hilcorp Alaska,LLC • Exploratory ❑ Development Q - 193-048 • 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22141-01-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 477.05 - Will planned perforations require a spacing exception? Yes ❑ No ❑., I MILNE PT UNIT SB G-08A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025906' MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 5,240 - 4,318 ' 5,226 4,300 • N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' Surface 2,736' 9-5/8" 2,736' 2,366' 3,520psi 2,020psi Intermediate Production 4,876' 7" 4,876' 3,957' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8" 6.5#/L-80/8RD 4,259 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SC-1R Packer and N/A ' 4,615MD/3,703ND and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development❑., - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/21/2015 Commencing Operations: OIL E. 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 correct to the best of my knowledge. Contact Stan Porhola Email sgorholaahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature �e7."'l Phone 777-8412 Date 6-/6/1 COMMISSION USE ONLY [ r Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 — Li9`-( Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: A 3 Ooo , S Lo j 7" ( PIA 57-9 ' 1 i5' its,-: ) le Zo'-r ;L, e<<c:‘. 74,st- rte?it-4- 4 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / 0 —Y v APPROVED BY Approved by: ("Weal /:i COMMISSIONER THE COMMISSION Date: l (f_..,/,s--' ,f"•f 3 1� T n I n I K� �I t� ��I���� Submit Form and Form 10-403 Reviser35/2015 qr� daboI tbhllaMlII for 12 months from�e date of aooroval. Ananhmenrc in rn,nrcatp Well Prognosis Well: MPU G-08A Hilcorp Alaska,LL Date:8/10/2015 Well Name: MPU G-08A API Number: 50-029-22141-01 Current Status: SI Oil Well [ESP] Pad: G-Pad Estimated Start Date: August 21st, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 193-048 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: 1,669 psi @ 4,000' TVD (Last BHP measured 4/25/2015) Maximum Expected BHP: 1,669 psi @ 4,000'ND (No new perfs being added) Max.Allowable Surf Pressure: 184 psi (Based on SBHP taken 4/25/2015 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000'ND of oil cap) Brief Well Summary: MPU G-08A was drilled in 1993 using Nabors 22E as a sidetrack of the original G-08 wellbore and completed with a gravel packed completion in the Schrader Bluff sands. The well has had multiple ESPs due to excessive solids production. Notes Regarding Wellbore Condition • Suspect failed screens in gravel pack causing excessive solids production. • Casing last tested to 2,000 psi for 30 min down to 4,836'on 7/17/1993. Objective: The purpose of this work/sundry is to pull the failed ESP, cleanout fill inside the gravel pack completion and run a new ESP with screens hung off the bottom. Sce�„ Brief Procedure: WO Rig Procedure: 1. Circulate well with 8.4 ppg lease water down tubing and fill casing. 2. Set BPV. ND Tree. NU 11" BOPE. ASIA¢l R:zy_ 3. MIRU Hilcorp ASR#1 WO Rig. 273- 4. Test BOPE to 250 psi Low/3,00 i igh,annular to 250 psi Low/),. High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8" test joint. 5. Bleed any pressure off tubing and casing. Pull BPV. 6. MU 2-9/16" landing joint(8RD) and pull over string weight("'25k)on tubing hanger to confirm free. 7. POOH. Lay 2-7/8"tubing on the pipe rack(re-run good joints). Lay down ESP. 8. MU 6-1/8" bit and junk baskets and RIH w/2-7/8"tubing/workstring. 9. Clean out fill inside 7" 26#casing down to+/-4,615' MD(SC-1R Packer). 10. POOH. Lay 2-7/8"tubing on the pipe rack. LD bit and junk baskets. 11. PU RTTS and RIH w/2-7/8"tubing/workstring. 11 Well Prognosis Well: MPU G-08A flilcorp Alaska,LL Date:8/10/2015 12. Set RTTS at+/-4,600' MD.Test casing to 2,000 psi for 30 min. 13. Release RTTS. POOH. LD RTTS. Lay down 2-7/8"tubing/workstring. 14. MU 2-1/8" mill and junk baskets and RIH w/1.660"x 2-7/8" tubing/workstring. 15. Clean out fill to seal sub at 5,220' MD below screens. a. Min ID is 2.000"at seal sub. b. Min ID is 2.440 thru screens(17 jts). c. Min ID is 3.960"above screens. 16. Circulate bottoms up x 2 with 8.4 ppg lease water. 17. POOH. Lay 1.660"and 2-7/8"tubing on the pipe rack. LD mill and junk baskets. 18. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. a. Run 2-7/8"XN profile, 2 ea GLMS, and heat trace. b. RU to use clamps to secure heat trace to tubing(ensure adequate clamps). 19. Set base of ESP at+1-4,250' (Pump intake around +/-4,170'). Land tubing hanger. 20. Lay down landing joint. Set BPV. ND BOPE. NU existing 2-9/16" 5,000#tree. Pull BPV. 21. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 22. RD Hilcorp ASR#1 WO Rig. 23. Replace IA x OA pressure gauge if removed (7"x 9-5/8"). 24. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic • Milne Point Unit • 14 Well: MPU G-08A SCHEMATIC Last Completed: 7/7/2008 Hilcorp Alaska,LLC PTD: 193-048 CASING DETAIL Orig.KB Elev.:35'AGL(Nabors 27E) Size Type Wt/Grade/Conn ID Top Btm 13-3/8° Conductor 54.5/K-55/N/A 12.615 Surface 115' J ,,, 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,736' 13-3/8' 7" Production 26/L-80/Btrc 6.276 Surface 4,876' 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 4,259' JEWELRY DETAIL No Depth Item 1 147' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 2 2,522' Heat Trace 3 4,054' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 4 4,193' 2.31"XN Nipple:2.25"No Go 2 5 4,212' Discharge Head:FPHVDIS 9-5/8" 4 4 6 4,213' Pump:SXD 140-P10 7 4,230' Gas Separator Intake 8 4,236' Tandem Seal Section 9 4,249' MSP Motor,55HP, 1,259 Volt,26 amp 10 4,257' Pumpmate w/6 Fin Centralizer:Bottom @ 4,259' 11 4,615' Packer:Baker Model-SC-1R w/4.0"ID 12 4,628' Sliding Sleeve:Baker Model'S'4.38"ID 13 4,883' Johnson Pre-Pack Single Screens 4.5"x 2-7/8"12ga.2.44"ID,17 jts,342'Long 14 5,228' Flapper Valve Assembly 15 5,233' Baker V-Set Shoe w/Check Valves-2.0"ID OPEN HOLE DETAIL TOC Est@ The 8.5"open hole was under-reamed to 12"below the 7"casing shoe from 4,870'to 5,234'(3,956'to 3,900' 4,312'TVD.)"NA"sand top 4,882'MD/3,968'TVD."OB"sand base 5,146'MD/4,226'TVD. 3 GRAVEL PACK DETAIL 4-1/2"OD x 2-7/8"pre-packed single screen liner surrounded by 22,000lbs of 20/40 sand. ' 4 WELL INCLINATION DETAIL _ KOP @ 500' 4g, Max Hole Angle=50 deg.@ 3,250'MD Ih Max Hole Angle through perforations=19 deg. • 6 OPHOLE/ MENT DETAIL 7 20" 452 sx of ArcticsetCEIV in "Hole ..•8 9-5/8" 900 EN sx Perm E,300 sx Class30 'G'in 12-1/4"Hole 7" 195 sx Premium"G"in 8-1/2"Hole 46 TREE &WELLHEAD 9 Tree WKM 2-9/16"5M Wellhead 11"5M FMC w/11"x 2-7/8"FMC Tbg.Hngr., 10 2-7/8"8rd Threads T&B.2.5"OW BPV profile GENERAL WELL INFO • in id ,'11 API:50-029-22141-01-00 T 4,82 Cementer @4.823' � �•ooa.: 12 Sidetrack Completed by Nabors 27E -7/22/1993 • RWO&Multiple Gravel Packs -4/4/1995 External Csg ,i1 Packer @4,836' ft RWO w/Nabors 4ES-6/15/2000 7" ( RWO w/Nabors 3S-7/7/2008 !' '#' 13 t~F ...14 ;AC<:-:r.. •.'i..15 TD=5,240'(MD)/TD=4,318'(TVD) PBTD=N/A(MD)/PBTD=N/A(TVD) Revised By:STP 7/21/2015 • Milne Point Unit • II Well: MPU G-08A PROPOSED SCHEMATIC Last Completed: Proposed Hilcorp Alaska,LLC PTD: 193-048 CASING DETAIL Orig.KB Elev.:35'AGL(Nabors 27E) Size Type Wt/Grade/Conn ID Top Btm ill . 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 115' yp,1± 9 5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,736' 13-3/8' 7" Production 26/L-80/Btrc 6.276 Surface 4,876' 1 i TUBING DETAIL 4 t- 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 4,250' 1 r Y.. a JEWELRY DETAIL > ii i` v, No Depth Item i� 1 150' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 t A 2 2,500' Heat Trace 1+ 3 4,000' GLM Camco 2-7/8"x 1"Side pocket KBMG M-2 4 4,184' 2.31"XN Nipple:2.25"No Go 2 5 4,203' Discharge Head:FPHVDIS 9-5/8'. ri 6 4,205' Pump:SXD 140-P10 7 4,228' Gas Separator Intake 8 4,227' Tandem Seal Section 9 4,240' MSP Motor,55HP, 1,259 Volt,26 amp 10 4,248' Pumpmate w/6 Fin Centralizer:Bottom @ 4,250' 11 4,265' ESP Shroud,5.5"15.5#(Handing off motor,suspending sand control screens) 12 4,270' Sand control screens(3 jts) TOCEstK 13 4,615' Packer:Baker Model-SC-1R w/4.0"ID 3,900' 14 4,628' Sliding Sleeve:Baker Model'S'4.38"ID t" 15 4,883' Johnson Pre-Pack Single Screens 4.5"x 2-7/8"12ga.2.44"ID,17 jts,342'Long 3 16 5,228' Flapper Valve Assembly F 17 5,233' Baker V-Set Shoe w/Check Valves-2.0"ID IR i 4 4 0 OPEN HOLE DETAIL 44 µ, The 8.5"open hole was under-reamed to 12"below the 7"casing shoe from 4,870'to 5,234'(3,956'to i )+ ; 4,312'TVD.)"NA"sand top 4,882'MD/3,968'TVD."OB"sand base 5,146'MD/4,226'ND. 1 I GRAVEL PACK DETAIL +h6 4-1/2"OD x 2-7/8"pre-packed single screen liner surrounded by 22,000lbs of 20/40 sand. air 7 WELL INCLINATION DETAIL $ KOP @ 500' =,l inn Max Hole Angle=50 deg.@ 3,250'MD Ir„ Max Hole Angle through perforations=19 deg. 7 !.9 'a : OPEN HOLE/CEMENT DETAIL 44 A 10 20" 452 sx of Arcticset IV in 30"Hole 11 9-5/8" 900 sx Perm E,300 sx Class'G'in 12-1/4"Hole W7" 195 sx Premium"G"in 8-1/2"Hole 12 p TREE&WELLHEAD 14 Tree WKM 2-9/16"5M .; t Wellhead 11"5M FMC w/11"x 2-7/8"FMC Tbg.Hngr., HOS >. >74 s<. 13 2-7/8"8rd Threads T&B.2.5"CIW BPV profile ©4,823' i ,‘'`•,.;''114 GENERAL WELL INFO Extend API:50-029-22141-01-00 Packer©4,836 ; Sidetrack Completed by Nabors 27E -7/22/1993 7 _ - r. RWO&Multiple Gravel Packs -4/4/1995 RWO w/Nabors 4ES-6/15/2000 •, 15 RWO w/Nabors 35-7/7/2008 16 i''' 17 TD=5,240'(MD)/TD=4,318'(TVD) PBTD=N/A(MD)/PBTD=N/A(ND) Revised By:STP 8/10/2015 Milne Point 2015 ASR Rig 1 iric .i� u.�.�.. Knight Oil Tools BOP 11" BOPE Stripping Head ?MP!3.98' ° Hydril ° GK 11"-5000 ill iii IiIL iii MU II 4.54' - CI -U" I H 2 7/8-5 variables 'ti Il4111"-5000 L '-= Blind Ii ll I 2 1/16 SM Kill Line Valves 21/16 5M Choke Line Valves •� In 111111 111 1111 2.00' I . ' i �f. _ : 1! � lit quit III Iiii • Manual Manual Manual HCR Updated 7/23/15 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I q~"~/-~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs 'of various kinds Other COMMENTS: Scanned by Dianna Vincent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: is~ UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~~~ FILE # 6~~ ~ ~ ~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 -Fax (907) 276-7542 • • F r E AlnSEA SEAN PARNELL, GOVERNOR i �1 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Ken Allen �a �. �° Engineering Team Leader (� BP Exploration (Alaska), Inc. 0 "F P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPG -08A Sundry Number: 312 -058 Dear Mr. Allen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P Cathy / Foerster Chair DATED this (0 day of March, 2012. Encl. 3i //Z. r cEI VED y � STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMISSION FEB 'I 2n ».7/6�� APPLICATION FOR SUNDRY APPROVAL <.:.,, st.� w,. L 4.iag Cons. Commission 20 AAC 25.280 Anchrage 1. Type of Request: ❑ Abandon - ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -® Development ❑ Exploratory 193 -048 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22141 -01-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPG -08A ' Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL025906 Milne Point Unit / Schrader Bluff 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): 5234' - 4313' - 5234' 4313' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 2736' 9 -5/8" 2736' 2366' 3520 2020 Intermediate 4870' 7" 4865' 3952' 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open Hole w/ Gravel Pack Assy: Open Hole w/ GPA: 3710' - 4305' 2 -7/8 ", 6.5# L -80 4255' 4609' - 5226' Packers and SSSV Type: Baker Model SC -1 R Packer (Gravel Pack Assembly) Packers and SSSV 4609' / 3710' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - 0 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 5, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG -181 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Johnson, 564 -4171 Printed Name Ken Allen Title Engineering Team Leader ---, Prepared By Name/Number: Signature �:_. --ter L, Cam-- - Phone 564 Date a/ .2_, Joe Lastufka, 564 -4091 f Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3(7705? Sundry Number Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 4 3 500 p si &D / Other: . 140 f-:4 rpi e -4 w :- ... -{4. c r'. T Subsequent Form Required: / O — / 0 7 APPROVED BY / �� For Approved By: , COMMISSIONER THE COMMISSION Date 3 C rrnris ed 1 Q Q � f • 0� I / . / � IYIJ 7N` U i�d � O RI 6 IN A L licate /�/L— Submit In Du P 'f • • Milne Point Well MPG -08A Schrader Producer F ,� ( l v Sundry Notice MPG -08A is a long term shut -in producer. The wellbore was completed in 1993 with a gravel packed screen place across the Schrader N and 0 sands. MPG -08A has been shut -in since 8/22/2008 due to a Matrix Bypass Event to injector MPJ -02, excessive solids production and a high ESP failure rate. It is suspected that the screens also have failed. Itis planned to plug abandon the MPG -08A and drill MPG -08B. The proposed sidetrack will be a conventional, single selective completion, Schrader Bluff NB, OA and OBa injector. This will be part of a pattern development to provide waterflood support to producers in HU07 in the Milne Point Unit. This injector will be drilled just south of the northern bounding fault for the hydraulic unit. k •� (( waJ /1t "er q 5r10,1 �vncv� . d•:, �t less t Operations are expected to start April 5th, 2012. v ur a ' 44d iteti Pro 1010 w olr ,, � , T 4 w� r�J.� Shod allow {or Present Well Condition Summary R� ,� d / 'c f i1 frlfsQ01 W fie yyee Z( Casing Length Description MD TVD Burst Collapse Conductor 105 20" 91.1# H -40 Welded 105 105 1530 520 Surface 4868 9 -5/8" 36# K -55 BTC 2736 2366 3520 2020 Intermediate 4870 7" 26 #, L -80, BTC 4870 3956 7240 5410 Liner 625 4.5" Screened Liner 5234 4312 Screened Screened Tubing 7510 2 -7/8" 6.5 #, L -80, EUE 4253 3405 10570 11170 Screen Depths (MD) 4877' - 5219': 4.5" - 12 gauge - 2.44" ID Procedure Pre -Rig Operations per Sundry 1. Pressure test pack -offs on tubing and tubing spools to 5000 psi. Function all lockdown screws. 2. Verify that DGLV is set in top station @141' and that DGLV is pulled from bottom station 3. SBHPS prior to start of rig work. (SBHPS on 8/26/11 showed static BHP building) 4. Circulate well & freeze protect. 5. Injectivity test /MIT -OA (verify casing shoe is open) 7 6. Set & test BPV. Drilling Rig Operations .1. Move in and rig up Doyon 14. 2. Pull the BPV with tested lubricator. Circulate out diesel freeze protection with 9.6 ppg brine through tubing perfs at -4167' MD. 3. Set BPV and perform a rolling test to 500 psi from below for 10 minutes. If unable to attain 500 psi, record rate and pressure and visually confirm that BPV is not leaking • • 4. Rig up OA to bleeder tank and bleed pressure to zero psi. Monitor to ensure well is dead in preparation for 7" cut and pull. 5. Nipple down tree and tubing adapter. Nipple up BPOE with 2 -7/8" X 5 -1/2" VBRs in upper and lower ram cavities. Test BOPE to 250 psi low / 3500 psi high including annular with 2 -7/8" and 4" test joints Note: If there is sufficient height, install spacer spool above the tubing spool to allow testing of the lower set of rams with a conventional test plug. If unable to install spacer spool, test lower rams with a test joint screwed into the tubing hanger. 6. Pull BPV with tested lubricator per FMC. 7. Pull and lay down 2 -7/8" 6.4 #, L -80 tubing and ESP completion from 4253'. % 8. RIH with bit and scraper. Clean out well to liner top packer @ 4609' MD.v 9. RU Eline. Run CBL with either USIT or isolation scanner a nd log 7" casing from -4590' MD to surface. 10. Run Gyro CAAT log on Eline from -4590' MD to Surface • 11. Run and set 7" cement retainer @ 4569' MD. Test cement retainer and 7" casing to 3500 si. v 12.Stiiig into retainer and establish injection into gravel packed screened liner for cement squeeze. If unable to establish injection proceed to step 14. 13. Cement squeeze the screened liner with 15.8 ppg class G cement (yield - 1.16 cuft/sx). The cement volume to be squeezed will be determined from the injection rate. The 12" X 4 -1/2" annulus has been gravel packed with 20/40 anhe annular volume is very limited. The pipe volume equals 7.6 bbls or 36.6 sxs. r/ d t N14. Pull out of the cement retainer and set a balanced cement plug from the retainer to the top of cement in the annulus as determined from the cement bond Togs or 500' above k" t the cement retainer which ever is greater. The top of cement in the annulus is 'v v estimated at 4075' MD (494'). Cement will be 15.8 ppg with a yield of 1.16 Cu. Ft. / eyVi sack. The 500' minimum plug will require 19.1 bbls or 92.6 sacks of cement and the top of cement inside casing is at -4069'. - T. S psi- e /3d 15. Pull up to -4069' MD and circulate the well clean at the top of the cement plug. i 16. If cement bond log showed poor quality bonding in the annulus: a. Rig up lubricator and pressure test. RIH with E -line and perforate a 5 ft interval in rto the 7" casing at -20' above top of cement (-4069') in annulus as picked from cement bond log. Perforations are estimated at -4049'. b. Perforate a second 5 ft interval at -3950' MD (99 ft above first perforations). c. Run a gauge ring (minimum 5.560 ") through the upper perforation interval to ensure .�' the EZSV cement retainer will pass drift. Rig down E -line and lubricator. GM d. Run in hole with a 7" EZSV cement retainer on 4" drill pipe. Set EZSV at -3970' MD S�Z between the perforation intervals. Break circulation through perforations behind 7" casing and condition hole for cement. e A Note: If circulation is not achieved, increase pressure over formation fracture gradient and inject -5 bbls to verify zonal isolation. e. Pump -10 bbls of 15.8 ppg class G cement to fill casing x 7" annulus. f. Pull out of the cement retainer and set a 600' balanced cement plug on top of the / cement retainer. Cement will be 15.8 ppg class G with a yield of 1.16 Cu. Ft. / sack. The 600' plug will require 32.1 bbls or 155.6 sacks of cement and the top of cement will be at -3370'. g. Pull up to -3370' MD and circulate out any excess cement. 17. Pull out of hole. Close blind /shear rams. Pressure test cement plug to 250 psi low and 2000 psi high for 30 minutes. Confirm strength of cement plug is at least 1000 psi prior to pressure testing 18. Based on cement bong log, plan to cut casing @ 2836' —100' below 9 -5/8" casing shoe. Run in hole with a 7" EZSV cement retainer on E -line. Set EZSV at 2940' MD 19. Make -up a 7" casing cutting assembly and RIH. Tag top of cement retainer at 2940'. 20. Pickup and cut casing at 2836'. Displace the annulus with 9.3 ppg brine and pump sweeps of Safe - Surf -O as needed until returns clean up. POH and lay down multi- string cutter. Note: Be prepared for diesel freeze protect and potentially dead crude in OA returns. 21. Change out top variable rams to 7" casing rams and test to 250 psi low and 3500 psi high. Have a safety joint with FOSV for 7" casing. 22. Engage mandel hanger with spear and pull the mandrel hanger and 7" casing from the cut through the Wellhead /BOPE per FMC. Lay down casing. 23. Change 7" casing rams to variable rams. Test rams to 250 psi low / 3500 psi high including annular with 3 -1/2" and 4" test joints. 24. RIH with 3 -1/2" tubing stinger on DP and tag top of cement retainer. 25. Pull out of the cement retainer and set a 600' balanced cement plug on top of the cement retainer from 3940' to 2340 w. Cement will be 17.0 ppg class G with a yield of 1.01 Cu. Ft. / sack. The 600' plug will require 45.3 bbls or 253.2 sacks of cement. 26. Run bit and scraper in 9 -5/8" casing to —2300' MD 27. RU Eline. Run CBL with either USIT or isolation scanner and log 9 -5/8" casing from —2300' MD to surface 28. Run Gyro CAAT log on Eline from 2300' MD to Surface ✓ 29. Dress off cement, pressure test plug and casing to 2500 psi. Prepare to sidetrack and drill MPG -08B as per drilling permit. S S • MPG-08A Current Completion Tree, WKM 2 9/18" 5M MPU G-08A Welatead: 11" 5M FMC. iN/11"x 2 718' FMC tbg. hng, 2-71W End. top and I - Heat Trace to 2515. 0 I 0 --t. bottom, 2.5" CM BPV profile. 0 q -, -i 0 :I 20" 91.1 p�, H-40 108 k Carrico 2 7/8" x 1" ' -.1 sidetrocket KBMO-M-2 14T 0 / KOP g spa 0 ,, :t Max, hole angle = 50 deg. 325(7 MD, 0 I Max, hole angle thrte parts deg, 0 :t I - " 9-5/8". 38afft., K-55, Btrc. 1 v30. .1 a + 1 # 0 IP : 00 2-7/8 pot L-80. a rd EUE tbg, 0 0 ( drift ID = 234r. Cap, = .00579 bpf) it r 26 opt L-80, BTC mod production csg, ( drift ID ra 8.151", cap.= 0.0383 bpf ) 0 i Carrico 2 718" x 1" 4048* 1 i t sidepook et KBNIG-N12 I 2 31' XN Npple 225 NO MB 0 0 0 0 1 zi, Discharge Head: F PI4VDIS 420a 0 al o r. we 4 CC Puy*: SXD 140-P10 420T VII .-.,,- II Gas Separator Intake 4224 ...,_ Tandem Seal Section 423CT Wit / 411M lik Motor, 55 hp. 1258 v. /28 4243 . wr, tap amps, air , . i ) PUMP MATE wil 15 fin [425Y I t I Centaliter 1r , Baker Model SC-1R Packet V 1 III 4.0" ID 0 4809 NE) r. 2W/ft 4 : .4-,* 0 0 ( A Baker Model "S" Sliding Sleeve 428" ID - 4822" MD I Howard Smith Single Screen Pre-padt 45' x 2-7/8 12 ga., 2.44 ID, 342 It, top 64877' MD Flapper valve assy, @ 5222 1.09) Baker VSet Shoe w/Check Valves, 2.0' ID .'..! 5226 MD . „ TO 5234 — - DATE REV, eV COMmENTs MILNE POINT UNIT 4/4/95 DBR RWO/Multple Gravel P a oks WELL No 2 G 8/15/00 WAN RWO Nabors 4ES APO 50-028-22i41-01-00, 07-0705 JRP RWO Nabors 3S 01/10112 DJ Coffected 7' Depth &API Nuttier BP EXPLORATION (AK) • S III, MPG-08A Abandonment Itt, W10v12 Wier' 8U MPU G-013A KOP 500' %Neared d','. 11" SMW7011, vat ti'x 2 7 OP FMC fas, tona 2.70W' $ 14, tep anti — relax mitre = 50 deg Pattern. 25 GM EIPV pr. - . 2,5o ii A 21r iiit1 ppt, H- I 105 rataX Wit00 11 WO .4 Setttal =19 Deg i J -234 7 I Tap et Camara ::::::;::::DS•IVS:::::::::::: ....... ..........,.....-stc:::::::::::::. I ' 6 l'.V.'.7.7.".::::::....... :. ... : . :. .......1:...11......-c......c.....1* .... ,'...."...--" e ., . -, t 1<kt)‘' . %.....................w........... , 7....7 .% •1:::: :::::::::::: ::::" LiO4 ZOO& n :. *".•::::11.111.1.•;1'.7. 1..7.. I ..213361 7'. C Jiang Cut ...7- . Zr Ll04 2 ' r•' --"..----.111111 -.2G40° r Bridge Pam Brine I Ealsrnated TOC C asing :e;e:oweAnrowe I 3 yatr tf R e clue* 41 tjact I 3.42tet 1 .6-11. I :::::::: •.-•.r........•••••.: ; r r 2e ppt, LSO, 13/0 mod met ▪ . Owned Calci - Citable:Id a& Reamer Li, 2„.. ( 1 ) ( drift ID =0 151".. eap =00303 a .47. r_1:1"."1"1":"17 - ' &Siouan Petit GO Auld ff Vacated 7.- itlog •........ mi.■... p . % 44=5115115r i - . - -. 43434ir Estimated TOC Maluku CEMENT %'" • :::. 11...- .iSi5 -4 .....:..c. ,464" 1"::::. "."Y.T.'.7.1•Ye.t. ' Coned* Pilg .....--""'" 4 ....... ..................... " ...... ..... .e.......e......... ..1..... Heavy .. ..p. C c=3 r Cement R otairmt ,-, :. - . : . * . . , ..... 5%... ...,%:::::::: w 414 p. p at 410 ' . .. -.. . . .. 0 „.„, , , . .. . . : . .. • .. . 1 .. z . LI I Z. Bator 5C-1 a er - 111 gr am :i' pi ,...%-„ . :3 Z : : 4527 I E1* it r Medal "5" Skiing Heavy ....,"'-'4Ff put 400 1 • O 55: ...1. :.. • . • .:',.. :... '...74. .. j Sleeve - 438 ---- ",- ___,,..... nor tos .%. '..' .%....;...4. '...: 11.. '-" il V.: ...%. V.V....S.% ... . ,......._ 8 " ; ; ' 44- • MME 4.418. ": :... VS::: '.' i 49,1W 7' C sainit She* Howaael Saa0 'Devi* Saloon 61 A [two I '::::::: " i. : 4 1 .1:: : : .::.:::: 1 487T Pt-pa ik 45 x 2-76Er 12 ga " ) "ifil %,-....... ::::::' :,:....-:.: 2,44* ID, 342 ft mo igilff &Eva Pack Vi =XIS *W 14,9W' I ' . '.."! Camat Cil W Iuu 892 • • • erily I se•i• of svoons ../ .:::" : "PP:- •:::: -:: tE222' F . , id.ivk itittfilbFf" iimpol " . ------ "f . ::' . 5234 ID %.:...................:: ORT0 PAM tY - MANE PONT UNIT ROVOItti 1 0 Gravei P • . 4, WELL No : GALA 04141 RWO Nabors ..ES API : 6.429-27141-01-110 0770 PM jRp a WO Umbras 3s i ,ti 2.9 2 al • .... . Mandamus BP EXPLORATION . RIG FLOOR 33.7 ' XL M21 1 vALLYE LEGEND • ���" ,T71Nr�P, i 8tlW655 2 KM ii 5 CHOKE `� +5flO Ir 9 IL.P4D bawls ■■ - 5 TOP ME FIM4 III 1,1 W. toss AIL nest molt EC OM° TA MINs 57 SHAFFER, ISO 414., 6 SWIM 7 151151L.01 MRIn Pl 575 We. 30 HP SW ARw& 1.NLEN IIM. * Mr, am MN Mt NIL tiMMININ 0 al MANN TIMI 0 0 0 4( 3 •Mil r ONE DE y 111.11. aere. w a avAa. t`L MINN MIN It IN •Iti ION WM ■I' 110 1111E All,* 4110' 4111" rfat. um CD > iAr Nee N1 Is weiviaz fJ 3 Mr NM #! MN 41N O y �' I■IE NN •w w ra warm i .+CS. Ate M�1.wr _ Met �vlloyrlrlom ns rI SID Af.CtI U.AT� Fib W i t Cn W. .`x 4: i y1 15 80 HIES. 10 CALLONS EA 11 3 l CD 1 11 1 et,e`,Aek MI 3 Lr7P 5t EL6)h+i11ON I I ingaLEMINIOragang (5 I AM UTILITY NOM • el NRi SISO onm P9 I% Ili r pa •-- sums s tr ass rum +ca r r nw u - FIMINN NC IN 73 w i1 J>ti' small iE• II - ;aft ter . MEI Ili ..,;,.., , .. IM AG WIC Ns 14 —_ = y .1 A .— ACS® Raw 9 W S IWO M 116110111.111d OOP SISTER IN A111) X1 % AgEttLIZISKIDtalliaadtM UM f1 L,-NII uwi� - a. , 1e al wxwllw r:,G 010 11 T 91` rrr.r w1s 1 4I1n 1 I I 7 M691Lisi na inra LIST MATERIAL Item De scr i ratinn A 3-ir tf3' 10M Remote Operated Hydraulic Choke 8 3-P a' 5M Adrustflble Choke /a t 2 °111■ 5/4.1 Manual Date Valve 'a ) 2 - 3_._, i 5M Manual Gate Valve `� III . L" v �► ,o „is 1r n From CO 0 RIG ' 14 = OP's X sv Sri —. Al t ad � ' o Illi A / i, ,. To Mud /Gas a 1. iii Separator • i ' LEDGE White Handle Valves Divert Normally Open Divert LI / li Red Handle Valves Line ' / Normalcy Closed 4 , D€del 0 ? -08 -10 Rev. 2 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 r +ED C Z012- December 30, 2011 I 631 -- 0 4-0 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission rL 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, n� Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPG -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPG-01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG-02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG-05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG-07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 ---- " MPG -08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG-09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG -10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG -11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG -12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG -13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG -15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG -16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG -17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG -18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG -19 2041920 50029232280000 1.6 NA 1.6 NA 13.6 8/15/2011 $ '{ { STATE OF ALASKA OS . ~.. ,. A~ OIL AND GAS CONSERVATION COMNRSSION n _:, ,, REPORT OF SUNDRY WELL OPERATIONS ~' `` ~- `~ ~''` owl, ~: _,,~ 1. Operations Performed: ^ Abandon ®Repair Well ' ^ Plug Perforations ®Stimulate ~ ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development' ^ Exploratory 193-048 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22141-01-00' 7. KB Elevation (ft): 50.0' 9. Well Name and Number: MPG-08A 8. Property Designation: 10. Field /Pool(s): ADL025906. Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 5234 - feet true vertical 4315 feet Plugs (measured) None Effective depth: measured 5234 feet Junk (measured) None true vertical 4315 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 20" 105' 105' 1490 470 Surface 2736' 9-518" 2736' 2375' 3520 2020 Intermediate Production 5010' 7" 5010' 4095' 7240 5410 Liner ~~~~~~ AU G .E ~. ZODS Perl`OratlOn Depth MD (ft): Gravel Pack Assembly 4609' - 5226' Perforation Depth TVD (ft): Gravel Pack Assembly 3711' - 4307' 2-7/8", 6.5# L-80 4255' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker model SC-1 R Packer 4609' 12. Stimulation or cement squeeze summary: ee ace a ennce epo Intervals treated (measured): Treatment description including volumes used and final p ressure: Acid treatment while Rig is on Weil. Pumped 5 bbls 60/40 Methanol followed by 20 Bbls 7% Acid, 5 Bbls 60/40 Methanol and 23.5 Bbls sea water for displacement. Fluid Summary: 10 Bbls 60/40 Methanol, 20 Bbls 7% Acid and 23.5 Bbls Seawater. Final Tubing pressure 300. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 250 Subsequent to operation: 77 2 154 240 224 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist J Prepared By Name/Number: ' ` S nature Phone 564-4750 Date ~ ~'( ~ Sondra Stewman, 564-4750 Form 10-404 Revised 04 006 Submit Original Only ORIGINAL .5~~~~~u~~ 1008 I1~ Tree: WKM 2 9/16" 5M ~ MPU G-08A Wellhead: 11" 5M WKM, w/ 11"x 2 7/8" FMC tbg. hng. 2-7/8" 8rd. top and bottom, 2.5" CIW BPV profile. 20" 91.1 ppf, H-40 105' Camco 2 7/8" x 1" sidepocket KBMG-M-2 141' KOP @ 500' Max. hole angle = 50 deg. @ 3250' MD. Max. hole angle thru' perts = 19 deg. 9-5/8", 36#/ft., K-55, Btrc. 2736 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. (drift ID = 2.347", Cap. _ .00579 bpt) 7" 26 ppf, L-80, BTC mod production csg. (drift ID = 6.151", cap. = 0.0383 bpf ) "Heat Trace to 2515`. Camco 2 7/8" x 1 " 4048' sidepocket KBMG-M-2 2.31" XN Nipple 2.25" No-Go 4187' Discharge Head: FPHVDIS 4206' Pump: SXD 140-P10 4207` Gas Separator Intake 4224` Tandem Seal Section 4230' Motor, 55 hp, 1259 v. /26 4243' amps. PUMPMATE w/ 6 fin 4253' Centralizer Baker Model SC-1 R Packer 4.0" ID @ 4609' 4~VU 7", 26#/ft. 5,010' Baker Model "S" Sliding Sleeve 4.38" I D - 4622' M D Howard Smith Single Screen Pre-pack 4.5" x 2-7/8" 12 ga., 2.44" ID, 342 ft., top @ 4877' MD Flapper valve assy. @ 5222' MD Baker V-Set Shoe w/Check Valves, 2.0" ID @ 5226' MD TD 5,234' DATE EV.BY COMMENTS MILNE POINT UNIT 4/4/95 DBR RWO/Multiple Gravel Packs WELL No : G-08A 6/15/00 GMH RWO Nabors 4ES API : 50-029-22070 07 07 08 - - JRP RWO Nabors 3S BP EXPLORATION AK • • MPG-08A -WELL EVENT SUMMARY Date Summary 6/16/2008 PERFORMED SBHPS W/ SPARTEK STATIC GAUGES G 3590' MD & 4159' MD 6/17/2008 ATTEMPTED TO REACH BOTTOM STATION SAT DOWN ~ 3221' SLM PULLED BK DPSOV & SET BK-DGLV C~ 170' MD 6/17/2008 (Freeze Protect TBG) T/I/0= 200/250/300 Pump diesel down TBG to freeze protect. TBG locked up C~3 4 bbls away. ATTEMPT TO GET IN HOLE W/ 2.25 DRIVE DOWN BAILER «<HEAVY FLUID LRS UNABLE TO DISPLACE»> 6/18/2008 UNABLE TO WORK DEEPER THEN 2716' SLM W/ 2.25" DRIVE DOWN BAILER RIH W/ OC, 1.78" CENT, 1.5 SAMPLE BAILER, SD ~ 4099' SLM, COLLECT SAMPLE ,RIH W/ 2.0 GAUGE RING, UNABLE TO GET DEEPER THAN 3884' SLM. RAN 5' X 2" DRIVE DOWN BAILER, WORK TO 3997' SLM, METAL MARKS ON BAILER SHOE, RAN 2" LIB TO 4020' SLM, NO IMPRESSION. RAN 9' X 2" DRIVE DOWN BAILER, WORK TO 4042' SLM, RAN 2.125" GAUGE RING WORK TO 3997' SLM, OUTER EDGE ON GAUGE RING SMOOTH. RAN 6' X 2.25" DRIVE DOWN BAILER, UNABLE TO GET DEEPER THAN 2816' SLM. RUN 2.5 OK-5 W/O CENT SPRINGS 2x TO 4016' SLM UNSUCCESSFUL, RUN 2.5 OK-5 W/CENT SPRINGS UNABLE TO PASS 3810' SLM RUN 2.112" BROACH TO 4013' SLM CLEAN, UNABLE TO GET DEEPER, IN HOLE W/ 9' OF 2" DRIVE DOWN BAILER 6/19/2008 RIH W/ 9' OF 2" DRIVE DOWN BAILER SD C~3 4037' WORK TO 4051' SLM, RECOVER - 3/4 GAL OF GRITTY MUD PULL BK-DGLV FROM STA #2. UNSUCCESSFUL ATTEMPT TO PULL STA #1 W/ 2 1/2 K KOT, ATTEMPT TO PULL (STA # 1) W/ 2.5" OK-5, UNABLE TO. RAN W/ KJ, 2.05" CENT, 5' X 1.25" WB, 2.875" BLB, 2.0" GAUGE RING, SD ~ 3213' SLM, WORK TO 3236' SLM, UNABLE TO GET DEEPER. RAN 2.5" OK-5, SD ~ 4021' SLM, PULLED SLIGHT BIND C~ 4006' SLM, UNABLE TO SD, NO LUCK. RESET 1" BK-DGLV @ 170' MD. 6/20/2008 Demobe well house, foundation, and piping Tq blinds to spec. Note did not set BPV dew to Coil Unit getting on well right away. 6/22/2008 RAN HEAD/ SWIVEU 2 WEIGHT BARS/ CCU FIRING HEAD/ 2 FT LOADED 1-11/16" HSD TBG PUNCHER (SMALL), 4 SPF(9 SHOTS TOTAL) /ORIENTING SUB. MAX OD 1-11/16", LENGTH=30.1 FT, WEIGHT=130 LBS. Shot tba from 4014 - 4016' MD. SURFACE AND VISUAL CONFIRMATION OF GUN FIRING. ****MASTER, SWAB, SSV LEFT CLOSED. NOTIFIED DSO. FINAL TBG/IA/OA: 150/200/350 PSI**** 6/22/2008 (injectivity test) T/I/0= 0/0/0 Pump 25 bbls 60/40 down TBG for injectivity test to proof pert. holes. Awgers continued on 06-23-08 6/23/2008 (injectivity Test) T/I/0= 0/0/0 Pump 20 bbls 60/40 meth down TBG ~ 1 bpm to proof perf. holes.( Note; Pressure built to 1800 psi on TBG and IA ~ 20 bbls away.) FWHP=1000/1000, 6/23/2008 Demobed well ,foundation ,and process piping riser and laterals Note: did not put BPV in hole per Mark O. due to E-Line ctettina on well to Perf 6/24/2008 MPU Well Support tech set BPV to complete demobe . • MPG-08A -WELL EVENT SUMMARY Date Summary 6/28/2008 SBHPS ***ARRIV ON LOC WELL S/I *** MADE 30 MIN STOP ~ 3516 SLM , MADE 3 HR STOP C~3 4,017' SLM ««« SET BPV »»»» ***TURN WELL OVER TO DSO *** 7/1/2008 (Acid Treatment) Stand By for job. 7/2/2008 • Assist Nabors 3S (Acid Treatment) -Stand by for rig to circulate well, released will come back when rig closer to ready 7/5/2008 (Acid Treatment while Rig is on well.) Pumped 5 bbls 60/40 methanol followed by 20 bbls 7% Acid, 5 bbls 60/40 methanol and 23.5 bbls sea water for displacement. 7/7/2008 T/I/0=0/0/320 Freeze Protect (Post RWO) -Pumped tbg w/15 bbls crude. Pumped IA w/65 bbls crude. Casing valves open. Wing, master, ssv & swab closed. Tag well & notify operator. Final WHP's=50/270/320 7/21/2008 Well Support Tec PT Production and test laterals lines to 1150 psi for 10 mins with diesel, Then Pulled BPV from the well. 7/24/2008 (Freeze Protect TBG) T/I/0= 200/50/300 Pump 15 bbls 60/40 meth down TBG to freeze protect. FWHP= swap=closed/ wing=closed/ ssv=closed/ master=open/ IA and OA open to gauges. FWHP= 200/240/300 Page 1 of 1 .WELL SERVICE REPORT • WELL JOB SCOPE UNIT MPG-08A RWO EXPENSE LRS 64 DATE DAILY WORK DAY SUPV 7/5/2008 ACID TREATMENT IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSB335273-D LRS-FOWLER PERL MIN ID DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY ( Acid Treatment while Rig is on well.) Pumped 5 bbls 60/40 methanol followed by 20 bbls 7% Acid, 5 bbls 60/40 methanol and 23.5 bbls sea water for displacement. LOG ENTRIES Init-> TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 00:00 Start Ticket. Arrive location. 00:05 Load seawater from vac truck. 00:25 PJSM. MIRU. RU Acid trans ort. 01:45 PT to 3500 osi. r Rig to line up for 02:32 1 start 60/40 50*F 500 Start um in down well. 02:37 1.5 5 Swa to acid. 02:39 2 start acid 60*F 950 Start Acid. 02:48 2 20 1000 Swa to 60/40 methanol. 02:50 1 start 60/40 50*F 250 Start 60/40 methanol 02:55 1 5 300 Swa to seawater. 02:56 1 start h20 60*F 300 Start seawater. 03:16 1 23 300 Shut down. RDMO. 03:59 End Ticket. FLUID SUMMARY 10 bbls 60/40 methanol 20 bbls 7% Acid 23.5 bbls Seawater • BP EXPLORATION Operations Summary Report Page 1 of 7 Legal Well Name: MPG-08 Common Well Name: MPG-08 Spud Date: 6/15/2000 Event Name: WORKOVER Start: 6/28/2008 End: 7/7/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/7/2008 Rig Name: NABORS 3S Rig Number: i Date ', From - To Hours Task Code NPT Phase Description of Operations 6/28/2008 23:00 - 00:00 1.00 RIGD P PRE PJSM Rig down floor for move to MPG-08. 6/29/2008 00:00 - 02:00 2.00 RIGD P PRE Scope down and lay down Derrick, remove hand rails and landing, R/D Pipe Shed and Pits. 02:00 - 02:30 0.50 RIGD P PRE PJSM with Truck drivers. 02:30 - 03:30 1.00 RIGD P PRE Move Carrier off Well with BP /WSL, Toolpusher and Pad operator present. 03:30 - 04:30 1.00 MOB P PRE Mobilize the Rig and Components from MPE-Pad to MPG-Pad. 04:30 - 06:30 2.00 RIGU P PRE Spot the BOPE Cradle behind well slot MPG-08A. Lay out Herculite and Rig Mats in preparation for the Carrier. Spot the Camp, Shop, Generator and Parts Trailer per approved camp siting form. 06:30 - 07:00 0.50 RIGU P PRE Back up the Carrier over well slot MPG-08A with the BP WSL and Toolpusher. The Pad Operator gave the verbal okay to back up over the well. 07:00 - 09:30 2.50 RIGU P PRE Spot the Pipe Shed and Pits Modules and connect to the Carrier. Raise and scope the Derrick. RU Handy Berm around the Rig. The Rig was accepted at 09:30 hrs on 6/29/2008. 09:30 - 11:30 2.00 KILL P DECOMP RU double annulus valve and begin RU circulating lines to the Tree. GPB Well Support rig down the Tiger Tank and hardline and move it from MPE-Pad to MPG-Pad. 11:30 - 14:30 3.00 WHSUR P DECOMP RU Lubricator with Well Su ort Techs and ressure test to 500 si. Pull the 2" T e "H" BPV. The WHPs are as follows: Tubin = 630 si , IA = 600 si , OA = 325 si. LD Lubricator. Continue RU Tiger Tank and hardline and circulaing lines. 14:30 - 15:00 0.50 KILL P DECOMP Pressure test surface lines to 3,500 psi. Pressure test hardline to the Tiger Tank to 500 psi. Good tests. Notify MPU of venting gas. 15:00 - 15:30 0.50 KILL P DECOMP Hold pre-kill /pre-spud safety meeting with the whole crew. 15:30 - 16:30 1.00 KILL P DECOMP Open the well to a closed choke, Tubing = 570 psi , IA = 520 psi. Bleed the gas off to the Tiger Tank, fell right off. Tubing = 0 psi , IA = 0 psi. Break circulation with heated seawater down the Tubing taking returns up the IA to the Tiger Tank. Pump at a rate 3 bpm / 850 psi on the Tubing and 250 psi on the IA. Got returns on surface after 7 bbls away. Pump a total of 25 bbls down the Tubing and shut the pump down. Close the Choke and attempt to bullhead into the formation at 0.5 bpm. Pressure up to 1,500 psi on both the Tubing and IA. Bleed the pressure off and open the Choke. Resume circulating down the Tubing taking returns to the Tiger Tank at a rate of 3 bpm / 950 on the Tubing and 450 on the IA. After 30 bbls away, the pressure on the Tubing dropped to 610 psi and 100 on the IA. Pump a total of 150 bbls with clean returns observed on surface. Final circulating pressure on the Tubing was 590 psi and the IA was 20 psi. 16:30 - 17:00 0.50 KILL P DECOMP Shut down and monitor the well, Tubing = 0 psi , IA = 0 psi. Total returns to the Tiger Tank was 167 bbls, total loss = 20 bbls. Check the Tubing and it's dead, check the IA and has some crude on top. 17:00 - 18:00 1.00 KILL P DECOMP Break circulation down the Tubing taking returns up the IA to the Tiger Tank to clean up the crude. Pump an additional 50 bbls of heated seawater at 3 bpm. Check the well -dead. Blow down and RD circulating lines. 18:00 - 19:00 1.00 WHSUR P DECOMP Install TWC with FMC wellhead tech. Test TWC from above to Printed: 7/23/2008 2:31:42 PM • Page2of7~ BP EXPLORATION Operations Summary Report Legal Well Name: MPG-08 Common Well Name: MPG-08 Spud Date: 6/15/2000 Event Name: WORKOVER Start: 6/28/2008 End: 7/7/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/7/2008 Rig Name: NABOBS 3S Rig Number: Date I From - To i Hours I Task I Code I NPT I Phase 6/29/2008 18:00 - 19:00 1.00 WHSUR P 19:00 - 20:00 1.00 WHSUR P 20:00 - 22:30 2.50 BOPSU P 22:30 - 23:00 0.50 BOPSU P 23:00 - 00:00 1.00 BOPSU P 6/30/2008 100:00 - 03:00 I 3.001 BOPSUR P 03:00 - 04:00 1.00 WHSUR P 04:00 - 05:00 1.00 WHSUR P 05:00 - 06:00 I 1.001 WHSUR I P 06:00 - 07:00 1.00 PULL P 07:00 - 07:30 0.50 PULL P 07:30 - 15:30 8.00 PULL P 15:30 - 18:00 2.50 PULL P 18:00 - 19:00 1.00 CLEAN P 19:00 - 20:00 1.00 CLEAN 20:00 - 22:30 2.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 7/1/2008 00:00 - 02:00 2.00 CLEAN P 02:00 - 03:00 I 1.00 I CLEAN I P 03:00 - 05:30 I 2.501 CLEAN I P Description of Operations DECOMP 3.500 psi for 10 charted minutes. Good test. . DECOMP ND production Tree. DECOMP PU BOP from shipping cradle, NU DSA, BOPE, hook up accumulator lines, Kill and Choke lines. DECOMP Function test BOPE and Koomey unit. DECOMP Pressure test BOPE to 250 psi low and 3,500 psi high with a TWC in the tubing hanger, per BP / AOGCC Regulations. The Rams were tested with 2-7/8" Test Joint. Chuck Scheve with the AOGCC waived the state's right to witness the BOPE test at 08:45 hrs on 6/29/2008. DECOMP Continue the BOPE test. The Annular, dart and full open floor safety valves were tested to 250 / 3,500 psi. The test was witnessed by the BP / WSL and Nabors Toolpusher. DECOMP PU / MU Opso Lopso and lubricator, Tested lubricator 500 psi for 5 minutes, Well support techs pull TWC. DECOMP PU / MU landin 'oint, FMC wellhead tech BOLDS, tubing and IA = 0 psi, pull hanger free with 43 K. Observe well for 10 minutes -well dead. DECOMP Circulate Well at 4,014' MD, pumped 142 bbls 8.4 ppg seawater, 3 BPM at 450 psi with no gains or losses, small amount of crude during initial returns then cleaned up to clean seawater. MW in = 8.3+ppg , MW out = 8.3+ ppg. DECOMP Pre-tour checks. RU Elephant Trunk and Spooling Unit. DECOMP Lay down the Hanger and Landing Joint. DECOMP POOH with existing 2-7/8" ESP Completion standing back C seawater Started encountering scale on the OD of the pipe on stand #58 out of the hole -3,650'. Found Tubing punch holes in the 10' pup joint above the bottom GLM. The bottom GLM was packed off with sand /fill. Had pressure and wellbore fluids in the first 3 Joints out of the hole beneath the bottom GLM (Jts #126-128 out of the hole). Used the hydraulic Tubing punch to safely drain and lay down these Joints. The last Tubing Joint above the ESP was packed off with dry sand /fill. DECOMP On surface with ESP Assembly. BOLD existing ESP Assembly with Centrilift. Inspect both GLMs and Tubing in the Pipe Shed with Milne Point PE and Well Ops Coordinator. Confer with Milne Point Engineering and decision made to change out both GLMs with new ones and to change out the whole Tubing string as well due to the scale buildup on the ID of the pipe. DECOMP Clear the Rig floor of ESP tools. DECOMP Clean Rig floor. DECOMP PU/MU BHA #1= Mule shoe, 11 joints of (1-1/4" CS-HYD, 3.02#, N-80), XO, 9 joints of (2-7/8" 10.4#, Pac DP), XO, _ 628.87' DECOMP Strap in hole from Derrick to 25 stands (2,192') at 00:00 hrs. DECOMP Continue to strap in hole from Derrick to 61 stands, tagged fill at 4,460'. DECOMP Circulate bottoms up at 36PM / 960 psi, some mixed silty crude oil in returns. DECOMP Clean out from 4,460' to 4,478' reverse circulate out crude and very fine gray silt. 36PM / 1030 psi with thick black crude in Printed: 7/23/2008 2:31:42 PM • BP EXPLORATION Operations Summary Report Page 3 of 7 Legal Well Name: MPG-08 Common Well Name: MPG-08 Spud Date: 6/15/2000 Event Name: WORKOVER Start: 6/28/2008 End: 7/7/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/7/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task i ~ Code I NPT I Phase Description of Operations 7/1/2008 03:00 - 05:30 2.50 CLEAN P DECOMP returns. Reverse circulate until the returns cleaned up. Pumped 3 Tubing volumes to achieve clean returns. 05:30 - 06:30 1.00 CLEAN P DECOMP Continue RIH with stands of DP to the to of the Packer at 4 609' with no roblems. 06:30 - 07:30 1.00 CLEAN P DECOMP Circulate bottoms up with seawater at the Packer at a rate of 3 bpm / 1030 psi. Gas and crude in returns. Circulate until clean returns with 8.4 ppg returns. 07:30 - 18:00 10.50 CLEAN P DECOMP RIH with ease inside the 4" ID section of the screen assembly. Ta fill at 4 616'. Wash down to 4 640'. Reverse circulate clean with 1.5 tubing volumes. Continue washing down the long way each individual joint. Close the Annular and reverse out fill until clean, average reverse rate of 3 bpm / 1,030 psi. Seein as and sand eve tubin bottoms up on surface. The sand is extremely fine and taking on average two to three tubing volumes to clean up. Continue RIH joint by joint repeating the same steps. 18:00 - 19:30 1.50 CLEAN P DECOMP PUW = 35K. SOW = 25K. Tag solid bridge ~ 5012' while reverse circulatin ~ 3 BPM ~ 970 si. ressure spiked to 1500 psi and lost circulation. Circulate the long way to clear TBG. Reciprocate pipe to 4994' while working the pump and bleeder to 1500 psi. Obstruction broke free after several attempts. Pulled 15K over to free string. CBU 3 TBG volumes ~ 3 BPM / 1030 psi -recovered fine sands and gas to surface. Continue washing hard sands with circulating parameters - 3 BPM ~ 970 to 1030 psi. 19:30 - 00:00 4.50 CLEAN P DECOMP Continue washing hard sands alternating from the long way to reverse circulating 1 joint at a time. Circulating parameters: - 3 BPM ~ 970 to 1200 psi. Recovering fine, beach sands and gas to surface with traces of heavy crude. V1/ashed down from 5012' to 5071'. 7/2/2008 00:00 - 03:00 3.00 CLEAN P DECOMP Washed from 5071' to 5080'. Broke thru bridge ~ 5080' and washed down joint to 5111'. Reverse clean w/ 3 BPM ~ 950 psi. Pressure dropped to 750 psi and lost 30 bbls while circulating. Open we I an monitor osses. tatic osses minimal. 03:00 - 06:00 3.00 CLEAN P DECOMP Wash down circulating thru the TBG then reversing out sand from 5111' - 5220' with out problems. Circulating the long way losing 20 bbls/hr ~ 3 BPM. Reverse circulating losing 40 bbls/hr ~ 3 BPM. Recovered sand with small scale chunks. 06:00 - 06:30 0.50 CLEAN P DECOMP While reverse circulating at 3 bpm / 1,000 psi at target death of 220' lost returns after 25 bbls umped. Shut down and line up to circulate the long way and open the well up to a closed choke. 06:30 - 08:30 2.00 CLEAN P DECOMP SITP = 10 psi , SICP = 60 psi. Bleed off through the Choke and the pressure bled off instantly. Check for flow -static. Break circulation down the Tubing up the IA at a rate of 3 bpm / 950 psi. Pumped a total of 160 bbls. Shut down and monitor the pressures, Tbg = 0 psi , IA = 0 psi. 08:30 - 09:30 1.00 CLEAN P DECOMP Circulate the long way taking returns to the Tiger Tank to make room for clean fluid and sweeps. Circulate at a rate of 1.75 bpm / 1,000 psi with max circulating pressure of 1,100 psi and final circulating pressure of 900 psi. Pumped a total of 100 bbls with 40 bbls of returns in the Tank. Printed: 7/23/2008 2:31:42 PM • BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: MPG-08 Common Well Name: MPG-08 Spud Date: 6/15/2000 Event Name: WORKOVER Start: 6/28/2008 End: 7/7/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/7/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase '; Description of Operations 7/2/2008 09:30 - 10:30 1.00 CLEAN P DECOMP Shut down and monitor the well. Observe the well and the fluid is flowing up teh IA and down the flowline. Started with a trickle ane gradually increasing. Shut the well in and observe shut in ressures. Confer with Anchorage Engineering and decision made to dislace the well to clean seawater. 10:30 - 11:00 0.50 CLEAN P DECOMP PJSM with the crew on displacing the well. SITP = 70 psi , SICP = 40 psi. 11:00 - 13:00 2.00 CLEAN P DECOMP Break circulating down the Tubing up the IA through the Choke with the Annular closed. Pumping at a rate of 1 bpm / 1,200 psi with no returns. Pumped a total of 120 bbls. Try to work the Pipe through the Bag - no Joy. 13:00 - 14:00 1.00 CLEAN P DECOMP Open the Bag and circulate at a rate of 2 bpm / 990 psi. Pull to max pull of 95K (58K overpull) and work the Pipe up the hole. Work it up the hole a total of 20' with no returns. 14:00 - 15:00 1.00 CLEAN P DECOMP Confer with Anchorage Engineering on plan forward. SICP = 0 psi due to plugged off around the Pipe. SITP = 400 psi. Bleed off through the Bleeder and pressure up to 120 psi. Continue bleeding the pressure off to 0 psi and monitor. The Tubing is staying at 0 psi. 15:00 - 16:00 1.00 CLEAN P DECOMP PUMU 2nd TIW Valve and pressure test to 3,000 psi - OK. SITP = 0 psi ,SICP = 0 psi. Hold PJSM with the crew on plan forward. 16:00 - 18:00 2.00 CLEAN P DECOMP Work the Pipe out of the hole Joint by Joint with the TIW Valve and circulating hose on top of each Joint. Break out each Joint and monitor fluid in the Tubing -static. POOH and come free at 5,111'. POOH with PUW = 32K to the top of the Packer at 4,609'. 18:00 - 20:00 2.00 CLEAN P DECOMP Reverse circulate 30 BBL hi-vis sweep down the backside ~ 3BPM / 550 psi. Returned minimal sands across shakers. Lost 130 bbls while circulating. 20:00 - 23:00 3.00 CLEAN P DECOMP Shut down pump, TBG= 190 psi, CSG= 170 psi. Bleed down thru choke -excessive returns with increasing crude trace throughout. TBG= 110 psi, CSG= 90 psi. Repeat process several times and monitor until TBG &CSG reached 0 psi. Open well & monitor, slow stream flow. MU 1 joint and reciprocate down to 4640' without overpull. Flowing returns not slowing down. 23:00 - 00:00 1.00 CLEAN P DECOMP CBU the long way ~ 3BPM / 550 psi. No losses occuring. Increase in crude returns along with gas bubbles. Shut down pumps. TBG= 0 psi, CSG= 0 psi. Intermitant flow occurring. 7/3/2008 00:00 - 02:00 2.00 CLEAN DECOMP Monitor well. Confer with town about next steps. 02:00 - 06:00 4.00 CLEAN DECOMP PJSM. Single in from 4640' to 4703'. Reverse circulate 1 BPM / 120 psi - 0 losses. Increase rate to 1.5 BPM / 170 psi, recovering gas, crude and very fine clay sands - 0 losses. Increase to 1.75 BPM / 230 psi, same returns over shakers - 0 losses. Increase rate to 2 BPM / 300 psi, incur 1 BBL loss while circulating. Decrease and remain ~ 1.75 BPM / 230 psi with out losses and good returns. Pump 10 BBL sweep and maintain rate /pressure thru surface to surface circulation. 06:00 - 06:30 0.50 CLEAN P DECOMP Service the Rig and pre-tour checks. 06:30 - 13:00 6.50 CLEAN P DECOMP RIH from 4,703' stopping to reverse circulate at 1.5 - 1.75 bpm / 250 psi max. Maintaining pressure at 250 psi or less to minimize losses while reverse circulating. Getting crude and Printed: 7/23/2008 2:31:42 PM • BP EXPLORATION Operations Summary Report Page 5 of 7 Legal Well Name: MPG-08 Common Well Name: MPG-08 Spud Date: 6/15/2000 Event Name: WORKOVER Start: 6/28/2008 End: 7/7/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/7/2008 Rig Name: NABOBS 3S Rig Number: Date .From - To Hours !, Task Code NPT Phase Description of Operations 7/3/2008 06:30 - 13:00 6.50 CLEAN P DECOMP 13:00 - 15:00 2.00 CLEAN P DECOMP 15:00 - 18:00 3.00 CLEAN P DECOMP 18:00 - 00:00 6.00 CLEAN P DECOMP 7/4/2008 00:00 - 04:00 4.00 CLEAN P DECOMP 04:00 - 06:00 2.00 CLEAN P DECOMP 06:00 - 09:00 3.00 CLEAN P DECOMP 09:00 - 19:00 10.00 CLEAN P DECOMP 19:00 - 22:00 3.00 CLEAN P DECOMP 22:00 - 00:00 2.00 CLEAN P DECOMP 7/5/2008 00:00 - 02:00 2.00 CLEAN C DECOMP 02:00 - 02:30 0.50 CLEAN C DECOMP gas on every bottoms up. POOH 1 stand periodically to move the Pipe and ensure we are not sticking. PUW = 35K ,SOW = 27K. Velocity through the workstring reversing approximately 250 feet per minute. Tap fill with 3K down weight at 4,959'. Reverse circulate clean at 1.7 bpm / 225 psi. Gas and crude seen after 26 bbls pumped (bottoms up). Getting real fine sand in returns. Reverse circulate until returns and sand clears up with zero losses. Strip through the Bag down to 4,987'. Mix and reverse circulate a 15 bbl hi-vis sweep surface to surface to clean out any remaining wellbore fluids and/or sand at 4,987'. Nothing significant seen with the sweep at surface. Continue to single in hole while reverse circulating TBG volumes ~ 1.7 BPM / 220 psi. No losses occuring. Circulate hi-vis sweeps until clean returns. Crude trace down minimum without gas to surface. Heavy volumes of fine beach sands along with scale pieces to surface. Circulate from 4987' to 5048'. Continue circulating from 5048' to 5080' ~ 1.7 BPM / 230 psi. Pressured up on TBG to 360 psi. Pulled out of tight spot & swap to the long way ~ 1 BPM / 100 psi and cleared obstruction. Reverse back in hole 1 TBG volume, crude & gas returns with minimal sands. Plugged up again, freed obstruction with 2500 psi down the TBG. Maintain reverse circulation C~3 1.5 BPM / 160 psi taking continued losses ~ -16 bbls/hr. Taking small bites with minimal sands to surface, larger amounts of crude back. Reverse circulate a hi vis sweep surface to surface at 5,142' at a rate of 1.5 bpm / 160 psi. Pumped a total of 208 bbls. Fine sand and crude in returns. Average loss rate of 15 bbls /hour. Continue RIH slowly through the Bag while reverse circulating clean. Maintaining the pump at approximately 1.5 bpm / 160 psi to minimize losses. Reverse circulated down to 5218'. Lost returns at 5,218' while reversing. POOH to string weight plus 1' and regain returns. Try to reach target depth of 5,220' again and not making any ho a at 5,218'. Reciprocate 1 stand & run back to bottom no problem. Re-establish reverse circulation with returns at 5,218'. PUW = 40k, SOW = 28k. Reverse circulate 30 bbl hi-vis sweep ~ 1.25 BPM / 160 psi surface to surface. Sand and crude returns to surface. Wellbore cleaned up. Perform "dry" run to mimic acid wash pumping procedure. Circulate 25 bbls down tubing ~ 1.5 BPM / 160 psi. Reciprocate pipe, PUW = 39k, SOW = 29k. POH to 4806' with no overpull. Monitor well for 10 min. RIH to 5218' with out problems. Reverse circulate ~ 5218'. 1BPM / 120 psi. No sand to surface. Hold PJSM with all crews involved with acid job. R/U SLB acid truck &LRS pump truck. Place neutralizing pill in Tiger Tank. Pressure test all lines from LRS pump truck to cement line to 3500 psi. L/D 1 jt to spot muleshoe ~ 5190'. R/U circulating pin to cement line. Printed: 7/23/2008 2:31:42 PM • BP EXPLORATION Operations Summary Report Page 6 of 7 Legal Well Name: MPG-08 Common Well Name: MPG-08 Spud Date: 6/15/2000 Event Name: WORKOVER Start: 6/28/2008 End: 7/7/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/7/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours .Task Code NPT Phase I; Description of Operations 17/5/2008 02:30 - 03:30 ~ 1.00 CLEAN ( C 03:30 - 04:00 I 0.50 I CLEAN I C 04:00 - 04:30 I 0.50 I CLEAN I C 04:30 - 08:30 I 4.00 I CLEAN I C 08:30 - 15:30 ~ 7.001 CLEAN P 15:30 - 18:30 I 3.001 CLEAN I P 18:30 - 19:30 I 1.001 RU 19:30 - 00:00 I 4.501 RUN 7/6/2008 ! 00:00 - 14:00 I 14.00 14:00 - 14:30 I 0.50 14:30 - 15:00 I 0.50 15:00 - 19:00 ~ 4.00 19:00 - 20:00 ~ 1.00 DECOMP Pump fluid as follows: -5 bbls of methanol ~ 1 BPM / 250 psi -20 bbls of 7% DAD acid ~ 2 BPM / 1000 psi (Pump truck pressure thru 1"lines) -5 bbls of methanol ~ 1 BPM / 250 psi -23.5 bbls of 8.4 seawater ~ 1 BPM / 250 psi Acid in place ~ 03:16. R/D LRS & SLB. Lost 5 bbls while circulating acid job. DECOMP POH with stands to 4876' (above the 2-7/8" screens) without problems. PUW = 40k, SOW = 27k. DECOMP RIH to 5218' and L/D 1 jt to place muleshoe jt f~ 5190'. R/U to reverse circulate well to clean seawater. DECOMP Reverse circulate with clean seawater to displace acid and wellbore fluids to clean seawater. Take all returns to the Tiger tank. Wells support tech checking returns of spent acid to surface. At 06:00 hrs, pH = 3 and solids content = 1.5%. At 07:00 hrs, pH = 6.5 and solids content = 1.5%. Reverse circulate until clean seawater on surface. Pumped a total of 212 bbls with a 32 bbls loss. MW in = 8.37 ppg , MW out = 8.37 ppg. Final pH on the truck with agitation = 9.0 and avg solids content = 1.0%. DECOMP POOH with Cleanout Assembly laying down Joints of 2-7/8" EUE 8rd Tubing in the Pipe Shed. Maintaining continuous hole fill while POOH with zero losses. 30 Joints laid down at 10:00 hrs. 70 Joints laid down at 12:00 hrs. DECOMP On surface with Cleanout Assembly. Break out and lay down BHA components. The XO from 2-7/8" EUE 8rd to 2-7/8" PAC DP was filled with scale from the ID of the 2-7/8" EUE 8rd. The Muleshoe shows no damage. RUNCMP Clear & clean rig floor. PU handling equipment for ESP completion. RUNCMP MU Pump, Motor & Seals. RIH w/ ESP & experienced cable completion as per tally. Installed La Salle protectors on first 9 jts, then every second jt. Make up torque avg = 2300 ft-Ibs. 1562' ~ 2400 hrs. RUNCMP Continue to run ESP com letion as per tally from 1562'. Installed La Salle protectors every second jt. MU Heat trace on jt #53 (2500'). Pumped 10 bbls of seawater down TBG ~ 1/2 BPM / 500 psi every 2000'. MU torque avg = 2300 ft-Ibs. Depth 2689' ~ 0600 hrs. 110 Joints in at 11:00 hrs. 130 in at 13:30 hrs. Ran a total of 131 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing. Ran a total of 32 LaSalle Clamps, 2 Armster Guards, 4 Protectolizers, 366 ea 6' Flat Guards and 38 ea 3' Flat Guards for a total of 404 Flat Guards. Used a total of 1566 bands. RUNCMP MU TIW and circulating head. Fill the Tubing with seawater and flush the pump a final time at a rate of 0.5 bpm / 500 psi. RUNCMP PUMU Landing Joint and Hanger. Orient the Hanger per FMC rep. RUNCMP Perform field connection splices on the ESP and Heat Trace Cables with Centrilift reps. RUNCMP Suck out stack. Land TBG HGR. RILDS_. Final PUW = 42k, SOW = 34k. Printed: 7/23/2008 2:31:42 PM • • BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: MPG-08 Common Well Name: MPG-08 Spud Date: 6/15/2000 Event Name: WORKOVER Start: 6/28/2008 End: 7/7/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/7/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code ~ NPT ~ Phase Description of Operations 7/6/2008 20:00 - 20:30 0.50 WHSUR P RUNCMP FMC d rod TWC. Test TWC to 3500 si for 10 min -charted. 20:30 - 22:30 2.00 BOPSU P RUNCMP ND BOPE & equipment. 22:30 - 00:00 1.50 WHSUR P RUNCMP NU tree & new adapter flange. 7/7/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP Test tubing hanger void to 5000 psi for 30 min. Test tree body with diesel to 5000 psi for 5 min. Centralift make final conductivity check on ESP and Heat Trace. 01:00 - 02:00 1.00 WHSUR P RUNCMP Test lubricator to 500 psi. Pull TWC. Set 2" H-type BPV with lubricator. tielease Rig ~ 0200 hrs. Printed: 7/23/2008 2:31:42 PM '~ STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 6/29/2008 Rig Rep.: J. Henson / J. Fritts Rig Phone: 6591487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. Hoffman/D.Rhodes Field/Unit & Well No.: MP G-08A PTD # 1930480 '~ Operation: Drig: Test: Initial: x Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P WeM Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Workover: x . Weekly: Anrndar.250/3500 Explor.: Bi-Weekly Valves: 250/3500 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 0 NA P Lower Kelly 0 NA P BaB Type 1 P Inside BOP 1 P Test Result Annular Preventer 1 135/8 5000 P Pipe Rams 1 2 718 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 31/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3100 P Pressure After Closure 1700 P 200 psi Attained 29sec P Full Pressure Attained 2 min 30 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg}: 2000 Number of Failures: 0 Test Time: 4 Hours Components tested ALL Repair or replacement of equipment wtil be made wither days. Notiy the North Slope Inspector 659-3607, follow witli written confirmation to Superviser at: Remarks: Tested with 2 7/8" test joint, test as~airkst Two Wav Check valve (TWC ). 24 HOUR NOTICE GNEN YES X NO Waived By Chuck Sheve Date 06/29/08 Time 0845 hrs Witness J.Fritts/D.Rhodes Test start 2300 hrs Finish ~m1~1 JUN ~ ~ 20D~ BOP Test (for rigs) BFL 11/14/07 Nabors 3s BOP Test MP G-08A 6-29-08.x1s Obi OR BEFORE DECEMBER 01 2000 STATE OF ALASKA , ALASKA _ AND GAS CONSERVATION COMN ;ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 50' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3176' SNL, 3459' WEL, SEC. 27, T13N, R10E, UM MPG-08A At top of productive interval 9. Permit Number / Approval No. 193-048 909' SNL, 4421' WEL, SEC. 27, T13N, R10E, UM O iGINAL lO. APl Number At effective depth 50- 029-22141-01 844' SNL, 4450' WEL, SEC. 27, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 844' SNL, 4450' WEL, SEC. 27, T13N, R10E, UM 12. Present well condition summary Total depth: measured 5234 feet Plugs (measured) true vertical 4315 feet Effective depth: measured 5234 feet Junk (measured) true vertical 4315 feet Casing Length Size Cemented MD TVD Structural Conductor 105' 20" 452 sx Arctic Set IV 105' 105' Surface 2736' 9-5/8" 900 sx PF 'E', 300 sx Class 'G' 2736' 2375' Intermediate 5010' 7" 260 sx Class 'G' 5010' 4095' Production Liner Perforation depth: measured Gravel Pack Assembly: 4609'- 5226' true vertical Gravel Pack Assembly: 3711' - 4307' f ~ !.."~ ,-,,, .;, ,.,, .... Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 4216' Packers and SSSV (type and measured depth) Baker 'SO-1R' packer at 4609' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble~',~ ~f~ Title TechnicalAssistant Date - Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 6/15/2000 22:00 - 00:00 6/16/2000 i 00:00 - 02:00 ~ 02:00 - 03:00 03:00 - 05:30 6/17/2000 6/18/2000 6/19/2000 05:30 - 08:00 08:00 - 09:00 09:00- 12:00 12:00- 13:00 13:00- 14:00 14:00- 15:30 15:30 - 22:30 22:30 - 00:00 00:00 - 00:30 07:30 - 08:00 08:00 - 10:00 10:00 - 13:00 13:00 - 15:30 15:30 - 23:30 23:30 - 00:00 00:00 - 01:00 01:00 - 03:30 03:30 - 04:30 04:30 - 06:00 06:00 - 08:00 08:00 - 10:00 10:00 - 11:00 11:00 - 13:00 13:00 - 15:00 15:00 - 19:30 19:30 - 21:00 ~21:00 - 23:00 23:00 - 20:00 00:00 - 03:00 03:00 - 05:00 05:00 - 06:00 MPG-08 MPG-08 WORKOVER NABORS NABORS4ES 1.50 2.00 2.00 1.00 2.0O 2.00 4.50 1.50 2.00 21.00 3.00 2.00 1.00 RIGU RIGU RIGU RIGU KILL KILL BOPSUF BOPSUF BOPSUF PULL PULL PULL PULL PULL RUNCOI~ RUNCO~ RUNCOI~ RUNCOI~ RUNCO~ RUNCOI~ RUNCOr~ RUNCOI~ RUNCO~ WHSUR BOPSUF TEST PULL COTR BOPSUF COTR PULL I COTR PULL ]COTR PULL ICOTR RUNCOMCOTR RUNCOMCOTR RUNCOh~GOTR RUNCOI~3OTR RUNCOI~COTR Start: 6/15~2000 Rig Release: 6/19/2000 Rig Number: Spud Date: 6/15/2000 End: 6/19/2000 Group: RIG Description of Operations i DECOMP ! DECOMP DECOMP DECOMP DECOMP [ DECOMP ! DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP DECOMP DECOMP DECOMP DECOMP DECOMP COMP COMP COMP COMP COMP Accept rig at 22:00 hrs 6/15/00. Rig up, lay lines, berm tanks RU HCR valve on annulus, hard line to X-mas tree. RU lubricator, pull BPV, RD lubricator Pressure test X-mas tree and lines to 3000 psi. Weight up brine to 10.0 PPg Kill well wi10.0 ppg brine. Initial WHP-550 psi, Annulus-1500 psi RU lubricator, set TWC, RD lubricator ND X-mas tree, NU BOP Function test and full body test BOP RU lubricator, pull TWC, RD lubricator MU landng joint, pull Tubing Hanger Pull and LD ESP completion and Heat Trace LD and service ESP. Pump shaft appears to be broken LD and service ESP LD 5 bad jts. 2 7~8" Tubing PU and service ESP Run 2 7/8" ESP completion 'Pinched ESP cable in slips. Splice cable Run 2 7/8" ESP completion w/Heat Traace Space out to Raychem Heat Trace PU Tubing Hanger, Install P3enetrators Make up ESP and Heat Trace cables to Penetrator connections. Check cables and connections-OK Land Tubing Hanger, Install TWC. Pressure test TWC on annulus side to 200 psi. AIR while maintaining 200 psi test pressure=1.0 bpm ND BOP NU X-mas tree, Test ESP and Heat Trace connections. Heat Trace connection failed ND X-mas tree, NU and Function test BOP Pull Tubing Hanger to floor, re-test Heat Trace connections. Shows failure of Heat Trace downhole RE-land Tubing Hanger. Install Bell Nipple and Flowline. Full body test BOP RU Lubricator, pull TWC, pull and LD Tubing Hanger POOH while LD Heat Trace LD Heat Trace spool and clear floor for TIH TIH wi2 7/8" ESP completion MU Hanger, splice ESP cable to Penetrator connector !Make splice to Penetrator connection, Check splice and Penetrator connection-OK. Install TWC and land Tubing Hanger. Test TWC to 200 psi from annulus side !ND BOP, NU X-mas tree iTest adapter and X-mas tree to 5000 psi. RU lubricator, pull TWC, install BPV. Release rig 06:00 Printed: 813/2000 2:49:15 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing x Alter casing __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3176' SNL, 3459' WEL, SEC. 27, T13N, RIOE At top of productive interval 893' SNL, 4432' WEL, SEC. 27, T13N, RIOE At effective depth At total depth 828' SNL, 4461' WEL, SEC. 27, T13N, RIOE Stimulate __ Plugging__ Perforate__ Repair well x Other x Replace ESP 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 59' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPG-8A 9. Permit number/approval number 93-48/Cons. order #347 10. APl number 50- 029-22141-01 11. Field/Pool Mi/ne Point- Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 5234 feet Plugs (measured) 4307 feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth true vertical Tubing (size, grade, and measured depth) 2-7/8", L-80 EUE 8rd tubing to 4202' MD w/ FC925 FPL T ARC pump to 4242' MD Packers and SSSV (type and measured depth) RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MAY 1 5 1995 Alaska Oil & Gas Cons. Commission Anchora; '~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of V~ll Operations x Oil x Gas Suspended 17. I hereby certify a I~, eiders, going is t~e and correct to the best of my knowledge. Signed ~~~,J ~L~ Title Drillin~ Engineer Supervisor Form 10-404 Rev (~6/15/88 Service SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONo PAGE: 1 WELL: MPU G-8A BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/05/95 02:00 SPUD: RELEASE: 04/10/95 04:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 04/05/95 ( 1) TD: 5234 PB: 5227 04/06/95 (2) TD: 5234 PB: 5227 04/07/95 (3) TD: 5234 PB: 5227 SET TWO WAY CHECK MW: 0.0 MOVE RIG FROM MPU J-01 TO MPU G-O8A AND SPOT OVER WELL. BERM AND SPOT TIGER TANK HOOK UP LINES TO TREE AND RIG LUBRICATOR TO PULL BPV. PREPARE TO PUMP INFLUX FROM WELL BORE. PREP TO PULL TBG MW: 0.0 RD LUBRICATOR. TEST LINES, OK. PUMP DOWN TBG W/ 120 DEGREE, 9~ BRINE. DISPLACE CRUDE, GAS AND WATER TO FLOW TANK. PUMPED 190 BBLS. MONITOR WELL. WELL DEAD. SET TWC. ND TREE AND ADAPTER FLANGE. NU DBL STUD ADAPTER AND BOPE. BREAK AND BACKOFF HYDRIL CAP. FRAC SAND BEHIND ELEMENT. CLEAN OUT. REPLACE SEAL RINGS AND HYDRIL ELEMENT. REPLACE CAP. NU FLOWLINE. TEST BOPE. RU TO PULL TBG AND WO DRILL SITE MAINTENANCE. ATTEMPT TO PULL TWC. UNABLE TO SCREW IN DUE TO FRAC SAND. CLEAN FRAC SAND OFF TBG HANGER. PULL TWC AFTER NUMEROUS TRIES. RD LUBRICATOR. PREP TO PULL TBG. REV CIRC XANVIS SWEEP MW: 0.0 FINISH LD LUBRICATOR. MU LANDING JT. WO NACL TO WT UP. RU AND HANG DRIP HOSE FOR ESP CABLE. WT UP PITS F/ 8.8#-9#. HEAT FLUID TO 140 DEGREE. FILL HOLE W/ 12 BBLS. CIRC ONE HOLE VOLUME. CIRC SMALL AMOUNT CRUDE. HEAT WELL BORE TO 120 DEG OUT. BOLDS. PULL HANGER TO FLOOR. LD HANGER. MONITOR WELL. STRING ESP CABLE THRU DRIP LINE. POH W/ 2 7/8" TBG. SLM AND DRIFT. INSPECT AND LD ESP. RECOVERED 313 BANDS AND 6.3 FLATS. LEFT 10 BANDS IN HOLE. SET WEAR RING. PU SLOTTED PUP JT AND KELLY. WASH OUT BOP STACK. MU 5.75" MAGNET. RIH ON 2 7/8" TBG TO TOP OF PACKER @ 4605' DPM. REVERSE CIRC 50 BBLS XANVIS/BREAKER SWEEP AROUND. At~ska Oil & Gas Cons. Commissio~ Anchora-~ WELL : MPU G-8A OPERATION: RIG : NABORS 4ES PAGE: 2 04/08/95 (4) TD: 5234 PB: 5227 REVERSE CIRC HOT DIESEL MW: 0.0 CONTINUE REVERSE OUT SWEEP. MONITOR WELL, OK. POH. LD 4 BAD JTS. LD MAGNET. RECOVERED 1 BAND AND SMALL PIECES. RU CAMCO SL. TEST LUBRICATOR, OK. RUN #1 2" CENTRALIZER TO 2250'. COULD NOT GET DEEPER. 900# DRAG WHEN POH. RUN #2 6" GR/JB TO 1050'. COULD NOT GET DEEPER. 600# DRAG WHEN POH. ALL TOOL STRINGS CLEAN. ASSUME PARAFFIN/ASPHALTINE BUILD-UP IN CASING. RD CAMCO. MU 5.5" MAGNET AND RIH ON 2 7/8" TUBING TO 4605'. R/U AND CIRC WHILE HEATING WELLBORE FROM 58 TO 110 DEG. CONTINUE CIRC WELL WHILE HEATING 150 BBLS DIESEL, ON TRUCK TO 175 DEG. REVERSE CIRC 150 BBLS HOT DIESEL. CONTINUE DISPLACE AROUND W/ 9# BRINE. RETURNS THRU CHOKE. SHIPPED DIESEL TO FLOW TANK. FIRST +/- 60 BBLS DIESEL RETURNS WERE VERY DIRTY. REMAINDER LOOKS CLEAN. 04/09/95 (5) TD: 5234 PB: 5227 RUNNING 2 7/8" COMPLETION MW: 0.0 FINISH DISPLACING HOT DIESEL OUT. MONITOR WELL, OK. POH. LD MAGNET. NO RECOVERY. WO CAMCO. RU CAMCO. TEST LUBRICATOR, OK. RUN #1 6" GR/JB TO 4587'. RECOVERED 5 BANDS. RUN #2 RERUN TO 4602'. RECOVERED 1 BAND. RUN #3 RERUN TO 4606', NO RECOVERY. RUN #4 2" CENTRALIZER TO 5020'. POH. RD CAMCO. PULL WEAR RING. RU TO RUN 2 7/8" COMPLETION. RIH W/ 3 STDS TBG, LD SAME. MU AND SERVICE CENTRALIFT PUMP. MU PIGTAIL. RIH W/ ESP COMPLETION. RU TO RUN RAYCHEM HEAT TRACE. CONTINUE RIH. 04/10/95 (6) TD: 5234 PB: 5227 04/11/95 ( 7) TD: 5234 PB: 5227 SIGNATURE: WORK ON ANNULAR PREVENTER MW: 0.0 FINISH RUNNING ESP COMPLETION. HEAT TRACE F/ 2265'. SPACE OUT AND MU HANGER. MU PENETRATORS. HEAT TRACE PENETRATOR DID NOT APPEAR TO BE MAKING UP PROPERLY. MAKE ESP PIG TAIL SPLICE. MODIFY FMC HEAT TRACE PENETRATOR NUT. RETEST HEAT TRACE AND ESP PENETRATORS. LAND HANGER. RILDS. LD LANDING JT. SET TWC. ND FLOW NIPPLE. REMOVE HYDRIL CAP. TEAR DOWN HYDRIL AND INSPECT. REPLACE SEALS. RELEASE RIG MW: 0.0 FINISH REPAIR ANNULAR. TEST, OK. ND BOPE. NU ADAPTER FLANGE AND TREE. TEST, OK. PULL TWC. FREEZE PROTECT ANNULUS TO 2300' W/ 70 BBLS 110 DEG DIESEL. BULLHEAD 14 BBLS 60/40 MEOH/SOURCE H20 DOWN TBG. RU LUBRICATOR. SET BPV. SECURE WELLHEAD AND TREE. RELEASE RIG @ 1600 HRS ON 04/10/95. / ×~ - DATE: (drilling l~perintendent) RECEIVED MAY 1 5 1995 Alaska Oil & Gas Cons. Commission L~'~i C(}Hir. ~}A'r~! S 0'? .... o~:...,..93 Da'!::e: 04/'18//95 09/"20/' 1993 09/'22/ I 93 09/' 22/' 199 ..':~ 09/02/i993 09,/02/" '1993 07/28/ ~ 993 09/02/ 1993 09/02/1993 09/0S/lO ..... '- , . ..., o q .::~ /0 © '1 q q ~' 09 / . .... /' . ........ :~ 09/02/' '199}~ · ~. ,. ...... ::~ 07/26/'/99S s,/e S J"/C) I n '¥ 't: ')' a '1 !/e S Fi 0 September 21, 1993 Conoco Inc.' 3201 C Street, Suite 205 Anchorage, AK 99503-3999 (907) 564-7600 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: G-8A; WELL COMPLETION OR RECOMPLETION REPORT AND LOG Dear Mr. Johnston, Attached are two copies of Well Completion or Recompletion Report and Log, Form 10-407, and associated information for Milne Point Unit Well G-8A. Please direCt any questi°n~' regarding this matter to me at564-7660. Sincerely, Tom Yeager SHEAR Specialist attachments CC: JDP, TJY G-8A Well File Chevron Occidental STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Ciassification of Service Welt OIL ~i~ GAS [] SUSPENDED ~ ABANDONED [] SERVICE ~_~ ~I~,~/~,~ 2. Name of Operator Conoco Inc. ! ~:~-~' 93-48 / ~~ 81APl Number 4. Location of well at surface i' ~'>~'~.~I 9. Unit or Lease Name 3176'FNL, 3459'FEL, Sec. 27, T13N, R10E, U.M., NSB,~ /Milne Point Unit: At Top Producing Interval 10. Well Number 893'FNL, 4432'FEL, Sec. 27, T13N, R10E, U.M., NSB, At Total Depth ~~~ V~J~.It~iEi? ~ Kuparu--11'FieldandP°°lk 828'FNI., 4461'FEL, Sec. 27, T13N, R10E, U.M., NSB, River Fi. eld Schrader Bluff ]7ool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 29'KB AGL (DF 59') I ADL 25906 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband, [ 15. Water Depth, if offshore 116. i~.1o, of Completions Sidetrack 7/15/93 7/16/93 7/22/93 I N/A feet MSL t 1 17. Total Depth (MD+TVD) ~.~ugBackDepth(MD+-FVD) 19. Dir'ectionalSurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 5234'MD/4307'TVD N/A YES ~ NO [] IWaiver feet MD 1_+1850' TVD 22. Type Electric or Other Logs Run Gyro to cover sidetrack f/4600' MD to surface) MWD- Resistivity, GR, Neutron, Density, (4 arm caliper- unsuccessful) 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED G-8 54.5tt K-55 30" ~52sxs Arctic Set IV None !3 3/8". 9 5/8" G-SA (S. 7" 36# r.) 26{ KA55 L-80 SETTING DEPTH MD TOP ~ BOTTOM 29' (sur~) lOO' 29' (surl) 2731' 29' (surf) 4865' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) The 8.5" open hole was underreamed to 12" below the 7" casing shoe f/5234'-4870' (4307'-3951' TVD). "NA" sand top 4882' MD/ 3963'TVD. "OB" Sand base 5146' MD/4221'TVD. Gravel pack description: 4-1/2" OD X 2-7/8'~ ID single screen prepacked liner surrounded by 22,000 lbs. of 20/40 sand. _(No perforations) 12 1/4" 8 1/2" 900sx Perm E+300sx G 195sx Premium G None None 25. TUBING RECORD SIZE IDEPTH SET (MD) PACKER SET (MD) 2 7/8", 6.51 4522' None: 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED None 27. PRODUCTION TEST Date First Production 7/31/93 Method of Operation (Flowing, gas lift, etc.) ESP Lift Date of Test Hours Tested PRODUCTION FOR IOI L-BBL GAS-MCF 9/3/93 24 TEST PERIOD I~t221 0 Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF Press. 500 500 24-HOUR RATE I~ 221 0 28. CORE DATA WATER-BBL CHOKE SIZE GAS-OIL RATIO 120 N/A I 0 WATER-BBL OIL GRAVITY-APl 120 N/A Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC NAME NA Sand Top NB Sand Top NC Sand Top NE Sand Top OA Sand Top OB Sand Top MEAS. DEPTH 4882 4.943 4970 4997 5084 5153 TRUE VERT. DEPTH 30. 3963 4011 4038 4064 4149 4216 '"'""'¢~ OR M ATI 0 N TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 9~ ~the foregoing is true and correct to the best of my knowledge Title INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and tog on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this welt is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Itern 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". F or,'n 10-407 WELL No. G-8A CASING SKETCH MILNE POINT UNIT APl No.: 50-029-22141 PERMIT No.: 91-26 DRILLED: 5/50/91 ARCTIC PACKED: OPEN (P) NOTE: SEE G-8 CASING SKETCH FOR SIDETRACK OPERATOR: CONOCO INC. AND FISH INFORMATION· SURFACE LOCATION: 3176' FNL, 3459' FEL, SEC. 27, T15N, RIOE, U.M. BOTTOM HOLE LOCATION: 828' FNL, 4461' FEL, SEC. 27, T15N, RIOE, U.M. SPUD DATE: 5/24/91 SIDETRACK DATE: 7-15-93 RKB 29' NABORS 22E RIG FMC CSG SPOOL 15 5/8", 54.5#, K-55 WELD SET @ 100' CEMENT DATA: 452 SKS ARCTIC SET IV 9 5/8", 56#, K-55, BTRC, SET @ 2751' CEMENT DATA: LEAD; 524 BBLS, 900 SKS, PERMAFROST "E" W/ 5#/SK GILSONITE @12.3 PPG TAIL; 61.5 BBLS, 300 SKS, PREMIUM "0" W/ 0.2% CFR-5 & 2% CoCL @ 15.8 PPO TOC EST. 3900' 4610' BAKER SC-IL 709-40 PACKER 4820' 7" HOS CEMENTER 4855'-4855' CTC EXTERNAL CASING PACKER INFLATED W/ DRILLING MUD TD 5234' 7"-26#, L-80 BTRC SET @ 4865' CEMENT DATA" 5505 BBLS, 195 SKS, PREMIUM "G" W/ 0.5% D156 + 0.5% D065 + 0.2% D046 + 1.0% S1. OPEN HOLE GRAVEL PACK GRAVEL PACK SCREEN ~conoco) EPNA - ANCHORAOE DIVISION APPROVED BY: JDP DATE: 9-20-95 DRAFTED BY: OKF CAD FILE: WCAO8A NOTES: ALL DEPTHS MEASURED RKB = 27' NABORS 22E KDB-SL = KDB-GL = 2. MAX. ANGLE = 50'@ 3250~ .3.K.O.P. = 500' SIDETRACK = 2779' 4. SLANT HOLE: YES 5. TREE TYPE: FMC 2 9/16", 5000//, W~ 2 7/8" 8rd TREETOP CONNECTION 6. COMPLETION FLUID: 9.0 PPG NaCI 7. ESP ASSEMBLY: CENTRILIFT FC-650 PUMP, 184 STAGES, 65HP, 1250V/30A MOTOR, STD. INTAKE, (;SBT SECTION, PHD UNIT 7" CASING @ 4870' WELL No. G-8A COMPLETION SKETCH MILNE POINT UNIT (P) APl No.: 50-029-22141-01 PERMIT No.: 95-48 COMPLETED: 7/22/93 LAST WORKOVER: N/A ]---,---- FMC TUBING HANGER 158 JTS. 2 7/8", 6.5#, L-80, 8rd EUE TUBING ESP CABLE - No. 2 CL-350 4412' 2 7/8" x 1" GASLIFT MANDREL W/ DUMMY VALVE INSTALLED 1 JT. 2 7/8", 6.5//, L-80, 8rd EUE TUBING CHECK VALVE @ 4446' md 2 JTS. 2 7/8", 6.5#, L-80, 8rd EUE TUBING 4513' TOP OF ESP 4522' BOTTOM OF ESP 4609' ~//-~4622' /-4653' 4655' 4876' 4877' BAKER MODEL SC-1R PACKER (4.0" ID) BAKER MODEL "S' SLIDING SLEEVE (4.38" I.D.) "XO" 5" CSG BTRC x 4 1/2" CSG BTRC BAKER 4 1/2" 8rd EUE BLANK PIPE (221') "XO" 4 1/2" 8rd EUE BOX x 2 7/8" lORD NU PiN (2.44" I.D.) HOWARD SMITH SINGLE SCREEN PREP ACK 4 1/2" x 2 7/8" 12 GA., 342' (2.44" ID) GRAVEL PACK OF 20/40 MESH GRAVEL 5234' TD 5220' "XO" 2 7/8" lORD NU x 4 1/2" 8rd SHORT PIN (2.44" I.D.) 5220' UNIVEE SEAL SUB 5221' "XO" 4 t/2" BTRC BOX x 4 1/2" 8rd SHORT PIN 5222' FLAPPER VALVE ASSEMBLY 5525' "XO" 4 1/2" BTRC PIN x 4 1/2" 8rd LONG BOX 5226' BAKER V-SET SHOE W/ CHECK VALVES (2.0" I.D.) 5227' BOTTOM OF V-SET SHOE {COI'IOCO) EPNA - ANCHORAGE DIVISION IAPPROVED BY: BGA DRAFTED BY: GKF DATE: 8-27-93 CAD FILE: WCOG8A Detailed Activity Report ........... ~.;~.~:.L!~!:.L~.:~:.:~:.:~U?;~!~:.~:~.:.L:.:`~.:~:`.:.:.:~`~..E~:~:.~.:`~...:~:.:.~:.:.:.:.:.:.~:.~:.21~:.~:.~:`1:.1112111~:.~;.~::~:.:.~:.~:.:.:::.~:.~::~:.~:.~:~:.~:.~;~:.~:.~::~:.~:.~:.~:.:.:.~:.:~:.~:.~:.~:.~!~:.%.:~:.:~;::.:;`/!~:.~:.:/.~..~....~.;`~.~..~??~.?:.:~..~..:.~:.~:.~:.~::~:.!:.::??~.~.:.~???;~!~::.:~.:~:~?:i~.???:~:.~:.~L:.!:.f.::.:~::.~f.:.L 07/09/1993 1 PIB lA 18.00 06:00 00:00 0.0 MOVE PIPESHEDS, PUMP,MOTOR, BOILER AND SUBBASE COMPLEXS TO G PAD 07/10/1993 1 PIB 1C 11.00 00:00 11:00 0.0 PIN GOOSE NECKS, MOVE SUB OVER HOLE, SET MUD COMPLEX, SET BOILER AND MOTOR COMPLEX, INSTALL SKATE AND GERONIMOE LINE 11 P6 5 1.00 11:00 12:00 0.0 RU UP TO KILL WELL I PIB 1C 0.50 12:00 12:30 0.0 LEVEL SUB 11 P6 5 4.50 12:30 17:00 0.0 RU TO KILL WELL, CIRCULATE OUT GAS AND OIL, HAD 1000# GAS PRESSURE ON ANNULUS 11 P6 45 1.00 17:00 18:00 0.0 REMOVE TREE 11 P6 45 3.00 18:00 21:00 0.0 NU BOP 11 P6 15A 0.50 21:00 21:30 0.0 PULL BPV, INSTALL 2 WAY, RU TO TEST 11 P6 15A 2.50 21:30 00:00 0.0 TEST BOP's -ECEiVE ~...:.i:~ ~,!~ ?~ CONOCO Detailed Activity Report 07/1111993 07/12/1993 07/13/1993 11 P6 15A 2.50 00:00 02:30 5430.0 11 PlO 23 10.50 02:30 13:00 5430.0 11 PlO 28 1.50 13:00 14:30 5430.0 11 P6 28 1.00 14:30 15:30 5430.0 11 P6 28 1.00 15:30 16:30 5430.0 11 P6 45 2.50 16:30 19:00 5430.0 11 L6 42A 2.00 19:00 21:00 5430.0 11 L6 42A 2.50 21:00 23:30 5430.0 11 P6 45 0.50 23:30 00:00 5430.0 11 P6 15F 1.00 00:00 01:00 5430.0 11 P6 15A 1.00 01:00 02:00 5430.0 11 P6 24 0.50 02:00 02:30 5430.0 11 P6 9 1.00 02:30 03:30 5430.0 11 P6 28 0.50 03:30 04:00 5430.0 11 P6 28 0.50 04:00 04:30 5430.0 11 P6 23 3.50 04:30 08:00 5430.0 11 P6 28 1.00 08:00 09:00 5430.0 11 P6 31B 1.00 09:00 10:00 5430.0 11 P6 45 2.00 10:00 12:00 5430.0 11 P6 6F 2.00 12:30 11 P8 6F 1.00 14:30 11 P6 45 1.50 15:30 11 P6 5 1.50 17:00 11 P6 45 1.00 18:30 11 P6 45 0.50 19:30 11 P6 6F 1.00 20:00 11 P6 45 1.50 21:00 11 P6 15A 0.50 22:30 11 P6 45 1.00 23:00 11 P6 45 0.50 00:00 11 P6 28 0.50 00:30 11 P6 45 1.00 01:00 11 P6 28 1.00 02:00 11 P6 6F 3.50 03:00 11 P6 28 1.00 06:30 12:30 5430.0 14:30 5430,0 15:30 5430,0 17:00 5430,0 18:30 5430.0 19:30 5430.0 20:00 5430.0 21:00 5430.0 22:30 5430.0 23:00 5430.0 00:00 5430.0 00:30 4648.0 01:00 4648,0 02;00 4648.0 03;00 4648.0 06:30 4648,0 07:30 4648.0 FINISH TESTING BOPE. PULL 2-WAY Cl~ P/U HANGER 4', & ClRC OUT OIL POOH W/ESP WHILE L/D 2-7/8" TBG. CK ESP & MOTOR, L/D EACH. CLEAR FLOOR & CHANGE OVER TO 15', 500 TON. ATTEMPT TO PULL PACK-OFF, CHANGE OUT PACK-OFF RET TOOL, PULL PACK-OFF. R/U TRISTATE 7" CASING SPEAR W/ ESTENSION. R/U DRESSER ATLAS W/L UNIT & M/U APRS FREE POINT TOOL & RIH -- FREE POINT 7" ~ 2100' & 2700' (SHOWS FREE PIPE). RIH TO 3500' & FREE POINT 100' INCREMENTS WHILE POOH -- SHOWS STUCK PIPE. RECHECK FREE POINTS ~ 2100' & 2700' TO CK TOOL -- SHOWS STUCK PIPE. FREE POINT TOOL FAILURE -- POOH W/FREE POINT TOOL. CHANGE OUT SPRINGS & PADS ON FREE POINT TOOL. PERFORM SURFACE CK-- GOOD. RIH TO 2700' & ATTEMPT TO FREE POINT -- SHOWS STUCK PIPE. CHECK FREE POINT @ 2100' AND 1000' -- SHOWS STUCK PIPE. POOH FOR FAILED FREE POINT TOOL. ADJUST SPRINGS TO STIFFER SE-I-FING & CHANGE OUT JARS. PERFORM SURFACE TEST o- GOOD TEST. RIH TO 2700', 2000' & 1000' -- SHOWS STUCK PIPE. POOH W/FREE POINT TOOL & PULL 200K TO 260K (60K OVER) W/8.5" STRETCH. TALKED TO APRS, FELT THAT FP READING @ 2700' ON FIRST TOOL BEFORE FAILURE WAS GOOD & STRETCH TEST INDICATES FREE PIPE TO SHOE. R/D TRISTATE, APRS, & DRESSER ATLAS FREE POINT EQUIPMENT. INSTALL 7" PACKOFF & TEST TO 5000 PSIG. CHANGE TOP SET PIPE RAMS TO 3.5", RUN TEST PLUG & TEST DOOR SEALS TO 3000 PSIG. PULL TEST PLUG & RUN SHORT WEAR BUSHING. SLIP & CUT DRILL LINE. CHANGE OUT BAILS. MU EZSV & 3.5" WIPER DART CATCHER. RIH W/EZSV WHILE PU 3.5" DP. CHANGE OUT BAILS, SET EZSV @ 4752', & MU CMT HEAD. DISPLACE 9.5 PPG NaCl BRINE OUT OF HOLE W/8.4PPG LSND DRILLING FLUID. PUMP 32 BBLS H20, STING INTO EZSV, TEST CMT LINES TO 4500 PSIG, PUMP 10 BBLS H20 WHILE EST INJ RATES THROUGH PRE-PACK GP SCREENS. MIX & PUMP 78 BBLS (375 SXS) 15.8 PPG G CEMENT, DROP 3.5" WIPER DART & DISPLACE W/RIG PUMPS. PUMP 74 BBLS BELOW EZSV, UNSTING AND DUMP 4 BBLS (104') OF CEMENT ABOVE EZSV. POOH DRY 4 STDS & REVERSE CIRCULATE 60 BBLS. NOTE: Ca++ TRACES IN CLOSE ANNULAR AND TEST 7" CASING TO 1500 PSIG FOR 30 MINUTES -- BLED OFF 50 PSIG -- GOOD TEST, POOH W/3.5" DP & F_.ZSV SEFFING TOOL & WIPER PLUG CATCHER. MU 7" CSG CUTTER & RIH TO 2850'. LOCATE COLLAR @ 2866', PU TO 2836', & CUT CASING (100' BELOW 9-5/8" CSG SHOE), CLOSED BAG AND ATTEMPTED TO ESTABLISH CIRC FROM 7" CASING INTO 7"X9-5/8" ANNULUS THRU CUT -- UNSUCCESSFUL, PULL UP TO 2704' & MAKE CUT BELOW COLLAR @ 2700'. CLOSE HYDRIL, PRESSURE UP ON 7" CASING & MONITOR CORRESPONDING PRESSURE INCREASE ON 7"x9-5/8" ANNULUS -- COMMUNICATION ESTABLISHED. BLED OFF PRESSURE & MONITOR WELL -- DEAD, POOH W/7" CASING CUTTER, CHANGE TOP RAMS F/3,5" TO 5" AND INSTALL 7" RAMS INTO LOWER RAM BODY. PULL SHORT WEAR BUSHING, INSTALL TEST PLUG, & TEST RAM DOORS TO 3000 PSIG, BACK OUT LOCK DOWN PINS & PULL 7" PACK-OFF, FINISH PULLING 7" PACK-OFF, CHANGE OUT BAILS FOR LONG BAILS. STAB INTO 7" CSG W/SPEAR, GRAPPLE, & PACK-OFF, PUMP HI-VIS PILL & CIRC 2 CSG ANNULAR VOLUMES, RECIPROCATE PIPE 10' STROKES WHILE PUMPING 2ND BU. RU 7" CSG EQUIPMENT, POOH LiD 83 JTS 7" 26# L80 BTRC CSG + 1 5' CUT OFF PIECE. RD CSG PULLING EQUIPMENT & CLEAR FLOOR, CONOCO Detailed Activity Report 07/14/1993 11 P6 6F 3.00 07:30 10:30 11 P6 28 2.00 10:30 12:30 11 P6 45 0.50 12:30 13:00 11 P6 6F 1.50 13:00 14:30 11 P6 6F 1.50 14:30 16:00 11 P6 45 0,50 16:00 16:30 11 P6 6F 1.50 16:30 18:00 11 P6 28 1.00 18:00 19:00 11 P6 29C 0.50 19:00 19:30 11 P6 6F 1.50 19:30 21:00 11 P6 45 1.00 21:00 22:00 11 P6 6F 1.50 22:00 23:30 11 P6 28 0.50 23:30 00:00 11 P6 45 1.00 00:00 01:00 11 P6 45 0,50 01:00 01:30 11 P6 5 0.50 01:30 02:00 11 P6 6F 1.00 02:00 03:00 11 P6 28 1.50 03:00 04:30 11 P6 15A 1,00 04:30 05:30 11 P6 6F 1,00 05:30 06:30 11 P6 5 1.00 06:30 07:30 11 P6 6F 0.50 07:30 08:00 11 P6 45 1.00 08:00 09:00 11 0,00 09:00 09:00 11 P6 6F 1.50 09:00 10:30 11 P6 6F 1.50 10:30 12:00 11 P6 45 9.00 12:00 21:00 8 P2 2A 1.00 21:00 22:00 8 P2 2A 1.00 22:00 23:00 4648.0 4648.0 4648.0 4648.0 4648,0 4648.0 4648.0 4648.0 4648,0 4648.0 4648.0 4648.0 4648.0 4752.0 4752.0 4752.0 4752,0 4752,0 4752.0 4752.0 4752.0 4752.0 4752,0 4752.0 4752.0 4752.0 4752,0 2720,0 2729.0 2744.0 MU 7"' CSG SPEAR & GRAPPLE W/PACKOFF & RIH WHILE P/U 5", CHANGE OUT SAVER SUB AND STAB-IN GUIDE F/3,5" TO 5" ON TOP DRIVE, STING INTO 7"' LATCH FISH, PULL 220K (95K OVER PU) JARS HIT AND GRAPPLE RELEASED FROM FISH, ATTEMPTS TO LATCH FISH AGAIN FAILED, POOH W/FISHING ASSY (NO FISH), CHANGE OUT DAMAGED GRAPPLE. PACK-OFF DAMAGED ALSO, MU GRAPPLE W/O PACKOFF, RIH W/5" DP & LATCH FISH, RELY×ED JARS & PULLED ON FISH W/255K OVER TOP DRIVE & PU, REPEATED 5 TIMES -- NO MOVEMENT. COCKED JARS & P/U W/ lOOK OVER & 150K OVER -- SET OFF JARS BOTH TIMES -- NO MOVEMENT, PU W/200K OVER, SET OFF JARS, GRAPPLE UNLATCHED, ATTEMPTS TO LATCH FISH AGAIN FAILED, POOH W/FISHING ASSEMBLY -- GRAPPLE BROKEN -- LEFT HALF OF GRAPPLE IN HOLE, L/D SPEAR & MU 7"' CASING CUTTER ON 1 STAND OF 3,5" DRILL PIPE, STAND CASING CUTTER BACK & MU OVERSIZED 7"' CASING GRAPPLE & PACK OFF ON 5" DP, WAITING ON ORDERS. RIH W/7"' CASING CUTTER ON I STD OF 3,5" DRILL PIPE, SPACE OUT & MAKE CUT @ 2789' (60' BELOW THE 9-5/8" CSG SHOE). POOH W/7" CASING CUTTER, STAND BACK STD OF 3,5" DP W/CSG CUTTER, M/U 7" CASING SPEAR W/ OVERSIZE GRAPPLE AND PACKOFF, I.JD 7"' CSG CUTTER, P/U GRAPPLE, SPEAR, & RIH, STING INTO FISH & JAR LOOSE. CBU. POOH, L/D 7" CASING FISH. (1 JT 41.5', I CUT PIECE 50.4' W/PIN END, & 1 CUT PIECE 11,5' W/COLLAR, CHANGE BOTTOM RAMS F/7"' TO 3-1/2" & INSTALL WEAR BUSHING, RIH W/3-1/2" DP OPENENDED. CBU & SPOT HI VIS PILL F/3313'-3013'. POOH TO 3007'. TEST CEMENT LINES TO 2500 PSlG. PUMP 30 BBLS H20, PUMP 25 BBLS G CEMENT W/ADDITIVES, PUMP 3 BBLS H20, DROP 3.5" WIPER DART, PUMP 11 BBLS 8.6 PPG LSND MUD, CEMENT BLEND: CLASS G + 1.35%BW0C D013 + O.2%BWOC D046 + IO0%BWOC D053 + 0.8% BWOC D065. PERTINENT DEPTHS: CALC TOP OF CEMENT @ 2807', 9-5/8" CSG SHOE IS @ 2729'. TOP OF 7"' FISH IS @ 2789', CALC BOT OF CEMENT @ 3007'. POOH SLOWLY 7 STDS TO 2350' (PIPE PULLED DRY) & CBU -- NO SIGN OF CEMENT RETURNS @ BOTTOMS UP. POOH & CHANGE BAILS TO 10' 350 TON & CHANGE BOTTOM PIPE RAMS TO 5", P/U & STAND BACK DIRECTIONAL STEERING BHA, M/U & STAND BACK ENOUGH 5" TO DRILL TO TD WITH STDS, CONTINUE TO WAIT ON CEMENT TO DEVELOP 1000 PSIG COMPRESSIVE STRENGTH @ 40 DEGREE BOTTOM HOLE TEMPERATURE AS PER FIELD BLEND TEST. PUMP 5 BPM & ROTATE 30 RPM WHILE SLACKING OFF F/2400' TO 2720' -- NO HARD CEMENT. CBU & OBSERVE FOR CEMENT. GREEN CEMENT & BOTTOMS UP. PUMP @ 5 BPM W/30 RPM ROTARY F/2720' TO 2739' (10' OUT OF 9-5/8" SHOE). DID NOT TAKE ANY WEIGHT. PU INSIDE SHOE, TURN PUMPS AND ROTARY OFF. SLACK OFF TO 2744' (15' OUT OF SHOE). DID NOT TAKE WEIGHT. PU & SPACE BIT OUT OF SHOE 5' & CBU -- GREEN CEMENT AT BOTTOMS UP HAS CONSISTENCY OF FUDGE BUT NO HARDNESS. DISCUSS OPTIONS W/DRLG MANAGER -- DECISION MADE TO CUT TROUGH IN LOW SIDE OF HOLE AND UNDERCUT OLD HOLE 10' ABOVE THE 7" CSG STUB ALLOWING CEMENT ABOVE 7"' CSG STUB MORE TIME TO CURE. 1. CEMENT RETURNS INDICATE PLUG DID NOT FALL OUT INTO RATHOLE, 2, CONSULTED DS ABOUT CEMENT RECIPE TO GET GOOD SET AT 40 DEG. THEY SPENT 1 MO~J' 3N THIS BLEND CONOCO Detailed Activity Report 8 0.00 23:30 23:30 2744.0 8 0.00 23:30 23:30 2744.0 8 P2 2B 0.50 23:30 00:00 2744.0 07/15/1993 8 P2 2B 0,50 00:00 00:30 2779,0 8 P2 2B 8.50 00:30 09;00 4327.0 8 P2 6F 2.00 09:00 11:00 4327.0 8 P2 6F 2.00 11:00 13:00 4327.0 8 P2 2B 4.00 13:00 17:00 4850.0 8 P2 2B 8.00 17:00 01:00 5204.0 07/16/1993 07/17/1993 8 P2 2B 0.50 00:00 00:30 5234,0 8 P2 5 1.00 00:30 01:30 5234.0 8 P2 6C 2,50 01:30 04:00 5234.0 8 P2 28 2.00 04:00 06:00 5234.0 8 P2 6B 2.50 06:00 08:30 5234.0 8 P2 5 2.50 08:30 11:00 5234.0 8 P2 6F 4.50 11:00 15:30 5234.0 8 P4 24 1.50 15:30 17:00 5234.0 8 P4 28 1.00 17:00 18:00 5234.0 8 P4 13A 5,00 18:00 23:00 5234.0 8 P4 5 0.50 23:00 23:30 5234.0 8 P4 13A 0.50 23:30 00:00 5234.0 8 P4 13A 2.00 00:00 02:00 5234.0 8 P4 28 1.50 02:00 03:30 5234.0 8 P4 5 3.50 03:30 07:00 5234.0 8 P4 5 0.50 07:00 07:30 5234.0 AND REALLY DIDN'T HAVE ANY OTHER TIMELY RECOMMENDATIONS ON ALTERING THIS BLEND OR COMING UP WITH A DIFFERENT ONE. ARTIC SET SET CEMENTS ACHIEVE 800 PSIG COMPRESSIVE STRENGTHS; HOWEVER, THEY REQUIRE 48 TO 72 HRS TO DO SO. 3, WHEN RUNNING CASING INTO THE SIDETRACK HOLE, THE WEIGHT OF THE PIPE 7" SHOE JT AND ECP SHOULD CAUSE THE PIPE TO FALL INTO THE UNDERCUT SIDETRACK INSTEAD OF TRACING THE OLD HOLE TO THE 7" CASING STUB. ORIENT TOOL FACE DOWN & RECIPROCATE F/2734'-2779' WHILE PUMPING W/NO ROTARY. PREPARE TO SIDETRACK WELL. CIRC & WORK PIPE WHILE CUTTING TROUGH TO UNDERCUT SIDETRACK HOLE UNDER 7" CSG STUB FISH, SIDETRACK HOLE WHILE DRLG F/2779'-2820', PULL UP TO 2729' (7" CSG STUB @ 2789') & RUN INTO 2820' WITH PUMPS ON -- SMOOTH, NO PROBLEM. SHUT PUMPS OFF, PULL UP TO 2779' & RIH TO 2820'-- NO PROBLEM. SIDETRACK SUCCESSFUL, DRLG F/2820'-4327'. CBU & PUMP DRY JOB. SHORT TRIP TO 9-5/8" CSG SHOE @ 2729', HOLE SWABBING -- PUMP OUT OF HOLE FROM 3950'-2909'. CLEAN FLOOR, RIH WIPE TIGHT SPOT @ 4043' AFTER STACKING UP W/5OK, TIGHT SPOT WIPED OUT, DRLG F/4327'-4850', CONTROL DRLG @ 60 FPH F/4850'-5204', NOTE: THE POROSITY TOOLS ARE READING HIGH VALUES DUE TO HOLE WASHOUT AS WAS EXPERIENCED ON THE L-12 LOGS, WILL POOH ON WIPE TRIP AND LD MOTOR, PREPARED TO RELOG THE SCHRADER BLUFF WITH POROSITY TOOLS @ 60 FPH -- CONTINGENT UPON APPROVAL F/ CONOCO ANCHORAGE, CONTROL DRLG F~' -- TD OF 8.5" HOLE SECTION.~"'5"Z~''' PUMP HI-VIS PILL, CBU, & PUMP DRY JOB. POOH -- NO HOLE PROBLEMS (SLM -- NO CORR). DOWNLOAD MWD TOOL DATA, L/D MOTOR, M/U NBSTAB, & MILLTOOTH BIT, RIH TO TD @ 5234' -- NO HOLE PROBLEMS & NO FILL. ClRC & COND MUD FOR RUNNING CASING -- PUMP DRY JOB, POOH LiD DRILL PIPE & BHA, PULL WEAR BUSHING, INSTALL TEST PLUG, CHANGE TOP SET OF RAMS TO 7", AND TEST DOOR SEALS TO 2000 PSIG, RU CASERS & HELD PRE-JOB SAFETY & OPERATIONAL MEETING. RIH W/63 JTS OF 7" 26# L80 BTRC CSG TO 9-5/8" CSG SHOE -- ADJUSTED RUNNING SPEED ACCORDING TO ACTUAL DISPLACEMENT. NOTE: BAKER LOCKED & TACK WELDED ALL CONNECTIONS F/FLOAT SHOE TO PIN OF CSG JT #2. TACK WELD PINS OF JT#2 & JT#3 IN COLLAR OF JT#2. M/U TIW VALVE & HEAD PIN, CBU, B/O TIW VALVE & HEAD PIN. RIH SLOWLY W/JTS 84, 65, & 66 TO ENSURE CSG FALLS INTO UNDERCUT SIDETRACK HOLE -- SEEN NO INDICATION OF 7" CASING STUB FISH, CONTINUE TO RIH W/ 7" CSG. FINISH RIH W/113 JTS. OF 7" 26# L80 BTRC CSG. MU CEMENTING HEAD, PRESSURE TEST TO 4000 PSIG, & CIRC 200 BBLS, PUMP ES CEMENTER WIPER DART & BUMP UP BAFFLE COLLAR W/RIG PUMP. PRESS UP & HELD PRESS AT 800, 1200, 1600, 2000 PSIG STAGES, SHEARED ECP OPEN AT 2200 PSIG & SWITCH OVER TO DOWELL & INFLATE ECP (EXTERNAL CSG PKR), DETECTED LEAK AFTER ECP INFLATED -- WOULD NOT HOLD PRESSURE. CALLED DRLG MANAGER, DISCUSSED OPTIONS, DECISION MADE TO PROCEED W/CMT JOB, PRESSURE UP TO 2750 W/RIG PUMPS & SHEAR HOS OPEN, ClRC 100 BBLS & PUMP 30 BBLS 10,8 PPG SEPEOLITE SPACER. CONOCO Detailed Activity Report 8 P4 12A 1.00 07:30 08:30 5234,0 07/18/1993 8 P4 15B 8 P4 28 8 P2 10 8 'P2 28 10 P6 28 10 P6 15A 10 P6 6C 10 P6 9 10 P6 6F 11 P6 6F 11 P6 2A 11 P6 6F 11 P6 5 0.50 08:30 09:00 5234.0 0.50 09:00 09:30 5234.0 4.00 09:30 13:30 5234.0 1.00 13:30 14:30 5234.0 1,50 14;30 16:00 5234.0 3.00 16:00 19:00 5234.0 0.50 19:00 19:30 5234.0 1.00 19:30 20:30 5234.0 3.50 20:30 00:00 5234.0 0.50 00:00 00:30 5234.0 3.50 00:30 04:00 5234.0 0,50 04:00 04:30 5234.0 1.50 04:30 06:00 5234.0 P6 P6 45 3.50 06:00 09:30 5234.0 2.00 09:30 11:30 5234.0 11 P6 5 11 P6 5 11 P6 6F 11 P6 6C 11 P6 6F 11 P6 5 11 P6 6F 0.50 11:30 12:00 5234.0 2.50 12:00 14:30 5234.0 2.00 14:30 16:30 5234.0 1.00 16:30 17:30 5234.0 2.50 17:30 20:00 5234.0 0.50 20:00 20:30 5234.0 1.50 20:30 22:00 5234.0 11 P6 5 11 P6 3B 0.50 22:00 22:30 5234.0 1.50 22:30 00:00 5234.0 00:00 09:00 5234.0 11 P6 5 1.50 09:00 10:30 5234.0 11 P6 5 3.50 10:30 14:00 5234.0 11 P6 6F 2.00 14:00 16:00 5234.0 11 P6 45 4.00 16:00 20:00 5234.0 PUMP 60 BBLS H20 SPACER, MIX & PUMP 30.2 BBLS OF 15.8 PPG CLASS G CEMENT W/ O.5%D156+O.5%DO65+O.2%D046+1.0%S1. PUMP 2 BBLS H20, DISPLACE & BUMP CLOSING PLUG W/2500 PSlG. HELD PRESSURE 3 MINUTES -- NO LEAKS DETECTED. TEST CASING TO 2000 PSIG F/30 MINUTES -- 50 PSIG LEAK OFF. R/D CEMENTERS & CASERS EQUIPMENT. CLEAR FLOOR. R/U SCHLUMBERGER & RUN GYRO SURVEY F/ 4600' TO SURFACE. B/O & L/D LANDING JT., INSTALL PACK-OFF, & TEST SEALS TO 5000 PSIG. CHANGE SAVER SUB & PIPE GUIDE ON TOP DRIVE F/5" TO 3.5". CHANGE TOP PIPE RAMS F/7" TO 3.5". INSTALL WEAR RING & PERFORM WEEKLY BOPE TEST -- WAIVED BY LOU W/AOGCC. STRAP & M/U 4-3/4" BHA. CUT & SLIP 105' OF DRILL LINE. RIH W/6.125" BIT & SCRAPERS ON 3.5" DRILL PIPE. (WET GOING IN W/SCRAPERS.) RIH W/BIT & TANDEM SCRAPERS ON 3.5" DP. TAG IS DV TOOL @ 4817'. DRLG ES CEMENTER DV TOOL, PLUG CATCHER, & FLOAT SHOE. RIH TO 5234 (TD). CBU & PUMP 20 BBL HI-VIS HEC SWEEP (ADDED BREAKER -- J-134 DOWELL @ 10#/1000 GALLONS) & DISPLACE LSND DRILLING FLUID FROM THE HOLE W/9.0 PPG CLEAR FILTERED (10 MICRON) BRINE. PULL UP INTO 7" CASING SHOE @ 4870', CLEAN #7 PIT, POSSUM BELLIES, UNDER SHAKERS, & TROUGH. PUMP 25 BBL HI-VIS HEC SWEEP, 50 BBLS DIRT MAGNET CASING WASH, 25 BBLS HI-VIS HEC SWEEP. GAS CUT BRINE & OIL TO SURFACE WITH BOTTOMS UP. CLOSE IN ON ANNULAR PREVENTER & CIRCULATE OIL & GAS CUT MUD THROUGH CHOKE LINE & GAS BUSTER. OPEN ANNULAR & ClRC & COND BRINE. ClRC & FILTER BRINE. POOH W/BIT & SCRAPERS. M/U DB UNDERREAMER, JARS, & STAB -- 10 DCs, RIH TO 4635', CIRC OIL & GAS CUT BRINE, SHUT IN ANNULAR & CIRC THRU CHOKE & GAS BUSTER, FINISH RUNNING IN HOLE, UR BLADES HANGING UP IN LAST 100' OF CASING & THEN AGAIN THROUGHOUT OPEN HOLE INTERVAL, ClRC OUT OILLY BRINE AND SEPARATE F/ ACTIVE SYSTEM, UNDERREAMING F/5234'-5209', PLUGGING UP FILTERS ON DE -- EVALUATE OPTIONS IN PIT TO SEPARATE SOLIDS OUT OF BRINE, UNDERREAMED THE 8.5" HOLE W/12" "DB" UNDEREAMER (TRISTATE), UR F/5229' UP TO 7" CASING SHOE @ 4870', PUMPED 5 BPM W/1375 PSIG, 270-290 AMPS TORQUE, 80 RPM ROTARY, PU 2-3K, UR THE WHOLE INTERVAL W/NO PROBLEMS UNTIL 4895' -- AT THIS DEPTH THE TOP DRIVE TORQUE DRIVE TORQUED UP AND STALLED OUT, RESTARED UR OPERATION & FINISHED UR TO 7" CASING SHOE W/NO PROBLEMS. FILTER SUFFICIENT QUANTITY OF BRINE. PULL UP 20 FOOT INTO CASING SHOE & PUMP 20 BBL HI-VIS SWEEP AT 3 BPM -- SPOT OUTSIDE OF DP. RIH TO 4872' W/DP UR OUTSIDE OF CASING & PUMP SWEEP TO SURFACE @ 5 BPM (189 AV). OBSERVED PILL RETURN AT SURFACE -- CLEAN (CONCLUSION: NO CUTTINGS BED ON LOW SIDE OF HOLE.) ClRC HOLE WHILE WEIGHTING UP F/9.0 PPG TO 9.2 PPG. POOH W/DB UNDERREAMER TOOL (TRISTATE) -- MISSING ONE BLADE. R/U SCHLUMBERGER TO RUN BGT/GR (4-ARM CALIPER): RUN I -- RIH & TAG UP @ 4886' (OA SANDS). RUN 2 -- REPLACE METAL GUIDE W/HOLE FINDER. RIH & TAG UP @ 4886' AGAIN. POOH W/SCHLUMBER & R/D OUT OF WAY -- STANDBY. CONOCO Detailed Activity Report 11 P6 07/20/1993 11 P6 11 P6 07/21/1993 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 07/22/1993 P6 P6 P8 P8 P8 P8 P8 P8 P8 P8 P8 P8 P8 P8 P8 P8 P9 P9 P9 P9 P9 P9 P9 P9 P9 P9 P9 6F 4.00 20:00 00:00 5234.0 6F 1.00 00:00 01:00 5234.0 45 3.00 01:00 04:00 5234.0 45 1.50 04:00 05:30 5234,0 6C 1,00 05:30 06:30 5234.0 13D 7.50 06:30 14:00 5234.0 5 1,00 14:00 15:00 5234.0 13D 6.50 15:00 21:30 5234.0 32B 1.00 21:30 22:30 5234.0 45 0.50 22:30 23:00 5234,0 15E 1.00 23:00 00:00 5234.0 45 0.50 00:00 00:30 5234.0 32D 1.00 00:30 01:30 5234.0 329 ~!~5~ ~ ~0~0~ ".'~ 5234.0 32D 0.50 03:00 03:30 5234,0 28 6F 28 6C 24 28 45 28 13A 13A 28 28 28 1,00 03:30 04:30 5234.0 3.00 04:30 07:30 5234.0 1.50 07:30 09:00 5234.0 1.00 09:00 10:00 5234.0 1.50 10:00 11:30 5234.0 2.00 11:30 13:30 5234.0 0.50 13:30 14:00 5234.0 2,50 14:00 16:30 5234.0 6,50 16:30 23:00 5234.0 1.00 23:00 00:00 5234,0 2.00 00:00 02:00 5234,0 1.00 02:00 03:00 5234.0 1.50 03:00 04:30 5234.0 14A 6,50 04:30 11:00 5234.0 15F 14C 0.50 11:00 11:30 5234.0 3.00 11:30 14:30 5234.0 M/U 6" BIT & RIH TO 5229' -- THIS IS DEPTH UNDERREAMING OPERATION BEGAN AT. SEEN BOPPLES OF 2-4K STACK WHILE RIH W/ THE LAST JOINT OF STAND #48 AND STAND #49 -- WIPED HOLE W/EACH. NO OTHER PROBLEMS, PULL OUT OF OPENHOLE INTO 7" CASING @ 4870' WITH NO PROBLEMS. POOH W/6" BIT, R/U SCHLUMBERGER: RUN 3 -- RIH & TAG UP @ 4916', P/U WITHOUT EXTENDING 4-ARM CALIPER ARMS. SET DOWN @ 4886' -- UNABLE TO ADVANCE. POOH. RUN 4 -- ADD WEIGHT BAR TO GCT/GR. RIH & SET DOWN AT 4886' -- POOH AFTER FAILING TO ADVANCE TOOL. RUN 5 -- REMOVE CENTRALIZER F/TOOL TO MAKE TOOL SLICK. RIH & TAG @ 4886' -- UNABLE TO ADVANCE -- POOH & R/D SCHLUMBERGER. RIH W/4-3/4" DC, POOH WHILE L/D SAME. M/U GRAVEL PACK ASSEMBLY, RUN WASH PIPE INTO SAME, & M/U SC-1LR PACKER. CLEAR FLOOR OF HANDLING EQUIPMENT, CIRC OUT OIL & GAS CUT BRINE. RIH W/GP ASSY, BREAK CIRC & CIRCULATE OUT OIL & GAS CUT BRINE.EVERY 1000' WHILE RIH TO 5227'. R/U TREATING MANIFOLD, BAKER & DOWELL LINES & EQUIPMENT, DROP BALL TO SET PACKER. HOLD PRE-JOB SAFETY & OPERATIONAL MEETING. SET BAKER SC-ILR PACKER W/RIG PUMPS & TEST BACKSIDE TO 1500 PSIG - PACKER SET & HOLDING. PULL & SHEAR SEAL ASSY. HELD SAFETY AND OPERATIONAL MEETING WITH NEW CREW AFTER TOUR CHANGE. PICKLE 3-1/2" DP W/DS AND REVERSE OUT 2 DP VOLUMES W/RIG. PERFORM GRAVEL PACK TREATMENT W/ DOWELL: 68 BBLS SLURRY @ 2 PPG GRAVEL. 22 BBLS SLURRY @ 2.5 PPG GRAVEL. 171 BBLS SLURRY @ 3.0 PPG GRAVEL. OPERATIONAL NOTES: SCREEN OUT PRESSURE 2160 PSI. FINAL TREATING PRESSURE 622 PSIG. 22433# GRAVEL PLACED BEHIND SCREEN. CALCULATED AVE HOLE SIZE IS 11,6", REVERSE OUT TWO DP VOLUMES AND ATI'EMPT TO ESTABLISH INJECTION IN TREATING POSITION, PRESSURED UP TO 1300 PSIG W/ NO INJECTION -- SCREEN OUT CONFIRMED, R/D GRAVEL PACK EQUIPMENT, REINSTALL 3-1/2" PIPE GUIDE ON TOP DRIVE, POOH L/D 3-1/2" DP, FINISH L/D GP TOOLS & CLEAR RIG FLOOR, RIH W/9 DC & POOH L/D, CHANGE TOP RAMS F/3-1/2" TO 2-7/8", PULL WEAR BUSHING, RUN TEST PLUG, & TEST RAM DOORS TO 2000 PSIG, CLEAR RIG FLOOR, LOAD ESP PUMP BOXES INTO PIPE SHED. UNLOAD ESP EQUIPMENT, R/U CABLE SPOOLER & 54" SHEAVE. HOLD PRE-JOB SAFETY * ESP RUNNING MEETING, MAKE UP MOTOR, TANDEM SEAL SECTION, PUMP AND TEST ALL OILS, ROTATION, AND ELECTRICAL HOOKUP OF CABLE. RIH W/ESP ON 141 J'rS. OF 2-7/8", 6.5#, L80, 8RD EUE. CHECK CONDUCTIVITY EVERY 1000 FT. M/U TBG HANGER, LANDING JT, & PREPARE FOR SPLICE, MAKE SPLICE @ IN CONTROL LINE @ FOR PIGTAIL BELOW TBG HANGER, B/O 3'PUP IN HANGER AND CHANGE OUT FOR 2' PUP -- SPLICE WAS ABOUT 2" SHORT. M/U PIGTAIL TO PENETRATOR IN TBG HANGER, PERFORM CONDUCTIVITY TEST, LAND TBG HANGER, B/O LANDING JT., CLEAR ESP & TUBING RUNNING EQUIP F/RIG FLOOR, N/D FLOWLINE, REMOVE BOP RAMS F/RAM BODIES, N/D BOPE, REMOVE ALL BOPE F/ SUBSTRUCTURE, TEST PENETRATOR FOR CONDUCTIVITY, N/U TREE & TEST TO 5000 PSIG. BREAK OUT TREE FROM TBG ADAPTER FLANGE & ROTATE 180 DEGREES TO ORIENT ESP PENETRATOR AND PRODUCTION LINE TO FLOWLINE SIDE OF PAD -- COMPLIMENTS OTHER WELLS ON PAD. CONOCO Detailed Activity Report 11 P9 45 1.50 14:30 16:00 5234.0 11 P9 45 1.00 16:00 17:00 5234.0 11 P9 45 1.00 17:00 18:00 5234,0 13 PIB 45 0.00 18:00 18:00 5234,0 07/23/1993 13 A1B 29C 24,00 00:00 00:00 0,0 13 0.00 00:0o oo:o0 o.o FZ PROTECT WELL -- PUMP 60 BBLS DIESEL DOWN 2-7/8"X7" PRODUCTION ANNULUS WHILE TAKING RETURNS UP TBG THRU EMPTY POCKET IN 1" GLM, SWAP LINES & PUMP 12 BBLS DIESEL DOWN 2-7/8" PRODUCTION TBG WHILE TAKING RETURNS UP 2-7/8"XT' PRODUCTION ANNULUS, R/D LINES, INSTALL TREE CAP, CLEAN UP CELLAR, DISPOSE OF ALL PIT FLUIDS DOWN 7"X9-5/8" INJECTION ANNULUS, CONTINUE CLEANING PITS, CONTINUE CLEANING PITS -- RELEASED RIG F/AFE 1509 AND G-SA WELL @ 1800 HRS ON 7/22/93. NOTE: NABORS IS CLEANING & PAINTING SUBSTRUCTURE WHILE PENDING BP CONTRACT W/RIG, THIS COULD SAVE CONOCO A DEMOB CHARGE TO J-PAD, CONTINUE CLEANING PITS -- COMPENSATION MADE FOR EXTRA TIME TO N/D BOPE IN REGARD TO THE 1800 HR RIG RELEASE, NABORS iS WAITING WITH RIG OVER THE G-8A WELL PENDING BP DECISION WHETHER OR NOT TO CONTRACT RIG. ON SATURDAY, 22E WILL EITHER MOVE TO PRUDHOE OR STACK OF THE J/G DEEP CONDUCTOR IN PREPARATION FOR NEXT YEARS DRILLING. NOTE: 1. BPV INSTALLED IN G-8A WELLHEAD. 2. EMPTY POCKET IN 1" GLM @ 4412' RKB. l[ [ I I I I [ [ L Il II[llll[ l[ Illlll l[ [ Illll I Ill [ I Il [ I [ Il Ill [ I 11 I I I I 111 I Il I Illll ...... SURVEY CALCULATION AND FIELD WORKSHEET oob No, 0450-01239 Sidetrack No. Page 1 of ! :t Company CONOCO, ,NC. ~ ...... Rig Contractor & No, _N_ab___o_r~ _A_.k .D_ri_lli~n_g.._- _I/_2_2_-_E- Field MILNE POINT UNIT ~rrL/~ Well.Name.& No. __P_A._.D_~_8~R___D,,,,,, ,,, ................. , ,,,,, ~~"~'='"'~--L ~', ~ '~ ,~ , ................ Survey, Section,,,, ,,Name TELECO, , MWD, ,, BHI Rep. M ROSS / TOMAYER / FOSTER Target TVD (FT) Target Coord~. 0,000 Depths Measured From: RKB ~ MSLE~ ssE]! Target Description Target Coord.~ ~ Slot Coord. E/W -3459,00 Magn. Declination 29,160 Calculation Method MINIMUM CURVATURE Target Direction (D~) Build\Walk\DL per: lOOft[~ 30m[~ lOm[~I Vert, Sec. Azim. 336.86 Magn. to Map Corr, 29.160 Map North to: OTHER ................................. S01:IVEY DATA ................................. Date Toot I Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Depth Angle Direction Length TVD , Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment ..... _Typ~ .L, (F~ ,([%)) (~o) (F'r) ~ ,(F'r) i (FT) (Ff') (_P~!.,~O0 Fr) Drop (-) Left (-) I MWD 2729.00 48,09 337.99 2363.37 1098.58 1002.30 -448.30 TiE IN POINT 14-JUL-93. _ _ ............... M~!~_] 3117,00 49.90 334.00 388.00 2617.99 . 1390,48 1269.61 I -567.50~ ...... 0.90 I 0.47 -t,03 6 3/4~ MlC 1 Deg AKO 14-JUL-93 MWD t 3211.00 50.50 336.80 94.00 2678.17 1462.66 1335.26 -597.55 2.38 0,64 2.98 14-JUL-93 MWD / 3306.00 49.70 335.70 95.00 2739.11 1535.54 1401.97 -626.90 1.22 -0.84 -1.16 '~4-JUL~93I' MWD 3400.00 49.00 337,10 94.00 2800.35 1606.85 1467.32 -655.45 1.35 -0.74 1.49 14-JUL-93 M 3589.00 46.50 336.40 93.00 2927.57' ' 1' 746.59 15951 -1,18 -0.75 14-JUL-93 'i MWD / 3780.00 46.40 339.60 96.00 3059.36 1884.80 1724,15 -761.76 1.06 0.10 1.46 ..... 14-JUL-93! MWDt' 3968.00 46.10 339.90 92.00 3189.89 2019.95 1850.86 -809.20 0.64 0.33 0.76 14-JUL-ga ii MWD 14063,00 41.70 I 340.30 95.00 '- 3258.32 2085,70 1912.78 I -831.63 - '4.64t -4.63 0.42 ,x~h'~:'- J {39.60 339.20 Iii 94.0095.003329'00t 2147,58 1971,06 j-852.72 1.00I -0.96I -0.42 14-JUL-93 . MWD 4157.00 40.80 339.90 14-JUL-93 : MWD i 4252.00 i 3401.56 2208.83 2028.51 -874.14 1.35 ; -1.26 -0.74 14-JUL-93i; MWD i,, 4347.00 I 35.30 i 336.40 ti 95.00 3476.96 It 2266.56 2082.00 [ -895.89 4.87 i -4.53 I -2.95 14-JUL-ga MWD [ 4538.00 27,70 it 339.60] 96.00 3640.32 i 2365.24 2173.15, -933.70 3.47 -3,23 [ 2.60 14-JUL-03 i MWD i 4726.00 19.20 341.70 94.00 3812.48 2440.21 2243.90 -958.92 4.82 -4.79 1.49 14-JUL-93I MWD t 4821.00 14.00 339.60 95.00 3903.49 2467.27 2269.52 I -967.84 5.51 I -5.47 -2.21 14-JUL-93 !' MWD 4912.00 12,30 335.70 91.00 3992.101 2487.96 2288.68 I -975.66 2.11 -1.87 -4.28 14-BUI..-~3 ! MWD S006.00 ~1.90 334.70 94.00 4084.01 2507,66 2306.56 I -~83.~3 0.48I -0.42 I -1.0~ ~: [11~~: ] Company CONOCO, INC. Rig Contractor & No. Nabors Ak Drilling- #22-E Field M!L..NE pOINT UNIT . Well Name & No. PAD G/8RD Survey Section Name TELECO MWD BHI Rep. M ROSS / TOMAYER / FOSTER INTE iiii i iii iiii i ii ii i ii ii i i i ii i ii J; WELL DATA Target TVD (~T) Target Coord. N/S Slot Coord. N/S -3176.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS["] Target Description Target Coord. E/W Slot Coord. E/W -3459.00 Magn. Declination 29.160 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Watk\DL per: 10Oft[~ 30m[~ 10m~ Vert. Sec. Azim. 336.86 Magn. to Map Corr. 29.160 Map North to: OTHER .... .... ' .................... SuRvE~ DATA ................ Survey I q ....... 'I' ,"-'-~,~,-~-- ~,,,, i r, ...... ' ..... ' Total Coordinate ....... Build Rate Walk Rate - .~,~ ,.~,,~. ~ .~, ~ ~ v,.,,~,~ verzlCal -- ................ Date ~Tool ~ Depth t Angle I Direction : Length TVD Section N(+) / S(-)-T E(+) / W(-) DL Budd (,+,) Rlght (+) Comment /ype i (FT) I pO) ~_j (aC) i (VT) (FT) (F'r) i (FT) (P~r mO FT~ Drop [-} Left (-) .................... t ........................................................................... ~- .......................... 14-JUL-931 MWDI 5234.00 110.70! 337.90T 80.00 4307.47 2552.89 2347.88! -1002.36 0.83 -0.75 1.87 i ProjectedData-NOSURVEY I ...................... .............................. .... ................. ....... .... ! ...... ! ......... ~ _ ~ .............. [ ................ ~!_ ~.~ .... ~_.~ .... .:i,~'~. ..... , ...... ~ ............... f ...... ~- ......... i ....................................................... i . I __ ,,,,,! i i ii i i i i i i ! i i i i DEFAULT GCT-A .002 Input DLIS FIELD 17-JUL-1993 02:00 39910.5 FT DEFAULT GCT-A .007 Output DLIS Files FIELD 17-JUL-1993 03:18 40000.0 FT 39910,5 FT i OP System Version: 5C0-423 )epth (GDEP) (ET) 4600.033 4600.000 4500.000 4400.000 4300.000 4200.000 4100.000 4000.000 3900.000 3800.000 3700.000 36OO.0OO 3500.000 3400.000 3300.000 3200.000 3100.000 3000.000 2900.000 2800.000 2700.000 2600.000 2500.000 2400.000 2300.000 2200.000 2100.000 2000.000 1900.000 1800.000 1700.000 1600.000 1500.000 1400.000 1300.000 1200.000 1100.000 1000.000 900.000 800.000 700.000 600.000 500.000 400.000 300.000 200.000 100.000 -0.033 epth (GDEP)I North departure (ND) (FT) 2184.54 2184.52 2142.80 2096.74 2045.78 1988.21 1927.48 1865.27 1799.08 1732.20 1664.91 1598.09 1531.47 1463.52 1395.18 1325.90 1256.98 1188.47 1120.79 1055.90 989.88 921.62 854.70 789.34 724.74 660.47 597.57 536.87 476.94 417.25 361.99 311.20 262.14 214.70 171.62 134.36 102.53 75.44 53.98 36.42 21.76 10.43 3.83 0,86 0.28 0.12 0.00 0.00, North departure East departure (ED) (FT) -973.31 -973.30 -956.66 -936.81 -913.92 -890.16 -866.13 -842.05 -815.95 -789.28 -762.37 -734.14 -704.99 -673.70 -641.68 -607.77 -573.34 -539.34 -506.00 -474.69 -445.88 -417.42 -389.07 -360.77 -332.26 -303.87 -275.83 -248.67 -221.84 -194.95 -169.68 -146.62 -124.15 -102.52 -82.25 -64.21 -48.69 -35.17 -24.31 -I5.52 -8.41 -3.16 -0.20 0.69 0.60 0.26 -0.16 0.00 East departure True Vertical Depth (TVD) (ET) 3640.88 3640.85 3551.54 3465.04 3382.14 3303.93 3228.21 3153.72 3083.46 3014.07 2945.16 2876.33 2807.69 2741.35 2675.74 2612.10 2548.34 2483.93 2418.30 2348.97 2279.63 2212.32 2143.63 2073.44 2002.63 1931.48 1858.98 1784.30 1708.87 1633.28 Section ! (CWEL) borehole borehole (VSEC) / (D/HF) I (AZ]M) (DEVl) (Fl') IDEG) 239~1.55 2.34 ' 337'.63 (D5~).08 1553.90 1470.90 1386.72 1301.40 1213.47 1122.47 1028.96 933.67 836.62 738.57 639.91 540.70 440.98 341.03 241.03 141.03 41.03 -59.00 True Vertical 2391.54 2346.63 2296.41 2240.58 2178.32 2113.12 2046.39 1975.43 1903.46 1831.06 1758.54 1685.82 1611.03 1535.54 1458.49 1381.53 1305.10 1229.78 1157.68 1085,59 1011~731' 939.08 867.86>~ 797,23~ 726~99 658.12 591 ,525,94 · 460.52 ~399'~85 343.94 289.98 237.86 190.39 148.95 113.55 83.35 59.22 39.58 23.31 10.82 3.58 0.51 0.01 0.01 0.07 0.00 Vertical Section 3.04 337.63 25,06 3,49 337.86 28.89 2,89 335.66 31.77 2.44 336.67 36.56 1.68 338.29 40.40 1.64 338.44 40.86 0.95 338.98 43.73 0.66 338.33 46.04 1.14 338.13 46.35 1.21 338.26 46.45 1.42 336.34 46.61 1.28 336.35 46.90 1.01 334.97 49.13 1.13 334.35 49.35 1.02 333.56 50.69 1.05 333.42 50.07 1.07 333.89 49.73 1.90 334.00 47.69 1.54 334.37 45.13 0.93 337.44 47.44 0.75 337.24 47.33 0.80 336.78 45.91 1.02 336.34 45.04 1.07 336.16 44.82 1.32 336.08 44.42 1.99 335.89 42.71 2.13 335.92 40.78 2.41 335.88 41.18 2.13 335.50 39.83 1.91 335.53 34.94 2.61 335.46 33.63 3.14 335.51 31.97 3.53 335.26 30.10 3.44 334.38 26.50 3.03 334.13 22.45 2.60 333.77 19.28 2.00 333.32 15.74 1.51 333.27 12.37 1.19 333.51 10.32 2.63 334.81 8.30 2.54 335.16 5.84 1.52 340.33 2.62 0,56 353,57 0.88 0.18 32.89 0.13 0.29 74.58 0.30 0.77 80.42 0.10 0.00 283.25 0.60 Nell Azimuth of I Deviation of curvature /,..~,=, · borehole[ borehole 6324/6116 Nielson Way Anchorage, AK 99518 907-563-3269 Fax: 907-563-5865 907-562-2646 Fax: 907-561-1358 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Atto: Larry Grant Well Reference Data: Well No: MPU G8-RD Field: Schrader Bluff County: North Slope State: Alaska Date: 14 September 1993 AP1 No: 50-029-2214101 BH-INTEQ No: 1239 Enclosed is the following data as listed below: 1 - LIS Data Tape ~ 1 - LIS Verification Listing RECEIVED SEP 2 0 199,3 Alaska Oil & Gas Cons. Commission Anchorage Upon receipt, please sign and return to Baker Hughes INTEQ 6116 Nielson Way Anchorage, AK 99518 ~ /~ Atto: Tom Brockway 6324/6116 Nielson Way Anchorage, AK 99518 907-56Y3269 Fax: 907-563-5865 907-562-2646 Fax: 907-561-t358 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Atto: Larry Grant Well Reference Data: 1~ Well No: MPU G8- Field: Schrader Bluff County: North Slope State: Alaska Date: 28 August 1993 AP1 No: 50-029-2214101 BH-INTEQ No: 1239 Enclosed is the following data as listed below: Log Type DPRI~50, 1 BDF~R l TOTALS: 4 M~_easured..Dep~ Logs Bluelines Folded Sepias ~r~ r~ 1 5 J' l ,~1-~~' 1 Rolled Sepias Mylar Film 0 &"T&q-. ~20 i0 0 t~ 0 0 0 0 0 4 0 0 Log Type Bluelines True ertical Depth Logs Folded Sepias Rolled Sepias Mylar Film -I',~J::, 1 Cd 1 1 1 TOTALS: 4 4 0 o 0 0 0 0 0 o o Upon receipt, please sign and return to Received By: _/~. ~.~,_~~ ; ; Baker Hughes INTEQ 6116 Nielson Way Anchorage, AK 99518 Atto: Tom Brockway Date: SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2 ! 75 PLEASE REPLY TO JUL 2 SCHLUMBERGER WELL SERVICES Pouch 340069 ?rudhoe Bay, AK 99734-0069 Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention' Linda Starr Gentlemen' Enclosed ore 3 B_L_Lprintsof the Company Conoco, Inc. BGT, Run 1, 7/20/93 GCT, Run 1, 7/17/93 Well Milne Point Unit G-SA Field Milne Point Additional prints are being sent to: 1 BL prints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 PT County North Slope State Alaska 1 BL prints , 1 RF Sepia Chevron U.S.A. 11111 South Wilcrest. Houston, TX 77099 ~: Larry Sydora 713/561-3674 1BL prints Conoco, Inc. _lOOQ..South ~e Ponca CitMt OK 74603 Attn: Janet Webb, 1030 EB 1BL prints , 1RF Sepia OXY U.S.A., Inc. fa_i)_e~ta Driva, S-ire 600? Midland, TX 79705 Attn: John Carrol 915/685-5898 _~ka Oil & Gas Conservat~xon ~-CommiSsi0n-~-. I 3001 porcupine Drive ~ttn: Larry Grant __ p~i-n t s The film is returned to Conoco, Linda Starr We appreciate the privilege of serving you. __prints prints ~L~I-m v ~ Very truly yours, SCHLUMBERGER WELL SERVICES OH/CH (Il BL/3RF) _Ra_Y_mp_n_d_N_: _Pig_k_e~ s al .~T~ ItT M A NAOI[I~ Conoco Inc, 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 May 4, 1993 Mr. Mike Mender Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Response to Question About MPU G-8 Completion Milne Point Unit, North Slope Borough, Alaska Dear Mr. Mender: As per our conversation on April 29, 1993, following is a written summary of our discussion. The questions you posed were "Could water production be shut-off in any sand member in the future with the proposed G8 open hole gravel pack completion?" and "Would waterbreak-through in one sand member compromise the ultimate recovery of the remaining sand members?". My response was that water shut-off in a discrete sand member probably would not be possible with the proposed G8 open hole gravel pack completion. The nature of the Schrader Bluff Formation is such that sand control with gravel packs is required. The close proximity of the sands to each other necessitates completion of multiple sands behind the same screen. However, we don't believe that this compromises the effectiveness of the waterflood or ultimate recovery. We do not anticipate injecting more than 3,000 BWPD into an injector, which services 1 to 3 producers. The producers are pumped through 7 inch casing with electric submersible pumps, lift capacity greater than 5,000 BWPD, and don't anticipate water volumes that can't be handled. Should future injection profile distribution be desired, we would attempt it at the water injection wells rather than the producers. The completions of the water injectors may be more conducive to water shut-off. Please contact Steve Deckert, Senior Reservoir Engineer, at (907)- 564-7615 if you have any questions or require additional information. Yours Very Tru~y,~~ ~ ~ Steven L. Deckert Senior Reservoir Engineer File: G8 well cc: Tom Yeager RECEIVED MAY ;; 1993 Alaska Oil & Gas Cons. Commissio. Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 18, 1993 J. D. Polya Drilling Engineering Supervisor Conoco Inc. 3201C Street, Suite 200 Anchorage, AK 99503 Re: Milne Point Unit G-SA Conoco, Inc. Permit No. 93-48 Sur. Loc. 3176'FNL, 3459'FEL, Sec. 27, T13N, R10E, UM Btmnhole Loc. 814'FNL, 4468'FEL, Sec. 27, T13N, R10E, UM Dear Mr. Polya: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector.on the North Slope pager at 659-3607. David W. ~hnston \ -"' Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. la. Type of work Drill -- Re-Entry - STATE OF ALASKA ALASKA ,.~J- AND GAS CONSERVATION C©,v~MISSION PERMIT TO DRILL 20 AAC 25.005 i dri,, o, S, at, r. ph,o O v ,opm. t Deepen~1 Service -- Developement Gas ~ Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO INC. KB 28' AGE feet Kuparuk River Field Schrader Bluff Pool 3. Address 6. Property Designation 3201 C Street, Suite 305; Anchorage, AK 99503 RDL 25906 4. Location of well at surface 3176" FNL, 3z~59" FEL, Sec. 27, T13N, R10E, U.H.,NSB, AK At top of productive interval 880" FNL, 4~0" EL, Sec. 27, T13N, RIOE,U.N.,NSB, AK At total depth 81~' FNLs ~!68' FELs Sec. 27, T13N, RIOE,U.N.,NSB, AK 12. Distance to nearest property line 6260 feet 13. Distance to nearest well 60' @ SlJRFACE feet 16. To be completed for deviated wells Kickoff depth 2800 feet Maximum hole angle ~9 0 18. Casing program size Hole Casing 30" 13-3/8" 12-1/&" 9-5/8" 8.5" 7" 12" ~.5" Specifications 5a.5 IK-55 I"eldi 36 IK-55 ] BTRC 12766 1 -8o IBT C NABORS 122E RI KB=: 28' ) ! , 19. To be completed for Redrill, Re-entry. and Deepen O 7. Unit or property Name Hilne Point Unit 8. Well number G-8A 9. Approximate spud date July 1, 1993 14. Number of acres in property 256O 11. Type Bond (see 20 AAC 25.025) B1 anket Number 8086-15-5q Amount $200,000 15. Proposed depth (MD and TVD) 523~' HI)/~295' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1850 psig At total depth CrVD) 1950 psig Setting Depth Top Bottom 28' I 28' i 108'i108' i A.CT,C ! PAK p0wN s~pUEE7_E )erations. 7111 Quantity of cement (include stage data) ~52 SX Arctic Set IV 900 SX ASIV & 300 SX C]assC 167 SX Class G N/A GP Screen x 9-s/8%290s2, ~ ,c r, r~ Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Nabors 27E RKF = 35" Casing Length Structural N/A Conductor 80" Surface 2373' Intermediate N/A Production ~975' Liner ~15' Perforation depth: measured true vertical 5765 feet ~500 feet 5051" - 5~.15' feet 39~-q' - q250' feet Size 13-3/8" 9-5/8"' Plugs (measured) 5~30' ND- 5765' ND APR 2 6 199~ Junk (measured) N/A Alaska Oil & Gas Cons. C0m~ Anchorage Cemented Measured depth True Vertical depth Surface 115" 115" Surface 2736' 2368' 7" TOC@ 3870' ND ~-1/2" N/AGPScreen Open hole 5010" MD - 5~30' ND Open hole 3960' TVD - &26~' TVD 5010' 5~29' 3153' 20. Attachments Filing fee [] Property plat ~ BOP Sketch · Diverter Sketch [] Drilling program ~ Drilling fluid program EX] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~c~.. Title Drilling Engineering Supervisor Date Commission Use Only IAPI number Approval date 50- o~.~'- :~.2./~'/- ~,/ ...,-~--/~ - Permit Number ?~- ~'? Conditions of approval Samples required [] Yes ~ No Mud Icg required IL-] Yes .3~ No Hydrogen sulfide.measures [] Yes ,~ No Directional survey required ,1~ Yes [] No Required working pressure for BOPE ~2M; 3M; ~ 5M; 1OM; ~ 15M Other: ~ ned ~Y by order of Approved by David V?~ johnston Commissioner the commission See cover letter for other requirements Form 10-401 Rev. 12-1-85 Submit in triplicate Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 March 18, 1993 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: PERMIT TO DRILL Dear Mr. Johnston, Attached are three copies of Permit to Drill, Form 10-401, and associated information for Milne Point Unit Well G-8A. Also attached is check number 1057 in the amount of $100.00 to pay the fee identified in AAC 25.005. Please direct any questions regarding this application to our Drilling Engineer, Mr. Joe Polya, at 564-7668. Sincerely, Tom Yeager SHEAR Specialist attachments CC: JDP, CVL, TJY G-8A Well File Chevron Occidental NOTES: 1. STATE PLANE COORD1NA1-ES ARE ZONE 4. 2. ALL GEODEDC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. G PAD PROPOSED EXPANSION G PA APR - Alaska Oi~ & Gas , LEGEND / EXISTIN(3 WELL 8'5'42" LOCATION IN MILNE PT. VICINITY MAP o 3 6 MILES SEC. 27, T. 15 N., R 10 E., U.M. WELL] g-5 G-6 G-7 G--8 FROM NORTH UNE FROM EAST UNE 3354' FNL 3294' FNL 5255' FNL 3176' FNL 3435' FEL 5445' FEL 3451' FEL 3459' FEL STATE PLANE COORDINATES-ZONE 4 WELL I! NORTH (Y) EAST (X) G-5 I, Y 6,014,561.26 G-6 ! Y 6,014,420.66 (3-7 Y 6,014,480.06 G-8 i Y 6,014,539.45 X 557,168.77 X 557,160.53 X 557,T51.88 X 557,143.43 GEODETICr~.,.~.~""~'-'-'ONS,, NAD 1927 WELL 6;--5 G-6 G-7 G-8 N OR, TH LAllTIJDE 70' 26' 59.5¢1" 70' 27' 00.126" 70' 2T 00.710" 70' 27' 01.295" WEST LONGITUDE 149' 32' 00.916I' 149' 32' 01.150" 149' 32' 01.385" 149' 32' 01.620" PROPOSED WELL 333~ ~ctc SLVg. ~'~ -'~ PROPOSED WELL LOCATIONS . G-S, G-6, G-7 & G-8 ~=: ~-=-~ ~------- O~ "~'?"'~-'i~°~ '''/~ CHECKED: HERRING ~ ~ ~ I I V SCALE: I" = 500' Alaska Oil a Gas Cons. AnchoragO Fill Line [~ F low Ltne ~nu~ Pre,,,~ntor. Threaded Cornelian Ram Rem Choke Ltne~ 3" 58¢38~ Manual Gate ?'alve & 3" HOR VALVE 'Ki~ Ltne~ Two 3" Valves Tubing Spool w/ 2"-5000~t Side Outlets Cas.lng Spool w/ 3"-5000~t Side Outlets 9-5/8" Su.nt~ece. Casing 13-3/8" Conductor I, BOP STACK SIZE RATINO MEETS APl RP53 & SPEC Ok FOR CLASS 5M 2, BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAULIO CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL MAN}FOLD LOCATED REMOTE WITH t68 GALLON ACCUMULATOR, RESERVO]R UN]T, & AUXiLiARY ENERO¥ SOUROE FOP, S¥STEH ACT]VAT]ON, ~ MiNiMUM ONE SET BLIND RAMS &. TWO SETS APPR. OPR]ATE' P]?E RAMS. 5,CHOKE & KiLL MAN]FOLDS SHOWN SEPARATELY TO MEET AP] RP 53 CLASS 5H REQU]REHENTS, D1VERIER STACK FOR t 3 3/8" CONDUC'1'OP, 4 OPEN ~¢IFR VA.T.,VR$ 1. The hydraulic control system will be in accordance with APi specifications and AOGCC requirements- 2. The HCR valve will open when the preventer closes. A single 10" relief line will run off of the drilling spool HCR and go straight out the back of the sub base to reserve pit or open pad area (safe area). Down wind diversion will be accomplished with a tee with two knife valves on both sides of the tee and they will be linked together to enable one to always be open and the other to be closed. l..IC CONTROLLED R[I~.OT£ O?£RATCO R[_MOI'£_Pc¢'~"=r.._~__,,,_ G:.SE RYDR,6ULIC C~)NTRCK.LED R[3~OTE O~£,RAT£O E[~OT£ PRESSURE G,~G£ SENSOR AOJUSTAI~LE CHOKE MANIFOLD o. __ V.6.RIASL£ CGk'T~X. · . . ., :- TO ATI,~OSPI-I[:RIC ~UD/GAS.. SEPARATOR. GET-AWAY LINE TO RESERVE PIT '"v~ 8 7"' OD CASING t30P ST~CK Ch,_,.,.= $ ,i<ILL P..A;:tFOLDS FOR q s/8'~ t~OP IJAt,'-IFOLD LAYOUT - CONOCO, INC_ · [% / D~SER~ ~ I I T ~ ........ ~ ,,, ,, ........ ~ - , · I~l ~ ' '1~ )' : I, . ~ ........ - . ,~ ~ ..... I ....~'~,L t,~ ~ ~ /, ' .... [ ' ~ ' ~ ~ % Il! . ~- I ~,...i. ll~! ~,~,.::1._1 ........ ~ i,,,,.... H~ I I II! ~1~;'~;.,1' .... ~~ rnl ~l.." . I I I / ~ ' IFLOWLNEC~N~' ~1 I 2'~ ~/~ / ' ' i'i '/ ~ .i i<>l ~ ~ I ~ {~v I I / :LOWL~EC~N~ I .I CO~u~ C~ ~ V~V[ ~ --..1~)~ MUD CLEANER ~ ~ ~ / ~ i I I ~/~ ~ ,, ~uoc~.~. , I ~z ~ ~w~w I ...... I~ I I~.1 I ~ H~, MUD PUMP Nol ~v I I MUD ~LEANER I 'r ~e~ / I~T I I ,,--,~ I~ · . J ~~t~ I ,, ' G-8 PROPOSED SIDETRACK & RECOMPLETION PROCEDURE MILNE POINT UNIT ** OPEN HOLE GRAVEL PACK ** MARCH 15, 1993 OBJECTIVE: -- To achieve an openhole gravel pack completion and optimize production rates by minimizing both formation and ~ompletion related damages. An openhole gravel pack type well would reduce the drilling and completion costs for future Schrader Bluff Wells. The SBPRMT feels that the G-8 openhole gravel pack can be performed to achieve a +2 skin for which the corresponding calculated flowstream is 600 BOPD. DISCUSSION: This procedure involves plugging the original G-8 wellbore through the production interval and sidetracking the well. This sidetrack could follow either of two scenarios dependant upon the free point results of the 7" casing. SCENARIO ~1 (Preferred) The 7" casing string in G-8 should be free from surface to the 9-5/8" casing shoe (@ 2736'md) since the well has not yet been arctic packed. If the 7" casing is free above 3100'md (Estimated TOC @ 3870'md), then it will be cut and pulled below the 9-5/8" shoe and the well will be sidetracked to a new bottomhole location 300 feet west of the original wellbore and will be vertica~ through the "N" and "O" sand production intervals. The 8.5" pilot hole will be underreamed to 12" while reverse circulating with a clear brine -- Reverse Circulating Underreamer (RCU). The reverse circulating is intended to prevent the drill cuttings from being exposed to the underreamed hole section thereby eliminating plugging and subsequent formation damage. Since the clear brine will not form a wallcake, the need for clean-up and the damage associated with a wallcake are eliminated. However, without a wallcake, borehole stability risk increases; therefore, a vertical wellbore has been designed through the production interval. In the absence of a wallcake, two possible problems may arise if fluid losses become excessive: 1) The first problem would be lost production due to a water block or relative permeability change as a result of the excessive water losses. Hysteresis tests will be performed and a single well radial flow simulation model will be constucted in an attempt to answer this concern before the G-8 work is performed. PAGE 1 Alaska Oit & Gas Co~s. 2) The second problem would be failure to maintain sufficient returns up the drill pipe (> 2 BPM) to clean the cuttings out of the hole. In this case, plans will be to spot HEC/CaC03 pills (mix HEC with 12 hour breaker) across the production sands. These CaC03 pills would be cleaned up with HCL once the pre-packed gravel pack screens are in place prior to pumping the gravel pack. - If this underreaming technique is unsuccessful, the c6ntingency will be to change over to a CaC03/Xanvis drilling fluid system, circulate conventionally, and finish underreaming from TD up toward the 7" casing shoe -- DB Underreamer. This method should minimize formation damage since the newly underreamed hole is not exposed to the circulation of the drill cuttings which are circulated away from and above the newly underreamed hole section. Also, the underreamed hole section is not exposed to tool joint rotation and subsequent wellbore deformation. Each underreamer technique employs a different type underreamer of which both the "RCU" and "DB" underreamers are being designed, built, and tested by Baker Tristate. If the 7" casing is not free below the 9-5/8" casing shoe, then the contingency will be to cut and pull the 7" casing at 2725'md. Set a 9-5/8" EZSV at 2675' and pump 150' of lineal cement below and 50' of cement above. Then cut a section in the 9-5/8" casing shoe from 2520'md to 2580'md. Sidetrack the well at 2550'md to the new bottom hole location 300' west of the original wellbore. The underreaming method would be determined based on the above mentioned conditions. SCENaRiO ~2 If the 7" casing is not free above 2725' md, then a decision will have to be made to either burn over or mill the 7" casing to 2700'md (Return to Scenario 1) or pull the gravel pack screens. The well would then be sidetracked below the 7" casing shoe using a 6-1/8" bit to drill the pilot hole which will then be'undereamed to 8-1/2". The reverse circulating underreamer (RCU) method using clear brine will still be the primary plan with the DB underreamer method using CaC03/Xanvis as a contingency. . ' The completion will involve running pre-packed gravel pack screens across the N and O sands in the openhole and performing a free water/sand slurry gravel pack. Prior to working on the well hold a pre-job safety meeting with all rig personnel to discuss the general safety hazards of the operation (completion fluids, frac treatment, gravel pack, etc.). The current plan is to perform this work with the Nabors 22-E Rig (Top Drive) after completion of the drilling program on L-Pad. PAGE 2 Prepared by: Openhole Gravel Pack Stage: Wellbore Preparation Stage: Bruce Augustine, Anchorage Jack Burman, PER Walter Martin, PER Joe Polya, Anchorage PAGE 3 Oil & 6;~s Cons. Commission Ar, cho?a,..s.e Milne Point Well G-8 Well Completion Procedure (Cont'd) Contents Page 4 Page 5 Page 6 Page 22 Page 28 Well Information Completion Fluids G-8 Sidetrack & Wellbore Preparation Stage Open Hole Gravel Pack Stage ESP Installation Procedure PAGE 4 Milne Point Well G-8 Well Completion Procedure (Cont'd) Well Information Casing: 7" 26 $ L-80 -- ID = 6.276" Capacity = 0.03826 bbl/ft = 0.2148 ft3/ft Set @ +/-5010 ft MD (3984 ft TVD) ' PBTD'. 5430 ft MD (4261 TVD) Existing Open hole: 5010 - 5430 MD Underreamed from 8-1/2" pilot hole to 12" 5014 - 5428 ft MD (3987 - 4259 ft TVD) Deviation: 48.2° maximum hole angle at 2715 ft MD. +/-45° in open hole section KB: 28 ft (Nabors 22-E) Workstring: 3-1/2" 15.5# IF Drill Pipe (2" API Drift) Inner Diameter: 2.602"; Minimum ID: 2.125" Tensile Strength = 323,000 lbs. Torsional strength 21,000 ft.lbs. Capacity = 0.00658 bbl/ft (152.05 ft/bbl) Annular Capacity = 0.0264 bbl/ft (37.93 ft/bbl) Note: No allowance for upsets Fluids: 8.6 ppg NaCl (to be used as the completion fluid). Diesel will be used for freeze protection after landing hanger and nipple up oPerations are complete. Underream fluid is a 8.5 ppg NaCl system'to be maintained to incorporate ~ 20% drill solids versus total solids. Disposal: Ail contaminated brine, diesel, produced fluids, frac fluids, etc., will be disposed of by injection down the 9 5/8" by 7" annulus or will be transported to the central reserve pit or the facility for disposal. NOTE: During this workover, the 7" will be pulled and until the 7" is rerun and cemented, the 7"x9-5/8" annulus will not be unavailable for disposal. PAGE 5 Milne Point Well G-8 Well Completion Procedure (Cont'd) Page 6 Milne Point Well G-8 Well Completion Procedure (Cont'd) Completion Fluids Brine density for the completion operation is ~esi~ned based on BHP plus minimal overbalance (30 to 50 psi maximum) to prevent fluid loss to the formation. Required brine density is 8.6 ppg. Methanol (at a concentration of 12% by volume) will be used for freezing point suppression in some brine. Recipe for methanol brine mixing is to use 8.9 ppg NaCl brine with 12% by volume methanol, for a final brine density of 8.6 PPg. **** Methanol is a highly flammable liquid and poses a health hazard when inhaled, ingested, or when it contacts the eyes or skin. Maintain adequate ventilation in enclosed areas, and utilize protective clothing, rubber gloves, and safety goggles when handling this material. Consult MSDS for further information. Maintain at least 150 bbl of fluid in the pits at any time. Any less will make it impossible to circulate through the pits and filter unit and have fluid left to pump into the well. Maintain the filtration system during this operation. No fluid goes into the active tanks without passing through the filter unit. The system consist of a DE press and appropriate guard filters. The two micron absolute filter should be the last filter in line before the fluid enters the pit. Turbidity measurements are to be made as a QC check of fluid solids concentration. A reading of 20 NTU in the volume tank is acceptable. The well can be assumed to be clean when returns are below a 50 NTU reading. Compensate for diesel content when using NTU readings if necessary. Operators of the filter unit should be given the responsibility of checking brine volume and density during deliveries and maintaining a record of each. Any discrepancy should be reported immediately. Low density or contaminated fluids should not be added to the system. Only clean, filtered brine should be pumped into the well at any time during the completion operation. During the gravel pack pumping, the return rate needs to be monitored closely to detect lost circulation or fracturing occurring. Page 7 Milne Point Well G-8 Well Completion Procedure (Cont'd) G-8 Sidetrack & Wellbore Preparation Stage Pre MIRU Operations: Ae Coordinate perforating joint of 2-7/8" tubing.above ESP with production prior to MIRU. Be Install BPV in Tree, Remove Wellhouse, Flowlines, Remove Electrical Equipment, and prepare location for MIRU (blade level around well). Ce Drilling Foreman will ensure that he has a lockout tag on the G-8 electrical panel in the ESP building. De Arrange to have the 7"x9-5/8" casing annulus pressure recorded. If the pressure is zero, then open the valve to atmosphere to confirm that the backside is dead -- no pressure. If a pressure is recorded, then calculate the Kill Fluid Weight required and coordinate the proper freeze point Combination with Baroid to utilize left over brine from the L-II, L-12, or L-13 completion to kill this backside annulus before moving the Nabors 22-E Rig onto the well. OPERATIONAL NOTE: DURING THIS JOB, DOPE ONLY THE PIN END OF ALL TUBUL~RS (SPARINGLY) ~ND USE A ~AG TO WIPE OFF/%LL EXCESS DOPE BEFORE CONNECTIONS GO THRU ROTARY. The openhole ,type completion is susceptable to damage from pipe dope. The pipe dope can plug the pore throats of the formation as well as the pre-packed liner screens. Since there is not a treatment to remove this type damage and it is detrimental to production, the best cure is to prevent it by applying dope sparingly on pin ends as stated. This will prevent excess dope from being deposited on the inside of the tubulars which would then be carried to formation and screens during circulation. &1so, by wiping off all excess dope from the outside of connections, the dope is not smeared along inside of casing and later deposited on the pre-packed screens. Page 8 Milne Point Well G-8 Well Completion Procedure (Cont'd) 1.0 Ensure BPV is installed in Tree & MIRU Workover Rig on G-8 Well. ENSURE THAT ALIGNMENT PIN IS BACKED OUT. 1.1 Kill Well with 8.6 ppg NaC1 Brine with 12~ methanol utilizing Hot Oil Truck (Note: Maximum allowgble Fluid Temperature is 150 degrees Farenheit to prevent damage to the ESP Cable). Pull BPV and set 2 Way Check. 1.2 N/D Tree & N/U BOPE. Install 2-7/8" Pipe Rams. Test BOPE to 3000 psig high/500 psig low with exception of annular preventer to be tested to 1500 psig high/500 psig low. Pull 2-Way Check. 1.3 Pull 2-7/8" tubing while spooling ESP cable. Ensure ESP Company rep is on location to inspect pump as it comes thru rotary. Visually inspect cable as it is POOH and note the tubing joint number (depth) and description of any damage. 1.4 Change Pipe Rams f/2-7/8" to 5". 1.5 Back out lower lock down screws and ensure that the upper lockdown screws are backed out, MU the pack-off running/retrieving tool, and pull 7" pack-off -- this will allow movement of 7" casing hanger for 7" casing free point. 1.6 RU E-line Unit, M/U 7" casing spear and spear top joint of 7" casing with 5" grade "G" drill pipe. RIH w/ strain gauge and determine free point (MAXIMUM ALLOWABLE PULL IS 370,000 LBS -- see Note below) of 7".casing at ±3700 feet (Estimated Top of Cement). POOH w/ strain gauge. Unlatch 7" casing spear and POOH. NOTE: The 80% tensile strength values for the 7",265, NS0, BTRC casing and the 5", 19.5#,Grade "G" drill pipe are 483K and 443K, respectively. Total string weight of the 7" casing string is 11SK lbs -- this value accounts for buoyancy of a 9.0 ppg fluid. The casing was landed in tension; therefore, 370K pounds of force (485K - 113K) is the maximumallowable pull to determine the free point of the 7" casing. 1.7 Change Pipe Rams f/5" to 3-1/2". Page 9 Milne Point Well G-8 Well Completion Procedure (Cont'd) 1.8 MU pack-off running tool and run 7" pack-off. Tighten lockdown screws and test pack-off to 5000 psig for 10 minutes. RUN SHORT WEAR BUSHING! 1.9 If the 7" casing is not free below 2300'md, p~OCEED TO STEP 2.0. 1.10 Rig Down and Release E-Line Unit. 1.10 Build LSND drilling fluid system in pits. 1.11 MU 7" EZSV, TIH while PU 3-1/2" drill pipe, ~and set @ 4750'. Pump 76.8 bbls (375 SXS) 15.8 ppg Class G Cement thru EZSV, Unsting, Dump 3.8 bbls (19 SXS) 15.8 G Cement on Top of EZSV (100' of cement on top of EZSV). Pull to 4650' and circulate hole clean while watching for cement returns (contaminate w/ sugar and divert to cuttings trough). Displace hole w/ LSND drilling fluid. 1.12 Close pipe rams and test casing to 1500 psig for 30 minutes -- acceptable final pressure is 1350 psig. Record Test results on IADC. 1.13 Finish POOH. NOTE: Rack Pipe in the derrick to accommodate the use of both 3-1/2" and 5" drill pipe. 1.14 If the 7" casing is free above 3100'md, PROCEED TO STEP 4°0° Note: If the 7" casing free point is between 2900'md and 3100'md, the well can still be successfully sidetracked below the 9-5/8' casing shoe. However, the MWD azimuth reading tool will experience magnetic interference from the resulting 7" casing stub for the first couple hundred feet of the sidetrack. Consequently, this would require either a gyro survey to fulfill the requirement for directional surveys every 100' or a waiver from the state. 1.15 If the 7" casing is not free below the 9-5/8" casing shoe @ 2736'md, but is free inside the shoe @ 2725'md PROCEED TO STEP 6.0. Page 10 Milne Point Well G-8 Well Completion Procedure (Cont'd) 1.16 If the 7" casing is free above 2300'md, PROCEED TO STEP 5.0. 2.0 M/U the Baker Model "S" Retrieving Tool (size 8D-40 which is designed to pull the Baker Model SC-iL 70-40 Packer) w/ 4.75" oil and bumper jars and the Tristat~ Vibrator Tool -- TIH while PU 3.5" Drill Pipe: 1) TIH and latch retrieving tool into packer, about 10,000 pounds set down weight will ensure the catch sleeve and latch of the retieving tool are engaged. 2) Apply 14,000 to 15,000 pounds up-strain to shear screws in the collet support sleeve. Further up-strain allows movement of the packer body to relax the slips and elements. Note: At this point the up-strain is being pulled from the bottom of the packer. 3) Pull a slight strain above neutral weight (1000 to 2000 pounds) and rotate 15 turns to the right. This simultaneously releases the safety sub and the anchor latch of the retrieving tool. 4) Latch retrieving tool back into packer, about 10,000 pounds set down weight. 5) Pick up and vibrate packer and gravel pack screens free. Note: Recommended Maxim_umA11owable Pull on the 80- 40 Retrieving Tool is 300,000 lbs.) 2.1 If packer and Gravel Pack Screens pull free, POOH and lay down assembly -- Note: Schematic of the Gravel Pack Assembly is included in Attachment #1. PROCEED TO BTEP 3°0° 2.2 If Gravel Pack Assembly does not pull free; Unlatch from packer by pulling a slight strain above neutral weight (1000 to 2000 pounds) and rotate 15 turns to the right; and POOH w/ Retrieving Tool, Oil and Bumper Jars, and Tristate Vibrator. Page 11 Milne Point Well G-8 Well Completion Procedure (Cont' d) 2.3 RIH w/ chemical cutter to cut 2 875" 6 4~ L-80 · I · ! Buttress tubing between'pre-pack screens @ 5259' (See Baker Schematic of Pre-pack Screen w/ Pipe_Tally in Attachment #1). POOH w/ chemical cutter. (Note: Keep E- Line Unit on standby.) . Safety Note: See Attachment #6 for Chemical Cutter Safety. 2.4 MU the Baker Model "S" Retrieving Tool w/ 4.75" oil and bumper jars and the Tristate Vibrator Tool, RIH, Latch Packer with 10,000 lbs. of set down weight, and Attempt to Pull the Packer and Gravel Pack Screens. Note: Recommended Maximum A11owable Pulling Weight on the 80-40 Retrieving Tool is 300,000 lbs. 2.5 2.6 If packer and Gravel Pack Screens pull free, POOH, Verify Fish, and Lay Down Gravel Pack Assembly -- Note: Schematic of the Gravel Pack Assembly is included in Attachment #1. PROCEED TO STEP 3.0. If Packer and Gravel Pack Screens do not pull free, RU the E-Line Unit, RIH w/ chemical cutter~ and cut the 4.5", 11.6#, N-80, Buttress Casing below Packer @ _+4990' (Make cut to ensure that top of fish is ±20' up inside 7" shoe), and POOH w/ chemical cutter. * Requires special 3.75" severing head. Safety Note: See Attachment #6 for Chemical Cutter Safety. . 2.7 MU the Baker Model "S" Retrieving Tool w/ 4.75" oil and bumper jars and the Tristate Vibrator Tool, Latch onto Packer with 10,000 pounds set down weight, and POOH w/ Packer and 6 joints of 4.5" casing plus a cut. Verify and Lay Down Fish. If fish does not pull, Repeat Step ~2.6. If fish is recovered, Release the E-Line Unit. Note: Recommended Maximum Allowable Pulling Weight on the 80-40 Retrieving Tool is 300,000 lbs. (NOTE: If the last fish pulled easily and it is felt the top of fish is free of sand, then Step 2.8 can be skipped and proceed to step 2.9. However, the Tristate Vibrator does not allow circulation thru the tool, and in the event that sand is encountered over the fish, it will require two additional trips to latch the fish.) Page 12 Milne Point Well G-8 Well Completion Procedure (Cont'd) 2.8 RIH w/ 5.75" OD Overshot w/ 4.5" Grapple (Note: Dress overshot with pack-off for circulating since there may be sand on top of the fish), Bumper Sub, Oil Jar, and (6) 4.75" drill collars with Tristate Vibrator. ~atch Fish and attempt to pull Gravel Pack Assembly. If fish is recovered, release E-Line Unit and PROCEED TO'STEP 3.0. 2.9 RIH w/ Baker Model "S" Retrieving Tool w/ 4.75" oil and bumper jars and the Tristate Vibrator Tool, Latch fish, and Attempt to pull Gravel Pack Assembly. If successful, POOH, Verify and L/D fish, Release E-Line Unit, and PROCEED TO STEP 3.0. 2.10 2.11 RIH w/ ~270' of 5.75" TSS Wash pipe w/ 6" OD burning shoe dressed to 4.875" ID washover to 5" OD flapper valve. Washover blank and pre-pack screen to ~5260'. Pooh and L/D wash pipe and burning shoe. RIH w/ 5.75" overshot w/ the 4.5" Grapple, bumper jar, and oil jar. Latch fish and jar free. Pooh, L/D and tally fish, Clear rig floor of all fishing tools. 3.0 Build minimal amount of LSND drilling fluid to displace hole and drill 350' of 6-1/8" hole. 3.1 RIH w/ 6" bit and displace wellbore fluid with LSND drilling fluid while cleaning out gravel pack sand and fill to 5430' or top of fish -- pump gelled sweeps if necessary. Shut down pumps and wiper trip to shoe to confirm fill is cleaned out. 3.2 Set sidetrack cement plug using balanced plug technique from 5430' or top of fish to extend 50' inside the 7" casing shoe -- calculated TOC at 4960' (Possibly will require 2 plugs due to length of interval.) Pull to ±4850' and circulate hole clean while watching for cement returns (contaminate w/ cement, and divert to cuttings trough). POOH and L/D 6" bit. 3.3 M/U 6-1/8" Steerable Directional Assembly (Directional/Gamma Ray MWD) & RIH to 4800' & WOC -- Total of 12 hrs from time cement was pumped. 3.4 Dress top of cement plug, and begin sidetrack as shallow as possible out of the 7" casing shoe. 3.5 Sidetrack and drill ahead according to the proposed directional plan (see Attachment #2). Page 13 Milne Point Well G-8 Well Completion Procedure (Cont'd) 3.6 Circulate and cut the mud weight back to 8.5 ppg -- make sure returns clean up. 3.7 Make wiper trip to the 7" shoe. When ba6k at TD, displace openhole with 8.5 ppg NaCl brine. Pull up inside 7" Shoe -- Mix and pump (at highest 'allowable rate) two 15 bbl hi-vis HEC sweeps while rotating and reciprocating pipe to clean cuttings bed off low side of hole in preparation to reverse circulate underream. When gelled sweeps return to surface, divert to the cutting trough. 3.8 4.0 Finish POOH, and L/D directional assembly. PROCEED TO STEP 8.0. MU 7" mechanical casing cutter and TIH on 3-1/2" drill pipe to free point of 7" casing verified in Step 5 -- Cut 7" casing and POOH with casing cutter. 4.1 Back out lower lock down screws and ensure that the upper lockdown screws are backed out, PULL SHORT WEAR BUSHING, MU the pack-off running/retrieving tool, and pull the 7" pack-off -- this will allow the 7" casing hanger and casing to be POOH. 4.2 Change Pipe Rams f/ 3-1/2" to 7". 4.3 Have TIW Valve BU into 4.5" IF Box X 7" BTRC Pin XO, Function Test, and have available on the rig floor in the open position. 4.4 MU 7" casing spear, spear top joint of 7" casing, POOH and verify the 7" casing fish. NOTE: When backing out the 7" casing hanger, DO NOT back the pup out of the 7" casing hanger. Back the pup out of the full joint of ?" and visually inspect the threads -- if necessary, send in to machine shop to have threads recut or pup. backed out and new one bucked up into 7" casing hanger. Have ready for Step 7.8. 4.5 Change Pipe Rams f/7" to 3-1/2". RUN LONG WEAR BUSHING! 4.6 MU Cementing Sub, RIH to 3200' with 3-1/2" drill pipe and using the balanced plug method, spot a 14 bbl HI-Vis XCD pill mixed to the drilling fluid mud weight. This Hi-Vis Pill is intended to Prevent the upcoming sidetrack cement plug from falling out into the rathole. Page 14 Milne Point Well G-8 Well Completion Procedure (Cont'd) 4.7 POOH to 3000'md and set 300' balanced sidetrack cement plug (2700'-3000') using 16.5 ppg Class G Cement w/ sand and sufficient accelerator to account for the shallow depth and low temperature (Have cement company perform cement tests to verify 2.5 hour thickening, time and adequate compressive strength to serve as sidetrack plug). 4.8 5.0 Pull into 9-5/8" casing shoe to 2600' and circulate hole clean while watching for cement returns (contaminate w/ sugar and divert to cuttings trough). PROCEED TO STEP 7°0° MU 7" mechanical casing cutter and TIH on 3-1/2" drill pipe and cut 7" casing @ just above free point. POOH. 5.1 Back out lower lock down screws and ensure that the upper lockdown screws are backed out, PULL SHORT WEAR BUSHING, MU the pack-off running/retrieving tool, and pull the 7" pack-off -- this will allow the 7" casing hanger and casing to be POOH. 5.2 Change Pipe Rams f/ 3-1/2" to 7". 5.3 Have TIW Valve BU into 4.5" IF Box X 7" BTRC Pin XO, Function Test, and have available on the rig floor in the open position. 5.4 5.5 5.6 6.0 MU 7" casing spear, spear top joint of 7" casing, POOH and verify the 7" casing fish. RUN LONG WEAR BUSHING! NOTE: When backing out the 7" casing hanger, DO NOT..back the pup. out of the 7" casing hanger. Back the.pup out of .the full joint of 7" and visually inspect the threads -- if necessary, send in to machine shop to have threads recur or pup backed out and new one bucked up into 7" casing hanger. Have ready for Step 7.8. Change Pipe Rams f/7" to 5". RUN LONG WEAR BUSHING! ******Install Ditch Magnets in the Possum Bellies!******* MU pilot mill and 7" metal muncher, RIH on 5" drill pipe to 7" casing stub, and mill to 2725'md, and POOH. PROCEED TO STEP 6.6. MU 7" mechanical casing cutter and TIH on 3-1/2" drill pipe and cut 7" casing @ 2725'md. Page 15 Milne Point Well G-8 Well Completion Procedure (Cont'd) 6.1 Back out lower lock down screws and ensure that the upper lockdown screws are backed out, PULL SHORT WEAR BUSHING, MU the pack-off running/retrieving tool, and p~ll the 7" pack-off -- this will allow the 7" casing hanger and casing to be POOH. . 6.2 Change Pipe Rams f/ 3-1/2" to 7". .6.3 6.4 Have TIW Valve BU into 4.5" IF Box X 7" BTRC Pin XO, Function Test, and have available on the rig floor in the open position. MU 7" casing spear, spear top joint of 7" casing, POOH and verify the 7" casing fish. NOTE: When backing out the 7" casing hanger, DO NOT back the pup out of the 7" ~asing hanger. Back the pup out of the full joint of ?" and visually inspect the threads -- if necessary, send in to machine shop to have threads recut or pup backed out and new one bucked up into 7" casing hanger. 6.5 Change pipe rams f/7" to 5". RUN LONG WEAR BUSHING! 6.6 MU 9-5/8" EZSV, TIH w/ 5" drill pipe and set at 2720', Pump 5.1 bbls (25 sks) of Class G Cement below EZSV, Unsting and Dump 3.9 bbls (19 sks) on top EZSV. Pull up to 2650' and circulate hole clean while watching for cement returns (contaminate w/ sugar and divert to cuttings trough). 6.7 Close pipe rams and test casing t~ 1500 psig for 30 minutes -- acceptable final pressure is 1350 psig. Record Test results on IADC. 6.8 Finish POOH. NOTE: Rack Pipe in the derrick to accommodate the use of both 3-1/2" and 5" drill pipe. 6.9 MU 9-5/8" Metal Muncher, TIH w/ 5" drill pipe, and mill a section from 2520' to 2580'md, POOH. (Note: 2520'md is the shallowest that a window can be cut in the 9-5/8" casing since the Schrader Bluff Pool Rules require a cemented surface casing shoe to 500'md permafrost base -- 1860' tvd for this well). Page 16 Milne Point Well Well Completion Procedure (Cont'd) 6.10 MU cementing sub and RIH w/ 5" drill pipe to 2650'. Mix and pump 14.3 bbls (70 sks) 16.5 ppg cement Class G Cement Plug using balanced plug technique. (Hgve cement company perform cement tests to verify 2.5 hour thickening time and adequate compressive strength to serve as sidetrack plug). 6.11 MU 8.5" steerable directional assembly with LWD tools (Directional/Dual Gr/EWR Resistivity Real-Time, Surface Read) . 6.12 RIH to 2470' with 5" drill pipe and WOC total of 12 hours since cement plug was spotted. 6.13 Dress off top .of cement plug while watching returns -- contaminate any cement and cement contaminated mud with sugar and divert to cuttings trough. 6.14 Sidetrack and drill ahead as per proposed directional plan see Attachment #3). PROCEED TO STEP 7.5. 7.0 POOH, Change 3-1/2" pipe rams to 5", RUN LONG WEAR BUSHING, & MU 8.5" steerable directional assembly with LWDtools (Directional/Dual Gr/EWRResistivity Real-Time, Surface Read). 7.1 RIH to 2600' while PU 5" drill pipe and WOC total of 12 hours since cement plug was spotted. 7.2 Dress off top of cement plug while watching returns -- contaminate any cement and cement contaminated.mud with sugar and divert to cuttings trough. 7.3 Sidetrack and drill ahead as per proposed directional plan (see Attachment #4). 7.4 At TD, Circulate hole clean. Short trip into the 9-5/8" casing and based on the hole condition either POOH or TIH to TD and circulate hole clean. POOH laying down 5" drill pipe. 7.5 Change Pipe Rams f/5" to 7" and PULL WEAR BUSHING! RU Casing Crew and Equipment. 7.6 Have TIW Valve BU into 4.5" IF Box X 7" BTRC Pin XO, Function Test, and have available on the rig floor in the open position. Page 17 Anchorage Milne Point Well G-8 Well Completion Procedure (Cont'd) 7.7 7.8 MU 7" Float Shoe, Baffle Plug Catcher Collar, 7" ECP, 7" ES Cementer and run 7" casing -- BAKER LOCK ALL CONNECTIONS INCLUDING PIN END OF 1ST two JOINTs OF CASING above ES CEMENTER AND TACK WELD ALL CONNECTIONS to the collar on the Znd joint of casing. Ensure that the ECP and ES Cementer are pinned according to the job application with the ES cementer MAXIMUM ALLOWABLE pressure setting less than 5000 psig -- this is 80% of burst of the 7" casing minus a 1000 psig safety cushion for the cement line test. MU 7" hanger, Cementing Head w/ Baffle Plug, and Cementing Lines. Pressure test Cementing Lines to 1000 psig above the opening pressure of the 7" ES Cementer. 7.9 Pump a minimum of 1.25 times the 7" casing volume. 7.10 OPTION A (Fill ECP w/ Cement): Pump 50 bbls of 11.0 ppg Sepiolite Spacer, Drop the Baffle Plug, Mix and Pump 30 bbls (146 sx) 15.6 ppg Class G Cement. Drop the closing plug. Clear Cement out of lines with 5 bbls H20. Displace and bump baffle plug -- Note: if pipe is reciprocated, ensure that hanger is landed before the ECP is inflated. Pressure activate the ECP inflating it w/ Cement. Continue to pressure up and open the ES Cementer. Pump ±30 bbls of mud to close the ES Cementer. OPTION B (,Fill ECP w/ LSND Drilling Fluid): Drop the Baffle Plug and displace w/. LSND drilling fluid until Baffle Plug seats on Baffle Plug Catcher Collar -- Note: if pipe is reciprocated, ensure that hanger is landed before the ECP is inflated. Pressure activate the ECP inflating it w/ LSND drilling fluid. Continue to increase the pressure and open the ES Cementer. Mix and Pump 30 bbls (146 sx) 15.6 ppg Class G Cement. Drop the closing plug. Clear Cement out of lines with 5 bbls H20. Displace and bump the closing plug to close the ES Cementer. 7.11 Test casing to 1500 psig for 30 minutes -- acceptable final pressure is 1350 psig. Record Test results on IADC. 7 12 RD Casing & Cementing Crews and Equipment. ND BOPE and install and test 7" pack-off to 5000 psig for 10 minutes. Page 18 Milne Point Well G-8 Well Completion Procedure (Cont'd) 7.13 Clean pits, RU DE Filter Unit, and line up pits to be able to isolate the filtered clean brine from the unfiltered return brine. -- 7.14 7.15 Change Pipe Rams f/ 7" to 3.5", RUN SHORT WEA~. BUSHING, & MU 6-1/8" bit and 6 or 8 4-3/4" drill collars. TIH with 3-1/2" drill pipe and drill out ES Cementer, Latch Down Baffle_Collar, and Float Shoe while cutting density of fluid back to 8.6 ppg. TIH to TD and displace the openhole with 8.5 ppg NaCl brine. POOH inside 7" Shoe -- Mix and pump (at highest allowable rate) two 15 bbl hi-vis HEC sweeps while rotating and reciprocating pipe to cutting bed off low side of hole in preparation to reverse circulate underream. When gelled sweeps return to surface, divert to the cuttings trough. 7.16 Finish POOH. Page 19 Milne Point Well G-8 Well Completion Procedure (Cont' d) 8.0 UNDERREAMING PROCEDURE Summary: ae (REVERSE CIRCULATING UNDERREAMERUTILIZING CLEA~FILTERED BRINE -- STEPS 8.1 - 8.6) This is the preferred method of underreaming for the G-8 well. The primary intent is to minimize formation damage by preventing the drill cuttings from coming in contact with the underreamed portion of the hole. Since it may be necessary to spot a pill in order to control fluid losses, it is hi~hlv recommended that the pill be spotted by Dumping down the drill DiDe as opposed to the annulus to achieve more precise placement. .In this event, it is essential that the drill.p~pe be circulated clean of cuttings before any conventional circulating is done to prevent exposure of the undereamed portion of the hole to drill solids (formation damage). This preferred underreaming method may not be possible either due to high fluid losses or borehole instability -- in either case, the contingency will be as follows. Be (UNDERREAMING FROM TD TO THE 7" CASING SHOE WITH A TRISTATE "DB" UNDERREAMER UTILIZING A CaC03/XANVIS DRILLING FLUID SYSTEM-- STEPS 9.0 THRU 9.5) This is the next best fit method for underreaming the G-8 well. To minimize formation damage, the hole is underreamed from TD back toward the 7" casing shoe. Circulation is conventional to minimize the exposure of the underreamed portion of the hole to drill cuttings laden fluid (formation damage). It is essential that drill solids be maintained at or below 20% of the total solids content. Page 20 Milne Point Well G-8 Well Completion Procedure (Cont'd) REVERSE CIRCULATE UNDERRE~M (RCU) WITH CLEAR BRINE: NOTE: It is essential that the brine be kept ~lean and filtered. Utilize all solids control equipment. In the event it becomes necessary to pump lost circulation pills, ensure that the returns are monitored and that the pills are diverted to the cuttings trough upon returning to surface. 8.1 MU reverse circulating underreamer with 8-1/2" blades or 12" blades for 6-1/8" or 8-1/2" hole, respectively. MU a 5' 3-1/2" drill pipe pup and a 6-1/8" stabilizer below that on the bottom of the underreamer, and TIH w/ 3-1/2" drill pipe. Drop the ball 1-7/8" composite rubber ball and pressure up down drill pipe to extend underreamer blades, pull up against the 7" shoe w/ 5K pounds to verify arms are open. Note: Underreamer blades will close by pulling up against casing shoe with 10-15,000 lbs. overpull. 8.2 Underream from the 7" shoe to TD according to the following criteria: 1. Maintain a minimum return flow rate of 2 bpm. · Keep track of losses via pump rate (bpm) versus return rate (bpm). 3. Pump only filtered fluid downhole. · Circulate until returns ~re cleaned up before shutting down pumps to make connections. · If losses become too great to maintain sufficient returns to clean the cuttings out of the hole, then be prepared to pump LCM pill. Use only sheared and filtered HEC (add breaker) with CaC03 bridging material. Spot pill down the drill pipe, let sit 20 minutes, and then reverse out diverting any gelled fluid returns to the cuttings trough. 0 If efforts to utilize the reverse circulating method fail (for whatever reason), PROCEED TO STEP 9.0. Page 21 Milne Point Well G-8 Well Completion Procedure (Cont'd) 8.3 At TD, continue to reverse circulate until returns clean up, short trip to the 7" casing shoe, and TIH to TD and tag for fill -- if fill is above the OB base attempt to reverse circulate to deepen hole; however, d%e to the extension, it may be necessary to trip out of hole and go in open ended or with a saw tooth circulating sub to reverse circulate the fill out to the desired depth. Remember, any conventional circulation to clean fill will expose the underreamed portion of the hole to drill solids plugginq and consequent formation damage. 8.4 POOH with underreamer -- Note: It will be necessary to pull against the 7" casing shoe w/ 10-15,000 lbs overpull to collapse the undereamer blades. 8.5 R/U E-Line Unit and run 4-arm caliper w/ GR from TD to 7" casing shoe for use in sand volume calculations. POOH with the 4-arm caliper and R/D the E-Line Unit. (If portions of hole are undergauge, consider underreaming these hole sections utilizing the same reverse circulating method.) 8.6 If the underreaming operation was completed with the clear brine system, then Proceed to Step 10. Page 22 Milne Point Well G-8 Well Completion Procedure (Cont'd) CONVENTIONAL CIRCULATION "DB" UNDERREAMER WITH CaC03 9.0 Clean pits, Build and displace the hole wi~h 9.0 ppg CaC03/Xanvis mixed according to the following, recipe: Xanvis/CaC03 System: 6.7 ppb KCL Salt 1.5 ppb Xanvis 4.0 ppb Dextrid 41 ppb Baracarb 9.1 MU Tristate "DB" Underreamer and TIH to TD. Underream the openhole section upwards toward the 7" casing shoe. All fluid density maintenance will be done with CaC03 additions. Circulate openhole section of the hole clean before shutting pumps off to make connections. 9.2 9.3 Maintain CaC03/Drill Solids ratio of 80/20 with out allowing drill solids content to become any greater than 20% -- the system will be replaced as a maintenance method. Utilize the Acid/Versenate test developed by Baroid to monitor the CaC0/Drill Solids ratio (See Attachment #4). Underream upwards to the 7" casing shoe. Circulate the hole clean. Pull into the shoe to collapse arms and RIH to tag for fill -- if fill is above the OB base, TIH and Underream to achieve at least 10' of rathole below the OB base at 4254' tvd. 9.4 R/U E-Line Unit and run 4-arm caliper w/ GR from TD to 7" casing shoe for use in sand volume calculations. POOH with the 4-arm caliper and R/D the E-Line Unit. (If portions of hole.are undergauge, consider underreaming these hole sections.) 9.5 RIH to TD and circulate while cutting the fluid density back to 8.6 ppg. Displace the openhole with 25% by volume excess 8.5 ppg NaC1 brine. Pull inside 7" Shoe -- Mix and pump (at highest allowable rate) two 15 bbl hi- vis HEC pills while rotating and reciprocating pipe to clean cuttings bed off low side of hole. When gelled sweeps return to surface, divert to the cutting trough. Pull up into the 7" casing shoe and finish displacing the hole with 8.5 ppg NaC1 brine -- Mix and Pump two 15 bbl Hi-Vis HEC pills while rotating and reciprocating drill pipe -- circulate at maximum rate to clean cuttings bed off low side of hole. When gelled Page 23 Milne Point Well G-8 Well Completion Procedure (Cont'd) sweeps return to surface, divert into cuttings trough. POOH. Page 24 Milne Point Well G-8 Well Completion Procedure (Cont'd) 10.0 Open Hole Gravel Pack Stage Clean all pits and fill with 8.6 NaCl brine; filter to 2 microns absolute. Fill frac tank with +/-500 bbls of same for g~avel pack. Secure tank for temporary storage of pickle and neutralizer. 10.1. Hold pre-job meeting to discuss the running of the gravel pack screens. 10.2. Pick up and slowly (90 sec/stand) RIH with the gravel pack assembly on drill pipe as follows (have as much of this equipment picked up before this time to minimize time M/U BHA): a. 4-1/2" Set Shoe/Perforated Sub/Flapper Valve Assembly. be 20 ft of 4-1/2" Single Screen Pre-pack (2-7/8" 12 gauge all welded stainless steel wire wrap screen base, 20-40 mesh gravel pre-pack, and 4-1/2" perforated outer pipe base). C. O-ring Sub. (a, b, and c picked up as one unit) d. Necessary length of 4-1/2" Single Screen Pre- pack to cover from Na Top to Ob Base based on the outcome of sidetrack operation (2-7/8" 12 gauge all welded stainless steel wire wrap screen base, 20-40 mesh gravel pre-pack, and 4-1/2" perforated outer pipe base). e. Crossover. f. 155 ft of 4-1/2" blank pipe, welded centralizers lowest joint (directly above pre-pack screen) in casing. ge Polished stinger/i-i/4" CSH tubing (length as required) inside screen as washpipe. h. Crossover. i · SC-iL Gravel Pack Packer with extensions and port closure sleeve. (Items h and i are picked up as one unit) Page 25 Alaska. Oil & G,:,o Cop. s. Anchorago Milne Point Well G-8 Well Completion Procedure (Cont'd) 10.3 10.4. Use screen table and dog collar when running pre- pack screen. -- Hang off blank pipe in rotary table wi~h 4-1/2" slips. NO EXCESS PIPE DOPE ON ANY CONNECTIONS. DOPE PIN ENDS ONLY. Rabbit all pipe as RIH. Be certain space-out of washpipe is correct before RIH with assembly. Fill the drill pipe every 5 stands with 8.5 ppg KCL brine. Run the gravel pack assembly into the well slowly, 90 sec/stand. At casing shoe record the pick up and slack off weights. DO NOT set down weight on bottom or on fill. If unable to get to bottom of underreamed section, wash as necessary and condition hole. If it becomes necessary to wash down the screen assembly, be certain not to exceed 1000 psi pump pressure (to prevent prematurely setting the packer). Hang off assembly in tension with end of assembly one (1) foot above TD. Prior to positioning the workstring space out to obtain a safe working height at the rotary table. Do not space out any connections in the BOP stack. Move workstring slowly! Rig up D/S pumping equipment on location. High pressure lines on all but the return line. The line from the manifold to the pit can be a high pressure hose (5000 psi RWP). All valves off the rig floor should be lined out prior to starting the treatment. This includes valves on the choke manifold and disposal tank. Flag these valves prior to starting the job. They should not be operated during the job. Attempt to hook up in a manner that will allow only valves on the rig floor to be operated during the job. A ball catcher will be made up in the treating line off of the lead off chicksan. The ball catcher and the squeeze manifold are supplied by the tool service company. Page 26 Milne Point Well G-8 Well Completion Procedure (Cont'd) A densitometer, pressure sensor and flow meters must be installed in the line between the workstring and high pressure pump. A flow meter must be installed in the line from the manifold to the pits. A pressure sensor must be installed between the manifold and ~he casing side. This equipment and the data recorder must be installed and checked out as soon as possible. 10.5. Hold a pre-job safety meeting for all personnel on location that could be exposed to hazards of the treatment. The two main points of concern to be stressed are material hazards (acids, bases, oxidizers, solvents) and pumping pressures. Discuss general safety precautions and first aid procedures (location of eye wash, responsible personnel, etc). 10.6. Using D/S pump, test lines to 5000 psi. treating lines, gauges, manifold, etc. with warm diesel, if necessary. Includes all Pressure test 10.7. Drop the setting ball and allow time for the ball to gravitate down (5 min per 1000 ft). Set the packer by pressuring up the tubing. Pressure up to 500 psi using rig pump and 8.5 ppg KCL fillup fluid, hold for two minutes, switch to D/S pumps (using 8.6 brine) and finish setting packer by pressuring up to 2000 psi, hold for five minutes. Pressure up to 2500 psi, hold for five minutes. Bleed pressure off. 10.8. Pressure test the annulus with D/S at 300 psi, 500 psi and 1000 psi to insure the packer is set properly. This procedure should release the running tool from the -packer. (Rotate 12 turns to the right to release running tool from the SC-iL Packer if hydraulic release fails) 10.9. Pickup to reverse position, blow out ball seat by pressuring up to 4500 psi using D/S. 10.10. Pump the 25 bbl of neutralizer solution to the disposal tank. Staying in the reverse position, pump the following using D/S to within 3 bbl of the crossover: a. Acid/solvent mixture (220 gal Super Pickle mixed in 300 gal 15% HC1 with inhibitor, iron sequestering agent, surfactant) Page 27 Anchorage Milne Point Well G-8 Well Completion Procedure (Cont'd) b. Water (or 2% KCL) from transport. Page 28 Milne Point Well G-8 Well Completion Procedure (Cont'd) Reverse circulate acid back to surface disposal tank with the rig pump at maximum rate. Divert flow to the pits after 1.5 workstring volumes pumped. Continue reversing until 70 bbl pumped while monitoring returns. Do not flow acid/solvent or gel int? the pits during this operation. **** Super Pickle is a combustible liquid and poses a health hazard when ingested, inhaled, or when it contacts the eyes or skin. Maintain adequate ventilation in enclosed areas, and utilize protective clothing, rubber gloves, and safety goggles when handling this material. Consult MSDS. **** HCl is a corrosive liquid and poses a health hazard when ingested, inhaled, or when it contacts the eyes or skin. Maintain adequate ventilation in enclosed areas, and utilize protective clothing, rubber gloves, and safety goggles when handling this material. Consult MSDS. 10.11. Wellbore ready for gravel pack. Continue circulating at 2 bpm and begin adding 1.5 ppg of 20-40 Mesh gravel to brine with blender. Pick-up to lower circulate position (taking returns through lower tell-tale) after pumping 50 bbl of "slurry". Monitor return rate and brine density; continue to dispose pill/mud/bleach or filter brine returns from the well. Be aware of return of bleach solution. Keep away from rotary - possible exposure to reaction products of bleach with mud. Monitor return fluid rate. If return rate (+/-) same as pump rate, increase pump rate to +/- 3 bpm in 0.25 bpm increments. If returns are same as pump rate, increase slurry loading in 0.25 ppg increments and monitor returns to maximum of 4 ppg. Be sue that pressure surges are not indicated in system, which indicates insufficient transport of gravel. At pressure increase or decrease in returns shift the tool to take returns through the main pre-pack screen (upper circulate position). Note amount of gravel pumped to this point. Complete pumping gravel pack until a 1000 psi over initial circulating pressure on main screen or a decrease in return rate change indicates that the screen is covered. (Theoretical Total gravel: +/-28700 lbs) Page 29 Milne Point Well G-8 Well Completion Procedure (Cont'd) Page 30 Milne Point Well G-8 Well Completion Procedure (Cont'd) 10.12. Immediately close annular, trap +/-500 psi on annulus, pick up to reverse circulate position and reverse workstring clean with 8.6 ppg brine (minimum of two hole volumes) at maximum rate using rig pumps.- Monitor returns and divert gel/gravel into the junk p~t. Flush out surface treating lines st same time. Insure top of packer is free of debris by manipulating service tool port above packer while reverse circulating. 10.13. After hole is reversed clean, place tool in main screen circulation position and pressure up. If rate/pressure indicate the screen is still covered then rig down treating equipment and prepare to POOH. If rate/pressure indicates exposed screen then repeat steps 10.11 and 10.12, keeping the tool in the main screen position. 10.14. POOH with running tool. Lay down drill pipe as POOH. Fill hole when POOH to compensate for the drill pipe removed from the well only. Do not attempt to keep the hole full to surface. This may result in large volumes of fluid lost to the formation. Page 31 Milne Point Well G-8 Well Completion Procedure (Cont'd) 11.0 ESP Installation Procedure 11.1. 11.2. 11.3. 11.4. 11.5. 11.6. PULL THE WEAR BUSHING. GIH with ESP, picking up and drifting 2-7/8" tubing as follows: a. ESP Assembly b. 2 Jts. 2-7/8" 6.4~ Production tubing c. 2" Check Valve d. 2 Jts. 2-7/8" 6.4~ Production tubing e. 1" GLM w/ 2'7/8" pups BU into each end f. 2-7/8" 6.4~ Production Tubing to surface g. 2-7/8" Tubing Hanger w/ 2 ft pup RIH with ESP no faster than 30 ft/minute. Before start-up of ESP the appropriate item will be run on wireline. Cut approximately 18" off of the lower pigtail before making the .splice to ensure sufficient cable length in the event the lower pigtail must be replaced. Attach two cable bands per tubing joint. Attach additional cable bands above and below cable splice. Locate the bottom of the ESP assembly to maintain +/-30 ft between assembly and the gravel pack packer. Do not space out with pup joints at surface. Ensure that alignment pin is backed out after landing tubing hanger. Pump sufficient diesel down annulus and tubing to fill to a depth of 2000 ft for freeze protection. ND BOP stack. NU production tree. Rig down to move. Page 32 Attachment #1 of G-8 Procedure Page I of 2 BAK~'R N~.O~..L °.Y.C-IL~ 70B4-40 ~R HO~E'L. °:S° :SLIDING ~t. EE:VE: OROSSOVER SU~, $' ~ ~X X 4 ~/~' ~TT. PIN ~ 7/8' V/ ~l~ ~ ~N V/ ~-40 ~K[R ~O V/ ~ 7/8' ~TT. ~X X a-el~ S[~ sue 3 l/a- X ' ~T BOX X PIN B~ER S1~ ~EEN P~AC~ 4 t/~' X ~KER ~0 V/ ~ 7/8' ~T. ~X X PIN ~U~T. PIN ~, 4 ~/2' ~T. BOX X PIN ~ER ~RF~TEO SUB ~/ ~ER O-RI~ ~ SUB, 4 4 ]/~' ~UTT. ~X X CASING ~ V/ 4 1/~' ~TT. ~KER '~N TY~' V-SET S~ ~/ 4 ~TT. ~X SAND TOP ~ Attachment #1 of G-8 Procedure Page 2 of 2 }~-b%~¢~~ SAND CONTRO ~ ~a,~,s-- ,CASING , i "i -- ~-'~-~ u~. ~r LINER ' ' .... - .... ' . [~- !~/~ J . ~" . ..~ , ,.~ -- JF ~.~ ~.e~ ~ . [ ¢' ' ' ' '' IF *~e, so ~.~ t :. ( I t II- ~e~,~ ~ / ~ -) -- &' -. / /F.:~o ~,~q i / ' /. . / . JJ ~.~ zo,~ .. i , ' ~ ' ~r ~.~.s~ ~.~. k ~ ~ - .. I ..... /I ,~nt,~ ~,~m ~ · % ,, t ' /I ~.~ ~.,~ / ~ - lC. s~.~ ~..~ i , ~ ~ I, ~ - /I ~sz~m ~:~ ~ _./ ...... ~ , - iF ~3~.~ ~.,s t ! ~ .. . t .... /iu 5~.s~ ~.o~l~,eo ~ ~*'~ ' ~ ' \ttachment #2 of G-8 Procedure Page I of 6 Creoted by : jones For: .f POLYA Dote plotted : 2-Mot-95 Plot Reference is (;-8 Rd#] Version #4. Coordinotes ore in feet reference slot CONOCO Structure : Pad O Well : 8Rd Location : Nor-th Slope, Alaska Field : Milne Poinl UnH £~d~f Ho/d WELL PROFILE DATA I~D In¢ Dir T~D 5040 52.37 34~2 ~.9~ 41~ 5379 ~2 3~.9~ 4254 ~95 --848 2717 -879 2792 -907 76t9 -917 41.92 KOP / Tie-In Point 60~G / ~oo' OOGL.~G 36.86 End Build & Turn End of Hold 44o0 i 2640 2680 2720 2760 2600 2840 2880 29t20 ] 2960 .3000 .3040 3080 .3120 Stole ] : 20_00 Vedical Seclion on 341.54 ozimuth wilh reference 0.00 N. 0.00 E from slot #~ 1I I 31~ filiAl|Il West .... I ! ! ' ~ ~2~80 _ - - A I I Z 0 ;tachment #2 of G-8 Procedure Page 2 of 6 CONOCO, Inc. Pad G &Rd slot f8 Mitre Point Unit North Slope, Alaska PROPOSAL L I ST I NG Eastman Teleco Your ref : G-8 Rd#1 Version #4 Our ref : propT06 License : Date printed : 2-Mar-93 Date created : 1-Mar-93 Last revised : 2-Mar-93 Field is centred on nTO 30 8.305,w149~8 7.22 Structure is centred on nTO 27 32.522,w149 30 20.177 Slot location is nTO 27 1.279, w149 32 1.762 Slot Grid coordinates are N 6014537.736, E 557138.618 Stol local coordinates are 3176.00 S 3459.00 ~ Reference North is True North ,Attachment #2 of G-8 Procedure Page 3 of 6 CONOCO, inc. Pad G,SRd Milne Point Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : G-8 Rd#1 Version #4 Last revised : 2-Mar-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogteg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 5040.00 44.82 349.93 3986.35 2594.81 N 847.63 5100.00 41.69 347.32 4030.04 2635.11 N 855.71 5200.00 36.64 342.18 4107.57 2696.02 N 872.16 5237.45 34.82 339.93 4137.97 2716.71 N 879.25 5378.79 34.82 339.93 4254.00 2792.51 N 906.95 0.00 2729.72 KOP / Tie-In Point 6.00 27'/0.51 6.00 2833.51 6.00 2855.37 End Buitd & Turn 0.00 2936.04 5428.79 34.82 339.93 4295.05 2819.33 N 916.74 ~ 0.00 2964.58 Alt data is in feet un[ess otherwise stated Coord{nates ~rofl] stot #8 and TVD from wet[head (59.27 Ft above m~an sea revel). Vet[ica[ section is from wet[head on azimuth 341.64 degrees. Dectination is 0.00 degrees, Convergence is 0.46 degrees. Catcutation uses the minimum curvature method. Presented by Eastman Te[eco ,ttachment #2 of G-8 Procedure Page 4 of 6 CONOCO, Inc. Pad G,8Rd Mitne Point Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : G-8 Rd#1 Version #4 Last revised : 2-Mar-93 Cor~ents in wetlpath MD TVD Rectangular Coords. Comment 5040.00 3986.35 2594.81N 847.63 ~ KOP / Tie-In Point - 5237.45 4137.97 2716.71N 879.25 ~ End Build & Turn Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3986.35 2594.81N 847.63~ n/a 3986.35 2594.81N 847.63~ 9 5/8" Shoe n/a 3986.35 2594.81N 847.63~ n/a 4295.05 2819.33N 916.74W ?" csg n/a 3986.35 2594.81N 847.63~ n/a 3986.35 2594.81N 847.63W 7" Csg Pt Att data is in feet un[ess otherwise stated Coordinates from slot fl8 and TVD from wet[head (59.27 Ft above mean sea level). Bottom bole distance is 234.92 on azifr~Jth 342.89 degrees from wellhead. To[at Dogleg for wettpath is 11.85 degrees. Vertical section is from wet[head on azilf~Jth 341.64 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the minirmJm curvature method. Presented by Eastman Teteco ,ttachment #2 of 6-8 Procedure Page 5 of 6 CONOCO, Inc. Pad G 8Rd stot fl8 NitnePoint Unit North Slope, Ataska CLEARANCE REPORT by Eastman Te[eco Your ref : G-8 Rdf/1 VersionS/4 Our ref : prop?06 License : Date printed : 2-Nar-93 Date created : l-Nar-93 Last revised : 2-Hat-93 Fietd is centred on n?O 30 8.305,u149 38 ?°22 Structure is centred on n?O 2? 32.522,w149 30 20.1T7 Stot tocation is nTO 27 1.279,u149 32 1.762 Stot Grid coordinates are N 6014537.736, E 557138.618 Stot tocat coordinates are 3176.00 S 3459.00 Reference North is True North Hain catcutation performed with florizontat Plane method ( UARNING: DATA BELOI~ IS TVD RANGE LIHITED, NOT ALL PROXIN'ITIES I~Y BE REPORTED ) Object ~ettpath Ctosest approach with 3-O minimumdistancemethod Last revised Distance N.D. Diverging from N.D. PMSS <O-5765'>,,8,PadG 5-Feb-93 -0.0 5040.0 5040.0 ,ttachment #2 of G-8 Procedure Page 6 of 6 CONOCO, Inc. Pad G,SRd Milne Point Unit,North Slope, Alaska CLEARANCE L[ST[NG Page 1 Your ref : G-8 Rd#1 Version #4 Last revised : 2-Mar-93 Reference wettpath Object wellpath : PMSS <O-5765'>,,8,Pad G M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates 5040.0 3986.3 2594.8N 847.6g 5040.0 3986.4 2594.8N 847.6~ 5100.0 4030.0 2635.1N 855.7~J 5101.9 4030.1 2637.9N 855.1~ 5200.0 4107.6 2696.0N 872.2~ 5212.6 4107.5 2716.0N 867.8~ 5237.4 4138.0 2716.7N 879.2~ 5256.0 4138.0 2746.6N 872.6~ 5250.0 4148.3 2723.4N 881.7~ 5270.7 4148.2 2757.0N 874.2~ Horiz Bearing 349.9 12.1 12.4 12.6 12.6 5378.8 4254.0 2792.5N 906.9~/ 5420.6 4254.0 2861.9N 890.6~ 13.3 I~oriz Dist 0.0 2.9 2O-4 30.7 34.4 · 71.3 Nin'm bist 0.0 2.2 15.3 22.9 25.7 53.9 All data is in feet unless otherwise stated Coordinates from slot #8 and TVD from wellhead (59.27 Et above mean sea [ever). Vertical section is from wellhead on azimuth 341.64 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the radius of curvature method. Presented by Eastman ~eleco Attachment #3 of G-8 Procedu, Page I of 6 ICreoted by : jones For: J POLYA IDote plotted : 15-Mar-93 IPIot Reference is G-8 Rd~l Version lCoordinotes (]re in feet reference slot ~8. CONOCO Structure : Pad G Field : Milne Point Unit Well : 8 Location : North Slope, Alaska 25~ 46.27 355.~ 2242 ~2 -396/ 8U~ 2~2 62~5 337.16 2434 e 1130 -~5 ~ ~970 62.85 ~57.16 2950 2022 -879 Hold ~578 0.~ 3~.79 4~00 25~. -11211 1 I V KOP / Tie-In Point //' 50.O0 54.98 5 DEC / 59.97 End o f/~(u, ld /' ...~. /" / ./ / ?× ? Begin ~gle Drop 45.~ 40.~ 35.00 25.00 20.00 15.00/ ~0:00 7.50 gOO 1050 1200 1550 1500 1650 1800 1950 2100 2250 2400 2550 2700 Scale 1 : 75.00 Vedlcol Secfion on $36.64 ozimufh with reference 0.00 N. 0.00 £ from slot ~8 - Wesf 1050 900 750 600 4.~' 500 150 / r /./ /, -'/"~ / // / _ lARGE7 Z 0 RE{,'EIVED ,~,ttachment #3 of G-8 Procedure Page 2 of 6 CONOCOo I nc. Pad G 8 slot f8 Hilne Point Unit North Slope, Alaska PROPOSAL LISTING by Eastman Teleco Your ref : G-8 Rd#1 VersionS5 Our ref : prop704 License : Date printed : 15-Mar-93 Date created : 1-Mar-93 Last revised : 15-Mar-93 Field is centred on 544582.018,6033467-392t999'OOOOO'N Structure is centred on n70 27 32.522,w149 30 20.177 Slot location is n70 27 1.279,w149 32 1.762 Slot Grid coordinates are N 6014537.736, E 557138.618 Slot local coordinates are 3176.00 S 3459.00 ~ Reference North is True North 'Attachment #3 of G-8 Procedur6 Page 3 of 6 CONOCO, Inc. Pad G,8 Mi[ne Point Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : G-8 Rd~l Version #5 Last revised : 15-Mar-93 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 2550.00 46.27 335.68 2241.69 882.05 N 395.68 ~ 0.00 2600.00 48.76 335.94 2275.46 915.68 N 410.78 ~ 5.00 2700.00 53.75 336.42 2338.02 987.02 N 442.26 ~ 5.00 2800.00 58.74 336.84 2393.57 1063.32 N 475.21 ~ 5.00 2882.41 62.85 337.16 2433.77 1129.52 N 503.31 ~ 5.00 966.64 KOP / Tie-]n Point · 1003.50 - 1081.47 1164.59 1236.50 End of Build 3000.00 62.85 337.16 2487.44 1225.95 N 543.92 ~ 0.00 3500.00 62.85 337.16 2715.61 1635.96 N 716.62 W 0.00 3970.59 62.85 337.16 2930.36 2021.86 N 879.17 ~ 0.00 4000.00 61.38 337.16 2944.11 2045.82 N 889.26W 5.00 4100.00 56.38 337.16 2995.78 2124.69 N 922.48 ~ 5.00 1341.13 1786.01 2204.73 Begin Angle Drop 2230.72 2316.30 4200.00 51.38 337.16 3054.71 2199.11 # 953.82 ~ 5.00 2397.05 4300.00 46.38 337.16 3120.46 2268.51 N 983.06 ~ 5.00 2472.35 4400.00 41.38 337.16 3192.52 2332.37 N 1009.96~ 5.00 2541.64 4500.00 36.38 337.16 3270.34 2390.19 N 1034.31 ~ 5.00 2604.38 4600.00 31.38 337.16 3353.34 2441.55 N 1055.94 ~ 5.00 2660.11 4700.00 26.38 337.16 3440.87 2486.04 N 1074.68g 5.00 2708.38 4800.00 21.38 337.16 3532.28 2523.34 N 1090.39 ~ 5.00 2748.85 4900.00 16.38 337.16 3626.88 2553.14 N 1102.95 W 5.00 2781.20 5000.00 11.38 337.16 3723.92 2575.24 N 1112.26 ~ 5.00 2805.17 5100.00 6.38 337.16 3822.70 2589.46 N 1118.25 ~ 5.00 2820.60 5200.00 1.38 337.16 3922.44 2595.69N 1120.87 ~ 5.00 2827.36 5227.57 0.00 336.79 3950.00 2596.00 N 1121.00 ~ 5.00 2827.69 TARGET 5500.00 0.00 336.79 4222.43 2596.00 N 1121.00 ~ 0.00 2827.69 557~.57 0.00 336.79 4300.00 2596.00 N 1121.00 ~ 0.00 2827.69 TD ALt data is in feet unless otherwise stated Coordinates from slot #8 and TVD from ~e[thead (59.27 Ft above mean sea level). Vertical section is from wellhead on azimuth 336.64 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the minimumcurvature method. Presented by Eastman Teteco ~vi~;,R 1 8 199;~ Alaska Oil & Gas Co~s. CommisSiOn Anch0rag0 Attachment #~ of G-8 i~rocedur~ Page 4 of 6 CONOCO, Inc. PROPOSAL LISTING Page 2 Pad 6,8 Your ref : G-8 Rcl#1 Version #5 Milne Point Unit,North Slope, Alaska Last revised : 15-Mar-93 Comments in wel[path MD TVD Rectangular Coords. Coolant 2550.00 2241.69 882.05 N 395.68W KOP / Tie-In Point - 2882.41 2433.77 1129.52 N 503.31W End of Build 3970.59 2930.36 2021.86 N 879.17 ~ Begin Angle Drop 5227.57 3950.00 2596.00 N 1121.00 ~ TARGET ° 5577.57 4300.00 2596.00 N 1121.00 ~ TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 2241.69 882.05N 395.68~ 28~.54 2411.05 1090.TSN 486.90~ 9 5/8" Shoe n/a 2241.69 882.05N 395.68~ 5577.57 4300.00 2596.00N 1121.00~ 7" csg n/a 2241.69 882.05N 395.68g 5227.57 3950.00 2596.00N 1121.00W 7" Csg Pt Targets associated with this weltpath Target name Position T.V.D. Local rectangular coords. Date revised G-8 Rd Revised not specified 3950.00 2596.00N 1121.00~ 9-Feb-93 All data is in feet unless otherwise stated Coordinates from slot #8 and TVD from wellhead (59.27 Ft above mean sea level). Bottom hole distance is 1861.11 on azimuth 337.06 degrees from wellhead. Total Dogleg for wellpath is 79.47 degrees. Vertical section is from wellhead on azimuth 336.64 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco Attachment #3 of G-8 Procedure' Page 5 of 6 CONOCO, Inc. Pad G 8 slot ~ Mitne Point Unit North SLope, ALaska CLEARANCE REPORT Eastman Teteco Your ref : G-8 Rc~l Version Our ref : propT04 License : Date printed: 16-HarD93 Date created : 1-Mar-93 Last revised : 15-Mar-93 Field is centred on 544587..018,6033467.392,999.00000,N Structure is centred onnTO 2? 32.522,w149 30 20.17T SLot Location is n?O 27 1.279, w149 32 1.762 Slot Grid coordinates are N 6014537.736, E 557138.618 SLot local coordinates are 3176.00S 3459.00 W Reference North is True North Main calculation performed with 3-0 minimum distance method Object uettpath Closest approach with 3-O minimum distance method Last revised Distance M.D. Diverging from M.D. PMSS <O-5765'>,,8, Pad G 5-Feb-93 0.0 2550.0 5317.6 Cons. Attachment #3 of G-8 Procedure Page 6 of 6 CONOCO, Inc. CLEARANCE LISTING Page 1 Pad G,8 Your ref : G-8 Rd#1 Version #5 Milne Point Unit,North Slope, Alaska Last revised : 15-Mar-93 Reference wellpath Object wetlpath : PMSS <0-5765'>,,8,Pad G Horiz M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing 2550.0 2241.7 882.0N 395.7~/ 2550.0 2241.7 882.0N 395.7~/ 90.0 2600.0 2275.4 915.7N 410.8~ 2600.0 2276.1 915.1N 410.6~ 158.3 2700.0 2338.0 987.0N 442.2~ 2699.8 2343.9 982.2N 440.1~ 155.6 2703.4 2340.0 989.5N 443.3~ 2703.2 2346.1 984,5N 441.0~ 155.2 2800.0 2393.6 1063.3N 475.2~ 2798.6 2410.1 1050.2N 467.2~ 148.6 Min'm Dist 0.0 0.9 ~.9 8.2 22~5 2882.4 2433.8 1129.5N 503.3W 2878.1 2464.1 1105.0N 487.7t~ 147.6 42.0 2896.0 2440.0 1140.7N 508.0~ 2891.2 247~.0 1114.0N 491.0~ 147.5 45.8 3000.0 2487.4 1226.0N 543.9~/ 2990,2 2541.0 1181.7N 514.9~ 146.7 75.3 3115.2 2540.0 1320.4N 583,7~/ 3098.7 2616.5 1255.4N 540.5~ 146.4 109.3 3334.3 2640,0 1500.1N 659.4g 3303.0 2761.8 1392.1N 584.6~/ 145.3 179.2 TCyt Dist 0.0 0.9 7.9 8.3 43.7 47.7 78.7 114.9 189.8 3500.0 2715,6 1636.0N 716.6W 3461.1 2874.4 1499.4N 612.91J 142.8 233.7 246.3 3553.4 2740.0 1679.8N 735.1~ 3513.8 2911.4 1535.7~ 622.3~ 141.9 250.7 263.5 3772.6 2840.0 1859.5N 810.8~1 3725.6 3057.4 1684.2N 660.8~ 139.4 317.0 333,2 3970.6 2930.4 2021.9N 879.2W 3907.7 3183.3 1812.4N 690.6~ 138.0 378.7 400.3 3991.4 2940.0 2038.8N 886.3~ 3927.4 3197.0 1826.2N 693.6~ 137.8 385.2 404,9 4000.0 2944.1 2045.8N 889.2~ 3935.6 3202.7 1832.0N 694.8~ 137.7 387.8 406.7 4100.0 2995.8 2124.7N 922.5~ 4030.4 3268.8 1898.5N 708,9QJ 136.6 413.9 424.6 4176.1 3040.0 2181.8N 946,5~ 4104.2 3320.4 1950.0N 720.2~J 135.7 428.5 434.3 4200.0 3054.7 2199.1N 953.8~ 4127.0 3336.4 1965.8N 723.7~J 135.4 432.1 436.6 4300.0 3120.4 2268.5N 983,0~ 4225.3 3405.6 2033.9N 739.4~ 133.9 442.4 443.4 4328.0 3i40.'~ 2286.9N 990.8~ 4253.1 3425.2 2053.0N 743.9QJ 133.4 443.9 444.3 4400°0 3192.5 2332.4N 1010.0~ 4318.0 3471.2 2097.7N 754.1~ 132.5 445.2 445.2 4461.8 3240.0 2368.9N 1025.3~ 4374.8 3511.7 2136.8N 761.91J 131.4 443.9 444.3 4500.0 3270.3 2390,2N 1034.3~ 4408.0 3535.5 2159.6N 766.0~ 130.7 442.1 443.0 4584.3 3340.0 2433.9N 1052.7~1 4491.4 3595.3 2216,9N 775.6~ 128.1 434.8 438.0 4600.0 3353.3 2441 .SN 1055.9W 4506,6 3606.2 2227,3N 777.5~J 127,6 432.9 436.7 4699.0 3440.0 2485.6N 1074.5~/ 4605.9 36~.2 2295.5N 790.2~ 123.8 416.2 425.4 4700.0 3440.9 2486.0N 1074.7~ 4606.8 367T.8 2296.1N 790.3~/ 123.7 416.0 425.3 4800.0 3532.3 2523.3N 1090.4~1 4700.6 3744.8 2.~S0.~ 803.3~J 119.6 392.5 408.1 4808.3 3540.0 2526.1N 1091.6~ 4708.1 3750.1 2365.8N 804,3~/ 119.2 390.3 406.4 364.4 360.4 334.0 329.0 304.4 299.6 280.4 277.2 275.6 269.2 280.1 301.9 307.8 330.8 4900.0 362.6.9 2553.1N 1102.9~1 4789.4 3808.1 . 2421.7N 815.3~ 114.6 4913.6 :~40.0 2556.6N 1104.4~ 4801.4 3816.6 2430.0N 816.9~! 113.8 5000.0 37~.9 2575.2N 1112.2W 4874.2 3~68.4 2480.2N 826.5g 108.4 5016.4 3740.0 2578.1N 1113.5W 4887.8 3878.1 2489.5# 828.3~ 107.2 5100.0 3822.7 2589.5N 1118.2W 4954.1 3925.3 2535.4N 836.8U 100.9 5117.4 ~40.0 2591.1N 1118.9~ 4967.7 3935.0 2544.8N 838.6g 99.4 5200.0 3922.4 2595.7N. 1120.9~ 5028.8 3978.4 2587.0N 846.2~ 91.8 5217.6 3940.0 2596,0N 1121,0~ 5041.4 3987.4 2595.8N 847.8~ 90.0 5227.6 3950.0 2596.0N 1121.0~ 5048.6 3992.4 2600.8N 848.7~ 89.0 5317.6 4040.0 2596.0N 1121,0~ 5111.0 4036.5 2644.3N 856.2~ 79.7 5417.6 4140.0 2596.0N 1121.0~ 5179.5 4084.5 2692.6N 864.1~ 69.4 5500.0 4222.4 2596.0N 1121.0~ 5236.3 4124.2 2732.8N 870.4~ 61.4 5517.6 4240.0 2596.0N 1121.0~ 5249.1 4133.1 2741.7N 871.8~ 59.7 5577.6 4300.0 2596.0N 1121.0~ 5291.2 4162.6 2771.4N 876.4~ 54.4 384.9 381.3 356.1 350.9 323.1 317.1 290.0 284.8 282.1 269.3 291.3 332.4 343.0 382.8 Att data is in feet unless otherwise stated Coordinates frocn stot fA8 and TVO from wellhead (59.27 Ft above mean sea level). Vertical section is from wellhead on azimuth 336.64 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the radius of curvature method. Presented by Eastman Teleco Attachment #3 of G-8 Procedure Page 5 of 6 CONOCO, Inc. Pad G 8 slot ¢/8 MitnePoint Unit North SLope, ALaska CLEARANCE REPORT Eastman TeLeco Your ref : G-8 Rd~l Version #5 Our ref : prop704 License : Date printed: 16-Mar-93 Date created : 1-Mar-93 Last revised : 15-Mar-93 FieLd is centred on S44582.018,6033467.392,999.00000,N Structure is centred onnTO 27 32.522,w149 30 20.177' SLot Location is nTO 27 1.279,~149 32 1.762 SLot Grid coordinates are N 6014537.736, E 55713.618 SLot Local coordinates are 3176.00 S ~459.00 ~ Reference North is True North Main caLcuLation performed with 3-0 minimum distance method Object wettpath CLosest approach ,ith 3-0 minimum distance mthod Last revised Distance M.D. Diverging from M.D. PMSS <0-57651>,,8,Pad G 5-Feb-93 0.0 2550.0 5317.6 MAR 1 8 1995 Alaska 0il & Gas Cons. Commission Anchorage Attachment #3 of G-8 Procedure Page 6 of 6 CONOCO, Inc. CLEARANCE LISTING Page 1 Pad 6°8 Your ref : 6-8 Rd#1 Version #5 Milne Point Unit,North Slope, Alaska East revised : 15-Mar-93 Reference weltpath Object weltpath : PMSS <O-5765'>,,8,Pad G Horiz T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing 2550.0 2241,7 882.0N 395.7W 2550.0 2241.7 882.0N 395,7W 90.0 2600,0 2275.4 915.7N 410.8W 2600.0 2276.1 915.1N 410.6W 158.3 2700,0 233~.0 987.0N 442.2W 2699.8 2343.9 982.2N 440.1W 155.6 2703.4 2340.0 989.5N 443.3W 2703.2 2346.1 984.5N 441.0W 155.2 2800.0 2393.6 1063.3N 475.2W 2798.6 2410.1 1050.2N 467.2W 148.6 Min'm Oist 0.0 0.9 ?'.9 8.2 22,5 TCyI Dist 0.0 0.9 7.9 8.3 23.0 2882.4 2433.8 1129.5N 503.3W 2878.1 2464.1 l105.0N 487.7W 147.6 42.0 43,7 2896.0 2440.0 1140.7N 508.0~ 2891,2 2473.0 1114.0N 491.0W 147.5 45.8 47,7 3000.0 2~7.4 1226.0N 543.9W 2990.2 2541.0 1181.7N 514.9W 146.7 75.3 78.7 3115.2 2540.0 1320.4N 583.7W 3098.7 2616.5 1255,4N 540.5W 146.4 109.3 114.9 3334.3 2640.0 1500.1N 659.4W 3303.0 2761.8 1392.1N 584.6W 145.3 179.2 189.8 3500.0 2715.6 1636,0N 716,6W 3461.1 2874,4 1499.4# 612.9W 142.8 233.7 246.3 3553.4 2740.0 1679.8N 735.1W 3513.8 2911.4 1535.7N 622.3W 141.9 250.7 263.5 3772.6 2840.0 1859.5N 810.8U 3725.6 3057.4 1684.2N 660.8W 139.4 317,0 333.2 3970.6 2930.4 2021.9N 879,2W 3907.7 3183.3 1812.4N 690.6W 138,0 378.7 400.3 3991.4 2940.0 2038.8N 886.3W 3927.4 3197.0 1826.2N 693.6~J 137.8 385.2 404.9 4000.0 2944.1 2045.8N 889.2W 3935.6 3202.7 1832.0N 694.8~ 137.7 387,8 406.7 4100.0 2995.8 2124.7N 922.5W 4030.4 3268.8 1898.5N 708,9W 136.6 413,9 424.6 4176.1 3040,0 2181.8N 946.5W 4104.2 3320.4 1950.0N 720.2W 135.7 428.5 434.3 4200.0 3054,7 2199.1N 953.8W 4127.0 3336.4 1965.8N 723.7W 135.4 432,1 436.6 4300.0 3120,4 2268.5N 983.0W 4225.3 3405.6 2033.9N 739.4W 133.9 442,4 443.4 4328.0 3140,0 2286.9N 990.8W 4253.1 3425.2 2053.0N 743.9W 133.4 443.9 444.3 4400.0 3192,5 2332.4N 1010.OW 4318.0 3471.2 2097.7N 754.1W 132.5 445,2 445.2 4461.8 3240,0 2368.9N 1025.3W 4374.8 3511.7 2136.8N 761.9W 131.4 443.9 444.3 4500,0 3270.3 2390.2N 1034.3W 4408.0 3535.5 2159.6N 766.0W 130.7 442.1 443.0 4584,3 3340,0 2433.9N 1052.7W 4491.4 3595.3 2216.9N 775.6W 128.1 434.8 43~.0 4600.0 3353.3 2441.5N 1055.9W 4506,6 3606.2 2227.3N 777.5W 127.6 432.9 436,7 4699.0 3440.0 2485.6N 1074.5W 4605.9 3677.2 2295.5N 790.2W 123.8 416.2 425.4 4700.0 3440.9 2486.0N 1074.7W 4606.8 3677.8 2296,1N 790.3W 123.7 416.0 425.3 4800.0 3532.3 2523.3N 1090.4W 4700.6 3744.8 2360,6N 803.3W 119.6 392.5 408.1 4808.3 3540.0 2526.1N 1091.6~ 4708.1 3750.1 2365.8N 804.3W 119.2 390.3 406.4 4900.0 3626.9 2553,1N 1102.~ 4789.4 3808.1 . 2421,7~ 815.3W 114.6 4913.6 3640.0 2556.6N 1104.4W 4801.4 3816,6 2430.0N 816.9W 113.8 5000.0 3723.9 2575,2N 1112.2W 4874.2 3868.4 2480.2N 826,5W 108.4 5016.4 3740.0 2578.1N 1113.5W 4887.8 3878.1 2489.5N 828.3W 107.2 5100.0 3822.7 2589.5N 1118.2W 4954.1 3925.3 2535.4N 836.8W 100.9 364.4 360.4 334.0 329.0 3O4.4 299.6 280.4 277'.2 275.6 269.2 280.1 301.9 30?.8 330.8 5117.4 3840.0 2591.1N 1118.9W 4967.7 3935.0 2544.8N 838,6W 99.4 5200.0 3922.4 2595,7N 1120,9W 5028.8 3978,4 2587.0N 846,2W 91.8 5217,6 3940.0 2596,0N 1121.0W 5041.4 3987.4 2595.8N 847.8W 90.0 5227,6 3950.0 2596.0N 1121.0W 5048.6 3992.4 2600.8N 848.7W 89,0 5317,6 4040.0 2596.0N 1121.0W 5111.0 4036.5 2644.3N 856.2W ?9.7 5417,6 4140.0 2596.0N 1121.0W 5179.5 4084.5 2692.6N 864.1W 69,4 5500.0 4222,4 2596,0N 1121.0W 5236.3 4124.2 2732.8N 870.4W 61.4 5517,6 4240,0 2596.0N 1121.0W 5249.1 4133.1 2741.7N 871.8W 59,7 5577,6 4300.0 2596.0N 1121.0W 5291.2 4162.6 2771.4N 876.4W 54,4 384.9 381.3 356.1 350.9 323.1 317.1 290.0 284.8 282.1 269.3 291.3 332.4 343.0 382.8 Att data is in feet unless otherwise stated Coordinates from stol #8 and TVD from wellhead (59.27 Ft above mean sea level). Vertical section is from wellhead on azimuth 336.64 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the radius of curvature method. Presented by Eastman Te[eco dtachment #4 of G-8 Proce~ .~e Page 5 of 6 CONOCO, Inc. Pad G 8Rd slot ~8 Mitne Point Unit North SLope, ALaska CLEARANCE REPORT Eastman Teteco Your ref : G-8 Rd~l Version Our ref : prop683 License : Date printed : l?-Apr-93 Date created: 9-Feb-93 Last revised : 17-Apr-93 FieLd is centred on5/~582.018,603~67.392,999.00000,N Structure is centred on nTO 27 32.522,w149 30 Stol Location is nTO 27 1.279, w14932 1.762 SLot Grid coordinates are N 6014537.7~S, E 557138.618 SLot Local coordinates are 3176.00 S ~59.00 W Reference North is True North Main catcutationperformed with Horizontal PLane method Object ~ettpath PMSS <O-5765'>,,8,Pad G CLosest approach with 3-D minimun distance method Last revised Distance M.D. Diverging from M.D. ?-Apr-93 0.0 2800.0 2800.0 ECEIVED APR 2 6 1993 Alaska Oil & Gas Cons. Commissior' Anchorag~ Att hment #4 Page 6 CONOCO, Inc. Pad G,BRd Mitne Point Unit,North Slope, Alaska Reference wellpath M.D. T.V.D. Rect Coordinates 2800.0 2411.0 1051.2N 467.6%; 2840.7 2438.2 1079.4N 478.8%; 2900,0 2477.2 1120.6N 495.9~ 3000,0 2543.1 1190.2N 524.6W 3100,0 2609.0 1259.8N 553.3%; 3200.0 2674.8 1329.3# 582 · 0%; 3300.0 2740.7 1398.914 610.7t4 3400.0 2806.5 1468.414 639.4t4 3500.0 2872,4 1538.0N 668.1~ 3600.0 2938.2 1607.6N 696.8t4 3700.0 3004.1 1677.114 725 3800.0 3070.0 1746.~ 754.314 3900.0 3135.8 1816.214 785.0~ 3976.7 3186.3 1869.6N 805 4000.0 3201.8 1885.714 811.614 4100.0 3271.4 1952.0N 839.0~ 4200.0 3345.9 2013.7N 864.5%; 4300.0 3424.8 2070.4N 887.9g 4400.0 3507.8 2121.914 909.2W 4500.0 3594.5 2168,0N 928.2~ 4600.0 5684.5 2208.3N 944.814 4700.0 3777.2 2242.714 959.0%4 4800.0 3872.4 2271 . 114 970.7%1 4871.9 3942.0 2287.714 977.6W 4900.0 3969.4 2293.5N 980. Or4 4911.9 3981.0 2296.0N 981.0~ 5000.0 4066.8 2314.3N 9~8.6W 5100.0 4164.3 2335.1H 997.1~ 5183.9 42~.0 2352.6N 1004.3~ 5200.0 4261.7 2355.9N 1005.714 5234.2 4295.0 2363.0N 1008.6%; of G-8 Procedure of 6 CLEARANCE LISTING Page 1 Your ref : G-8 Rc~l Version #8 Last revised : 17-Apr-93 Object wetlpath : PMSS <O-5765'>,,8,Pad G Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates Bearing Oist Dist 2800.0 2411.0 1051.2N 467.6W 158.9 0.0 0.0 2840.0 2438.1 1078.8N 478.1W 128.0 1.0 0.8 2897.3 2477.2 1118.2N 492.5g 126.3 4.2 3.3 2993.1 2543.1 1183.'rN 515.6~ 125.9 11.1 8.9 3087.9 2608.9 1248.1N 538.0%; 127.3 19.2 15.5 3181.0 2674.8 1310.414 559.3g 129.8 29.6 23.7 3273.4 2740.7 1372.214 578.8~ 129.9 41.6 33.8 3365.6 2806.5 1434.4N 596.2W 128.2 55.1 45.7 3458.3 2872.4 1497.5N 612.4W 126.0 68.9 57.6 3552.4 29:58.3 1562.5# 629.3~ 123.7 81.2 68.4 3648.0 3004.1 1629.5N 646.9%1 121.2 92.0 78.5 3743.8 3070.0 1697.1N 664.0W 118.8 103.0 89.9 3839.2 3135.8 1764.2# 679.9t~ 116.8 115.5 102.7 3912.1 3186.3 1815.5# 691.2W 115.4 125.9 113.3 3934.4 3201.8 18~1.214 694.6~ 115.0 129.1 116.5 4034.2 3271.4 1901.214 709.5g 111,4 139.2 127.7 4140.4 3345.9 1975.2N 725.8~ 105.5 143.9 135.4 4252.5 3424.8 2052.6N 743.8%; 97.0 145.2 140.8 4369.3 3507.8 2133.0H 761.2W 85.7 148.3 147.9 4490.3 3594.5 2216,1# 775.5W 72.5 160.1 159.4 4616.0 ~:~4.5 2302.5N 791.614 58.4 179.8 174.3 4746.2 3777.2 2391.9N 809.5~ 45.1 211.2 194.6 4879.8 3872.4 2484.0N 827.3~ 34.0 256.7 222.7 4977.6 3942.0 2551.614 8~9.8~ 27.6 297.7 248.2 5016.1 3969.4 2578.3N 844.'/~1 25.4 315.3 259.3 5032.5 3981.0 2589.6N 846.7%1 24.6 322.8 264.1 5154.3 4066.9 2674.8N 861.2g 19.4 382.3 301.4 5293.5 4164.3 2T~.ON 876.714 15.4 454.2 346.8 5409.2 4246.0 2854.0N 889.3~ 12.9 514.5 386.6 5431.4 4261.7 2869.5N 891,8W 12.5 526.1 394.5 5478.3 4295.0 2902.1N 897.0%; 11.7 550.5 411,4 Att data is in feet unless otherwise stated Coordinates from stol #8 and TVD from wellhead (59.27 Ft above mean sea level). Vertical section is from wet[head on azimuth 336.86 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the radius of curvature method. Presented by Eastman Teleco Att. ~_hment #4 Page fo G-8 Procedure 3o£6 CONOCO, Inc. Pad G,8Rd Mitne Point Unit,North Slope, Alaska MD TVD Rectangular Coords. PROPOSAL LISTING Page 2 Your ref : G-8 Rd#1 Version #8 Last revised : 17-Apr-93 Comments in weL[path Comment 2800.00 2411.05 I051.23 N 467.62 2840.67 2438.17 1079.38 N 478.84 3976.69 3186.34 1869.57 N 805.00 4871.87 3942.00 2287.68 N 9~.56 4911.90 3981.00 2296.00 N 981.00 5183.87 4246.00 2352.55 N 1004.34 5234.16 4295.00 2363.01 N 1008.66 Tie-In Point End Build & Turn Begin Angle Drop 7" Csg Pt - End Angte Drop TARGET - T/ NA Sands TARGET - B/ OB Sands TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 2411.05 1051.23N 467.62W 2800.00 2411.05 1051.23N 467.62W 9 5/8" Shoe n/a 2411,05 1051.23N 467.62~ 4871.87 3942.00 2287.68N 9T/.56W 7" Csg Pt n/a 2411.05 1051.23N 467.62~ 5234.16 4295.00 2363.01N 1008.66~ 7" csg Targets associated with this we[[path Target name Position T.V.D. Local rectangular coords. Date revised G-8 Rd Revised not specified 3981.00 2296.00N 981.00W 9-Feb-93 G8 B/OB Target not specified 4246.00 2352.55N 1004.34~ 17-Apr-93 G8 7" Csg Target not specified 3942.00 2287.68N 977.56W 17-Apr-93 Ali data is in feet unless otherwise stated Coordinates from slot #8 and TVD from wellhead (59.27 Ft above mean sea level). Bottom hole distance is 1418.97 on azimuth 337.59 degrees from wellhead. Total Dogleg for wettpath is 37.43 degrees. vertical section is from wellhead on azimuth 336.86 degrees. Declination is 0.00 degrees, Convergence is 0.46 degrees. Calculation uses the minimum curvature method. Presented by Eastmen Teleco REEEIVED APR 6 199) Alaska Oil & Gas Cons. C;orm-nissioi~ Anchorage Creoted by : jones For: ~ POLYA Dote plotted : 17-Apr-93 Plot Reference is (;-8 Rd#l Version #8. Coordinotes ere in feet reference slot #8. True Vertical Depths ore reference wellheod. BAKER HUGHES INTEQ ~.chment #4 of G-8 Proceduz Page 4 of 6 '~ CONOCO Sfrucfure : Pad G Well : 8Rd Field : Milne Poinf Unif Locofion : North Slope, Alaska WELL PROFILE DATA .... Point .... MO Inc Dir 1VD KOP 2800 47.54 338.95 2411 End of Build 2841 48.81 337.57 2438 End of Hold 3977 48.81 337.57 3186 £r~l of Drop 4~72 13.00 537.57 3942 r~rget 4912 13.00 5~7.57 3981 End of Hold 5184 13.00 557.57 4246 D~d of Hold 5234 13.00 337.57 4295 North 1051 1079 -479 1870 -80," 2288 -978! 2296 -981: 2352 - 1004 2363 - 1009J 2~_ .. ~ - 2400. · 2550. _ 2700_ '-t--- 2850. · 30(XL 0 - ~ 3150~ _f.-- - ~ 3300_ - 34~_ _ I I v 1350 1200 1050 900 I t I I. I I [ I N 2~.43 DEG W :~569'(T0 TD) Tie-In Point 9 5/8 Shoe 48.00 End Build & Turn MAXIMUM ANGLE 48.81 DEG 48.00 Begin Angle Drop 44.00 40,00 36.00 52.00 DROP 4 DEG / 100' 28.00 24.00 ~0.00 O0 MAXIMUM ALLOWABLE TARGET ANGLE 13 DEG Csg Pt - End Angle Drop TARGET - T/ NA Sonds Sonds k TARGET - B/ OB ID ~,'~ 900 1050 ! 200 1350 1500 ! 650 1800 1950 21DO 2250 2400 2550 2700 Scale 1 : 75.00 Vertical Section on ~36.86 ozlmufh with reference 0.00 N, 0.00 E from slot #B 2850 3000 3150 3300 3450 West ...... -.~ 750 600 ~,50 500 I I I I ! I I 3300 .3150 . °2700 _2550 _ _2400 _ _2250 _ _2100 _ _1950 _ _1800 _ _1650 _ .1500 _ _1350 _ _1200 _ _1050 _ _ 900 _ _ 75Z~ A i I Z o A~asks. OJJ .& 6as CoRs. Oottii~SS~o Anchorago Attachment #6 of G-8 Procedure Page I of 2 CHEMICAL CUTTERS SAFETY PRECAUTIONS The CHEMICAL CUTTER, WHEN USED AND HANDLED PROPERLY-is a safe Tool. However, like any oil field pipe cutting device, when safety procedures and precautions are not followed, the Tool CAN BECOME DANGEROUS. Assdmbly and disassembly procedures are outlined in this manual. The instructions must be followed without exceptions. 1. No personnel should handle the CHEMICAL CUTTER unless the individual has been fully trained and properly instructed in the use and safe handling of the Tool. 2. Always wear rubber gloves and goggles, or a face shield, while handling the CHEMICAL CUTTER both before and after fh-ing. 3. Always use a Protective Sleeve over the Tool. A Protective Sleeve is a piece of heavy wall aluminum tubing that covers the lower half of the Tool from the middle of the Chemical Cylinder to the Bull Plug. It should be secured in place with three thumb screws. 4. Keep the Severing Head as far away from the body as possible when handling the Tool. 5. The Chemical Cylinders should be assigned a definite area for storage. We recommend that the Cy~rs be stored in a place that will not expose them to heat in excess of 120 degrees F.; or excessive cold below 60 degrees F. 6. Never drop the Cylinders or permit them to strike each other violently. Do not drag, roll, or slide CyLinders even for a short distance. Be sure they are securely fastened during shi'pment so that they are not subjected to hard blows or jars that may damage the seals and allow chemical leakage. 7. Never transport the Chemical Cylinders while they are assembled to any other part of the Tool. 8. Never remove the special Shipping Plugs on either end of the Chemical Cylinder until immediately before using the Tool at the well site. 9. Do not tamper with the inner seals of the Cylinder. Do not touch the chemical or residue left on the Tool after firing. 10. Bromine Trifluoride is not flammable, but can support combustion. S~all fires ma~x be controlled by carbon dioxide or dry chemical extinguishers. ~ ~ ~ ~ ~ ~ '~' L) Attachment #6 of G-8 Procedure Page 2 of 2 11. NEVER FIRE OR DISCHARGE THE CHEMICAL CUTTER OUT OF THE WELL FOR ANY REASON!! FIRST AID SUGGESTIONS The chemical, Bromide Trifluoride, is a highly toxic, colorless to gray-yellow liquid, having the highest boiling point (127 degrees C) of the halogen fluorides. It is extremely reactive, forming the highest known fluorides of the elements from the halides. Bromine Trifluoride will react violently with most organic compounds. Since Bromine Trifluoride is so extremely corrosive to human tissue and the eyes,' personnel working with this material should wear clean rubber gloves, safety goggles or safety shield, and a protective apron. SUMMON A PHYSICIAN IMMEDIATEI.Y FOR ANY PERSON WHO HAS BEEN BURNED OR OVERCOME BY BROMINE TRIFLUORIDE. However; prior to the physician's arrival, first aid measures should be taken. Those listed below are based upon common practice in the industry. Their adoption in any specific case should be subject to prior endorsement by a competent medical advisor. 1. Remove exposed victim from the area. 2. For exposure due to inhalation, oxygen should be administered by trained .personnel only. Artificial respiration should be given only if breathing has ceased. 3. For external exposure, wash with a large amount of water. 4. If the bum is severe enough to cause blisters, DO NOT BREAK THEM DURING FIRST AID TREATMENT. The bum should be neutralized by making a paste of bicarbonate of soda and water. Spread paste liberally until burning sensation has subsided somewhat and natural color begins to return. The burn can also be neutralized with Zephirine Solution. This must. be prepared by a physician. 5. In the event chemical gets into the eye(s), wash the eye(s) out thoroughly with clean, running water for at least 15 minutes. (If needed, have someone hold the eyelids open). If personnel should be wearing contact lenses, they should be removed immediately. Attachment 5 of G-8 Procedure 1· · · · ® · · e ACID VERSENATE TEST FOR DETERMINATION OF CaCO3 BRIDGING MATERIAL IN WHOLE MUD Measure out 10 cc's whole mud into mud cup. Dilute with 350 cc's deionized Water and stir. Filter the water/mud solution through an API filter paper. Use extra deionized water to wash out the mud cup to get all the solids into the filter cell. Dry the filter paper and solids from Step 3 and transfer the dried solids to a beaker. Add 15% HCL (@ 5-10 cc's) to the dried solids in the beaker until all the calcium carbonate has been dissolved (add acid until there is no more effervescence indicating a reaction between the acid and calcium carbonate). Pour the acid solution from Step 5 into a 100 ml volumetric flask. Wash out beaker with deionized water and pour into same 100 ml flask, then add deionized water directly to the flask to the 100 ml mark. Titrate 1 ml of the Step 6 solution using the standard Versenate Test for Calcium using 20 epm hardness titrating solution. Calculate lb/bbl calcium carbonate ~s follows: (ml 20 epm titrating solution) X (3.5) = lb/bbl CaCO3 Test procedure from Baroid as per Steve Blattel (10/92). TO. FROM: DATE: MIKE MINDER, AOGCC JOE POLYA, CONOCO INC. March 25, 1993 SUBJECT'. G-8A PERMIT TO REDRILL Dear Sir: First, I am sending the two pieces of information you requested in our conversation on March 25: 1. Drilling Fluid Program and the 2. Cement Volume Calculation. Secondly, I am requesting that AOGCC correct the setting depth of the 9-5/8" casing shoe on the Form 10-407 submitted in June of 1991 by Conoco also needs this depth to be corrected. The erroneous reported depth was 2408'md / 2145'tvd. The correct depth should be 2736'md / 2368'tvd. J.D. Polya Drilling Engineering Supervisor G-8A DRILLING FLUID PROGRAM I. DRILL 8.5" HOLE SECTION: Regardless of the sidetrack depth, the 8.5" hole section will be drilled with a Low Solids Non-Dispersed (LSND) water based mud with the following properties: TVD MD 3540 4818 3989 5277 4254 5542 4300 5588 Formation Mw YP Pv FY FL K Sand Top 9.0 15 12 45 8 Na Sand Top 9.2 12 8 35 6 Ob Sand Base 9.4 12 8 35 6 TD 9.4 12 8 35 6 II. A long string of 7",26#,L-80,BTRC casing will be run from surface and set at 5238'md (3950'tvd) -- this is in agreement with the Schrader Bluff Pool Rules which requires the production casing to be set within 50 feet of the N Sand Top. An External Casing Packer will be used in conjunction with a Hydraulically Operated Two-Stage Cementing Tool to isolate and prevent contamination of the openhole section from cement. III. The 8.5" openhole section from 5238'md to 5588'md (3950'tvd to 4300'tvd) will then be underreamed to 12" using either 8.5 ppg KCL brine or 9.0 ppg CaC03/Xanvis drilling fluid. CEMENT VOLUME CALCULATIONS I. CASING CEMENT JOB In accordance with 20 ACC 25.030d4A-C and the Schrader Bluff Pool Rules the 7" will be set within 50' of the N Sand Top at 5238'md and the cement volume calculated to extend 500'md above the K Sand Top (4818'md/3540'tvd). The corresponding calculated Top of Cement is 4300'md in the 8.5" hole. ® · Volume Factor: 7" Casing in 8.5" hole (enlarged to 9"): (9~' - 72)/1029.4 8.5" Openhole: (93/1029.4) = 0.0311 bpf (0.1745 ft3) 0.0787 bpf (0.4418 ft3) Slurry Volume CalcUlation: Annular Volume: (5238'-4300') * 0.0311 bpf = 29.5 bbls (165.5 ft3) Shoe and ECP Volume (Use 9" Hole for 60'): 60' * 0.0787 bpf = 4.7 bbls (26.4 ft3) Total Cement Slurry Volume: 29.5 + 4.7 = 34.2 bbls (192.0 ft3) Note: The yield for Class "G" Premium Cement is 1.15 ft~/sack Therefore, 192.0 ft3 / 1.15 ft3/sack = 167 sacks RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchorage State: Alaska Borough: Well: G--SA Field: Kuparuk River st. Perm # 93-48 Date 4/'28/93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length lA 7 3942 28 4854 P_.A 0 0 0 0 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 26 L-80 BTC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/It psi/It 9.4 0,489 0.389 0,0 0,000 -0,100 0.0 0.000 -0.100 0.0 0.000 -43.100 0,0 0.000 -0,100 0,0 0,000 -0.100 0,0 0.000 -0.100 0.0 0.000 -0.100 0,0 0,000 -0,100 0.0 0,000 -0,100 Maximum Minimum Pressure psi 1850 0 0 0 0 0 0 0 0 0 Yield psi BDF 7240 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! 0 #DIV/O! 0 #DIV/0! 0 #OlV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV'/O! Tension Strength K/Lbs 1C 126.204 2C 0 3C 0 4C 0 5C 0 6(3 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 604 4.79 0 #DIV/O! 0 #DN/0! o #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O.I 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 1533 0 0 0 0 0 0 0 0 0 Resist. (:DF 5410 3.530 0 #DIV/O! 0 #DIV/O.I o #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! Page 1 MPUG-SA.XLS State: Well: Field: State Permit it G-SA Kuparuk River 93-48 Engineer. Work Shee~. Date: 4/28/gg Ca~ing T~e Ca~g Size -Inches Casing Length- Feet Hole Diameter-Inches Cement- S~_is111 Cement- Yield111 Cement- Cu~c tt 111 Cement- Cubic It 111 Cen'~ - Sacks112 Cement- Yield112 Cement- Cubic tt 112 Cement- Cubic tt 112 Cement- Sacks113 Cement- Yield113 Cement- Cubic It 113 Cement- Cubic tt 113 Cement- Fill Factor Conducto~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 itDIV/O! SuM~ace 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 I~DIV/0! Liner 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 IIDIV/O! Ca~'rg Tj~e Casing Size -Inches Casing DepIh - Feet Hole Diameter-Inches Cement- Sacks111 Cement-Yield 111 Cement- Cubic It 111 Cement- Cubic tt 111 Cement- Sacks112 Cement- Yield112 Cement- Cubic tt 112 Cement- Cubic It 112 Cement- Sacks113 Cement-Yield 113 Cement- Cubic tt 113 Cement- Cubic tt 113 Cement- Cubic It / Vol Cement-Interval It Top of Cement- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV,,"0! itDIV/O! Intermediate 112 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0! #DIV/O! Rinted 4,'28/93 Production 7.000 4,872.000 8.500 16;7.00 1.15 192.05 192.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 192.05 1,514.51 3,357.5 Measured Dep'th / STATE OF ALASKA -'~ OIL AND GAS CONSERVATION COMMI,. .)N 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well. Alter casing __ Repair well __ Plugging X Time extention Stimulate Change approved program __ Pull tubing ,, Variance Perforate Other 2. Name of Operator 5. Type of Well: 6. Conoco Inc. Development X 3. Address Exploratory ~ 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic__ 4. Location of well at surface , 8. 3176' FNL, 3459' FEL, Sec. 27, T13N, R10E, U.M. NSB AK At top of productive Interval 9. 543' FNL, 4323' FEL, Sec. 27, T13N, R10E, U.M. At effective depth At total depth 93' FNL, 4410' FEL, Sec. 27, T13N, R10E, U.M. 12. Present well condition summary Total depth: measured 5765 feet true vertical 4507 feet NSB AK NSB AK Plugs (measured) None Datum elevation (DF or KB) KB 35' (AGL) Unit or Property name Milne Point Unit Well number G-8 Permit number 91-26 10. APl number 50-029-22141 11. Field/Pool ' Kuparuk River/Schrader Bluff feet Effective depth: measured 5430 feet true vertical 4264 feet Junk(measured) None Casing Length Size Structural Conductor 80' 13-3/8" Surface 2373' 9-5/8" Intermediate Production 4975' 7" Uner 654' 4½" Perforation Depth: measured true vertical Cemented Measured depth Surface Surface True vertical depth TOC@ + 3870' Openhole gravel-packed 115' 115' 2408' 2144' 5010' 3959' 5425' 4260' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 4756' MD Packers and SSSV (type and measured depth) None MAY '1 O 199;5 !as .uJl & U0 s, ,{ 0.mmisst .u 13. Attachments Description summary of proposal, Refer to Form 401 filed for the Milne Point Unit G-8A. 14. Estimated date for commencing operation June 15, 1993 16. If proposal was verbally approved Name of approver Date approved Detailed operations program .. 15. Status of well classification as: BOP sketch Oil. X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / ~-'~ .B.G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance. Mechanical Infegrity Test __ Subsequent form required 10- Approved by orde issioner Form 10-403 Rev 06/15/88 ~,,,~ ~ ~-- -'~----- Date Suspended Date ~/,5-/~f ..~ IApproval N,~ --//' 4:~ SUBMIT IN TRIPLICATE ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2) Loc [2 thru 8~]"' (3) Admin >~Z [9 thru 153 [10 & 13] [14 thru 22] ( 5 ) BO P E ,,~z~.~.,,,~ 4/- .~.~'- ~ ~ '[23 thru 28] Company (/~-~ ~ ~r~ ~Z'~ . Lease & Well __ -- YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease number appropriate .......................................... Does well have a unique name & n~nber ................................ I s conductor st r ing provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface ~ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~Ood~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... NO REMARKS geo 1 o~ty-· engineering' DWJ__ MTM//~ RADS> LG 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nL~nber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' UM ~ ..... MERIDIAN' SM" ~ TYPE: Exp~.. ~ Inj .... P~Hr i 1 1 "~ P "',',, -rz ~0 u'~ ---I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTING FOR: ~~ CONOCO, INC. ~, ~' MPU G-8 RD " SCHRADER BLUFF RECEIVED SEP 2 0 199~ _A/aska .Oil & Gas Cons. ComrnJssion Anchorage ICJ OFILHEI ATCM ATDC BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDCM PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR CONOCO, INC. MPU G-8 RD Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Bulk Density Compensated [RWD] Bulk Density Time Since Drilled [RWD] Bulk Density Data Density Integrated [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Density Long Space Apparent [RWD] Photoelectric Cross Section [RWD] Density Porosity (LS) [RWD] Density Porosity (SS) [RWD] Delta RHO - Density [RWD] Density Short Space Apparent [RWD] Gamma Ray Memory (APl) [RWD] Neutron Far Base [Base] · ~ Neutron Near Base [Base] ~ Neutron Porosity Time Since Drilled [RWD] Neutron Porosity Data Density Integrated [RWD] Neutron Porosity (LS) Borehole Corr [RWD] Neutron Porosity (SS) Borehole COrr [RWD] Neutron Porosity Ratio Borehole Corr. [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Elapsed Time [RWD] Phase Difference Data Density Integrated [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference LS is Limestone SS is Sandstone RWD is Recorded While Drilling -dB -dB g/cc mins pts mmho/m mmho/m g/cc B/e p.u. p.u. g/cc g/cc MWD-API cps cps mins. pts p.u. p.u. deg mins pts ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Mon 13 SEP 93 10:49a != = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 1234567890123456789012345678901234567890123456789012345678.90123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = I , ! Decode LIS Information records: 0=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units 1 =tape units 6 LISTFREQ = 100, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0 = no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0 = OFF, 1 = ON 9 FORCETYP = 0 , ! (1 = BIT,2= LIS ... thru 35=Array Accoustic) (see table) 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (file0001.dat, etc.) 11 WRITETAP = 1 , ! Write Tape-Image File: 0=NO, I=YES 12 SPLITLIS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END _1 != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , ~- COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 100, LISTMAX = 0, STATS = 0, FORCETYP = 0 , -" WRITEASCII = O, WRITETAP = 1 , SPLITLIS = 1 , -- SUBFILES = /0/, INTERPOLATE = 'YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. ! !-- CONSTANT PARAMETERS ........................................... AUTOCURV= O.O00000E+O0 AUTOFILE= O.O00000E+O0 COMMENTS: 1.00000 FORCETYP= O.O00000E+O0 INFOREC$= 1.00000 LISTFREQ= 100.000 LISTMAX = O.O00000E+O0 LISTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPLITLIS = 1.00000 STATS = O.O00000E +00 WRITEA$C= O.O00000E+O0 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 drlength= O.O00000E+O0 listwave= O.O00000E+O0 maxrecln= O.O00000E+O0 minrecln= O.O00000E+O0 nsamples= O.O00000E+O0 numcurvs= O.O00000E+O0 numdatar= O.O00000E+O0 numrecfl= O.O00000E+O0 tfendep = O.O00000E+O0 tflevsp = O.O00000E+O0 ffstdep = O.O00000E +00 wcrbot = O.O00000E +00 wcrlevsp= O.O00000E + O0 wcrtop = O.O00000E +00 !-- ARRAY PARAMETERS .............................................. SUBFILES(1) = O.O00000E+O0 SUBFILES(2) = -9999.00 SUBFILES(3) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(9) = -9999.00 SUBFILE$(10) = -9999.00 SUBFILES(11) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(17) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(23) = -9999.00 SUBFILE$(24) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(30) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(34) = -9999.00 SUBFILE$(35) = -9999.00 SUBFILES(36) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(51) = -9999.00 SUBFILE$(52) = -9999.00 SUBFILES(53) = -9999.00 $UBFILES(54) = -9999.00 SUBFILES(55) = -9999.00 $UBFILES(56) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(59) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(69) = -9999.00 SUBFILE$(70) = -9999.00 SUBFILES(71) = -9999.00 $UBFILES(72) = -9999.00 SUBFILES(73) = -9999.00 SUBFILE$(74) = -9999.00 SUBFILES(75) = -9999.00 SUBFILE$(76) = -9999.00 SUBFILE$(77) = -9999.00 $UBFILES(78) = -9999.00 SUBFILES(79) = -9999.00 SUBFILE$(80) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(84) = -9999.00 8UBFILES({~5) ~ -~Jg<J.O0 8UBFILE~(80) = -9999.00 SUBFILE$(87) = -9999.00 SUBFILES(88) = -9999.00 SUBFILE$(89) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(110) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(128) = -9999.00 !-- STRING PARAMETERS ............................................. INTERPOL- YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1239\1239.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 100) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS= 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE= n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE = 1 to enable this feature) LIS comment record decoding (COMMENTS=l) has been enabled by user input. LIS information record decoding (INFORECS=I) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC = 1) Tape Subtile I is type: LIS **** REEL HEADER **** MWD 93/9/13 1239 01 **** TAPE HEADER **** MWD 93/9/13 1239 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: MPU G-8RD APl NUMBER: 500292214101 OPERATOR: Conoco Inc. LOGGING COMPANY: BAKER HUGHES INTEQ TAPE CREATION DATE: 13 SEP 93 JOB DATA BIT RUN1 BIT RUN2 BIT RUN3 JOB NUMBER: 1239 LOGGING ENGINEER: T. FOSTER OPERATOR WITNESS: J. POLYA SURFACE LOCATION SECTION: 27 TOWNSHIP: 13N RANGE: 10E FNL: 3176 FSL: FEL: 3459 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 59.00 GROUND LEVEL: 31.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 2729.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: NO DEPTH SHIFTING PERFORMED ON THIS TAPE. $ **** FILE HEADER **** MWD .001 1024 LIS COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 2698.0 5233.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 2698.0 5233.0 $ REMARKS: $ CN : Conoco inc. WN : MPU G-8RD FN : Schrader Bluff COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 1213141516 000 I 0000000 1 000 1 Rep Code Count Bytes 68 10 40 Sum: 10 40 40 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 1 2 3 4 5 6 7 8 9 10 RHOB MWD 68 1 G/CC 4 PEF MWD 68 1 BN/E 4 DRHO MWD 68 1 G/CC 4 GR MWD 68 I GAPI 4 FCNTMWD 68 1 CPS 4 NCNT MWD 68 1 CPS 4 NPHI MWD 68 1 PU-S 4 RA MWD 68 1 OHMM 4 ROP MWD 68 1 FPHR 4 RP MWD 68 1 OHMM 4 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 23 FRAMES * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 221 Tape File Start Depth = 2698.000000 Tape File End Depth = 5233.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7552 datums Tape Subtile: 2 290 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subtile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 2698.0 5233.0 $ 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 MWD DENSITY/NEUTRON $ STOP DEPTH 15 JUL 93 M1.33 M1.33 MEMORY 0.0 2698.0 5233.0 0 11.3 48.0 TOOL NUMBER 2501-30 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 42.0 MUD PH; 10,0 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN)' 8.500 DRILLER'S CASING DEPTH (FT): 0.0 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.520 MUD FILTRATE AT MT: 0.480 96.0 MUD CAKE AT MT: 0.000 0.0 0.0 96.0 NEUTRON TOOL MATRIX: SANSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: ALL DENSITY DATA HAS BEEN PROCESSED USING A WDS WEAK FILTER. INTERVAL FROM 2729 TO 4850' MD (2362 TO 3931' TVD) BIT DEPTH WAS DRILLED UP TO 1200 FT/HR. THEREFORE, POROSITY DATA IS NOT GOOD QUALITY DATA. CONOCO PERSONNEL WAS NOT INTERESTED IN THE QUALITY OF THE POROSITY DATA ABOVE 4850' MD (3931' TVD). DRILLER'S 9 5/8" CASING DEPTH: 2729' MD. LOGGER'S 9 5/8" CASING DEPTH: 2730' MD. INTERVAL FROM 5201 TO 5234' MD (4275 TO 4307' TVD) WAS NOT LOGGED DUE TO BIT TO SENSOR OFFSETS. $ CN : Conoco Inc. WN : MPU G-8RD FN : Schrader Bluff COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 1. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 I 0000000 1 000 1 nep(~ode (3cunt Bytes 68 32 128 ~. Sum: 32 128 128 fndun a [F 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 I -dB 4 3 BDCM MWD 68 1 G/CC 4 4 BDEM MWD 68 I MINS 4 5 BDIM MWD 68 1 PTS 4 6 CADE MWD 68 1 MMHO 4 7 CPDE MWD 68 1 MMHO 4 8 DCCM MWD 68 1 4 9 DLAM MWD 68 1 G/CC 4 10 DPEMMWD 68 1 MINS 4 11 DPLMMWD 68 1 PU 4 12 DPSMMWD 68 1 PU 4 13 DRHMMWD 68 1 G/CC 4 14 DSAMMWD 68 1 G/CC 4 15 GRAMMWD 68 1 GAPI 4 16 NFBM MWD 68 1 CPS 4 17 NNBMMWD 68 1 CPS 4 18 NPEM MWD 68 1 MINS 4 19 NPIMMWD 68 1 PTS 4 20 NPLM MWD 68 1 PU 4 21 NPSM MWD 68 1 PU 4 22 NRCM MWD 68 1 RATI 4 23 PDCM MWD 68 1 DEG 4 24 PDEM MWD 68 1 MIN 4 25 PDIM MWD 68 1 PTS 4 26 RACM MWD 68 1 OHMM 4 27 RADE MWD 68 1 OHMM 4 28 ROPA MWD 68 I FPHR 4 29 ROPS MWD 68 1 FPHR 4 30 RPCM MWD 68 1 OHMM 4 31 RPDE MWD 68 1 OHMM 4 32 TCDM MWD 68 1 DEGF 4 128 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# O) 930 BYTES * Total Data Records: 1449 Tape File Start Depth = 2698.000000 Tape File End Depth = 5233.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57310 datums Tape Subtile: 3 1527 records... Minimum record length: 62 bytes Maximum record length: 930 bytes Tape Subtile 4 is type: LIS **** TAPE TRAILER MWD 93/9/13 1239 01 **** REEL TRAILER **** MWD 93/9/13 1239 01 Tape Subtile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 13 SEP 93 10:50a Elapsed execution time = 1 minute, 37.0 seconds. SYSTEM RETURN CODE = 0 Tape Subfile I is type: LIS Tape Subtile 2 is type: LIS DEPTH RHOB FCNT NCNT RP 2698.0000 -999.2500 13.7305 5502.7988 -999.2500 2698.5000 -999.2500 13.7344 5503.3984 -999.2500 2700.0000 -999.2500 13.7461 5505.1973 -999.2500 2800.0000 2.2027 15.2861 5973.7588 8.3613 2900.0000 2.1809 16.5033 6012.5234 10.6480 3000.0000 -999.2500 -999.2500 -999.2500 12.3183 3100.0000 -999.2500 -999.2500 -999.2500 13.7209 3200.0000 2.1515 20.7317 6115.1025 9.8765 3300.0000 -999.2500 17.8750 6088.0000 13.3675 3400.0000 -999.2500 -999.2500 -999.2500 14.8226 3500.0000 2.2199 20.6625 6028.9980 9.6487 3600.0000 2.1474 17.2137 6065.0020 10.5125 3700.0000 2.1095 1,5.7057 0178.9580 8.0380 PEF NPHI -999.2500 59.2597 -999.2500 59.2443 -999.2500 59.1983 2.7239 57.1783 2.5765 51.6374 -999.2500 -999.2500 -999.2500 -999.2500 2.1638 40.1046 -999.2500 47.0386 -999.2500 -999.2500 2.5851 38.9541 2.7059 49.3040 2.2853 57.§~5 DRHO RA -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0493 16.0449 0.0419 16.6963 -999.2500 18.9852 -999.2500 18.0163 0.0159 14.7864 -999.2500 18.8331 -999.2500 23.7456 0.0233 15.5846 0.0071 17.5084 0.0556 10.5356 GR ROP 34.6601 -999.2500 32.2734 -999.2500 32.7679 -999.2500 84.6844 73.8159 75.1108 404.9329 44.8489 404.9329 56.4353 377.9614 45.7127 712.5956 50.1793 125.0528 39.5672 1387.7085 91.5508 201.4245 64.9928 413.4291 69.6609 1240.2874 DEPTH FONT RP RHOB NONT PEF NPHI DRHO RA GR ROP 3800.0000 17.0369 5.5051 3900.0000 15.0362 5.2736 2.1587 6042.0918 2.1630 6258.5264 2.6747 49.9237 2.8032 63.0812 0.0435 7.0472 0.0160 7.4708 63.1605 551.2386 85.0213 472.4216 4000.0000 16.2187 5.9603 2.1529 6153.9980 2.5586 54.7081 -0.0006 7.5098 78.4838 269.9210 4100.0000 18.6805 7.8802 4200.0000 24.7187 8.0133 2.1581 6214.335O 2.3112 6196.0000 2.4610 45.8233 2.5336 31.6316 0.0364 9.3288 0.0910 12.1288 74.7363 1033.3926 59.0796 564.3750 4300.0000 18.0313 14.5259 2.1201 6197.0010 2.4004 47.6218 0.0748 21.9234 52.1119 732.4219 4400.0000 15.8068 80.1860 2.0568 6024.4551 1.8003 56.1061 0.1137 -999.2500 33.6689 708.6326 4500.0000 18.8516 4.6381 2.2198 6227.5000 2.5585 45.1392 0.0214 5.6967 64.8019 767.7454 4600.0000 20.1082 3.1373 4700.0000 18.5580 9.4954 2.1354 6111.0762 2.2072 6212.8574 2.1843 40.4545 2.2947 46.6410 0.0170 3.7069 0.0630 10.5869 51.2678 1377.8564 54.7178 1062.9487 4800.0000 20.8506 3.5050 2.2977 6143.8994 2.9452 38.8821 0.0484 4.0815 88.9055 328.0840 4900.0000 23.1648 3.8536 2.2354 6426.9268 2.9798 36.0436 0.0675 4.7223 60.4414 60.0414 5000.0000 19.1004 3.5989 2.3209 6142.5264 3.1237 43.8093 0.1100 3.63~ 81.4430 43.4521 3100.0000 21.5414 3.1430 Z.ZOOl 6202.8545 ~.~191 37.9414 0.0518 3.7947 92.5341 51.3397 DEPTH RHOB PEF FCNT NCNT NPHI RP DRHO RA GR ROP 5200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.0202 -999.2500 3.0321 -999.2500 59.0631 5233.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 83.5175 Tape File Start Depth = 2698.000000 Tape File End Depth = 5233.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet -rape Subtile 3 is type: LtS DF.P-rH A'rCM A-rDC BDIM CADE cPDE DPEM DPLM DPSM GRAM NFBM NNBM NPLM NPSM NRCM PDIM RACM RADE RPCM RPDF-. TCDM 2698.0000 .999.2500 .999.25OO 34.6601 55.5829 .999.2500 .999.25O0 2698.2500 .999,2500 .999.25OO 32.9784 55.5749 .999.2500 _999.2500 2700.0000 .999.25OO .999.250O 32.7679 55.5193 .999.2500 .999.25O0 2800.0000 104.4444 2.7239 53.4354 220.3333 7.9261 2900.0000 160,4707 2.5765 75.1108 47.7499 398.0000 10.0489 3000.0000 .999.25O0 .999.2500 44.8489 .999.2500 11.5913 .999.2500 .999.2500 .999.2500 13.7305 59.2597 .999.2500 .999.2500 .999.25O0 .999.25O0 -999.25OO 13.7324 59.2520 .999.2500 -999.25OO .999.2500 .999.2500 .999.25O0 13.7461 59.1983 .999.25O0 .999.2500 0.1776 62.3252 29.6650 15.2861 57.1783 22.1866 8.3613 0.1740 59.8934 30.9387 16.5033 51.6374 22.5733 lo.648o .999.25O0 .999.2500 .999.25O0 5502,7988 361.0973 -999.25OO .999.2500 0.1442 52.6726 .999.2500 -999.2500 .999.25O0 Z§,7091 12,3183 .999.2500 .999.2500 .999.2500 55O3.0986 361.0657 .999.2500 .999.2500 .999.25O0 .999.25O0 .999.2500 5505.1973 360.8448 -999.2500 .999.25O0 0.2522 119.5990 27.1074 5973.7588 352.3312 16.0449 19.3125 BDCM DCCM DRHM NPEM pDCM ROPA 0.2418 93.9147 28.4274 6012.5234 328.2726 16.6963 21.2250 0.2108 81.1797 .999,2500 .999,2500 .999.2500 18,9~5Z 23.3611 .999.25O0 .999.2500 -999.25O0 .999.25O0 -999.2500 .999.2500 .999.2S00 .999.25OO .999.2500 .999.2500 -999.25OO .999.2500 .999.2500 .999.2500 .999.2500 .999.25O0 .999.2500 .999.25O0 2.2027 83.2041 0.0493 52.9O56 7.4566 67.9289 BDEM DSAM NPtM PDEM ROPS 2.1809 74.6427 0.0419 45.1182 6.3191 474.5758 .999.2500 69.9621 .999.2500 17.4116 5.7066 424.7444 .999.25O0 .999.2500 .999.2500 14.1500 .999.2500 .999.25O0 .999.2500 .999.25OO .999.2500 14,1750 .999.25O0 .999.2500 .999.2500 .999.2500 .999.2500 14.3500 .999.2500 .999.2500 RECEIVED SEP 2 0 199~ Alaska 0il & Gas Cons. Commission 34.0426 Anchorage 2.1534 2.1205 212.1035 32.5381 73.8159 44.3083 2.1370 2,1068 306.6316 40.2535 4O4.9329 17.1521 .999.2500 .999.2500 .999.2500 16.4416 4O4.9329 DEPTH BDIM DPEM GRAM NPLM PDIM RPCM ATCM CADE DPLM NFBM NPSM RACM RPDE ATDC CPDE DPSM NNBM NRCM RADE TCDM BDCM DCCM DRHM NPEM PDCM ROPA BDEM DLAM DSAM NPIM PDEM ROPS 3100.0000 -999.2500 -999.2500 56.4353 -999.2500 629.4615 12.9151 3200.0000 215.1071 2.1638 45.7127 36.2061 712.2858 9.3373 3300.0000 -999.2500 -999.2500 50.1793 43.0904 863.8749 12.5593 3400.0000 -999.2500 -999.2500 39.5672 -999.2500 926.1428 13.9297 3500.0000 311.9000 2.5851 91.5508 35.0343 1112.5000 9.1239 3600.0000 353.0000 2.7059 64.9928 45.3807 1330.0000 9.9215 0.1607 55.5051 -999.2500 -999.2500 -999.2500 24.8879 13.7209 0.2077 67.6295 32.6586 20.7317 40.1046 19.1924 9.8765 0.1486 53.0979 -999.2500 17.8750 47.0386 26.0222 13.3675 0.0987 42.1131 -999.2500 -999.2500 -999.2500 37.1622 14.8226 0.1909 64.1658 28.6587 20.6625 38.9541 20.7412 9.6487 0.1604 57.1153 32.9007 17.2137 49.3040 24.2639 10.5125 0.2230 72.8818 -999.2500 -999.2500 -999.2500 18.0163 23.8437 0.2748 101.2502 30.2098 6115.1025 270.3268 14.7864 24.2812 0.2126 74.8082 -999.2500 6088.0000 306.8693 18.8331 25.0312 0.1650 67.4646 -999.2500 -999.2500 -999.2500 23.7456 -999.2500 0.2601 103.6405 26.0644 6028.9980 265.2377 15.5846 26.0398 0.2299 95.1251 30.4608 6065.0020 317.5452 17.5084 27.1116 -999.2500 68.6339 -999.2500 3.5596 5.2859 355.7941 2.1515 77.1844 0.0159 3.3356 6.6575 714.0713 -999.2500 67.4764 -999.2500 8.8488 5.3851 104.9636 -999.2500 64.4118 -999.2500 2.7543 5.0003 1388.9399 2.2199 78.0039 0.0233 9.5778 6.7637 265.3867 2.1474 75.0775 0.0071 12.0394 6.3763 457.6961 3.2740 -999.2500 -999.2500 -999.2500 2.4198 377.9614 2.9241 2.1357 2.1251 372.4830 2.0156 712.5956 8.6526 -999.2500 -999.2500 456.0000 7.8875 125.0528 2.5145 -999.2500 -999.2500 -999.2500 1.5268 1387.7085 8.5025 2.1966 2.1811 558.6001 5.4666 201.4245 10.3765 2.1403 2.1355 611.8333 6,0016 413.4291 DEPTH BDIM DPEM GRAM NPLM PDIM RPCM 3700.0000 393.1817 2.2853 69.6609 53.9412 1544.0000 7.6263 3800.0000 415.7141 2.6747 63.1605 46.0174 1678.3333 5.2572 3900.0000 440.1429 2.8032 85.0213 59.5925 1808.3333 5.0394 4000.0000 481.3077 2.5586 78.4838 50.8886 1985.0000 5.6834 4100.0000 509.6251 2.4610 74.7383 41.8790 2166.3330 7.4793 4200.0000 548.4285 2.5336 59.0796 28.0179 2309.5000 7.6021 ATCM CADE DPLM NFBM NPSM RACM RPDE 0.3238 94.9160 35.1194 15.7037 57.6735 12.5838 8.0380 0.5081 141.8996 32.2419 17.0369 49,9237 7.9793 5.5051 0.4745 133.8546 31.9882 15.0362 63.0812 8.5788 5.2736 0.4754 133.1602 32.5794 16.2187 54.7081 8.5513 5.9603 0.3760 107.1945 32.2742 18.6805 45.8233 10.8547 7.8802 0.2687 82.4483 23.3190 24.7187 31.8316 15.0701 8.0133 ATDC CPDE DPSM NNBM NRCM RADE TCDM 0.3682 124.4097 32.7602 6178.9580 354.5184 10.5356 28.3538 0.5725 181.6489 29.7780 6042.0918 320.1886 7.0472 28.8125 0.5418 189.6226 29.5150 6258.5264 375.8998 7.4708 29.3199 0.5392 167.7780 30.1277 6153.9980 341.8730 7.5098 30.0437 0.4376 126.9007 29.8114 6214.3350 300.6364 9.3288 30.6875 0.3370 124.7933 20.5306 6196.0000 225.8446 12.1288 31.2326 BDCM DCCM DRHM NPEM PDCM ROPA 2.1095 84.6942 0.0556 6.5428 7.6559 1070.3831 2.1587 100.6500 0.0435 20.2902 9.8162 554.9108 2.1630 102.6606 0.0160 16.9032 10.0906 479.8108 2.1529 97.0561 -0.0006 22.3425 9.3268 289.51 48 2.1581 85.4573 0.0364 16.2555 7.7594 967.0259 2.3112 64.8182 0.0910 27.1629 7.6733 541.0211 BDEM DLAM DSAM NPIM PDEM ROPS 5.2026 2.0539 2.0168 690.7999 3.0410 1240.2874 4.6311 2.1151 2.0861 720.1819 3.2992 551.2386 16.1725 2.1470 2.1364 745.1578 5.0394 472.4216 21.2796 2.1535 2.1542 829.9999 5.9700 269.9210 15.4502 2.1226 2.0956 871.7775 4.8464 1033.3926 25.1241 2.2203 2.1645 958.0000 16.6714 564.3750 DEPTH BDIM DPEM GRAM NPLM PDIM RPCM 4300.0000 589.3335 2.4004 52.1119 43.6786 2531.6665 13.6086 4400.0000 621.5831 1.8003 33.6689 52.3783 2719.0000 71.1610 4500.0000 653.0001 2.5585 64.8019 41.1800 2872.0000 4.4405 4600.0000 687.4546 2.1843 51.2678 36.5029 3057.0000 3.0213 4700.0000 712.4546 2.2947 54.7178 42.7224 3225.2856 9.0195 4800.0000 783.0000 2.9452 88.9055 34.9439 3500.5000 3.3695 ATOM CADE DPLM NFBM NPSM RACM RPDE 0.1150 45.6134 34.4985 18.0313 47.6218 32.5365 14.5259 -999.2500 -999.2500 38.1963 15.8068 56.1061 -999.2500 80.1860 0.6333 175.5406 28.6684 18.8516 45.1392 6.3101 4.6381 0.9538 269.7677 33.6018 20.1082 40.4545 3.9847 3.1373 0.3266 94.4566 29.4059 18.5580 46.6410 12.5377 9.4954 0.8740 245.0050 24.1110 20.8506 38.8821 4.4077 3.5050 ATDC CPDE DPSM NNBM NRCM RADE TCDM 0.1802 68.8426 32.1166 6197.0010 309.6566 21.9234 32.0000 -999.2500 12.4710 35.9489 6024.4551 346.6548 -999.2500 27.4183 0.6966 215.6066 26.0745 6227.5000 297.6392 5.6967 28.4764 1.0158 318.7454 31.1874 6111.0762 273.8289 3.7069 28.9375 0.3863 105.3146 26.8388 6212.8574 303.9903 10.5869 -999.2500 0.9356 285.3064 21.3514 6143.8994 265.4909 4.0815 30.1562 BDCM DOOM DRHM NPEM PDCM ROPA 2.1201 65.0880 0.0746 203.8209 5.0749 695.7917 2.0568 32.3913 0.1137 23.5366 1.3225 734.0052 2.2198 108.9338 0.0214 23.5450 10.9457 804.6007 2.1354 130.6648 0.0170 29.8845 13.9311 998.9700 2.2072 78.4157 0.0630 25.9531 6.6364 730.8448 2.2977 124.0790 0.0484 50.6509 13.0250 299.9393 BDEM DLAM DSAM NPIM PDEM ROPS 202.5449 2.0452 1.9953 1043.4282 198.1270 732.4219 22.4630 1.9431 1.8673 1097.2727 18.7001 708.6326 21.7236 2.2002 2.1850 1143.2498 16.9967 767.7454 28.9426 2.1437 2.1179 1232.8464 22.9581 1377.8564 24.5623 2.1441 2.1021 1282.7141 19.5120 1062.9487 42.8803 2.2494 2.2311 1487.0000 12.5134 328.0840 DEPTH ATOM ATDC BDCM BDEM BDIM CADE CPDE DOOM DLAM DPEM DPLM DPSM DRHM DSAM GRAM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDCM PDEM PDIM RAOM RADE ROPA ROPS RPCM RPDE TCDM 4900.0000 0.7608 0.8239 2.2354 64.8768 1037.0000 211.7621 259.5001 118.7025 2.1680 2.9798 27.7568 25.1298 0.0675 2.1251 60.4414 23.1648 6426.9268 70.9144 1 687.0000 32.1429 36.0436 249.9770 12.2859 44.8758 3886.0000 5.1570 4.7223 59.3241 60.0414 3.7003 3.8536 33.0000 5000.0000 0.9274 0.9864 2.3209 62.0239 1279.0000 260.5851 277.8636 122.4448 2.2081 3.1237 22.7550 19.9461 0.1100 2.1294 81.4430 19.1004 6142.5264 69.31 43 2287.0000 39.8473 43.8093 289.7542 12.8152 42.3036 4280.0000 4.1205 3.8375 42.4443 43.4521 3.4652 3.5989 34.9375 5100.0000 0.9335 0.9959 2.2651 55.9866 1517.0000 263.5269 318.1685 130.4435 2.2131 3.3191 26.0193 23.3291 0.0518 2.1789 92.5341 21.5414 6202.8545 63.9121 2687.0000 34.0137 37.9414 259.4430 13.9153 38.4242 4679.0000 4.0897 3.7947 46.5430 51.3397 3.0321 3.1430 36.4375 5200.0000 1.1450 1.2019 -999.2500 -999.2500 -999.2500 329.8080 331.1060 132.8958 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.2527 35.9110 5078.0000 3.2131 3.0321 57.4032 59.0631 2.9155 3.0202 38.0625 5233.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 83.5175 83.5175 -999.2500 -999.2500 38.8125 Tape File Start Depth = 2698.000000 Tape File End Depth = 5233.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 4 is type: LIS
