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185-002
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,940 feet N/A feet true vertical 7,429 feet N/A feet Effective Depth measured 9,840 feet feet true vertical 7,363 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.3 / L-80 IBT 9,297' 6,991' Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2 / L-80 / BTRC 9,630' 7,221' 7"x3-1/2" S-3 Perm Hyd 7"x3-1/2" HB Packers and SSSV (type, measured and true vertical depth)7"x3-1/2" 2-B Perm N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 9,219, 9,322 & 9,600 6,938, 7,009 & 7,201 3,520psi 7,240psi9,921' 7,417' Burst N/A Collapse N/A 2,020psi 5,410psi Casing Conductor 9,888' 5,840'Surface Production 13-3/8" 9-5/8" 7" 80' 5,806' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-002 50-029-21266-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047434 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-07 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 115' 761 Size 115' 4,725' 0 10500 48 176150 169 322-691 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1022 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:45 pm, Jun 30, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.30 11:06:57 - 08'00' Taylor Wellman (2143) RBDMS JSB 071123 WCB 1-9-2024 DSR-7/6/23 _____________________________________________________________________________________ Revised By: TDF 6/27/2023 SCHEMATIC Milne Point Unit Well: MP C-07 Last Completed: 5/13/2003 PTD: 185-002 TD =9,940’ (MD) / TD =7,429’(TVD) Initial KB Elev.: 52’ (Alaska United #3) Original ground elevation: 17’ 7” 6 13 14 15 18 15 17 9-5/8” 1 4 16 MIN ID = 2.750” @ 9,630’ PBTD = 9,840’(MD) / PBTD =7,363’(TVD) 10 13-3/8” 12 19 2 3 5 7 Hole In Tubing @ 9,489’ Cement in IA between packers Fish – Milled Cement Retainers & Bridge Plug 8 11 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8” Conductor 48# / H-40 / N/A N/A” Surface 115’ N/A 9-5/8" Surface 36# / K-55 / BTRC 8.921” Surface 5,840’ 0.0773 7" Production 26# / L-80 / BTRC 6.276” Surface 9,921’ 0.0383 TUBING DETAIL 3-1/2" Tubing 9.3# / L-80 / IBT 2.992” Surface 9,297’ 0.0087 3-1/2" Tubing 9.2# / L-80 / BTRC 2.992” 9,322’ 9,630’ 0.0087 JEWELRY DETAIL No Depth Item GLM Detail –3-1/2” x 1.” MMG w/RK Latch 1 2,288’ST 6: Port= 12, Dev.= 30, VLV= Dome, TVD= 2,186’, 4/22/2014 2 4,510’ST 5: Port= 12 Dev.= 45, VLV= Dome, TVD= 3,803’, 4/22/2014 3 6,175’ST 4:Port= 16, Dev.= 46, VLV= SO, TVD= 4,936’, 4/22/2014 4 7,524’ST 3:Port= 0, Dev.= 48, VLV= DMY, TVD= 5,789’, 4/22/2014 5 8,428’ST 2: Port= 0, Dev.= 50, VLV= DMY, TVD= 6,396’, 5/14/2003 6 9,052’ST 1: Port= 0, Dev.= 51, VLV= DMY, TVD= 6,823’, 6/11/2011 7 9,110’ 3-1/2” Baker CMD Non-Elastomer Sliding Sleeve 8 9,166’ 3-1/2” HES “X” Nipple ID= 2.813 9 9,219’ 7” x 3-1/2” Baker S-3 Hydro Set Permanent Packer 10 9,277’ 3-1/2” HES “X” Nipple w/RHC Sleeve ID= 2.813 11 9,287’ 3-1/2” Mule Shoe with Stop Ring (bottom at 9,297’) 12 9,322’ 7” x 3-1/2” Baker “HB” Packer 13 9,360’ 3-1/2”Camco “W-1” Nipple ID= 2.812 14 9,393’’ 3-1/2” Camco MMG-2 Gas Lift Mandrel 15 9,438’’ 3-1/2” Camco MMG-2 Gas Lift Mandrel 16 9,478’ 3 Blast Joints 17 9,600’ 7” x 3-1/2”Baker “2-B” Permanent Packer 18 9,622’ 3-1/2” Camco “D” Nipple,ID= 2.750” 19 9,630' 3-1/2” WLEG OPEN HOLE / CEMENT DETAIL 9-5/8"552 bbls Permafrost E plus 56 bbls Class “G” and 9 bbls Permafrost C top job in 12-1/4” hole 7” 76 bbls Class “G” plus 60 sx Permafrost E top job in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 52° @ 6,900’ Hole Angle thru perforations= 48° TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC, w/ 3-1/2” FMC Tubing Hanger, 3-1/2” NSCT top and bottom CIW H Profile GENERAL WELL INFO API: 50-029-21266-00 Drilled and Completed by Alaska United #3 – 3-11-1985 RWO Convert to ESP by EWS Rig 4 – 5/27/1990 ESP RWO by EWS Rig 4 – 2/25/1992 Gas Lift RWO by Nabors 4ES – 5/13/2003 Squeeze and Frac with CTU – 6/6/2011 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Shot Date Status Size KUP C1 9,470’ 9,500’ 7,111’ 7,132’ 30 1/20/2023 Open 2-1/2” KUP C1 9,472’ 9,486’ 7,112’ 7,122’ 14 3/11/1985 Squeezed 5” KUP B6 9,540’ 9,565’ 7,159’ 7,177’ 25 12/22/2022 Open 2-1/2” 9,565’ 9,590’ 7,177’ 7,194’ 25 12/22/2022 Open 2-1/2” KUP B6 9,546’ 9,552’ 7,163’ 7,168’ 6 3/11/1985 Squeezed 5” 9,580’ 9,586’ 7,187’ 7,191’ 6 3/11/1985 Squeezed 5” KUP A3 9,686’ 9,706’ 7,259’ 7,273’ 20 3/11/1985 Open 5” KUP A2 9,726’ 9,752’ 7,286’ 7,303’ 26 3/11/1985 Open 5” Well Name Rig API Number Well Permit Number Start Date End Date MP C-07 E-Line 50-029-21266-00-00 185-002 12/22/2022 5/15/2023 12/23/2022 - Friday No operations to report. 12/21/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/22/2022 - Thursday WELL SHUT IN ON ARRIVAL. PRESSURE TEST PCE TO 250#LP-3,500#HP. RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT, 1-1/16" WEIGHT, 1 11/16" GR/CCL, 2 1/2" PERF GUN (25' LOADED W/ GEO CONNEX CHARGES). GUN #1: CCL OFFSET=7.7', PERF DEPTH=9,565'-9,590', CCL STOP DEPTH=9,557.3'. GUN #2: CCL OFFSET=7.7', PERF DEPTH=9,540'-9,565'', CCL STOP DEPTH=9,532.3'. WELL LEFT SHUT IN. No operations to report. No operations to report. 12/24/2022 - Saturday No operations to report. 12/27/2022 - Tuesday 12/25/2022 - Sunday No operations to report. 12/26/2022 - Monday RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT, 1-1/16" WEIGHT, 1 11/16" GR/CCL, 2 1/2" PERF GUN (25' LOADED W/ GEO CONNEX CHARGES). GUN #1: CCL OFFSET=7.7', PERF DEPTH=9,565'-9,590', CCL STOP DEPTH=9,557.3'. GUN #2: CCL OFFSET=7.7', PERF DEPTH=9,540'-9,565'', Well Name Rig API Number Well Permit Number Start Date End Date MP C-07 E-Line 50-029-21266-00-00 185-002 12/22/2022 5/15/2023 No operations to report. No operations to report. 1/21/2022 - Saturday No operations to report. 1/24/2023 - Tuesday 1/22/2023 - Sunday No operations to report. 1/23/2023 - Monday 1/20/2022 - Friday WELL FLOWING ON ARRIVAL. PRESSURE TEST PCE 200#LP-3,000#HP. RIH W/ 1 7/16" CHD (1" FN), 1 11/16" GR/CCL, 2 1/2" PERF GUN (30' LOADED W/ 11 GRAM CONNEX CHARGES). CCL OFFSET=8.5', PERF DEPTH=9,470'-9,500', CCL STOP DEPTH=9,461.5'. WELL LEFT SHUT IN. 1/18/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/19/2022 - Thursday No operations to report.This is all from 2023. The 2022 year is a typo, apparently. -WCB RIH W/ 1 7/16" CHD (1" FN), 1 11/16" GR/CCL, 2 1/2" PERF GUN (30' LOADED W/ 11 GRAM CONNEX CHARGES). CCL OFFSET=8.5', PERF DEPTH=9,470'-9,500 Well Name Rig API Number Well Permit Number Start Date End Date MP C-07 E-Line 50-029-21266-00-00 185-002 12/22/2022 5/15/2023 2/3/2023 - Friday No operations to report. 2/1/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/2/2023 - Thursday No operations to report. No operations to report. No operations to report. 2/4/2023 - Saturday WELL FLOWING ON ARRIVAL. RAN 2.67'' CENT., 2-1/2 RB (steel), TAG @ 9576' SLM, COULDN'T GET ANY DEEPER MADE (2) 2.67'' CENT., 10' X 2.5'' BAILER (ball) RUNS, WORKED FROM 9576' SLM DOWN TO 9580' SLM (recover 3 gallons sand). WELL FLOWING ON DEPARTURE. 2/7/2023 - Tuesday 2/5/2023 - Sunday No operations to report. 2/6/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-07 E-Line 50-029-21266-00-00 185-002 12/22/2022 5/15/2023 3/24/2022 - Friday No operations to report. 3/22/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/23/2022 - Thursday No operations to report. No operations to report. T/I/O= 1700/1600/20 TBG FL @ 5035'. IA FL @ 6175'. 3/25/2022 - Saturday No operations to report. 3/28/2023 - Tuesday 3/26/2023 - Sunday Freeze Protect Flowline (Header Pressure) Pumped 10 bbls 60/40 down Flowline 3/27/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-07 E-Line 50-029-21266-00-00 185-002 12/22/2022 5/15/2023 5/5/2023 - Friday No operations to report. 5/3/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O=250/700/100 Freeze protect flowline (Pre CTU) Pumped 10 bbls 60/40 down flowline. Final Whps=250/700/100. LRS CTU #2 - 1.50" Blue Coil Job Objective; FCO. MIRU CTU. 5/4/2023 - Thursday Make up 2" DJN drift BHA and RIH. Tag at 9550' ctm. Cleanout to 9601' ctm. Pump 20 bbl gel pill off bottom and chase ooh so surface. Lay in FP from 2500. RDMO CTU. WELL S/I ON ARRIVAL, DSO NOTIFIED. RAN 10'x2.5" PUMP BAILER W/ MULE SHOE BALL & S/D @ 9,600' SLM, RECOVERED ~2 CUPS SAND. RAN DUAL SPARTEK GAUGES & MADE 1 15min STOP @ 9,350' SLM AS PER WSL (good data). RAN 2.65" CENT, 2.5" RB (steel) & S/D @ 9,600' SLM, UNABLE TO LATCH PRONG AFTER 15min. RAN 2.67" CENT, 2'x1-7/8" STEM, 2.65" CENT, 2.5" LIB & S/D @ 9,600' SLM, HAVE FRAC SAND EMBEDED IN LIB BOTTOM. WELL S/I ON DEPARTURE, DSO NOTIFIED. No operations to report. 5/6/2023 - Saturday No operations to report. 5/9/2023 - Tuesday 5/7/2023 - Sunday No operations to report. 5/8/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-07 E-Line 50-029-21266-00-00 185-002 12/22/2022 5/15/2023 5/12/2023 - Friday MAKE 6 RUNS W/ 10' x 2.5" PUMP BAILER TO 9,600' SLM (recover 2.5 gal of fill/frac sand). 5/10/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 5/11/2023 - Thursday RAN 2.65" CENT, 10' x 2.5" PUMP BAILER TO 9,600' SLM, (recover 2 cups of cabolite, and fill, metal marks on btm). RAN 2.65" CENT, 2.5" RS, TO CA-2 PLUG AT 9,600' SLM (metal marks on rs, see log) No operations to report. MAKE 4 RUNS W/ 10' x 2.50" PUMP BAILER TO 9,600' SLM, (recover approx 1 gal of fill/frac sand). RAN 2.65" CENT, 2.5" SPLIT SKIRT JUS TO 9,622' MD, PULL CA-2 PRONG. MAKE 2 ATTEMPTS TO PULL CA-2 PLUG BODY W/ 3" RB TO 9,622' MD. 5/13/2023 - Saturday RAN 10' x 2.5" PUMP BAILER TO 9,600' SLM (recover 4 cups of fill). PULL CA-2 PLUG IN D-NIP @ 9,622' MD (see log). 5/16/2023 - Tuesday 5/14/2023 - Sunday GREASE CREW SERVICE TREE (all valves not holding). BAIL W/ 10' x 2.5" PUMP BAILER FROM 9,587' SLM - 9,600' SLM (recover 7 gal of fill/frac sand, see log). RAN 3" RB (steel) ATTEMPT TO PULL CA-2 PLUG BODY @ 9,622' MD. 5/15/2023 - Monday Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU C-07 50029212660000 185002 1/20/2023 AK E-LINE Perf Paxton 6 50133207070000 222054 1/24/2023 AK E-LINE Perf TBF A-07 50733200360000 167046 1/13/2023 AK E-LINE CBL TBF A-18 50733201430000 168076 1/22/2023 AK E-LINE Tubing Punch TBU D-09RD 50733201310100 181080 1/18/2023 AK E-LINE LDL Please include current contact information if different from above. By Meredith Guhl at 11:24 am, Feb 06, 2023 T37486 T37487 T37488 T37489 T37490 MPU C-07 50029212660000 185002 1/20/2023 AK E-LINE Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.06 11:33:21 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/04/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230104 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 09-45 50029220830000 190115 12/18/2022 READ Multi-Array-Pprof MPU C-07 50029212660000 185002 12/22/2022 AK E-LINE CCL Perf Please include current contact information if different from above. By Meredith Guhl at 1:06 pm, Jan 04, 2023 T37416 T37417MPU C-07 50029212660000 185002 12/22/2022 AK E-LINE CCL Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.04 13:10:29 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,940'N/A Casing Collapse Conductor M/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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9,297' 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.2 / L-80 / BTRC 9,630' 12/15/2022 7"x3-1/2" S-3 Perm Hyd., 7"x3-1/2" HB & 7"x3-1/2" 2-B Perm and N/A 9,219 MD/ 6,938 TVD, 9,322 MD/ 7,009 TVD & 9,600 MD/ 7,201 TVD and N/A See Schematic See Schematic 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 185-002 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21266-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT C-07 Length Size Proposed Pools: 115' 115' TVD Burst PRESENT WELL CONDITION SUMMARY 7,429' 9,840' 7,363' 3,240 N/A 80' 13-3/8" MILNE POINT MD N/A 3,520psi 7,240psi 4,725' 7,417' 5,840' 9,921' 3-1/2" 9.3 / L-80 IBT Perforation Depth MD (ft): 9-5/8" 7" 5,806' 9,888' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Anne Prysunka at 11:52 am, Dec 07, 2022 322-691 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.12.07 10:25:12 -09'00' David Haakinson (3533) X DLB 12/07/2022 10-404 3,240 MGR09DEC22 DSR-12/8/22gCW 12/09/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.09 16:12:16 -09'00' RBDMS JSB 121222 EL Add Perf Well: MPU C-07 Date: 12/2/2022 Well Name:MPU C-07 API Number:50-029-21266-00 Current Status:Producer - Offline Pad:C-Pad Estimated Start Date:12/15/2022 Rig:SL & EL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner Permit to Drill Number:185-002 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer: AFE Number:222-01363 Job Type:Perforate Current Bottom Hole Pressure: 3,963 psi @ 7,234’ TVD SBHPS on 05/09/2019 | 10.5 PPGE MPSP:3,240 psi (0.1psi/ft gas gradient) Max Deviation:52 deg @ 6,900’ MD Min ID:2.75 D-nipple @ 9,622’ Brief Well Summary: Well C-07 is a Kuparuk producer currently producing from the Kuparuk A2 and A3 sands. The well was initially a Kuparuk A and C producer until the C-sand perforations were squeezed with cement prior to an A-sand refrac. The C-sand formation is currently cemented behind pipe. The B-silts were never produced. Well C-07 is currently shut-in due to CFP unable to handle the high gas rate from the A-sand. Objective: x Isolate A-sand. x Perforate and flow the B-silt sand. x Perforate C-sand after B-silt flow period. Notes Regarding the Well & Design x 3 blast joints @ 9,478’ (4.25” OD, 2.992” ID, 20’ jts) x Last deepest entry, SL SBHP, 9,650’ MD, 5-9-2019 x B-silt/C-sand reservoir pressure estimated at 4,200 psi. Procedure Slickline Procedure (No Sundry Required) 1. MIRU Slickline Unit. PT PCE to 250 psi Low / 3,500 psi High. 2. MU 25’ of 2-1/2” Dummy Drift Gun and attempt to drift to perf depth @ 9,590’ MD. a. Last tbg drift: SBHP 5-9-2019 @ 9,650’ 3. Set 2.75” CA-2 plug in 2.75” D-nipple at 9,622’ MD with 3’+ prong. 4. PT tubing to 1,000 psi to confirm plug set, and cement is still competent across C-sand. 5. RDMO Slickline. E-line Perforating Procedure (SUNDRY REQUIRED) 6. MIRU EL unit and PT PCE to 250psi Low / 3,500 psi High. 7. PU Perf Gun BHA and perforate the interval listed below with two 25’ gun runs. a. Document changes in wellhead pressure and condition of guns as they return. 8. Perform log correlation pass. Contact OE or Geo to correlate to openhole log. 9. Contact Geologist and/or Ops Engineer to review depth and planned perforation depths prior to firing guns. -00 DLB EL Add Perf Well: MPU C-07 Date: 12/2/2022 a. Ops Engineer: Scott Pessetto scott.pessetto@hilcorp.com; (801) 822-2203 b. Geologist: Graham Emerson graham.emerson@hilcorp.com; (907) 793-0315 c. Perforating Guns: 2 - 2-1/2” HMX, 6 SPF, 60 degree phase guns. Formation Length (ft) Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Kuparuk B Silts ±50’ ±9,540’ ±9,590’ ±7,159’ ±7,194’ 10. RDMO EL unit. 11. Bring well on production to flow the B-silt sand. E-line Perforating Procedure (SUNDRY REQUIRED) 12. MIRU EL unit and PT PCE to 250psi Low / 3,500 psi High. 13. PU Perf Gun BHA and perforate the interval listed below. a. Document changes in wellhead pressure and condition of guns as they return. 14. Perform log correlation pass 15. Contact Geologist and/or Ops Engineer to review depth and planned perforation depths prior to firing guns. b. Ops Engineer: Scott Pessetto scott.pessetto@hilcorp.com; (801) 822-2203 c. Geologist: Graham Emerson graham.emerson@hilcorp.com; (907) 793-0315 d. Perforating Guns: 2 - 2-1/2” HMX, 6 SPF, 60 degree phase guns. Formation Length (ft) Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Kuparuk C ±30’ ±9,470’ ±9,500’ ±7,110’ ±7,131’ 16. RDMO EL unit. 17. Bring well on production to flow the C-sand with the B-silt sand. Attachments: 1. Schematic 2. Proposed schematic _____________________________________________________________________________________ Revised By: TDF 12/6/2022 SCHEMATIC Milne Point Unit Well: MP C-07 Last Completed: 5/13/2003 PTD: 185-002 TD =9,940’ (MD) / TD =7,429’(TVD) Initial KB Elev.: 52’ (Alaska United #3) Original ground elevation: 17’ 7” 6 13 14 15 18 15 17 9-5/8” 1 4 16 MIN ID = 2.750” @ 9,630’ PBTD = 9,840’(MD) / PBTD =7,363’(TVD) 10 13-3/8” 12 19 2 3 5 7 Hole In Tubing @ 9,489’ Cement in IA between packers Fish – Milled Cement Retainers & Bridge Plug 8 11 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8” Conductor 48# / H-40 / N/A N/A” Surface 115’ N/A 9-5/8" Surface 36# / K-55 / BTRC 8.921” Surface 5,840’ 0.0773 7" Production 26# / L-80 / BTRC 6.276” Surface 9,921’ 0.0383 TUBING DETAIL 3-1/2" Tubing 9.3# / L-80 / IBT 2.992” Surface 9,297’ 0.0087 3-1/2" Tubing 9.2# / L-80 / BTRC 2.992” 9,322’ 9,630’ 0.0087 JEWELRY DETAIL No Depth Item GLM Detail – 3-1/2” x 1.” MMG w/ RK Latch 1 2,288’ST 6: Port= 12, Dev.= 30, VLV= Dome, TVD= 2,186’, 4/22/2014 2 4,510’ST 5:Port= 12 Dev.= 45, VLV= Dome, TVD= 3,803’, 4/22/2014 3 6,175’ST 4: Port= 16, Dev.= 46, VLV= SO, TVD= 4,936’, 4/22/2014 4 7,524’ST 3: Port= 0, Dev.= 48, VLV= DMY, TVD= 5,789’, 4/22/2014 5 8,428’ST 2:Port= 0, Dev.= 50, VLV= DMY, TVD= 6,396’, 5/14/2003 6 9,052’ST 1: Port= 0, Dev.= 51, VLV= DMY, TVD= 6,823’, 6/11/2011 7 9,110’ 3-1/2” Baker CMD Non-Elastomer Sliding Sleeve 8 9,166’ 3-1/2” HES “X” Nipple ID= 2.813 9 9,219’ 7” x 3-1/2” Baker S-3 Hydro Set Permanent Packer 10 9,277’ 3-1/2” HES “X” Nipple w/RHC Sleeve ID= 2.813 11 9,287’ 3-1/2” Mule Shoe with Stop Ring (bottom at 9,297’) 12 9,322’ 7” x 3-1/2” Baker “HB” Packer 13 9,360’ 3-1/2”Camco “W-1” Nipple ID= 2.812 14 9,393’’ 3-1/2” Camco MMG-2 Gas Lift Mandrel 15 9,438’’ 3-1/2” Camco MMG-2 Gas Lift Mandrel 16 9,478’ 3 Blast Joints 17 9,600’ 7” x 3-1/2”Baker “2-B” Permanent Packer 18 9,622’ 3-1/2” Camco “D” Nipple,ID= 2.750” 19 9,630' 3-1/2” WLEG PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Shot Date Status Size KUP C1 9,472’ 9,486’ 7,112’ 7,122’ 14 3/11/1985 Squeezed 5” KUP B6 9,546’ 9,552’ 7,163’ 7,168’ 6 3/11/1985 Squeezed 5” 9,580’ 9,586’ 7,187’ 7,191’ 6 3/11/1985 Squeezed 5” KUP A3 9,686’ 9,706’ 7,259’ 7,273’ 20 3/11/1985 Open 5” KUP A2 9,726’ 9,752’ 7,286’ 7,303’ 26 3/11/1985 Open 5” OPEN HOLE / CEMENT DETAIL 9-5/8"552 bbls Permafrost E plus 56 bbls Class “G” and 9 bbls Permafrost C top job in 12-1/4” hole 7” 76 bbls Class “G” plus 60 sx Permafrost E top job in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 52° @ 6,900’ Hole Angle thru perforations= 48° TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC, w/ 3-1/2” FMC Tubing Hanger, 3-1/2” NSCT top and bottom CIW H Profile GENERAL WELL INFO API: 50-029-21266-00 Drilled and Completed by Alaska United #3 – 3-11-1985 RWO Convert to ESP by EWS Rig 4 – 5/27/1990 ESP RWO by EWS Rig 4 – 2/25/1992 Gas Lift RWO by Nabors 4ES – 5/13/2003 Squeeze and Frac with CTU – 6/6/2011 _____________________________________________________________________________________ Revised By: TDF 12/6/2022 PROPOSED Milne Point Unit Well: MP C-07 Last Completed: 5/13/2003 PTD: 185-002 TD =9,940’ (MD) / TD =7,429’(TVD) Initial KB Elev.: 52’ (Alaska United #3) Original ground elevation: 17’ 7” 6 13 14 15 18 15 17 9-5/8” 1 4 16 MIN ID = 2.750” @ 9,630’ PBTD = 9,840’(MD) / PBTD =7,363’(TVD) 10 13-3/8” 12 19 2 3 5 7 Hole In Tubing @ 9,489’ Cement in IA between packers Fish – Milled Cement Retainers & Bridge Plug 8 11 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8” Conductor 48# / H-40 / N/A N/A” Surface 115’ N/A 9-5/8" Surface 36# / K-55 / BTRC 8.921” Surface 5,840’ 0.0773 7" Production 26# / L-80 / BTRC 6.276” Surface 9,921’ 0.0383 TUBING DETAIL 3-1/2" Tubing 9.3# / L-80 / IBT 2.992” Surface 9,297’ 0.0087 3-1/2" Tubing 9.2# / L-80 / BTRC 2.992” 9,322’ 9,630’ 0.0087 JEWELRY DETAIL No Depth Item GLM Detail –3-1/2” x 1.” MMG w/RK Latch 1 2,288’ST 6: Port= 12, Dev.= 30, VLV= Dome, TVD= 2,186’, 4/22/2014 2 4,510’ST 5: Port= 12 Dev.= 45, VLV= Dome, TVD= 3,803’, 4/22/2014 3 6,175’ST 4:Port= 16, Dev.= 46, VLV= SO, TVD= 4,936’, 4/22/2014 4 7,524’ST 3:Port= 0, Dev.= 48, VLV= DMY, TVD= 5,789’, 4/22/2014 5 8,428’ST 2: Port= 0, Dev.= 50, VLV= DMY, TVD= 6,396’, 5/14/2003 6 9,052’ST 1: Port= 0, Dev.= 51, VLV= DMY, TVD= 6,823’, 6/11/2011 7 9,110’ 3-1/2” Baker CMD Non-Elastomer Sliding Sleeve 8 9,166’ 3-1/2” HES “X” Nipple ID= 2.813 9 9,219’ 7” x 3-1/2” Baker S-3 Hydro Set Permanent Packer 10 9,277’ 3-1/2” HES “X” Nipple w/RHC Sleeve ID= 2.813 11 9,287’ 3-1/2” Mule Shoe with Stop Ring (bottom at 9,297’) 12 9,322’ 7” x 3-1/2” Baker “HB” Packer 13 9,360’ 3-1/2”Camco “W-1” Nipple ID= 2.812 14 9,393’’ 3-1/2” Camco MMG-2 Gas Lift Mandrel 15 9,438’’ 3-1/2” Camco MMG-2 Gas Lift Mandrel 16 9,478’ 3 Blast Joints 17 9,600’ 7” x 3-1/2”Baker “2-B” Permanent Packer 18 9,622’ 3-1/2” Camco “D” Nipple,ID= 2.750” –Plug Set 12/X/2022 19 9,630' 3-1/2” WLEG OPEN HOLE / CEMENT DETAIL 9-5/8"552 bbls Permafrost E plus 56 bbls Class “G” and 9 bbls Permafrost C top job in 12-1/4” hole 7” 76 bbls Class “G” plus 60 sx Permafrost E top job in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 52° @ 6,900’ Hole Angle thru perforations= 48° TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” 5M FMC, w/ 3-1/2” FMC Tubing Hanger, 3-1/2” NSCT top and bottom CIW H Profile GENERAL WELL INFO API: 50-029-21266-00 Drilled and Completed by Alaska United #3 – 3-11-1985 RWO Convert to ESP by EWS Rig 4 – 5/27/1990 ESP RWO by EWS Rig 4 – 2/25/1992 Gas Lift RWO by Nabors 4ES – 5/13/2003 Squeeze and Frac with CTU – 6/6/2011 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Shot Date Status Size KUP C1 9,470’ 9,500’ 7,111’ 7,132’ 30 TBD Future 2-1/2” KUP C1 9,472’ 9,486’ 7,112’ 7,122’ 14 3/11/1985 Squeezed 5” KUP B6 9,540’ 9,570’ 7,159’ 7,180’ 30 TBD Future 2-1/2” 9,570’ 9,590’ 7,180’ 7,194’ 20 TBD Future 2-1/2” KUP B6 9,546’ 9,552’ 7,163’ 7,168’ 6 3/11/1985 Squeezed 5” 9,580’ 9,586’ 7,187’ 7,191’ 6 3/11/1985 Squeezed 5” KUP A3 9,686’ 9,706’ 7,259’ 7,273’ 20 3/11/1985 Open 5” KUP A2 9,726’ 9,752’ 7,286’ 7,303’ 26 3/11/1985 Open 5” STATE OF ALASKA • ALASKA AND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IN Exploratory ❑ - 185 -0020 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 M^ 50- 029 - 21266 -00 -00 8. Property Designation (Lease Number) : f 9. Well Name and Number: ADLO- 047434 MPC -07 10. Field /Pool(s): MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 9940 feet Plugs (measured) None feet true vertical 7429.42 feet Junk (measured) None feet Effective Depth measured 9840 feet Packer (measured) 9219 9322 9600 feet true vertical 7362.51 feet (true vertical) 6938 7009 7201 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 48# H -40 35 - 115 35 - 115 1740 750 Surface 5806' 9 -5/8" 36# K -55 34 - 5840 34 - 4725 3520 2020 Intermediate Production 9888' 7" 26# L -80 33 - 9921 33 - 7417 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 32 - 9297 32 - 6991 3-1/2" 9.3# L -80 9321 - 9630 7008 - 7221 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker S -3 Packer 9219 6938 3 -1/2" Baker HB Packer 9322 7009 3 -1/2" Baker 2 -B Perm. Packer 9600 7201 12. Stimulation or cement squeeze summary: Intervals treated (measured): r Treatment descriptions including volumes used and final pressure:`' JUL 1 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 326 77 140 170 Subsequent to operation: 354 106 125 114 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ' 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGD 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: NA Contact Joe Lastufka Printed N- - -- Lastu 4,11116,. Title Petrotechnical Data Technologist Signat ' ,IMP' , _ Phone 564 -4091 Date 7/12/2011 aW. `. ' BDMS JUC 13 1011 �"�. -_- � , L 7.13 . Form 10 -404 Revised 10/2010 Submit Original Only 7704 MPC -07 185 -002 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC -07 3/11/84 PER 9,546. 9,552. 7,163.61 7,167.74 MPC -07 3/1/85 PER 9,580. 9,586. 7,186.96 7,191.06 MPC -07 3/11/85 PER 9,472. 9,486. 7,112.35 7,122.07 MPC -07 3/11/85 PER 9,686. 9,706. 7,259.04 7,272.56 MPC -07 3/11/85 PER 9,726. 9,752. 7,286.05 7,303.55 MPC -07 2/25/92 STC 9,322. 9,600. 7,008.64 7,200.62 MPC -07 5/4/11 BPS 9,520. 9,752. 7,145.66 7,303.55 MPC -07 5/8/11 SQZ 9,375. 9,520. 7,045.2 7,145.66 MPC -07 5/11/11 BPP 9,520. 9,752. 7,145.66 7,303.55 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • MPC -07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/31/2011;"* *SLB Frac Crew * ** Job Scope: Fracture Targeted A2 /A3 Kuparuk Sands i « <InterAct Not Publishing »> Rig up frac equipment, LRS and Stinger tree saver. Pump break down /step down test, Scour Stage, Data Frac. Datafrac analysis !showed FG = 0.68, leak -off coef = 0.003 and final estimated net pressure build of — i 1000 psi. Pump Frac at 20 bpm using 40# x -link gel. Pad stage of 250 bbls. 1 PPA Flat stage 16/20 ceramic proppant w. 5 gpt of L065 (Scale Inhibitor) for a total of 42 gals in 100 bbls. Ramp 1 PPA - 4 PPA in 300 bbls. Ramp 4 PPA - 10 PPA in 450 bbls. 10 PPA Flat in 283 bbls. Flush vols of 27 bbls XL Gel, 27 bbls of non -XL Gel 26 bbls diesel placing freeze protect at —2987' 202,393 Ibs of 16/20 proppant 'behind pipe and 2,112 Ibs in Liner. Sand top est — 100' above top perf. ** *Job Complete * ** _........, .. . 5/31/2011 'T /I /0 =X /0/0 Assisted SLB crew w/ Frac. Pumped 3 bbls DSL down the IA to pressure up to 3000 psi. Pumped a total of 12 bbls DSL down the IA and bled as needed to maintain #3500 psi during job (bled IAP, 2.6 bbls fluid @ end of job). ** IA ;valve left open to gauges upon departure * *. FW P's= 2350/500/0 ;SLB Frac crew rigging down on Departure. t { E { 2 6/22/2011 !ASRC Test Unit #1, Continue Frac Flowback, ** *Job in Progress * ** Inlet MPC -07, Outlet MPC -23. I` 6/25/2011;ASRC Test Unit #1, End 6 hour test, Rig down Leave location, ** *Job Complete * ** Inlet MPC -07, Outlet MPC -23. 3 • • FLUIDS PUMPED BBLS 20 SEAWATER 45 DIESEL 371 20# LINEAR GEL 1856 YF140ST (X -LINK) 1530 J922 WIDEFRAC 100 ST 3822 TOTAL FLUIDS PUMPED GALS 85 F103 EZEFLO 42 L065 SCALE INHIBITOR 656 J877 SLURRY GUAR POLYMER 783 TOTAL FLUIDS PUMPED LBS 36 M275 MICROBIOSIDE 550 J475 BREAKER, EB -CLEAN 204,505 16/20 PROPPANT 205,091 TOTAL ` , • I D Tree: 3 1/8" - 5M FMC MP C-07 KDB - SL = 52 deg Wellhead: 11" 5M FMC KDB - GL = 32 deg w/ 3 1/2" FMC Tubing Hanger, 3.5" NSCT top & btm CIW H profile Ilk t 13 -3/8" 48# H-40 1 115' I ` GLV atrangement seen_ 0646 drawing was*** 4 Ptil f& OthirttYs twify if.thts re; the teiW+t 9 -5/8" 36# K -55 Btrsl 5,840'1 4 lip- " , 1.5 "X31/2" MMGw /RK KOP @ 900' ' # and tvd dg • Max. hole angle = 52 ° @ 5396' Hole angle thru' perfs = 47° 6 2,288' 2,186' 30 5 4,510' 3,803' 46 4 6,175' 4,936' 51 t 3 7,524' 5,789' 49 2 8,428' 6,396 46 1 9,052' 6,823' 46 7" 26 #/ft , L -80, BTRC Casing. Ilk 4 Bbis/ft = .0383 ID= 6.151" 3.5" 9.3 #/ft , L -80 , IBT. 3.5" Baker CMD Sliding sleeve ( 9,110' I Bbls /ft = .0087 ID = 2.992" 3.5" HES X- Nipple ( 2.813 ") 1 9,166 I 7" x 3.5" Baker S -3 Perm Pkr. 1 9,219' I 1 3.5" HES X- Nipple ( 2.813 ' ) f 9,276' I 1 Mule shoe 3.5" tbg. jt. w /stop 9,297' I Stimulation Summary: 7" x 3.5" Baker "HB" Packer 1 9,322' I 8/85 - 20,000# ISP LK - a 3 Camco " W -1" Nipple 2 812" L 9,360' I 9/89 - 97,400# Carb. LK - 1, LK - 2 pP ( ) PERFORATION SUMMARY 3.5" Camco "MMG -2" 1 9,393' 1 MK, LZ, LK -2 Perforations (12 spf) i 3.5" Camco "MMG -2" ( 9,438'1 SPF MD TVD - �® Hokin , _! ,8)' 948V, 12 9,472' - 9,486' 7,112' - 7,122' �"` ® 3 - Blast j o i nts 12 9,546' - 9,552' 7,163' - 7,167' 12 9,580' - 9,586' 7,186' - 7,190' 7" x 3.5" Baker "2 - B" Perm Pkr. 1 9,600' I 12 9,726' - 9,752' 7,286' - 7,303' IMP a 3.5" Camco "D" Nipple (2.75" id) 1 9,622' LK -1 Perforations (4 spf) SPF MD 'TVD WLEG 1 9,630' 1 4 9,686' - 9,706' 7,259' - 7,272' - _ PBTD 1 9,840 I 7" 26#, L- 80,BTC 1 9,921' I DATE REV. BY COMMENTS MILNE POINT UNIT 3/11/85 JHA Drill & Complete Audi #3 WELL C -07 02/25/92 Rwo EWS rig 4 API NO: 50 -029 -21266 05/14/03 MDO Rwo GL Completion Nabors 4 -es BP EXPLORATION (AK) STATE OF ALASKA ALASKA OlglIAND GAS CONSERVATION COMMISSIO • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations LJ Stimulate LJ Other VT erz $¢L Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown p Perforate ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc ,. Development El Exploratory ❑ 185 -002 -0 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 1 50- 029 - 21266 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047434 - MPC -07 9. Field /Pool(s): MILNE POINT, KUPARUK RIVER OIL 10. Present Well Condition Summary: Total Depth measured 9940 feet Plugs measured None feet true vertical 7429.42 feet Junk measured None feet Effective Depth measured 9460 feet Packer measured See Attachment feet true vertical 7104.03 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 13 -3/8" 48# H -40 35 - 115 35 - 115 0 0 Surface 5806 9 -5/8" 36# K -55 34 - 5840 34 - 4725.09 3520 2020 Intermediate None None None None None None Production 9888 7" 26# L -80 33 - 9921 33 - 7416.71 7240 5410 Liner None None None None None None Perforation depth Measured depth See Attachment feet t -. , V 2011 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 9321 - 9630 7007.95 - 7221.06 3 -1/2" 9.3# L -80 32 - 9297 32 - 6991.42 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): 9375' - 9520' RECEIVED Treatment descriptions including volumes used and final pressure: q { i 17 bbls of 16 ppb UNI Slurry Cement. Final Pressure = 2691 psig. 12. Representative Daily er a P pd ction or Injection Data Oil -Bbl Gas -Mcf M AI 14 U A Cepilukagenion Tubing Pressure Prior to well operation: 327 286 126 tin kes 171 Subsequent to operation: 0 0 0 0 1 ° 0 j 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Development IO " Service p Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ig Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name: Garry Catron Title: Data Management Engineer Signature L6 Phone: 564 -4657 Date 5/13/2011 Form 10 -404 Revised 10 /2010 RBDMS MAY 19 ZOjl Jam/ 1 7A1 cpy ,// ubmit Original Only • • MPC -07 185 -002 -0 Perforation Attachment Perf Opera Meas Meas Operation tion Depth Depth TVD Depth TVD Depth SW Name Date Code Top Base Top Base MPC -07 2/25/92 STC 9322 9600 7008.64 7200.62 MPC -07 5/8/11 SQZ 9420 9486 7024.32 7070.07 MPC -07 5/8/11 SQZ 9420 9520 7024.32 7093.66 MPC -07 5/8/11 SQZ 9420 9752 7024.32 7251.55 MPC -07 5/5/11 BPS 9460 9752 7052.03 7251.55 MPC -07 5/7/11 BPP 9460 9752 7052.03 7251.55 MPC -07 3/11/85 PER 9472 9486 7060.35 7070.07 MPC -07 5/4/11 BPS 9520 9752 7093.66 7251.55 MPC -07 3/11/84 PER 9546 9552 7111.61 7115.74 MPC -07 3/1/85 PER 9580 9586 7134.96 7139.06 MPC -07 3/11/85 PER 9686 9706 7207.04 7220.56 MPC -07 3/11/85 PER 9726 9752 7234.05 7251.55 AB D MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED 1 BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN 1 SQF SQUEEZE FAILED SPS SAND PLUG SET CSQZ,' SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • MPC -07 185 -002 -0 Packers and SSV's Attachment SW Name Type MD TVD Depscription MPC -07 PACKER 9219 6885.83 3 -1/2" Baker S -3 Packer MPC -07 PACKER 9322 6956.64 3 -1/2" Baker HB Packer MPC -07 PACKER 9600 7148.62 3 -1/2" BOT 2B Permanent Packer • • Daily Report of Well Operations Well Date Operation Comments ***WELL FLOWING ON ARRIVAL * * *(FRAC PREP). DRIFTED W/ 2.63" CENT, 3' X 1 -7/8" STEM, 2.72" CENT, 1.5" SAMPLE BAILER TO 9630' SLM. (NO RESTRICTIONS).. CLOSE SSD @ 9110' MD W/ 3 -1/2" "B" SHIFTING TOOL.. LRS LOAD TBG.. TEST TBG W/3 -1/2" X- SELECTIVE TEST TOOL FROM X- NIP MPC -07 5/3/11 DTB @ 9,276' MD. MIT -T 2500PSI (PASSED).. WELL LEFT S /I, TURN OVER TO T /I /O= 750/920/0. ASSIST SLICKLINE WITH LOAD TBG AND MITT ** *PASS * ** TO 2500 PSI. PUMPED 57 BBLS CRIESEL DOWN TBG. SLICKLINE SETS PLUG. PUMPED 23.5 BBLS DIESEL DOWN TBG TO BRING TBG PSI FROM 300 PSI TO 2500 PSI. MITT LOST 80 PSI IN THE 1ST 15 MINUTES AND 0 PSI IN THE 2ND 15 MINUTES FOR A TOTAL LOSS OF 80 PSI IN A 30 MINUTE TEST. MPC -07 5/3/11 LOD BLED BACK TBG PSI TO 135 PSI. PUMPED 6 BBLS 60/40. FWHP= 135/920/0. T /I /O= 750/920/0. ASSIST SLICKLINE WITH LOAD TBG AND MITT ** *PASS * ** TO 2500 PSI. PUMPED 57 BBLS CRIESEL DOWN TBG. SLICKLINE SETS S C S S PLUG. PUMPED 23.5 BBLS DIESEL DOWN TBG TO BRING TBG PSI FROM 300 PSI TO 2500 PSI. MITT LOST 80 PSI IN THE 1ST 15 MINUTES AND 0 PSI IN THE 2ND 15 MINUTES FOR A TOTAL LOSS OF 80 PSI IN A 30 MINUTE TEST. MPC -07 5/3/11 PTT BLED BACK TBG PSI TO 135 PSI. PUMPED 6 BBLS 60/40. FWHP= 135/920/0. ** *WELL FLOWING ON ARRIVAL***(FRAC PREP). DRIFTED W/ 2.63" CENT, 3' X 1 -7/8" STEM, 2.72" CENT, 1.5" SAMPLE BAILER TO 9630' SLM. (NO RESTRICTIONS).. CLOSE SSD © 9110' MD W/ 3 -1/2" "B" SHIFTING TOOL.. LRS LOAD TBG.. TEST TBG W/3 -1/2" X- SELECTIVE TEST TOOL FROM X- NIP MPC -07 5/3/11 PMD @ 9,276' MD. MIT -T 2500PSI (PASSED).. WELL LEFT S /I, TURN OVER TO MPC -07 5/4/11 BPS Plug set @ 9520' CTU #9 W/ 1.75" OD CT. OBJECTIVE: RETAINER CEMENT SQUEF7F MIRU CTU. MU AND RIH W/ PDS MEMORY GR/CCL LOGGING TOOL ENCASED IN 2- 3/8" OD PUMP THROUGH CARRIER W/ 2.70" OD JSN. LOG FROM 9702' CTMD TO 8221' MD, FLAG PIPE. POOH, LD TOOLS, CONFIRM GOOD DATA, MPC -07 5/4/11 JWL CORRECTION OF ( -8'). MU AND RIH W/ WFD COMPOSITF RRIrX F PI 1 J( 1 Jr. SFT CTU #9 W/ 1.75" OD CT. OBJECTIVE: RETAINER CEMENT SQUEEZE RIH WITH WEATHERFORD 2.720" CEMENT RETAINER. SET RETAINER AT 9460' MPC -07 5/5/11 BPS UNABLE TO GET INJECTION RATE UNSTING AND IT APPEARS THE LEAK IS CTU #9 W/ 1.75" OD CT. OBJECTIVE: RETAINER CEMENT SQUEEZE RIH WITH WEATHERFORD 2.720" CEMENT RETAINER. SET RETAINER AT 9460' UNABLE TO GET INJECTION RATE UNSTING AND IT APPEARS THE LEAK IS ABOVE RETAINER POOH. MU AND RIH W/ PDS MEMORY STP LOGGING TOOL. FREEZE PROTECT WELL W / 21 BBLS 60/40 METHANOL. AT SURFACE DOWN LOADED TOOLS AND DETERMINED THE LEAK IS AT LOWER MMG -2 MPC -07 5/5/11 LDL VALVE AT 9438'. RDMO «« JOB MPC -07 5/7/11 BPP 9460' -9752' CTU #9 W / 1.75" OD CT. JOB SCOPE: MILL CEMENT RETAINER AND SET ANOTHER RETAINER. MIRU. PREFORM WEEKLY BOP TEST. MU AND RIH W/ WFD 2.125" MOTOR/2.625" OD VENTURI /2.71" OD BURNOVER SHOE. TAG RETAINER. CORRECT TO RETAINER, FLAG PIPE FOR DEPTH CONTROL FOR SUBSEQUENT RUN. BURNOVER RETAINER AND PUSH TO COMPOSITE BRIDGE PLUG AT 9519' MD. POOH. LD BURNOVER SHOE - DID NOT RECOVER RETAINER. PERFORM INJECTIVITY TEST: 2 BPM AT 2090 PSI W/ MPC -07 5/7/11 FSH KCL. SET CEMENT RETAINER © 9420'. CONTINUED ON WSR 05/08/11 MPC -07 5/8/11 SQZ 9420' -9752' ` i • Daily Report of Well Operations Well Date Operation Comments CTU #9 W / 1.75" OD CT. JOB SCOPE: MILL CEMENT RETAINER AND SET ANOTHER RETAINER. PUMPED 17 BBLS OF 16 PPB UNI SLURRY CEMENT MPC -07 5/8/11 TAG .PUMPED 12 BBLS OF CEMENT BELOW RETAINER UNSTUNG AND LAID IN 5 CTU #9 W/ 1.75" OD CT. OBJECTIVE: MILL CEMENT & RETAINERS & COMPOSITE. MIRU CTU. MU AND RIH W/ WFD 2.125" OD MOTOR W/ 2.71" MPC -07 5/9/11 TAG OD 5- BLADED CONCAVE JUNK MILL. TAGGED TOP OF CEMENT AT 9375' CTU #9 W/ 1.75" OD CT. OBJECTIVE: MILL CEMENT & RETAINERS & COMPOSITE. MIRU CTU. MU AND RIH W/ WFD 2.125" OD MOTOR W/ 2.71" OD 5- BLADED CONCAVE JUNK MILL. TAGGED TOP OF CEMENT AT 9375' MPC -07 5/9/11 CTM CONTINUE MILLING AT 9408' «« CONTINUE WSR ON 5/10/11 »» CTU #9 W/ 1.75" OD CT. OBJECTIVE: MILL CEMENT & RETAINERS & MPC -07 5/10/11 CTM COMPOSITE «« CONTINUE WSR FROM 5/9/11 »» CTU #9 W/ 1.75" OD CT. OBJECTIVE: MILL CEMENT & RETAINERS & COMPOSITE «« CONTINUE WSR FROM 5/10/11 »» MILLED CEMENT AND CEMENT RETAINER & COMPOSITE PLUG @ 9520' PUSH PLUG OUT OF MPC -07 5/11/11 CTM TUBING TAIL TO 9660'. FREEZE PROTECT WELL TO 2500' WITH 22 BBLS OF ■ Tree: 3 1/8" - 5M FMC II M P C -07 - SL = 52 deg Wellhead: 11" 5M FMC KDB - GL = 32 deg w/ 3 1/2" FMC Tubing Hanger, 3.5" NSCT top & btm CIW H profile ' Flo 13 -3/8" 48# H -40 115' IA GLV arrangement seen on this drawing was set on 4/11/10. Always verify if this is the latest design. 9 -5/8" 36# K -55 Btrs 5,840' I , ro , r 1.5" X 31/2" MMG w/ RK KOP @ 900 kis # an tvd dg Max. hole angle = 52 @ 5396` 0 • ?I 6 2,288' 2,186' 30 Hole angle thru' perfs = 47° )_. 5 4,510' 3,803' 46 4 6,175' 4,936' 51 3 7,524' 5,789' 49 2 8,428' 6,396 46 �� 1 9,052' 6,823' 46 7" 26 #/ft , L -80, BTRC Casing. 0 Bbls /ft = .0383 ID = 6.151" '` it 3.5" 9.3 #/ft , L-80 , IBT. _ 3.5" Baker CMD Sliding sleeve 9,110' 1 Bbls /ft = .0087 ID = 2.992" ` 3.5" HES X- Nipple ( 2.813 ") . 9 I 1 9,219` 7" x 3.5" Baker S -3 Perm Pkr. IIMINIMMIMMI In MK s 3.5" HES X- Nipple ( 2.813 ") 1 9,276' Mule shoe 3.5" tbg. jt. wlstop 9,297' Stimulation Summary: 7" x 3.5" Baker "HB" Packer 9,322' 8/85 - 20,000# ISP LK - 2 9/89 - 97,400# Carb. LK - 1, LK - _ NI 3.5" Camco " W -1" Nipple (2.812 ") 9,360' PERFORATION SUMMARY 3.5" Camco "MMG -2" 9,393' MK, LZ, LK -2 Perforations (12 spf) 3.5" Camco "MMG-2" 9,438' SPF MD ND - Hole in tbg @ 9489''1 12 9,472' - 9,486' 7,112' - 7,122' - Bla 3 st joints 12 9,546' - 9,552' 7,163' - 7,167' 12 9,580' - 9,586' 7,186' - 7,190' 7" x 3.5" Baker "2 - B" Perm Pkr. 9,600' 12 9,726' - 9,752' 7,286' - 7,303' Mg 3.5" Camco "D" Nipple (2.75" id) 9,622' I LK -1 Perforations (4 spf) WLEG 9,630' SPF MD TVD 4 9,686' - 9,706' 7,259' - 7,272' PBTD 9,840' 7" 26 #, L- 80,BTC 9,921' DATE REV. BY COMMENTS MILNE POINT UNIT 3/11/85 JHA Drill & Complete Audi #3 WELL C - 07 02/25/92 Rwo EWS rig 4 API NO: 50 029 - 21266 05/14/03 MDO Rwo GL Completion Nabors 4 -es BP EXPLORATION (AK) •teased vn at uas ions Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 W Job Log Description Date BL Color CD MPI -13 AWJI -00055 SCMT t r 7n c r 10/18/09 1 1 MPC -07 AXBD -00057 MEM PROD PROFILE I o73� c� ;111 10/24/09 1 1 04 -11A AWLS 00040 INJECTION PROFILE U r(1 -i 10/24/09 1 1 V -220 AYS4 -00100 INJECTION PROFILE (J'? c_ {y 10/04/09 1 1 L -220 B1JJ -00035 MEM INJ PROFILE (REVISED) Z. nil 07/30/09 1 1 V -221 AXBD -00037 MEM INJ PROFILE (REVISED) T 0 006 is, 4. 07/28/09 1 1 L -214A AP3Q -00064 INJ PROFILE/RST (Jr° a(j(D- (Ste' n 10/06/09 1 1 S -22B AYTU -00052 INJECTION PROFILE U T r 1C4 '4- Q5/ I'3 If 10/27/09 1 1 14 -07 8581 -00016 PROD PROFILE —11 419/ 10/27/09 1 1 i 07 -05 AYS4 -00105 'SCMT /'t- -0 //9/. 10/28/09 1 1 R -28 AWL8 -00041 USIT I —a a 10/26/09 1 1 2- 08/K -16 AZCM -00046 PRODUCTION PROFILE A— 0 I fs9 n m 10/30/09 1 1 PSI -05 B14B -00080 TEMP WARMBACK SURVEY 0 e. a0 -q /1,90 A 11/03/09 1 1 C -12B B2WY -00030 MCNL a Qg (3 fs 'f5 `9 09/19/09 1 1 U -05A 09AKA0074 OH MWD /LWD EDIT OT(�_AO -D 7 n l 0 1 08/19/09 2 1 01 -18A 09AKA0151 OH MWD/LWD EDIT_ A- a 08/27/09 4 1 H -09 ANHY -00110 RSTttl fire, G t .1 hi 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center 1,R2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. t 1 Anchorage, AK 99503 2838 Sc~luIII~erger I i)~ - obd NO. 3880 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 f) ¡ Field: Prudhoe Bay C ;V Well Job# Loa Description Date BL Color D 15·12A 11211420 11'(;:11 \.:it<Avt:L PAcK 06/25/06 1 17-08 11211509 INJc" I lVi'll I'ROFILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-Q6A 11217266 INJECTION PROFILE 07/12106 1 P2-Q1 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-Q8 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-Q4A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06· 1 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-Q7 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 1.!-51 11212873 USIT 06/28/06 1 04-31 11217264 USIT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-Q7 10703937 MDT 10/13/03 1 02·16B 11209601 MCNL 04/25/06 1 1 L2-18A 11217234 MCNL 04/06/06 1 1 L5-Q9 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 . ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 07/19/06 e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 52' [] 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 1009' NSL, 2396' WEL, SEC. 10, T13N, R10E, UM X = 558065, Y = 6029290 MPC-07 At top of productive interval 9. Permit Number / Approval No. 185-002 887' NSL, 4849' WEL, SEC. 03, T13N, R10E, UM X = 555563, Y = 6034429 10. APl Number At effective depth 50-029-21266-00 1107' NSL, 5006' WEL, SEC. 03, T13N, R10E, UM X = 555404, Y = 6034647 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1168' NSL, 5048' WEL, SEC. 03, T13N, R10E, UM X = 555361, Y = 6034708 Sands 12. Present well condition summary Total depth: measured 9940 feet Plugs (measured) true vertical 7429 feet Effective depth: measured 9840 feet Junk (measured) true vertical 7363 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 13-3/8" 500 sx PF 'C" 115' 115' Surface 5803' 9-5/8" 1575 sx PF 'E', 275 sx Class 'G' 5840' 4725' Intermediate 200 sx PF 'C' (Top Job) Production 9884' 7" 375 sx Class 'G' 9921' 7417' Liner 60 sx PF 'E'(Top Job) Perforation depth: measured 9472'- 9486', 9546'- 9552', 9580'- 9586', 9686'- 9706', 9726'- 9752' true vertical 7112' - 7122', 7163' - 7168', 7187' - 7191', 7259' - 7273', 7286' - 7303' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 tubing to 9295'; 3-1/2", 9.2#, L-80 from 9322' to 9630'. Packers and SSSV (type and measured depth) 7" x 3-1/2" Baker S-3 Packer at 9237', 7" x 3-1/2" Baker 'HB' Packer at 9322' and a 7" x 3-1/2" Baker Packer at 9600'. ~ ~.~,,% ~,~, 13. Stimulation or cement squeeze summary "~ "'=' '~ Intervals treated (measured) JUN Treatment description including volumes used and final pressure Alaska 0il & Ga~; ~ ('t: "~ ,,'"'," ':"~ I? ~"~i 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr W~t~r-Bbl ~asing Pr~ssur~ Tubing Pmssur~ 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 117. I hereby certify that the foregoing is true ~rrect to the best of my knowledge Signed Sondra ' ' ' Title Technical Assistant Date - ~ i.~ I ~ ~ ! j~Pr~paredByNarne/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/1~~[. Submit In Duplicate BP EXPLORATION Page 1 of 7 Operations Summa Report Legal Well Name: MPC-07 Common Well Name: MPC-07 Spud Date: 2/25/1985 Event Name: REENTER+COMPLETE Start: 5/5/2003 End: 5/13/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2003 Rig Name: NABORS 4ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 15/7/2003 15:00 -20:00 5.00 MOB P PRE Rigged Down and Moved Off of MPI-03. 20:00 - 23:00 3.00 MOB P PRE Held PJSM. Moved from MPI-03 to MPC-07. 23:00 - 00:00 1.00 MOB P PRE Moved Over and Spotted Rig on MPC-07. Rigged Up. 5/8/2003 00:00 - 03:00 3.00 MOB P PRE Held PJSM. Raised and Scoped Derrick. Rigged Up. 03:00 - 04:00 1.00 WHSUR P DECOMP Held PJSM. Took on Seawater. Accepted Rig at 0300 hrs 05 / 08 / 2003. 04:00 - 05:00 1.00 WHSUR P DECOMP Held PJSM. R / U on Tree. 05:00 - 06:30 1.50 WHSUR. P DECOMP Held PJSM. R / U DSM Lubricator. Pulled BPV, R / D DSM. Annulus Pressure 2,000 psi, Tubing Pressure 1,400 psi. 06:30 - 07:00 0.50 KILL P DECOMP Rigged up HCR Valve on I / A. Rigged up Circulating Lines and Pressure Tested to 3,500 psi, OK. Pressure Tested Line to Tiger Tank to 1,000 psi, OK. 07:00 - 07:30 0.50 KILL P DECOMP Held PJSM on Well Killing Operations. 07:30 - 08:30 1.00 KILL P DECOMP Opened Well, Annulus Pressure 1,160 psi, Tubing Pressure 2,200 psi. Bullhead 100 bbls Down Tubing, Pump Rate 3 bpm, 900 psi. Pressure on I /A Dropped to 1,250 psi. Opened I /A through Choke Line to Tiger Tank and Continued Pumping Down Tubing. Pressure on I / A Bled Down to 0 psi w! No Returns. 08:30 - 09:30 1.00 KILL P DECOMP Lined Up to Bullhead Down Annulus. Attempted to Pump Down Annulus, Pressured Up to 2,800 psi w/3 bbls Away. Suspected Ice Plug. Called HB&R to Pump Heated Seawater. 09:30 - 13:00 3.50 KILL P DECOMP Held PJSM. R / U HB&R and Tested Lines to 3,000 psi, OK. Pumped 100 bbls 180 deg Seawater Down Tubing, Pump Rate 1.5 bpm, 2,050 psi. Observed Good Indication of Annulus Ice Plug Thaw. 13:00 - 14:30 1.50 KILL P DECOMP Held PJSM. Bullhead 200 bbls Down Annulus, Pump Rate 4 bpm, 2,300 psi. After Pumping 200 bbls away No Indication of Pressure Drop. 14:30 - 16:30 2.00 KILL P DECOMP Lined Up on Tubing. Pumped Down Tubing and Took Returns off of Annulus Through Choke to Tiger Tank. Pump Rate 3 bpm, 1,500 psi. Abundant Gas Returns f/300 bbls, Observed Annulus Pressure Increase to 2,200 psi then Drop to 130 psi After Pumping 370 bbls. 16:30 - 18:00 1.50 KILL P DECOMP Shut Down Pump. Allowed Pressure to Bleed Down. Shut Well in and Monitored Pressure. Annulus Pressure Built to 540 psi, Tubing Pressure Built to 550 psi. Bled Down All Pressures to 0 psi. 18:00 - 23:00 5.00 KILL P DECOMP Shut in Well and Monitored Pressures While Waiting on 9.9 ppg Brine from Mud Plant. Annulus Pressure Built to 430 psi, Tubing Pressure Built to 440 psi. Took on 450 bbls 9.9 ppg Brine. 23:00 - 00:00 1.00 KILL P DECOMP Held PJSM. Bled Down Tubing Pressure to 0 psi and Annulus Pressure to 290 psi. Staged Pump Up to 4 bpm, 200 psi w/18 bbls Pumped. Took Returns to Tiger Tank. Pump Schedule as Follows: bbls Pmp'd DP Pressure Annular Pressure 35 300 psi 50 psi 47 430 psi 130 psi 58 400 psi 110 psi 70 380 psi 120 psi 82 360 psi 120 psi Printed: 5/19/2003 10:43:19AM BP EXPLORATION Page 2 of 7 Operations Summa Report Legal Well Name: MPC-07 Common Well Name: MPC-07 Spud Date: 2/25/1985 Event Name: REENTER+COMPLETE Start: 5/5/2003 End: 5/13/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2003 Rig Name: NABORS 4ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 5/8/2003 23:00 - 00:00 1.00 KILL P DECOMP 116 380 psi 140 psi 146 390 psi 130 psi 5/9/2003 00:00 - 01:00 1.00 KILL P DECOMP Continued to Kill Well w/9.9 ppg Brine. Pump Schedule as Follows wi Pump Rate 4 bpm: bbls Pmp'd DP Pressure Annular Pressure 175 410 psi 110 psi 204 410 psi 70 psi 233 460 psi 90 psi 262 490 psi 80 psi 291 520 psi 60 psi 320 590 psi 60 psi 360 620 psi 60 psi 01:00 - 01:30 0.50 KILL P DECOMP Switched to Circulate Through Pits. Pump Rate 4 bpm, 620 psi. Pumped a Total of 437 bbls until Brine Weight Out 9.9 ppg. Shut Down Pump and Observed Well. Both Annulus and Tubing Had Slight Flow. 01:30 - 02:30 1.00 KILL P DECOMP Started Pump and Circulated Well w/9.9 ppg Brine, Pump Rate 6 bpm, 1,500 psi. Losses 108 bph. Slowed Pump to 4 bpm, 1,000 psi, Losses 54 bph. Pumped Total of 110 bbls. Shut Down Pump. 02:30 - 03:00 0.50 KILL P DECOMP Observed Well f/30 minutes. Well Dead. 03:00 - 03:30 0.50 WHSUR P DECOMP Held PJSM. Blew Down Lines and Pump. R / D Circulating Lines from Tree. Set TWC and Tested. 03:30 - 05:00 1.50 WHSUR P DECOMP N / D Production Tree. Inspected Threads in Tubing Hanger. 05:00 - 09:00 4.00 BOPSUF~ P DECOMP Held PJSM. N / U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Blind Rams, Mud Cross, Lower Pipe Rams w/2-7/8" x 5" Variable Rams. 09:00 - 12:00 3.00 BOPSUI~ P DECOMP Held PJSM. Tested BOPE. Tested Lower Rams, Blind Rams, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 3,500 psi High / 250 psi Low. Tested Annular Preventer to 2,500 psi High / 250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held w/No Leaks or Pressure Loss. Witnessing of BOPE test Waived by AOGCC Rep John Spaulding. 12:00 - 13:30 1.50 BOPSUR P DECOMP Held PJSM. R / U DSM Lubricator, Pulled TWC, R / D DSM. 13:30 - 14:00 0.50 PULL P DECOMP M / U 3-1/2" Landing Joint, R / U Circulating Head and Lines. Monitored Well. 14:00 - 15:00 1.00 PULL P DECOMP Started Pump and Circulated Well. Pump Rate 4 bpm, 550 psi. Pumped 34 bbls to Establish Circulation. 15:00 - 15:30 0.50 PULL P DECOMP 'Held PJSM. Closed Annular Preventer, BOLDS and Pulled on Tubing. Observed Pipe Movement w/88,000# of Up Weight. Observed Packer Release w/110,000# of Up Weight. Pulled Hanger Above Wellhead 6'. Circulated Well, Pump Rate 2 bpm, 150 psi While Waiting for Packer Elements to Relax. Fluid Loss Rate While Circulating 25 - 30 bph. 15:30 - 17:00 1.50 PULL P DECOMP Pulled Tubing Hanger to Floor. Circulated Well, Pump Rate 3 bpm, 350 psi. Moderate Amount of Gas Percolating Out of Fluid While Circulating. R / U Control Line Spooling Unit and ESP Cable Spooling Unit. Fluid Loss Rate While Circulating 25 bph. 17:00 - 17:30 0.50 PULL P DECOMP Terminated Control Line and ESP Cable Connections. Broke Out and L / D Tubing Hanger. Printed: 5/19/2003 10:43:19AM BP EXPLORATION Page 3 of 7 Operations Surnma Report Legal Well Name: MPC-07 Common Well Name: MPC-07 Spud Date: 2/25/1985 Event Name: REENTER+COMPLETE Start: 5/5/2003 End: 5/13/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2003 Rig Name: NABORS 4ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 5/9/2003 17:30 - 18:30 1.00 PULL P DECOMP POOH L / D 3-1/2" Tubing. Spooled Up Control Line and ESP Cable. 18:30 - 19:00 0.50 PULL P DECOMP Broke Out and L / D SSSV Assembly and Packer Assembly. R / D Control Line Spooling Equipment. 19:00-21:00 2.00 PULL P DECOMP POOHL/D3-1/2"Tubing. 21:00 - 21:30 0.50 PULL P DECOMP M / U Circulating Head and Lines. Pump Tubing Volume, 63 bbls, Pump Rate 5 bpm 550 psi. C / O Spools in ESP Unit. 21:30-00:00 2.50 PULL P DECOMP POOHL/D3-1/2"Tubing. 130 Jts Laid Down. 5/10/2003 00:00 - 07:00 7.00 PULL P DECOMP POOH L / D 3-1/2" Tubing. Recovered 285 Jts 3-1/2" Tubing, 3 Jts 2-7/8" Tubing, SSSV Assembly, 6 GLM Assemblies, 598 Steel Bands and 9 flat guards. Tubing was Plugged w/Sand From GLM #1 at 9,071'. Recovered Dummy GLM Valve from Pup Jt on Top of Pump Assembly. 07:00 - 08:30 1.50 PULL P DECOMP Held PJSM. Terminated ESP Cable Inspected, Broke Out and L / D ESP Pump. 08:30 - 09:00 0.50 PULL P DECOMP R / D 3-1/2" Tubing Handling Equipment. 09:00 - 09:30 0.50 WHSUR P DECOMP Ran and Set Wear Bushing. 09:30- 10:00 0.50 CLEAN P DECOMP Serviced Rig. 10:00 - 10:30 0.50 CLEAN P DECOMP Finished Strapping 3-1/2" DP in Pipe Shed. 10:30 - 11:30 1.00 CLEAN P DECOMP Held PJSM. M / U Clean Out BHA: Overshot - Extension - Drive Sub - XO - Casing Scraper - 3 x Boot Baskets - Bit Sub - Bumper Sub - Jars - 3 x 4-3/4" DC. Total BHA Length - 138.48'. 11:30-16:30 5.00 CLEAN P DECOMP RIHwlCleanOutBHAon3-112"DP. P I U DP from Pipe Shed. Fluid Ran over Top of DP. 16:30 - 17:30 1.00 CLEAN P DECOMP M / U Circulating Head and Lines. Circulated Well Surface to Surface. Pump Rate 6 bpm, 1,050 psi. Slight Show of Gas. 17:30 - 18:00 0.50 CLEAN P DECOMP RIH w/Clean Out BHA on 3-1/2" DP. P / U DP from Pipe Shed. 18:00 - 18:30 0.50 CLEAN P DECOMP M / U Circulating Head and Lines. Pumped DP Volume. Pump Rate 5 bpm, 900 psi. 18:30-21:30 3.00 CLEAN P DECOMP RIH wl Clean Out BHA on 3-112" DP to 9,188'. P I U DP from Pipe Shed. DP Slip Die Broke, 1/2 of Die Dropped Down Hole, 6"x 1". Pulled Slips and Replaced All Dies. 21:30 - 22:30 1.00 CLEAN P DECOMP R / U to Reverse Circulate. Took on 300 bbls of 9.9 ppg Brine. 22:30 - 23:30 1.00 CLEAN P DECOMP Held PJSM. Closed Annular Preventer, Reverse Circulated Down from 9,188' to 9,220'. Pump Rate 4 bpm, 500 psi. Circulated Full Bottoms Up. Losses 150 bph. Shut Down Pump, Gas Percolated up Through DP. Pumped Down DP to Clear Gas. 23:30 - 00:00 0.50 CLEAN P DECOMP R / U to Circulate Long Way. Washed Down from 9,220' to !9,250'. Pump Rate 5 bpm, 1,500 psi. Losses 70 bph. 5/11/2003 00:00 - 00:30 0.50 CLEAN P DECOMP Washed Down from 9,250' to 9,290'. Pump Rate 5 bpm, 1,400 psi. String Weight Up 137,000#, String Weight Down 75,000#. Tagged Up at 9,290', DPM. Overshot Length 8', Top of PBR -- 9,282', DPM. 00:30 - 02:30 2.00 CLEAN P DECOMP Pumped and Circulated Around 45 bbl Hi-Vis Sweep. Pump Rate 5 bpm, 1,400 psi. Observed Slight Amount of Sand Over Shakers w/Sweep. Fluid Losses 36 bph. 02:30 - 06:30 4.00 CLEAN 'P DECOMP POOH w/3-1/2" DP. 06:30 - 07:30 1.00 CLEAN P DECOMP Stood Back 4-3/4" DC. Broke Out and L / D Clean Out BHA. Casing Scraper Hung Up in Wear Bushing, Worked BHA Up and Down and Pulled Through Wear Bushing. Possible Junk in Hole. 07:30 - 08:30 1.00 CLEAN P DECOMP Ordered Out Slickline Unit. Printed: 5/19/2003 10:43:19AM BP EXPLORATION Page 4 of 7 Operations Summa Report Legal Well Name: MPC-07 Common Well Name: MPC-07 Spud Date: 2/25/1985 Event Name: REENTER+COMPLETE Start: 5/5/2003 End: 5/13/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2003 Rig Name: NABORS 4ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 5/11/2003 08:30 - 09:00 0.50 CLEAN N DPRB DECOMP Held PJSM. R / U HES Slickline Unit. 09:00 - 10:30 1.50 CLEAN N DPRB DECOMP !RIH w/6.05" Gauge Ring / Junk Basket. Tagged Up at 9,292' WLM. POOH, Recovered a Few Pieces of SS band in Junk Basket. 10:30 - 12:00 1.50 CLEAN N DPRB DECOMP M/U 4.54" LIB and RIH on Slickline. Tagged Up at 9,292'. POOH w/LIB. Impression in LIB Indicated broken slip die Beside PBR. 12:00 - 12:30 0.50 CLEAN N DPRB DECOMP R / D HES Slickline. 12:30 - 13:00 0.50 EVAL . P DECOMP Held PJSM. M / U HOWCO 7" Retrievable Bridge Plug. 13:00 - 16:00 3.00 EVAL P DECOMP RIH w/HOWCO RBP on 3 1/2" DP to 9,260'. Set RBP at 9,260' and Released from RBP. Tested RBP w/1,000 psi, OK. 16:00-17:00 1.00 EVAL !P DECOMP POOH and Stood Back 3 Stands. M/URTTSw/StormValve. RIH w/RTTS on 3-1/2" DP to 35'. Set RTTS at 35'. Closed Pipe Rams and Tested RTTS w/500 psi, OK. Bled off Pressure and Opened Pipe Rams. Released from RTTS and POOH. 17:00 - 19:00 2.00 WHSUR P DECOMP Held PSJM. Checked OA Pressure, 0 psi. Opened Outer Annular Valve. M / U Retrieving Tool, RIH, Latched and Pulled Wear Bushing. M / U Packoff Retrieving Tool and RIH. Latched Packoff. BOLDS Pulled Up on 3-1/2" DP w/12,000# Packoff Came Free, Pulled Packoff Through BOP Stack. M / U New Packoff on Tool, Ran and Set New Packoff. RILDS. Tested Packoff to 5,000 psi f/15 minutes, OK. R / D Packoff Running Equipment. Installed New Annulus Valves on Wellhead. 19:00 - 20:00 1.00 WHSUR P DECOMP RIH w/RTTS Latch on 3-1/2" DP. Latched and Released RTTS Packer. Pulled RTTS Packer to Floor, Broke Out and L ! D Same. 20:00 - 21:00 1.00 EVAL P DECOMP M / U Circulating Head and Lines and Opened Kill Line. Closed Pipe Rams. Pressure Tested 7" Casing to 2,500 psi. Pump Schedule as Follows: Stks Pressure 2 100 psi 6 300 psi 10 500 psi 15 800 psi 20 1,200 psi 25 1,600 psi 29 1,900 psi 34 2,200 psi 37 2,500 psi !Held 2,500 psi f/30 Minutes w/No Pressure Loss. Bled off Pressure, Opened Pipe Rams. R / D Circulating Head and Lines. 21:00-21:30 0.50 EVAL P DECOMP RIHw13-112"DPandLatchedRBPat9,260'.MIUTIWValve to DP. Released RBP, Fluid Dropped in Wellbore. 21:30 - 23:00 1.50 EVAL P DECOMP R / U Circulating Lines, Circulated Bottoms Up. Pump Rate 5 bpm, 1,300 psi. Observed Gas to Surface on Bottoms Up. Fluid Losses Averaged 40 bph. Pumped and Spotted 40 bbl Hi-Vis Pill on Bottom. 23:00 - 00:00 1.00 EVAL ~ DECOMP POOH L / D 3-1/2" DP. 5/12/2003 00:00 - 03:30 3.50 EVAL P DECOMP POOH L / D 3-1/2" DP 03:30 - 05:00 1.50 EVAL ~ DECOMP Held PJSM. Slipped and Cut Drilling Line 05:00 - 07:00 2.00 EVAL ~ DF:COMP POOH L / D 3-1/2" DP. Gas Percolating Up DP. Printed: 5/19/2003 10:43:19 AM BP EXPLORATION Page 5 of 7 Operations Surnma Report Legal Well Name: MPC-07 Common Well Name: MPC-07 Spud Date: 2/25/1985 Event Name: REENTER+COMPLETE Start: 5/5/2003 End: 5/13/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2003 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/12/2003 07:00 - 07:30 0.50 EVAL P DECOMP R / U Circulating Head and Lines. Circulated Down DP to Clear Gas. Monitored Well, R / D Circulating Equipment. 07:30 - 08:00 0.50 EVAL P DECOMP POOH L / D 3-1/2" DP, Broke Out and L / D HES RBP. RIH w/ Stand of 4-3/4" DC, Broke Out and L / D Same. 08:00 - 08:30 0.50 WHSUR P COMP M / U Retrieving Tool, RIH Latched and Retrieved Wear Bushing. R / D 3-1/2" DP Handling Equipment, R / U 3-1/2" Tubing Handling Equipment. 08:30 - 09:30 1.00 RUNCOitP COMP Cleared and Cleaned Rig Floor. Loaded Completion Jewelry into Pipe Shed. 09:30 - 10:30 1.00 RUNCOItl~ COMP Held PJSM. M / U Tail Pipe, X Nipple Assembly and Packer Assembly. Bakerlok'd All Connections Below Packer. 10:30 - 12:30 2.00 RUNCOI~I3 COMP RIH w/3-1/2" 9.3# L-80 IBT Tubing. Average M / U Torque 2,800 ft / lbs. Tagged Up at 1,250'. 12:30 - 13:00 0.50 RUNCOItl~I DPRB COMP Tagged up at 1,250' w/12,000# Set Down Weight. Pulled up w/ 3,000# - 5,000# of Overpull. Attempted to Work Tubing Past 1,250', No Success. Rigged Up Circulating Head and Line, Pumped Through Tubing, Pump Rate 3 bpm, 125 psi. Attempted to Work Tubing Past 1,250', No Success. 13:00 - 14:00 1.00 PULL N DPRB COMP POOH, Racked Tubing in Derrick. Observed Small Nick in Mule Shoe. 14:00 - 14:30 0.50 CLEAN N DPRB COMP Held PJSM. R / D 3-1/2" Tubing Handling Equipment, R / U 3-1/2" DP Equipment. Loaded and Strapped 50 Joints of 3-1/2" DP in Pipe Shed. 14:30-15:00 0.50 CLEAN N DPRB COMP HeldPJSM. M / U Clean Out BHA #2: 6" Junk Mill - 7" Casing Scraper - 2 x Junk Baskets - Bit Sub - Bumper Sub - Jars - 3 x 4-3/4" DC. BHA Total Length - 125.70' 15:00 - 16:30 1.50 CLEAN N DPRB COMP RIH w/Clean Out BHA #2 on 3-1/2" DP to 1,250'. Set Down at 1,250' w/2,000#, String Fell Through. Worked BHA from 1,250' to 1,300'. RIH w/Clean Out BHA #2 on 3-1/2" DP to 1,525'. 16:30 - 17:00 0.50 CLEAN N DPRB COMP M / U Circulating Head and Line. Circulated Bottoms Up. Pump Rate 5 bpm, 300 psi. 17:00 - 18:00 1.00 CLEAN N DPRB COMP POOH, L / D 3-1/2" DP. 18:00 - 18:30 0.50 CLEAN N DPRB ' COMP POOH w/BHA, Broke Out and L / D Same. 18:30 - 19:00 0.50 CLEAN N DPRB COMP Held PJSM. R / D 3-1/2" DP Handling Equipment, R / U 3-1/2" Tubing Handling Equipment. 19:00 - 20:30 1.50 RUNCOI~I~I DPRB COMP RIH w/3-1/2" Completion from Derrick to 1,250'. Set Down w/ 2,000# at 1,175'. Left 2,000# Set Down Weight on Tubing, Turned Tubing String w/Chain Tongs 1/8 Turn, Tubing Fell Through. Set Down w/2,000# at 1,250'. Left 2,000# Set Down Weight on Tubing, Turned Tubing String w/Chain Tongs 1/8 Turn, Tubing Fell Through. Stop Ring on Mule Shoe Hanging Up in Casing Collars. 20:30 - 00:00 3.50 RUNCOI~P COMP RIH w/3-1/2" 9.3# L-80 IBT Tubing. Average M / U Torque 2,800 ft / lbs. Set Down w/2,000# on Every Joint from 1,250' to 2,500'. Left 2,000# Set Down Weight on Tubing, Turned Tubing String w/Chain Tongs 1/8 Turn, Tubing Fell Through. Tubing Occasionally Hung Up from 2,500' to 3,200'. Left 1,500# Set Down Weight on Tubing, Rocked Tubing String Tubing Fell Through. 98 Joints Ran at 0000 hrs. 5/13/2003 00:00 - 08:00 8.00 RUNCOItP COMP RIH w/3-1/2" 9.3# L-80 IBT Tubing. Average M / U Torque 2,800 ft / lbs. Tubing Occasionally Hung Up from 3,200' to 6,500'. Left 1,500# Set Down Weight on Tubing, Rocked Tubing String Tubing Fell Through. Tubing Went in Hole Printed: 5/1912003 10:43:19 AM BP EXPLORATION Page 6 of 7 Operations Surnrna Report Legal Well Name: MPC-07 Common Well Name: MPC-07 Spud Date: 2/25/1985 Event Name: REENTER+COMPLETE Start: 5/5/2003 End: 5/13/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2003 Rig Name: NABORS 4ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 5/13/2003 00:00 - 08:00 8.00 RUNCOr~I~ COMP without Hanging Up from 6,500' to 9,292'. Tagged Top of PBR at 9,292' 08:00 - 09:00 1.00 RUNCOI~P COMP R / U Circulating Head and Line. Pump Rate 3 bpm, 250 psi. Lowered Tubing, Tagged Up at 9,292'. Rotated Tubing and Worked Tubing String Down, Mule Shoe Entered PBR, Stop Ring Bottomed Out at 9,301'. 09:00 - 09:30 0.50 RUNCOr~P COMP Spaced Out Tubing 4' Off Bottom w/3 Space Out Pups w/a Total Length: 17.60'. M / U Tubing Hanger and Landing Joint. 09:30 - 11:00 1.50 RUNCOI~' COMP Held PJSM. R/U Circulating Head and Lines. Reverse Circulated 250 bbls of Heated 9.9 ppg Brine w/Corrosion Inhibitor. Pump Rate 3 bpm, 250 psi. 11:00 - 11:30 0.50 RUNCOI~' COMP Tubing Parameters:String Weight Up 75,000#, String Weight Down 55,000#. Drained BOP Stack, RIH and Landed Tubing Hanger. RILDS, Broke Out and L / D Landing Joint. Completion Equipment Set At The Following Depths: Item Length Depth Mule Shoe w/Stop Collar 9.84' 9,297.10' X Nipple Assembly w/RHC Sleeve 20.64' 9,266.62' 1 Jt 3-1/2" 9.3# L-80 IBT Tbg 31.88' 9,234.74' S-3 Packer Assembly 27.20' 9,207.54' 1 Jt 3-1/2" 9.3# L-80 IBT Tbg 31.09' 9,176.45' X Nipple Assembly 20.67' 9,155.78' 1 Jt 3-1/2" 9.3# L-80 IBT Tbg 31.89' 9,123.89' Sliding Sleeve Assembly 23.57' 9,100.32' 1 Jt 3-1/2" 9.3# L-80 IBT Tbg 30.82' 9,069.50' #1 GLM Assembly 27.29' 9,042.21' 19 Jts 3-1/2" 9.3# L-80 IBT Tbg 596.93' 8,445.28' #2 GLM Assembly 27.28' 8,418.00' 28 Jts 3-1/2" 9.3# L-80 IBT Tbg 876.18' 7,541.82' #3 GLM Assembly 27.27' 7,514.55' 42 Jts 3-1/2" 9.3# L-80 IBT Tbg 1,321.37' 6,193.18' ~ GLM Assembly 27.38' 6,165.80' 52 Jts 3-1/2" 9.3# L-80 IBT Tbg 1,638.42' 4,527.38' #5 GLM Assembly w/RP Shr Valve 27.27' 4,500.11' 70 Jts 3-1/2" 9.3# L-80 IBT Tbg 2,194.50' 2,305.61' #6 GLM Assembly 27.43' 2,278.18' 70 Jts 3-1/2" 9.3# L-80 IBT Tbg 2,204.93' 73.25' 3-1/2" 9.3# L-80 IBT Pup Jt 9.75' 63.50' 3-1/2'"9.3# L-80 IBT Pup Jt 5.80' 57.70' 3-1/2" 9.3# L-80 IBT Pup Jt 2.05' 55.65' 1 Jt 3-1/2" 9.3# L-80 IBT Tbg 31.88' 23.77' Tubing Hanger 3.10' 20.70' 11:30 - 12:00 0.50 WHSUR P COMP Set TWC, Tested to 1,000 psi, OK. 12:00 - 13:00 1.00 BOPSUF:P COMP Held PJSM. N / D BOPE. 13:00 - 14:30 1.50 WHSUR P COMP Held PJSM. N / U Adapter Flange and Production Tree. Tested Hanger, Neck Seal and Void to 5,000 psi, OK. Tested Tree to 5,000 psi, OK. 14:30 - 15:30 1.00 WHSUR P COMP Held PJSM. R / U DSM Lubricator, Pulled TWC, R / D DSM. 15:30 - 16:00 0.50 WHSUR P COMP Dropped Ball/Rod Assembly. R / U Hardline to Tree and Annulus. Tested Line to 3,500 psi, OK. 16:00 - 18:00 2.00 WHSUR P COMP Pressured Up on Tubing to 2,500 psi to Set Packer. Pressure Printed: 5/19/2003 10:43:19 AM BP EXPLORATION Page 7 of 7 Operations Sumrna Report Legal Well Name: MPC-07 Common Well Name: MPC-07 Spud Date: 2/25/1985 Event Name: REENTER+COMPLETE Start: 5/5/2003 End: 5/13/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2003 Rig Name: NABORS 4ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 5/13/2003 16:00 - 18:00 2.00 WHSUR P COMP Tested Tubing to 3,500 psi f/30 Minutes, OK. Bled Tubing Pressure Down to 1,500 psi and Shut In. Pressure Tested I / A to 2,500 psi f/30 Minutes, OK. Bled Down Tubing and Sheared RP Valve. Bled Down All Pressures. 18:00 - 18:30 0.50 WHSUR P COMP Pumped Down Tubing and Took Returns Off of Annulus, OK. . Changed Valves, Pumped Down Annulus and Took Returns Off of Tubing, OK, to Ensure RP Valve Fully Sheared. 18:30 - 19:30 1.00 WHSUR ~ COMP Held PJSM. R / U First Energy. Tested Lines to 3,000 psi, OK. Pumped 80 bbls of Diesel Down Annulus to Freeze Protect. Pump Schedule As Follows: Bbls Pmp'd Rate Pressure 0 0.00 bpm 50 psi 3 1.50 bpm 450 psi 8 0.70 bpm 2,000 psi Shut Down Pumps and Allowed Pressure to Bleed Off 8 0.00 bpm 150 psi After 3 Minutes 15 2.47 bpm 1,100 psi 30 2.43 bpm 1,200 psi 45 2.43 bpm 1,250 psi 60 2.42 bpm 1,350 psi 80 2.43 bpm 1,450 psi Shut Down Pumps Pressure Bled Down to 300 psi After 10 Minutes. Shut In I / A. R / D First Energy. 19:30 - 20:00 0.50 WHSUR P COMP Held PJSM. R / U DSM Lubricator, Set BPV, R / D DSM. 20:00 - 21:30 1.50 WHSUR P COMP Opened Valves Between I / A and Tubing and Allowed Diesel to U-Tube. 21:30 - 22:00 0.50 WHSUR P COMP R / D Lines from Tree and Secured. Released Rig from MPC-07 at 2200 hrs 5 / 13 / 2003. Printed: 5/19/2003 10:43:19 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, ~~0~ Commissioner Tom Maunder, ~/'~~ P. I. Supervisor~'~ DATE: May 19, 2001 FROM' John Crisp, SUBJECT' Petroleum Inspector Safety Valve Tests Milne point Unit C Pad May 19, .2001' I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12198 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy · Supplement, I told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The ^OGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells #4,6 & 14 were shut in for repairs. SUMMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS MPU C Pad 5-19-01jc AlasKa Oil and Gas Conservation Commis~_ Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Jotm,...Crisp . Submitted By: J0h~,. C,,.r~. p Date: .~_. Field/Unk/Pad: Milne Point Unit C Pad Separator psi: LPS. 140 HP'~' ,., 5/19/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GENJ, Number Number PSI .P.SI Trip ,Code Code C,ode, Passed GAS or CYCLE C-01 1811430 140 100 110[ P P OIL C-02 1821940 C-03 " 1820500 140 ' 10{3.... 95 p " P OIL C-04 1821260 i40 i00 110 P " 4 OIL ,C-05A 1842430 140 100 100 P P ........ OIL , ,, ,,,,, ,, , , C-06 1842410 4300 2000 1950 P 4 WAG C-07 1850020 140 100 95! P 4 OIL C-o~ ' 1850140 '4300 2000 "'1900 P 4 WAG C'09 1850360 140 100 105~ P P OIL C- 13 1850670 C-14 '1850880 ' 140 ' iO0 100 P 4 OI'L C-15 1851030 , i i i __ C-17 1852630- 'E-20 1890150 ..... C-21 1940800 C-22A 1951980 140 100 "' 95'" P P 0IL , C-23 1960160 C-25A 1960210 4300 2000 "1900 'P 4 ....... w/~G i~_26 ' ' 195~060 ........ C-28 1960290 C-36 1980010 _ . C-39 1972480 ,, , , C-40 2002130 C-10 i850150 430~ 2000 1850 "P P ' WAG Wells: 12 Components: 24 Failures: 6 Failure Rate: 25.00o~] 90 Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: November 18, 2000 THRU' FROM' Blair Wondzell, ~ ' P. I. Supervisor t~(3o[c~ Lou Grima~:d~, ~ ~-.- PetrOleum Inspector SUBJECT: SVS tests BPX C-pad Milne Point Unit Kuparuk River Field Saturday, November 18, 2000; I witnessed the SVS tests on BPX C pad in the Milne Point of the Kuparuk RiVer Field. This was the three-mOnth test for this Pad due to a 26% fail rate witnessed by Inspector Jeff Jones on 7/9/00. The wells did somewhat better this time although 'the fail rate of 13.6% was still above the 10% expectable limit. Again, the gas injectors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV: The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spool adapter, Larry Niles (MPU OI advisor) will pursue this with the wellhead manufacturer as to proper repair and report back to me. The wellhouses were all very clean and it appears to be a high priority in the Milne facility. SUMMARy: I witnessed the SVS test on BPX C pad in the Milne Point Unit. 1 pad, 11 wells, 22 components, 3 failures. Wellhouse InspectiOns; 14 wellhouses, 1 failure (leaking T.S.A.) Attachments: SVS MPU C pad 11-18-00 LG.XLS cc: Niles/Shipley (MPU OI advisers) NON-CONFIDENTIAL SVS MPU C pad 11-18-00 LG.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: K.R.F./M.P.U./C pad Separator psi: LPS 140 Date: 11/18/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-01 1811430 140 100 120~ P P OIL C-02 1821940 C-03 1820500 140 100 105 P P OIL C-04 1821260 140 100 105 P 4 OIL C-05A 1842430 140 100 105 P P C-06 1842410 ,. C-07 1850020 140 100 110 P P OIL C-08 1850140 C-09 1850360 140 100 80 P P OIL C-13 1850670 C-14 1850880 140 100! 105 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 '1'40 100 110 P P OIL C-23 1960160 C-25A- 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P P WAG C-36 1980010 C-39 1972480 C-19i 1852960 4000 2000 2000 P 4 wAG Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.6%[] 90 Day Remarks: C-03 has gas leak on Tubing Spool adapter, Develop plan for repair and report back. 11/20/00 Page 1 of 1 V0kltrl6.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan SeamoUnt, Commissioner THRU DATE: July 12, 2000 Blair Wondzell, P. I. Supervisor FROM: Jeff Jones~, ~h~/~- SUBJECT: Petroleum I~sl~ct~r Safety Valve Tests Milne Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9~wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad; 12 wells, 23 components tested, 6 failures. 26% failure rate. 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAl_: SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: LaiTy Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASorC¥CLE C-01 1811430! 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 1001 100 P 4 OIL ~07C, '~;-- ' 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140! 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL I C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940: 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%[7] 9o Day Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. I~. 'XPLORATION (ALASKA) Loss Control Investigation Report Perso..pal Inlury In. .i, dent , Name IAge ISex- Nature of incident Spill (non-reportable) · · II ,SS NurtUrer IOccupatlon Nature of damag'~ or failure / Component Failure Experlence ...... I Nature of Injury System that was damaged or suffered loss I Well Head Hydraulic System IIII II [ II Agent Clasalflcmlon Equipment des~=ripflon Involved In damage or loss Hydraulic Fitt!,n, g iiiim iii i III Type Body part Estimated cost Actual cosl $5OO iiii II I Company BP Exploration (AK) III II IIII Department Milne Point Wells II _ iiiii I I I. CIR Number . Oc;:urrence date Time Report Date I.oration or facility 98-010 1/29/98 1030 1/29/98 MPU-Well Pad C I I -LI.L I I1~1. I. -_ IIIllI .... Substandard action Substandard condition Cause Procedure Violation Equipment Failure Improper Installation Illl I . I I lllll I J Probability Loae severity potential Je~-r<.~ ~;~J~ '/"/~r.,~5 3 LOW 3 LOW H. elr~,f ,u.,' -' · II IIIII Description of eventsAttachments IYesl While testing the safety valv~"~,stem on the C-07 well;'~' 3/8- Swagelok fitting"i~ the well head hydraulic panel parted. It sprayed approximately 2-3 quarts of aviation grade hydraulic oil inside and outside of the panel. Some of the spray hit the AOGCC inspector, Fortunately he was wearing the appropriate PPE and was not injured though he had to go and change clothes. Approximately 1 quart of fluid contacted the pad before a drip liner was put into place./fie r~-/- 5'o~.e~ ~;) ~.-~ '11 III I .... Ilia I ... III I Root Cause & Lea99ns Learned · i ......... IU_I See tho"attachment on the investigaiion by Shane McLeod. "~pon initial inspectior~', it'appears as ..~_ though the firing was improperly torqued during the initial installation. At some point the fitting had slipped from its original position and was subsequently retorqued without the tubing being properly seated in the fitting. Root cause is listed as Improper In~alle, tion with a contributing causal factor of ~m_or0per maintenance, Reme'd]al actl~'n pJan ' Target da~e "' Responsibility Research maintenance,,histor~ on C-7 ,.,2/15/98 Sh,,a,,ne McLeod R ,eview maintenance procedure,~ for leaking fittings. ,.2/15/98 Bill Nichols/L ,o,,u_is Cusack III II .. _ II I I I Joei Sinor/Bill Nichols ~ '~¢ ~/u',}'o,", ~ ~4.~! /'~ s/p~/c-/-~ ~. Bob CarrionI ~'E(~-,~/e~ ~ 7-~~~; Matt Warner/Fred Gipson' Safety Representative .~ ' '- '/ -13~te - ' Name-BPX Deperl ,_.lrn~~ ~. ....... ii111,1 iii ii i 0il & Gas Co~s. Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 December 30, 1993 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU C-7; REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Johnston, Attached are duplicate copies of the Report of Sundry Well Operations, Form 10-404, for converting Milne Point Unit Well C-7 to gas lift, Approval Number 93-204. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Att: cc: TJY Chevron Occidental C-7 Well File JAN - 5 1994 Ot~ & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIb~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation shutdown __ Stimulate__ Plugging __ Pull tubing __ Alter casing __ Repair well m Other X Convert to Gas Uft 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 305 Anchorage, AK 99503 5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface 1009' FSL, 2396' FEI~ Sec. 10, T13N, R10E, Umiat Meridian At top of productive interval 887' FSL, 4858' FEL, Sec. 3, T13N, R10E, Urniat Meridian At effective depth 1108' FSL, 5012' FEL, Sec. 3, T13N, R10E, Umiat Meridian At total depth 1172' FSL, 5048' FEL, Sec. 3, T13N, R10E, Umiat Meridain 6. Datum elevation (DF or KB) 52' KDB 7. Unit or Property name Milne Point Unit 8. Well number C-7 9. Permit number/approval number feet 10. APl number 50-029-21266 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 9940 feet Plugs (measured) true vertical 7429 feet None Effective depth: measured 9840 feet Junk (measured) true vertical 7361 feet None Casing Length Size Cemented Structural Conductor 78' 13-3/8" 500 SX Permf C Surface 5803' 9-5/8" 56 bbl Class G Intermediate 522 bbl Permf E Production 9884' 7" 76 SX Class G uner Perforation Depth: measured 9472'-9486', 9546'-9552', 9580'-9586', 9726'-9752' Measured depth 115' 5840' 9921' True vertical depth 115' 4725' 7417' RECEIVED true vertical 7112'-7122', 7163'-7167', 7186'-7190', 7286'-7303' JAN -5 1994 Tubing (size, grade, and measured depth) 3-1/2" 9.2#/ff, L-80, 9183' Alaska UJJ & Gas Corls. CommJssio Anchorage Packers and SSSV (type and measured depth) Otis FMX SCSSV @577', Otis RDH Pkr @598', BOT HB Pkr. @9322' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation (Injection) Subsequent to operation (Injection) Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 210 40 50 180 4OO 320 60 1200 Tubing Pressure 180 190 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Oil X Gas ~ Suspended Daily Report of ]Nell Operations 17' I hereby certify l~at the ~I~g°ing Signed k,, )~ /T~'~%~/ Sr. ProductionEnqineer Service Date 12/27/93 SUBMIT IN DUPLICATE Form 10-404 Rev 06]15]88 is true and correct to the best of my knowledge. J. H. Andrew Title u~ ~ 'uj IU:b4 FROM BP-MILNE CONOCO INC. DALLY WELL ACTIVITY REPORT PAGE. 004 - ALASKA ACTIVITY AT REPORT TIME; , ACTIVITY , ,7'b c,. ' 4~z,. IOSHA I"LWC DAYS WITHOUT YEAR TO DATE LA3T BOPE TEST BOP£ TEST DUE AD, CC VISIT? ENGINEER . COST SUMMARY DAILY CUMULATIVE PREVIOUS TOTAL PLANNED TROUBLE TOTAL DEC R9 '93 t6:58 FROM BP-MILNE PAGE.OOR CONOCO INC, DAILY WELL ACTIVITY REPORT ALASKA I ACTIVITY AT REPORT TI,ME: ,J,4~.J~_L~. .... ,,,,~J I ' 'i DAYS CUM/PLAN: TEMP/WC; J ~F J ..C_URRENT DEP..TH; MD HOURS J ACTIVITY · SERVICE PERSONNEL. NO. FLUID TYPE ! 0 ENSITY. ~--J~=~(~, LOSSES TODAY/CUM. RIG SAFETY PERFORM^N ALL DA~LY CO~TS !osH^j LWCi ~co * X... Y~R TO DATE ~T ~OPE TEST $ ~PE TEgT DU~ A~ VISIT? ENGINEER PILLS CUM. FLUID COST' $ SCSSV OPEN / CLOSED BPV IN/OUT PLUG DESC. COST ;SUMMARY PR EVtOUS TOTAL PLANNED TROUBLE TOTAL DAILY CUMUI.~TIVE ,, $ $ ..ECE!VED ,JAN -5 19! $ AFE C09T Alaska 0il_& EST. FINALCOST ' $ Anchorage J SUPERVISOR DEC ~ '~8 18:54 FROM~BP-MILNE PAGE.00B DAILY WELL ACTIVITY REPORT CONOCO INC. iW~L~ PROJECT: ACTIVITY AT REPORT TI ME' I DATE: I AFE/FACILITY; DAYS CUMIPLAN; Z.,. / ALASKA WEATHER; TEMP/WC.' / °F ACTIVITY I CURRENT DEPTH: MD RIG SAFETY PERF. O.R.,M_.A. NCE j ALL DALLY COSTS DAYS W1THOUT ........ ~-~_ ..~A~__ _ $ .ENVIRQ._NMENTALINCIDENT.S..~. ~tt/~tt Og--l. oc-F¢'~. .. $ DAYS WITHOUT YEAR TO DATE I~r'~,..EIV L~ I EIIBLS J, CUM. FLUID COST: $ t PLUG DESC. COST SUM MARY PREVIOUS TOTAL PLANNED BPV IN/OUT DAILY TROUBLE $ i SIAM -- R IOOA [TOTAL $ ~.~.~__0_..~ ...... ' UII & Gas ~0ns c~m~ission L~T BOPE TEST BOPE TEST DUE AOGCC VISIT? I;NGINEEFI CUMULATIVE Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK, 99503-3999 (907) 564-7600 July 28, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU C-7; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for converting Milne Point Unit well C-7 from production by electrical submersible pump to gas lift. Please direct any questions or concerns regarding this application to me at 564-7660. Sincerely, TOm Yeager SHEAR Specialist Attachment CC: JHA, TJY Chevron Occidental C-7 Well File RECEIVED J U L ~ 9 Alaska 0il & Gas Cons. 6ommiss~O° Anchorage " ' STATE OF ALASKA .. ALASKA OIL AND GAS CONSERVATION COMMISSION ~-~~ APPLICATION FOR SUNDRY APPROVALS - 1. Type of Request: Abandon __ Suspend __ Operation shutdown Re-enter suspended well //~/~,'¢ Alter casing ~ Repair well Plugging_ Time extention Stimulate__ Change approved program Pull tubing Variance __ Perforate __ Other x Convert to 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) \ Conoco Inc. Development x 52' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit Service 4. Location of well at surface 8. Well number 1009' FSI~ 2396' FEL, Sec. 10, T13N, R10E, Umiat Meridian C-7 At top of productive interval 9. Permit number 887' FSL, 4858' FEL, Sec. 3, T13N, R10E, Umiat Meridian 85-2 At effective depth 10. APl number 1108' FSL, 5012' FEL, Sec. 3, T13N, R10E, Umiat Meridian 50-029-21266 At total depth 11. Field/Pool 1172' FSL, 5048' FEL, Sec. 3, T13N, R10E, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 9940' feet Plugs (measured) true vertical 7429' feet Effective depth: measured 9840' feet Junk (measured) true vertical 7361' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 78' 13-3/8" 500 sx Permf C 115' 115' Surface 5803' 9-5/8" 56 bbl Class G 5840' 4725' Intermediate 522 bbl Permf E Production 9884' 7" 76 bb, Class G 9921' _ 7.417'... LinerRECEI VEL) Perforation Depth: measured g472-g486'; g548-g552'; 9580-g586'; g726-g752' true vertica17112-7122'; 7163-7167'; 7186-7190'; 7286-7303' JUL 9 199;5 Alaska 0il & Gas 00ns. 60mmiSs~0n Tubing (size, grade, and measured depth) 3-1/2" 9.2#/ft, L-80, 9183' Anchorage Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 577', Otis RDH Pkr @598', ROT HB Pkr. @9322' 13. Attachments Description summaryof proposal x Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: August 1, 1993 16. If proposal was verbally approved Oil x Gas ~ Suspended ~ Name of approver // Date approved Service 17. ! hereby ced ify that the,~foregoing is true and correct to the best of my knowledge. Signed t._. ~ /~1~Y~ J' H. Andrew Title Sr. Production Engineer Date July 16, 1993 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. I ¥ Plug integrity__ BOP Test __ Location clearance __ Mechanical Integrity Test~ Subsequent form required 10-~ Approved Copy Returned Original Signed By Approved by order of the Commission David W.. J~hn.~tnn Commissioner Date '?/~ c~.//~_~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point Unit C-7 Well Gas Lift Conversion The MPU C-7 well was originally completed as a producer in the Middle Kuparuk, Laminated Zone, and Lower Kuparuk intervals in March 1985. While the field was on line, it was produced by gas lift until being converted to ESP lift in May 1990. The initial ESP ran 496 days until the hanger penetrator pigtail connector failed. The well was producing 575 BOPD at the time of failure. A hole was punched in the tubing and the well was gas lifted at 300 BOPD until the ESP could be replaced. A new ESP was installed in March 1992. Production remained steady at 500+ BLPD until February 1993. Flowing bottomhole pressure began rising at that time and production dropped off, indicating mechanical degradation of pump performance. The well was shut in June 30, 1993 after a 479 day runlife. It is recommended that the well be placed on gas lift at this time to restore production. Gas lift mandrels were run during the completion to provide this contingent capability. The original C-7 gas lift line was removed back to the waterfall when the well was initially converted to ESP lift. It is recommended that rather than replacing this line, a jumper line be constructed to take high pressure injection gas from the adjacent C-9 injection line and bring it to C-7. Separate metering and control will be provided for both wells to minimize operational problems and to facilitate effective control and optimization. Casing pressure sensitive gas lift valves will be installed in the available mandrels. The well is expected to produce near the previous 500 BLPD rate (350 BOPD). J g L. ?- 9 Alaska Oil & Gas Cons. 'Ancl~orage WELL No. C-7 COMPLETION SKETCH MILNE POINT UNIT (P) APl No.: 50-029-21266 PERMIT No.: 85-2 COMPLETED: 3/11/85 LAST WORKOVER: 2/25/92 RECEIVED J U L 2 9 199;~ Alaska Oil & Gas Cons. Commission Anchorage 1/4" x .049 S.S. CONTROL LINE ELECTRIC SUBMERSIBLE PUMP CABLE NO. 2 CL-350 TUBING SEAL SUB ADAPTOR NOTES: 1. ALL DEPTHS MEASURED KDB-SL = 52' KDB-GL = 52' 2. MAX. ANGLE = 51.5' @ 6079' MD 3. K.O.P. = 500' 4. SLANT HOLE: YES 5. TREE TYPE: FMC 5 1/8" 5000// W/ 3 1/2" 8rd TREETOP CONNECTION 6. MIN I.D. = t.875" 'X' NIPPLE @ 608' 7. COMPLETION FLUID: 8.6 PPG NoCI W/12% MeOH 8. STIMULATION: 11/2/85 300 GAL. 10~ ACETIC ACID 900 GAL. 15% HCl ]200 GAL. MUD ACID FMC TUBING HANGER W/3-1/2" H BPV PROFILE 3 1/2" 9.2#/FT BTRS L-80 TUBING 2412' 4735' 6384' -- 7655' 9071' lOT 9113' 9183' 9223' 577' 2 7/8" OTIS 'FMX' TRSV SCSSV 598' OTIS 7" 26-32 'RDH' RETR. PACKER (1.94" ID) 608' 2 5/8" OTIS 'X' NIPPLE (1.875 ID) .5 1/2" 9.2#/FT L-80 8rd TUBING 650' 2 3/8" CAMCO KBMG MANDREL W/I" GLU 5/16" ORIFICE 3 1/2" 9.2#/FT BTRS L-80 TUBING 2 5/8" CAMCO KBMG GLM's W/ 1" DUMMY VALVES .. 2 5/8" CAMCO KBMG MANDREL 2 7/8" 6.5#/FT 8rd L-80 TBG. 2 7/8" CENTRILIFT CHECK VALVE 2 7/8" 6.5#/FT 8rd L-80 TBG. TOP OF ESP ASSEMBLY BOTTOM OF ESP ASSEMBLY FRACTURE: 8/85 20,000# ISP LK-2 9/89 97.400# CARBOLITE LK-1, LK-2 10. ESP: CENTRILIFT FC-650 204 STAGE, 1:5 TC GSBT SEAL, 65 HP 1250V/30A MOTOR MK, LZ LK-2 PERFORATIONS ('12 SPF) MD 1-VD 9472'-9486' 7112'-7122' 9546'-9552' 7165'-7167' 9580'-9586' 7186'-7190' 9726'-9752' 7286'-7505' IK-1 PERFORATIONS (4 SPF) MD TVD 9686'-9706' 7259'-7272' T' 26#/FT CASING @ 9921' CONOCO INC. ANCHORAGE DIVISION 9522' BOT 'HB' PACKER (ID = 2.89") 9560' CAMCO 'W-I' NIPPLE (ID = 2.812") 9395' CAMCO 'MMG-2' GLM (ID = 2.92") 9438' CAMCO 'MMO-2' GLM (ID = 2.92") 9478' 3 BLAST JOINTS 9598' BOT LOCATER SEAL ASSEMBLY (ID = 3.0") 9600' BOT '2-B' PERMANENT PACKER W/ MILLOUT EXTENSION 9622' CAMCO 'D' NIPPLE (ID = 2.75") 9650' TUBING TAIL IAPPROVED BY: JHA/HDS DATE: 03/16/92 DRAFTED BY: SJN CAD FILE' WCOC7 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 March 12, 1992 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Reports of Sundry Well Operations; Well Completion Reports Dear Mr. Johnston' Attached please find Reports of Sundry Well Operations for Wells C-7 and J-7 and Well Completion Reports for Wells G-5, G-7 and J-2. These wells are located on the Milne Point Unit. Please note that the Completion Reports for Wells G-5 and G-7 are resubmittals in order to correct inaccurate well locations. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Environmental Coordinator RJS/bgs Attachments CC C-7 Well File G-5 Well File G-7 Well File J-2 Well File J-7 Well File Chevron Occidental Hal Stevens/Van Heare, MPOC (w/o attachments) \RJS\AOGCC32.RJS RECEIVED MAR 1 9 1992 Alaska Oil & Gas Cons. Commissto~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown ~ Pull tubing ~ Alter casing 2. Name of Operator Conoco Inc. 3. Address 3201 C St., 4. Location of well at surface 1009' FSL, 2396' FEL, At top of productive interval 887' FSL, 4858' FEL, At effective depth 1108' FSL, 5012' FEL, At total depth 1172' FSL, 5048' FEL, 12. Present well condition summary Total depth: measured true vertical Suite 200~ Anchorage, AK Stimulate __ Plugging Repair well __ SEC. 10, T13N, R10E, UM SEC. 3, T13N, RiOE, UM T13N, R10E, UM T13N. RIOE. UM Effective depth: measured true vertical SEC. 3, SEC, 3, 9940 7429 9840 7361 Pedorate __ Other~_Replace ESP 5. Type of Well' Development X' Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) 52' KDB 7. Unit or Property name Milne Point Unit 8. Well number C-7 9. Permit number/approval number 85-2/~/-=v.~z ~ 10. APl number /_, 50--029-21266 11. Field/Pool Kuparuk River Field feet feet Plugs (measured) feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 78' 13-3/8" 5803' 9-5/8" 9884' 7" measured 9472-9486'' · Cemented Measured depth True vertical depth 500 sx Permf C 115' 115' 56 bbl Class G 5840' 4725' 522 bbl Permf E 76 bbl Class G 9921' 7417' 9546-9552'', 9580-9586'; 9726-9752' truevertical 7112-7122'', 7163-7167'', 7186-7190'; 7286-7303' Tubing (size, grade, and measured depth) 3-1/2" 9.2#/ft., L-80, 9183': Packersand SSSV(type and measured depth) OTIS "RDH" Packer @ 598' SSSV-OTIS TRSV @ 577' 13. Stimulation or cement squeeze summary NONE Intervals treated (measu red) NONE Treatment description including volumes used and final pressure NONE Bottom of ESP 9223' RECEIVED MAR 1 9 1992 Alaska 0il & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 604 116 6 0 186 Subsequent to operation (Surface Modifications in Progress) 15. Attachments [ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~ Oil ,~X Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ O'~,-~ ..~, ~ '~ Title SEI~1IOR FO~ Form 10-404 Rev 06/15/88 Service Date SUBMIT IN DUPLICATE L feet Milne..Poi._n.% C NO: 7.._-. .... WORKO_VER, .. A~I No,,: .... 50-.029-2~26.6 . L~ation: Milne Point Field - scHRAD~"BLUFF POOL A~B Number = 10-61- ! 448 Approve4: 11-18-92 /%FE ~%%~*:: $ 385,000 gross COS'I; tO Da~:e.' $240,041 gross 02-20-92: Continue to rig up on C-7. Change out BOP ~.~m~ to 31/2 tubing. off load and heat 500 BBLS of 8.6 12% methanol brine to 150 degrees. R/U to open 8SSV and annular vent valve on packer. R/U and lubricate BPV out. 800 PSI on tubing and 1300 PSI on CSG. All gas. Start bleeding CSG to ~lop tank. CSG bleed down to 30 PSI started getting diesel returns. Shut in CSG. Open tubing. Press. 625 PSI. Bleed to 150 PSI; started getting diesel returns. Shut in tubing. Check CSG pressure. Came up 120 PSI to 150 in an hour and 15 min. R/U and start circ. down tubing up CSG. Pumping 1 BBL/M at 300 PSI on a 26 choke. 02-21-92: Continue to circ. getting oil & gas returns. Pump rate 2 bbls/ min. at 30 PSI going through 44 choke. Had to shut down to due vac truck brake down. Start bleeding down csg. 300 PSi tubing o. Call out vac truck from Dead Horse. Start circ. at 100 PSI at I 1/4 bbls. min. Complete circ. Shut in for 1/2 hr. to check press on tubing & csg. Both dead. Set BPV. N/D tree & N/U BoP. R/U to pull BPV & set two way check, but had press on tubing. R/U & bullhead 25 bbls. down tubing. Then try to pump down csg., but press up to 500 PSI. Press up to 3500 PSI to shear out annular vent valve on Otis RDH packer. Still would not shear. R/U & check for press on tubing. No press. Pull BPV & set two way check. R/U & test BOP. Called AOGCC Dead Horse to witness BO~ test. No response back. Called AOGCC Anchorage. Got waiver from Mike Minder. R/U to pull two way check, but have press on tubing. Start to bleed press down to pull two way check. Pull two way check. R/U & bullhead 25 bbls. of 8.6 NaC1 with 12% Methanol down tubing. 02-22-g2: R/U & pull two way check. R/U & bullhead 25 bbls. down tubing. Hold pre-job safety meeting with all hands before releasing packer. Pick up landing JT. Make up in hanger. Pick up to 118K & shear out packer. Pull hanger to floor. Found ESp cable damaged. Cable was not hooked to penetrator & was hanging down hole. Fish cable to rig floor. Cable looks like it was damaged when tubing hanger was landed and then shorted out sometime during operations. R/U to control line. Open SSSV & annular vent valve on packer. Lay down SSSV & Otis RDH packer. Send both to otis. SSSV will be function tested and rebuilt if needed by Otis. Have RDH replacement packer on hand for completion. SSSV & RDH packer at floor. Function test annular vent valve. Would not shear. R/U & POOH with ESP RECEIV£D MAR 1 9 1992 Alaska Oil & Gas Cons. commisS'~or' Anchorage Equipment. Lay down perforated JT at 4935' RKB. ESP at rig floor. Brake out & lay down equipment. Lost 29 ESP bands. p/U & RIH on 3 1/2" Btrs. tubing with Otis PLS. retrievable bridge plug. continue to RIH. Continue to RIH with Otis PLS packer. Set packer at 9266~. Pick up weight 73K. Down weight 52K. Release from packer & PU 10" end of tubing 9256. Brake circ. Oil returns; recovered 160 bbls. R/U & test packer to 500 PSI. Held ok. R/U & pllmp 5 bbls. lead pill of HEC followed by 50 bbls. plus one bbl. of Safe Clean & then '10 bbls. more of HEC pills. Displaced with 325 bbls. of 8.6 NaCl with 12% Methanol brine. Complete circ. RIH to latch packer at 9266'. Could not latch packer. R/U & circ. over packer & latch. POOH packer dragging packer. Re- set. Shear out packer at 115K. POOH. PLS packer on Rig floor. Rubbers' on packer are shot. Also numerous ESP bands were wedged in slips. R/U & start in hole with ESP assembly. Service ESP equipment and RIH along with 6 GLM on production string. Ran 500 feet short of ESP cable. Change out spool. Make ESP cable splice and continue to RIH. Pick up RDH packer and SSSV. Cut and splice ESP cable for RDH packer. Test splice and penetrater. R/U SSSV control line and pressure test to 5000 PSI. RIH with remaining 3-1/2" tubing. Making ESP cable splice to tubing hanger. RECEIVED MAR 1 9 1992 Alaska Oil & Gas Cons. bommissio~ Anchorage COMPANY COMPANY REP. COUNTY S~.A. T E ..~.,.-~., FiE~/ CASING si; LINER s~z~ ISlZE iUPPER ~V2.' i LOWER DEPTH OTIS ......... OTIS PACKER INSTALLATION REPORT WEIGHT WEIGHT WEIGHT ,WEIGHT WEIGH T WELL NAME GRADE THREAD ITYPE COMPLETION FLUID IN CASING ~ ,~ GRADE THREAD TUBING ILOWER · M DDLE iUI~PER GRADE THREADI TYPE LOWER M DDLE UPPER DESCRI PTION ~WELL NAME COMPANY I FIELD ~ .. COMPANY REP. . . IWEIGHT GRAD HREAD TYPE COMPLETION FLUID IN COUNTY ISTATE iS,ZE WEIGHT GRADE THREAD TUBING jLOWER ' MIDDLE UPPER I,.2/7"~' 5"_/O,~Z'~ I A~' LINER ~ jSIZE WEIGHT GRADE THREAD TYPE ~LOWER iMIDDLE UPPER ........... ~i ............................ ~ ~, }SIZE ~[IG~T ~DE TH~[~O OPEraTOR'S N~M[ ~M~O ~ j Jsiz~WEIGHT G THREAD OTIS OFFIC iDAT~ _~ ~,~ ~ ITEM DEPTH LENGTH C~ rO . DESCRIPTION -- ~ I' I i '-- I ~ ~ ~~ ~.. ..- ~ I I I OEC --603- B J,P A GE ;o F ,OTIS, OTIS PACKER INSTALLATION REPORT '~ ~ COMPANY ~t~ .-~c. COMPANy REP. " COUNTY ISTATE ~LD SIZE" WEIGHT GRADE THREAD SIZE GRADE THREAD ' LINER j ~ J ~ j ~ ~ I UPPER j~; WEIGHT WEIGHT GRADE THREAD '~' i$1Z[ WEIGHT iGRADE THREAD I-.. , JSIZK WEIGHT iGRADE i THREAD ITEM DEPTH LENGTH j CC rD j TYPE COMPLETION FLUID IN TUBING ILOWER MIDDLE. UPPEF TYPE ~LOWE~ MIDDLE J UPPE~ LATCH IM~ ~~ OPERATOR'S NAME OTIS gREIgE IDATE DESCRIPTION ~-a~:es /0 TP, SV ' [ RECEIVED .MAR 1 9 1992 Alaska 011 & Was Oons. oommission Anchorage ~'. 0EC-6o3- ~ ~,p~: :_ : lffl"i~ ................................... MILNE POINT C-7 (P) OPERATOR: CONOCO INC. SlY. FACE LOCATION: 1009' FSL, 2396' FEL, Section 10, T13N, RiOE BOTTOM HOLE LOCATION: 4149' F~, 5032' EEL Section 3, T13N, RiOF SPUD DATE: 02/25/85 13 3/8" 48# H-kO at 1!5' 9 5/8" 36# K-55 ~trs. at 5840' Est. TOC at 8300'!* EC¥ 9623' ECF 96~?' 7T! 26# L-80 Btrs. at 9971' ORIGINAL ,~.,. 06/19/85 Datl NOTES: 1. 2. 3. 4. 5. 6. All measurements from tTDI,~ of Alaska United KDB - SL -- 52' KDB - GL = 35' Hax. apg]e = 51.5° @ 6079' M.D. KOP at 500' Slant Type He]e - YES 9 5/8" Surface CasSpg 1. Pumped 6C ~5]s cf Il ppg Sepiolite spacer for pre-flush. 2. Pumped 552 Bbls (1575 sx) of 12.3 ppg Permafrost "E" cement. 3. Pumped 56 Bbls (275 sx) of 15.8 ppg Class "G" cemept wJtk 3% ~aCl and 1% CFTC-2. 4. Displaced with 443 Bbls 9.3 ppg mud. NOTE: No cement returns to surface. 5. Pc~squeezed 9 Blbs of 15.6 ppg Permafrost Type "C" down annulus Centralizers: 1 per 80' surface - 5355' i per 4.0' 5355' - 5840' 7'; Productie~ Casing ]. Pumped 40 Bbis of 8.3 ppg Degcc ~r~f3usb. 2. Pumped 76 Bbls (375 sx) Class "C" cement with 1% CFR-2 and C.3% Ha!~d-2~. 2. Displaced with 376 Bbls of 10.2 pp~ ~eCl-¥aEr. NOTE: Mud returns lost while circu- latin~ near ~nd of displacement 4. Pumped 66 sx of 12.3 ppg Permafrost Type "E" for top job. 7" × 9 5/R" Annulus !. Pumped 33 Bbls f200 sx) of 15 ppg Permafrost "C" followed by 60 Bbls 7.7 ppg Arctic Pack. Ce~c~t/Arctic! Pack interface at 202©' ~, 1933 ' TVD. ~, Based on ]DO% excess Jn 8~" ho]c RECEIIYED MAR 1 9 Alaska Oil & ~as Co~ Anchor~ 1992 s. [;ornmisslo. 0 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 October 21, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Applications for Sundry Approvals Dear Mr. Johnston' Attached please find Application for Sundry Approval for Well C-7. This well is located at the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7653. Yours very truly, Wade L. Srock Senior Environmental Specialist RJS\bgs Attachments CC C-7 Well File \RJS\WP51 \AOGCC21 .RJS ECEIVED 0CT 2 3 1991 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown __ Re-enter suspended well . Alter casing __ Repair well __ Plugging_ Time extention Stimulate- Change approved program__ Pull tubing x Variance__ Perforatem Other x Replace ESP. 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development x 52' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit 4. Location of well at surface 8. Well number 1009' FSL, 2396' FEL, Sec. 10, T13N, R10E, Umiat Meridian C-7 At top of productive interval 9. Permit number 887" FSL, 4858' FEL, Sec. 3, T13N, R10E, Umiat Meridian 85-2 At effective depth 10. APl number 1108' FSL, 5012' FEL, Sec. 3, T13N, R10E, Umiat Meridian 50-029-21266 At total depth 11. Field/Pool 1172' FSL, 5046' FEL, Sec. 3, T13N, R10E, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 9940' feet Plugs (measured) true vertical 7429' feet Effective depth: measured 9840' feet Junk (measured) true vertical 7361' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 78' 13-3/8" 500 sx Permf C 115' 115' Surface 5803' 9-5/8" 56 bbl Class G 5840' 4725' Intermediate 522 bbl Permf E Production 9884' 7" 76 bbl Class G 9921' 741 Liner Perforation Depth: measured 9472-9486'; 9546-9552'; 9580-958~; 9726-9752' true vertical7112-7122'; 7163-7167'; 7186-7190'; 7286-7303' OCT 2 5 1991 Tubing (size, grade, and measured depth) 3-1/2" 9.2#/ft, L-80, 9630' Alaska 0il & Gas Cons. C0mm'tss[en Anchorage Packers and SSSV (type and measured depth) Camco TRDP-1A SCSSV @ 1912' BOT HB Pkr. @9322' BOT 2B Pkr. 9600' 13. Attachments Description summaryof proposal x Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: November 15, 1991 16. If proposal was verbally approved Oil x Gas __ Suspended Name of aF{prover Date approved Service 17. I hereby ce~tifythaI the foregoing is true and correct to the best of my knowledge. / Signed ;.~..~ i~, /~I~J~ J.H. Andrew Title Production Engineer Date October 18, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~ Approval No. Plug integrity BOP Test__ Location clearance| c:~ /,--- ~' ,~"t:~ Mechanical Integrity Test Subsequent form required 10-~ .&pproved Go~'~ ! · -- Returned il- (,":/1 _. ORIGINAL SIGNED BY Approved byorder of the Commission LONNIE ~. RI~,~ITI-!. Commissioner Date /0 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point Unit C-7 Well ESP Replacement Procedure Summary 1. MIRU workover rig. RECEIVED OCT 199t Alaska Oil & Gas Cons. Comm Ss Or Anchorage · Kill well by circulating hole full with 8.4 ppg source water. Spot salt-based LCM pills, if necessary, to control losses. 3. ND tree. NU and test BOP's. · MU landing joint to tubing hanger. PU 25,000# above pipe weight to release Otis RDH retrievable packer at 572'. 5. POOH with 3-1/2" production tubing and ESP. · RU wireline. GIH and tag sand fill in casing. POOH and RD wireline. TIH with sand bailer on production tubing and bail to clear perf interval, if necessary. · TIH with 7" retrievable bridge plug on 3-1/2" p~oduction tubing. Set 30' above top perforation. Test plug. · Release tubing from plug. Circulate casing clean with HEC pill, Dirt Magnet flocculent and source water until returns are clean. · Clean tubing by pumping, then reversing, surfactant. Super Pickle 10. Latch and release bridge plug. POOH with plug and tubing. 11. MU new ESP assembly and TIH on 3-1/2" production tubing. Install check valve two joints above pump and gas lift mandrel with dummy one joint above check. 12. MU an Otis dual packer with side penetrator. Install gas lift mandrel with gutted check valve one joint below. Install a 3- 1/2" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. 13. Land production tubing hanger and freeze protect annulus. 14. RU wireline and set a plug in an Otis X nipple located below the production packer. Pressure up against the plug to set the packer. POOH with plug and RD wireline. 15. Pressure test packer by pressuring up on annulus to 1800 psig. 16. Freeze protect tubing. ND BOP's, NU and test tree. 17. RDMO workover rig. RU and test flowline. Return well to ESP lift production. Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 October 15, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Applications for Sundry Approvals Dear Mr. Johnston: Attached please find Applications for Sundry Approvals for Wells C-7, L-8, L-9, and L-10. These wells are located at the Milne Point Unit. If you have any questions or require additional information please contact me at 564-7617. Yours very truly, Bob Soptei Environmental Coordinator RJS\bgs Attachments CC C-7 Well File L-8 Well File L-9 Well File L-10 Well File \FUS\WP51 \AOGCC20. RJS RECEIVED 0CT 1 1 1991 Alaska 0il 8, Gas Cons. C0mmissi0~ ~,nch0rage STATE OF ALASKA ~" ~'~ ~' ALASKA OIL AND GAS CONSERVATION COMMISSION '~' !? ~ ; APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend m Operation shutdown m Re-enter suspended well . Alter casing m Repair well Plugging __ Time extention Stimulate ~.~ Change approved program m Pull tubing Variance __ Perforate Other x Convert to Gas Lift 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development x 52' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit 4. Location of well at surface 8. Well number 1009' FSL, 2396' FEL, Sec. 10, T13N, R10E, Umiat Meridian C-7 At top of productive interval 9. Permit number 887" FSL, 4858' FEL, Sec. 3, T13N, R10E, Umiat Meridian 85-2 At effective depth 10. APl number 1108' FSL, 5012' FEL, Sec. 3, T13N, R10E, Umiat Meridian 50-029-21266 At total depth 11. Field/Pool 1172' FSL, 5048' FEI~ Sec. 3, T13N, R10E, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 9940' feet Plugs (measured) true vertical 7429' feet Effective depth: measured 9840' feet Junk (measured) true vertical 7361' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 78' 13-3/8" 500 sx Permf C 115' 115' Surface 5803' 9-5/8" 56 bbl Class G 5840' 4725' Intermediate 522 bbl Permf E Production 9884' 7" 76 bbl Class G 9921' 7417 Uner Perforation Depth: measured 9472-9486'; 9546-9552'; 9580-958~; 9726-9752' ECEIV£D true vertica17112-7122'; 7163-7167'; 7186-7190'; 7286-7303'OCT 1 ? 1991 Tubing (size, grade, and measured depth) 3-1/2" 9.2#/ft, L-80, 9630' Alaska 0JJ & Gas Cons, C0mm[Ss[en Anchorage Packers and SSSV (type and measured depth) Camco TRDP-1A SCSSV @ 1912' BOT HB Pkr. @9322' BOT 2B Pkr. 9600' 13. Attachments Description summaryof proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15, Status of well classification as: October 20, 1991 16. If proposal was verbally approved Oil x Gas Suspended ~ Name of approver Date approved Service · 17.1 hereby cel~ ifythati:he foregoing is true and correct to the best of my knowledge. Signed ~-,~'~/~/'ir~/'01~'' J.H. Andrew Tit~e Production Engineer Date October 14, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. 0 Plug integrity BOP Test Location clearanceI /7 //- '~! j Mechanical Integrity Test ~ Subsequent form required 10- Z/c~' Approved Copy Returned ORIGINAL SIGNED BY l~' ~ ' ff J ,- LONNIE C. Approved by order of the Commission Commissioner Date / 0 ' ,~ - ff I SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 Milne Point Unit C-? Well Convert to Gas Lift Producer The MPU C-7 well is an ESP producer. It is currently shut-in and awaiting workover following failure of the ESP. The following procedure is proposed to produce the well with gas lift until it is worked over. me · · · · · · RU wireline. GIH and tag/measure fluid level. Calculate maximum depth of injection. GIH with tubing punch with 1/8" Kinley check dart. Punch tubing and place dart at maximum depth of injection. RU gas lift injection line and metering equipment. Test new line and equipment as required. Begin gas lift injection. Measure and record rates. RECEIVED OCT 1 ? 1991 Alaska Oil & (;as Cons. Com~tss'to~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION REPORT OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown __ Stimulate m Plugging Pull tubing ~ J['''' Alter casing __ Repair well __ 2, Name of Operator CONOCO INC. 5. Type of Well: Development .__X Exploratory __ Stratigraphic __ 9973 Service ~ 3, Address P.O, BOX 340045, PRUDHOE BAY, AK 4, Location of well at surface 1009' FSL, 1396' FEL, At top of productive interval 4390' FNL, 4856' FEL, At effective depth At total depth 4149' FNL, 5032' FEL, SEC 10, T13N, RIOE, UN SEC 3, T13N, RIOE, UN SEC 3, T13N RIOE, UN Perforate Other X 6. Datum elevation (DF or KB) feet 7. Unit or Prop. ertv name MILNE POINT UNIT 8. Well number C-7 9. Permit number/approval number 90-390 10. APl number 5o- 029-21266 11. Field/Pool KUPARUK RIVER 12. Present well condition summary Total depth: measu red true vertical 9940' feet Plugs(measured) PBTD -9840' 7363' feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 13-3/8" 100 CF 115' 115' Surface 5,805' 9-5/8" 608 BBLS 5,840' 4,730 Intermediate Production 9,885 7" 76 BBLS 9,920' 7,363' Liner Perforation depth:measured MID KUP 9,472'-9,486', 9,546'-9,552', 9,580'-9,586' LOWER KUP 9,686-9,706', 9,726'-9,752' truevertical HID KUP 7,112'-7,122', 7,163'-7,167', 7,186'-7,190' LOWER KUP 7,259'-7,272', 7,286'-7,303' Tubing (size, grade, and measured depth) 3-1/2, 9.2", L-80, BTRC e9248' Packers and SSSV (type and measured depth) TOP PKR-BOT 'B' 89332' HIDDLE PKR - B0T '2B'@ 9600', OTIS RDH PKR e572', 13. Stimulation or cement squeeze summary N/A Intervalstreated (measured) N/A JUN 0 7 ]990 Aia~A .Oil & Ga~ Cons. Comml~On Anc'~ .... Representative Daily Average Production or I njec{l(~'ll~ta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Treatment description including volumes used and final pressure 14. Tubing Pressure Prior to well operation 821 243 35 1090 237 Subsequent to operation 791 176 70 30 198 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas_ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Kuparuk River- North Slope Borough, Alaska Milne Point C No. 7 CONFIDENTIAL MAY 24, 1990 MIRU, FILL TANKS W. SOURCE WATER, HEAT TO 100 DEGREES F. RU TRANS TECH SIL, LINES TO WELLHEAD, PULL BPV. BEGIN PUMPING SOURCE WATER DOWN TBG TO KILL. SID PUMPING & MONITOR PRESSURE - OPSI ON TBG AFTER 5 MINUTES. HEAT SOURCE WATER TO 150 DEGREES F AND FILL UP CSG W.233 BBLS. PUMP 20 BBLS WATER DOWN TG BEFORE RIH SIL RIH W/ JDC PULLING TOOL/PRONG- LATCH WRDP @1912'MD. SHEARED OFF. RIH W/JDC LATCH WRDP-POOH. PUMP 10 BBLS WATER DOWN TBG - OPSl. LATCH GLV IN BOTTOM GLM @9269' - BEGIN W/GLV TAKING RETURNS FROM ANNULUS. MAY 25, 1990 OFF LOAD & HEAT SOURCE WATER TO 100 DEGREES F BEGIN PUMPING DOWN TBG @80 PSI PUMPED 80 BBLS BEFORE GETTING RETURNS. CANNOT GET COMPLETE RETURNS @2 BPM. REVERSED CIRCULATION & PUMPED 43 BBLS DOWN ANNULUS - TOTALS...350 BBLS TBG. 276 BBLS ANNULUS CENTINUE MONITORING PRESSURES - TAG 0 PSI. ANNULUS OPSl. SET BPU, ND TREE, NU BOPE, TEST BOPE BOPE TEST WITNESS WAIVED BY BOBBY FOSTER, AOGCC. BOPE TEST GOOD. MU LANDING JT, TlW VALVE, POOH W/TBG HGR. POOH W/TBG. MAY 26, 1990 CONTINUE POOH W/3-1/2" TBG, GLM'S. LD BOTSA & COMPLETE TBG TALLY. ESP EQUIPMENT, SERVICE MOTOR/SEAL/POTHEAD RIH W/ESP, TBG. MU MAY 27, 1990 MU OtiS PKR, CABLE SPLICE TO PKR/ABOVE PKR MU OTIS SCSSV & RIH SET PKR @572' RKB 100K 65K LAND TBG HGR. RU TRANS TECH SlL TO RUN XX PLUG IN "X" NIPPLE @579' RKB POOH SlB MU TIW VALVE & PRESSURE UP W/DIESEL ON TBG TO 2500 FOR 15 MIN. TO SET PKR ELEMENTS. PRESSURE UP ON ANNULUS TO 500 PSI TO TEST PKR. GOOD TEST AFTER EXERCISING VENT VALVE 575 PSI - 15 MIN. RIH RETRIEVE XX PLUG POOH RD SlL UNIT SET BPV, ND BOPE, NU TREE/TEST TREE CLEAN PITS. MOVE RIG TO C-2. STATE OF ALASKA ALASKA OIL AND OJL~ CONSERVATION ~OP£ Inmpeottol~ Report R~trRll --_ Upp. Ke11¥ ~. ~ i i ~: .- - lnd Inlpeo~or/C~lilton offlo$ notlfled. ECEI.VE D orfg · AOOCC o - Opo?ttoe e - Supervisor C.004 (rev 05117/8g) Conoco Inc. IVlilne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. MIKE MINDER STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. MINDER, ATTACHED IS THE REQUEST FOR SUNDRY APPROVAL TO CONDUCT WORKOVER OPERATIONS ON THE C-7 WELL. THESE OPERATIONS WILL BE NECESSARY TO CONVERT THE PRODUCTION TECHNIQUE ON THE C-7 WELL FROM THE CURRENT GAS LIFT DESIGN TO ELECTRIC SUBMERSIBLE PUMP DESIGN. RESPECTFULLY, ~.D~LYA DRILLING FOREMAN ~k~.Oii.& Gas Cons. '"~ STATE O F ALAS KA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing "X-- Variance __ Perforate ~ Other "X'- 2. Name of Operator CONOCO INC. 3. Address P.O_ ROX .~400/t~. PRUDHOF RAY_ Al( cjc173d 4. Location of well at surface 1009' FSL, 1396' FEL, Sec 10, T13N, R10E, UM At top of productive interval 4390' FNL, 4856' FEL, Sec 3, T13N, RIOE, UM At effective depth 5. Type of Well: Development -X- Exploratory __ Stratigraphic __ Service __ At total depth 4149'FNL, 5032' FEL, Sec 3, T13N, RIOE, UM 6. Datum elevation (DF or KB) KB 35 feet 7. Unit or Property name MTINF POTNT UNTT 8. Well number ¢-7 9. Permit number 85-2 10. APl number I 50-- 029-212§~i 11. Field/Pool Kuparuk ~i v._~ ......... 12. Present well condition summary Total depth: measured true vertical 9940 ' feet Plugs (measured) 7363' feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor 80' 13-3/8" '100 CF Surface 5,805' 9-5/8" 608 BBLS Intermediate Production 9,885' 7" 76 BBLS Liner Perforation depth: PBTD - 9840' ~'~A\'"' 2 1 ]9~'.:~ .,,,.~, :,:',:;ka.Ojj & Gas Cons. Commissi0 ' ...... ~ ~nchora~ . Measured depth True ve~ical depth 115' 115' 5,840' 4,730' 9,920' 7,363' measured MID KUP 9,472'-,9,486', 9,546'-,9,552',, 9 580'-9,586' LOWER KUP 9,686 -9,706', 9,726 -9,752 ' truevertica~ID KUP 7,112'-,7,122', 7,163'-7,167% 7,186'-7 190' LOWER KUP 7,259 -7,272', 7,286'-7,303" ' Tubing (size, grade, and measured depth) 3-1/2, 9.2", L-80, BTRC ~ 9630' Packers and SSSV (type and measured depth)[oP PKR - BOT 'HB' ~ 9322'. BOTTOM PKR - BOT '2B' @ 9600't SSSV - CAMCO TRDP lA @ 1912' 13. Attachments Description summary of proposaX__ Detailed operations program L BOP sketch,Y~__ 14. Estimated date for commencing operation MAY 30, !990 16. If proposa/was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X._ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.,.~, ,~2~--~¢~. Title SI=II,OR PRODUCTION FORE"AN - - - FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test__ Subsequent form req.~i.[e~.'JO- ' ORIGINAL STONED U~ LONNIE C. SM!TH Approved Copy Retu Approved by order of the Commission _.. I _ [:J~)en~issi°ner Form 10-403 Rev 06/15/88 - lApprOval NO' Date '~-- 2.,_.~ ---~ SUBMIT IN TRIPLICATE MILNE POINT UNi, C-7 ACTUAL COMPLETION SKETCH COMPLETED ON 3-1 1-81i FMC TUBING H/UqK~R ./ 3 I/t" 'H' PROFILE I. All laelo~'elaente ere Ir®la KDB el KDB - 8L = 52' KDB - GL : ~5 KOP at ~' 7. M~. ingle 46° ~ 9~' FMC ~ 1/8' APl EOO0~ tree ~Hh ~ 1/2' · f~. treetop M~ feetrl¢t~n ~ C~O 'D' ~ et ~22' 10, APl Me. 11, G~t~n f~ld 10.2 ~g ~CI-~Br 12 ~, I~° ~s~g, 5" 9~s (Ali ~t~ ~E K~ ~72'- 94~' MD TI 12'- 7122' TVD I/2", 9.2~ L-~O Buffmsstul:m; (2.992"1D, 2.~67"1~'ift) 1912' 2188' GLM 3102' GLM 3945' GLM 4794' GLM 5522' GLM CAMCO 6Z83' GLM 7073' GLM 7830' GLM 8582' GLM 9269' GLM CAMCO WPDPI TRDP IA SSA SCSSV (2.BI2" ID) Not locked bul w/ wRDP- I- TRDP- IAEL iff place {I.SG2' lC)) 3 ~" KBUG GLM -- BOT 8' PBR Seal Ammbty (3.00" ID) BOT 'HB' pocket (2.89'1D) L-8 954E'- 9552' lad 7163'-7167' TVD L-9 MC'- cJ~E' MD 718~'-7190' TVD LK- 2 9~6'- 9752' MD ~86'- 7~' TVD DtL ~ 0~-~-~,) LK -I 97~' ~ 7272' TVO -- 9360' CAMCO 'W-I' ~active Nellie (2.812"1D} CAMCO 'MMG-2' Gas Lift Mandrel (GL.M)= 2.92'1D, -- s4~e' · 478' Blast Joint (-'20') 4.250'OD, 2.992" ID -- Blast Joint (4.250'00, 2.c~2'' ID) = t20' --Blast Joint (4.25C" 00, 2.992" ID) :t 20' 9~)8' BOT LOcoIor, ~al ~ly {3,~" ~' BOT '2~' ~m~f ~ker (5.875" ~, 4~" ID), with Ix~ (5.~" ~, 4.4~" ID)' FRACTURE STIMULATION; 9-16'85 Lower Kvp (2) 20,000 lbs ISP away (Sc;e~ned avl ) ACID STIMULATION Il- 2 - 85 Middle Kup / L-8/ L-9 900 gat 15% HCl 1200 9ol 12-3 Mud Acid 30 g*ol. IO°~ Acetic Acid Bm,~e .1D-44..4~ . -- c,~cc 'O' N~q.~" ~) 9630' Tuth~ TQ~t '.~. ~ ~21' 7" 25d~' L-lO ITRS {{.27~' lC), 6,1SI"drift} MIINE POINT C-7 (P) OPEP~TOR: CONOCO INC. SL~FACE LOCATION: 1009' FSI., 2396' EEL, Section 10, T13N, R10E BOTTOM HOLE LOCATION: 4149' FNL, 5032' EEL Section 3, T13N, R10E SPUD DATE: 02/25/85 NOTES: ]. All measurements fro~ IVD~ of Alaska United #3 2. KDB - SL = 52' 3. KDB - Gl, = J5' 4. Max. angle = 51.5° @ 6079' M.D. 5. KOP at 500' 6. Slant Type Hole - YES PBTD 9840' 13 3/£" 48# H-LO at 115' 9 5/8" 36# K-55 ~trs. at 5840' Est. TOC at 8300'±* ECF 9623' ECF 9642' 7~! 26# L-80 Btrs. 9 5/8" Surface Cas~ 1. Pumped 40 ~b]$ cf ]! ppg Sepiolite spacer for pre-flush. 2. Pumped 552 Bbls (1575 sx) of ]2.3 ppg Permafrost "E" cement. 3. Pumped 56 Bbls (275 ax) of 15.8 ppg Class "G" cement w~tb 3% NaCi and 1% CFR-2. 4. Displaced with 443 Bbls 9.3 ppg mod. NOTE: No cement returns to surface. 5. Pc~.~squeezed 9 Blbs of 15.6 ppg Permafrost Type "C" down annulus Centralizers: 1 per ~0' surface - 5355' 1 per 40' 5355' - 5840' 7': t'rod~:ct~em Cas~n~ 1. Pumped 40 Bbls of 8.3 ppg Descc pr~f]ush. 2. Pumped 76 Bbls (375 ax) Class "C" cement with 1% CFR-2 and 0.3% Ha!sd-2~. 3. Displaced with 376 Bbls of 10.2 pp~ NzC]-¥aEr. NOTE: Mud returns lost while circu- latinf near ~nf cf displacement 4. Pumped 60 sx of 12.3 ppg Permafrost Type "E" for top job. 7" x 9 5/8" Annulus 1. Pumped 33 Bbls (200 sx) of 15 ppg Permafrost "C'~ followed by 60 Bbls 7.7 ppg Arctic PacP. Cement/Arctic Pack interface at 2020' 1933' TVD. based on 100% excess in 8%" hole. MPU KUPRRUK RESERVOIR PROCEDURE FOR CONVERSION OF GRS LIFT WELLS TO ELECTRIC SUBMERSIBLE PUMP 1. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL. WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) C-2 7151 2732 1194 7.85 C-3 7017 2570 1548 7.54 C-7 7192 2370 1240 6.84 C-14 7050 3580 1432 10.3 C-16 7050 3600 1225 10.5 (NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP. 8.33 PPG SOURCE WATER WILL BE USED AS KILL FLUID FOR C-2, C-3, AND C-7. C-14 AND C-16 WILL BE KILLED WITH 10.3 AND 10.5 PPG NABR BRINES, RESPECTIVELY. CURRENTLY, 450 BBLS OF 10.3 PPG AND 450 BBLS OF 10.5 PPG NABR BRINE ARE BEING STORED IN TWO 500 BBL TIGER TANKS ON C PAD. THERE IS ENOUGH DRY BULK BEING STORED AT MILNE POINT ON C PAD TO MIX AN ADDITIONAL 600 BBLS OF 10.3 PPG AND 600 BBLS OF 10.5 PPG NABR IN THE EVENT THAT WE ARE WORKING ON EITHER C-14 OR C-16 DURING BREAKUP. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL. BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 30' PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES NOT LESS THAN 500 FT MD. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. (IMPORTANT NOTE: THE COMBINED MEASUREMENT OF THE DIAMETERS OF THE #2 ROUND CABLE DIAMETER AND THE SCSSV IS 6.07 INCHES -- THE DRIFT OF THE ?" CASING IS 6.059" (TO0 LARGE TO FIT). IT WILL THEREFORE BE NECESSARY TO SPLICE APPROX. 20 FT OF #2 FLAT CABLE TO EXTEND ACROSS THE SCSSV.) 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS T0~500 PSIG FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NEXT WELL. THIS PROCEDURE IS IN ACCORDANCE WITH AN EARLIER PROCEDURE WHICH WAS: PREPARED BY STEVE ROSSBERG, SENIOR PRODUCTION ENGINEER (3/23/90) REVIEWED BY MARC SHANNON, SUPV. PRODUCTION ENGINEER (3/2?/90) APPROVED BY GARY FLOWERS FOR JACK COPELAND, PRODUCTION SUPT. (4/3/90) $.D. POLYA DRILLING FOREMAN STATE OF ALASKA I 0 R ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing ~ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator Conoco Thc. 3. Address Box 340045, Prudhoe Bay, AK 99734 4. Location of well at surface 1009' FSL, 2396' FEL, At top of productive interval 4390' FNL, 4856' FEL, At effective depth Section 10, Section 3, Attotaldepth 4149' FNL, 5032' FEL, section 3, T13N, T13N, T13N, 5. Type of Well: Development x._x_ Exploratory __ Stratigraphic __ Service __ R10E, UM R10E, UM R10E, UM 6. Datum elevation(DForKB) KDB 52' Pad 17' , % UnitorPropertyname Milne Point Unit 8. Well number C-7 feet 9. Permit number 85-2 10. APl number 50--029-21266 11. Field/Pool Kuparuk River 12. Present well condition summary Total depth: measured true vertical 9940' 7363' feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet PBTD Casing Length Size Cemented Structural Conductor 80' 13-3/8" 100 cf 115' Surface 5,805 ' 9-5/8" 608 bbls 5,840 ' Intermediate Production 9,885 ' 7" 76 bbls 9,920 ' Liner Perforation depth: measured Mid Kup 9,472 '-9,486', 9,546'-9,552 ', Lower Kup 9,686'-9,706', 9,726'-9,752' true vertical Mid Kup 7,112'-7,122' 7 163'-7 167' , , , Lower Kup 7,259'-7,272', 7,286'-7,303' 9.2", L-80, BTRC @ 9630' Tubing (size. grade, and measured depth) 3-1/2, Measured depth 9840' RECEIVED s P281989 Alaska Oil & Gas Cons. Com[ 115' 4,730' 7,363' 9,580'-9,586', 7,186'-7,190' Packers and SSSV (type and measured depth) Top pkr - BOT 'HB' @ 9322', Bottom pkr - BOT '2B' @ 9600' SSSV - Camco TRDP lA @ 1912' 13. Attachments Description summary of proposal __ Detailed operations program __x BOP sketch __ 14. Estimated date for commencing operation October 4, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify th~the foregoing is true and correct to the best of my knowledge. Signed 4,, Title___.,(~'~ Production Foreman FOR COMMISSION USE ONLY Date 09/25/89 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C, SMITH Commissioner JApproval No. Approved Copy Returned Date C"~-. ~L)fl-. ~? Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ssi0. STIMULATION PROCEDURE ~-. ydraulically Fracture MPU Wel, !7 Milne Point Unit Surface Location: 1009' FSL, 2396' FEI, Sec. 10, T13N, RIOE, UM All depths are measured from KB datum. Casinq: Surface - g S/8", 36#/ft, K-55 btrs., set at 5,840t. Production- 7", 26#/ft, L-80, btrs., set at 9,921'. Capacity: 3.82 bbl/lO0' Burst Pressure: 7,240 psig Tubing: 3 1/2", 9.20#/ft, L-80, btrs @ 9,630' Capacity: 0.8700 bbl/lO0' Capacity of tubing/casing annulus: 2.64 bbl/lO0' Burst Pressure: 10,160 psig {no safety factor) Rat Hole Volume: 8 bbl. Present Completion: Single selective Middle Kuparuk 9,322'- 9,600'. Lower Kuparuk 9,686t- 9,706', 9,726'-9,752~ Present Status: Kuparuk producing well. Objective.;. Fracture stimulate the LK to increase the rate of production. ~Recommended Procedure ;. 1) Hold a pre-frac meeting with all contractors to discuss job requirements and safety prior to the job. 2) The well contains a Camco TRDP-1A SCSSV with WRDP-1-TRDP in place. Run in with slickline and retrieve WRDP and lock open the TRDP. Keep the valve open for the remainder of the job. 3) Run in the hole with slickline and retrieve gas lift valves from the mandrels depicted on the attached wellbore diagram. Install dummy valves in the mandrels. Run in the hole with slickline and place dummy valves in the selective interval gas lift mandrels located at 9,393' and 9,438'. Run in the hole with slickline and set tubing plug in "D" nipple set at g,622'. Pressure test tubing to 6,000 psig surface pressure {9,140 psig bottom-hole allows for a 10% safety factor on the tubing). Retrieve tubing plug. If tubing does not hold contact Anchorage office before proceeding. 4) Spot four 500 bbl frac tanks on location approximately 150' from the well- head. Elevate the rear of the tanks approximately 8" Visually inspect the interior of the tanks for cleanliness (do not climb into the tanks). Fill each tank with 500 bbls. of clean MPU injection water. The water should be heated and maintained at 75-80 degrees F in order to insure proper hydr- ation of the gelling agent. Distribution' TRP, JDC, PJG (2), MPU Senior Foremen RECEIVED ssP281989 & Gas Cons. Anchorage Fractu're MPU We' )7 "" February 24, 198~ ' Page 2 5) Rig up tree saver and service company pump lines (use no threaded cross- overs, swedges or valves). Install two shut-off valves on the wellhead. Use two in-line densiometers. Set up backup pumps for crosslinker and diesel. Rig up annulus pump to maintain 2,000 psig backside pressure. 6) Batch mix 2000 bbl. (84000 gal.) gelling agent at 40 lbs/lO00 gal containing 2% KCL, 500 ppm biocide and 5 gal anti-foamer per tank. Crosslinker, breaker, surfactant, non-emulsifier, 5% diesel and a particulate fluid loss material will be added on the fly as outlined in the pumping schedule ( See Material Detail). 7) Fill out the fluid report forms. Check all additives against the attached material detail. Continuously roll the tanks until the viscosity is within the recommended limits ( 45 to 55 at 300 rpm on Fan 35 viscometer). Check 'samples from the top and bottom of the tank, values should correspond within 3 cps. 8) Hold a safety meeting with all personal on location. 9) Pressure test the surface lines and tree saver to 6,000 psig. Check the lines to insure that there are no leaks. Pressure up the annulus to 2,000 psig and maintain throughout the job. 10) Prepare to pump the frac job as follows: A) Standby pumps (50%) are required. These pumps must be manned and primed to immediately come on .line if needed. A standby blender must be hooked up and ready to come.on line ~in. the~:case'of primary bl'ender failure. Pump the first $,000 gal of pre-pad on standby blender.'Shut down and record the ISIP. SWitch to main blender for the remainder of the job. B) Tank bottoms are included in the volumes listed in' step 6. Leave 50 bbls tank bottom. Use the in-line densiometers during the job. Record pressure and rate on a strip chart. Send the charts to the Anchorage office. D) Take samples of the crosslinked gel during the job. Place them in a water bath at 165 deg. F. Observe the samples and note when the gel breaks. E) Pre-Pad and flush fluid is not crosslinked and does not contain diesel oil. The last 1100 gal. of flush is 100% diesel to prevent freezing. F) DO NOT OVER DISPLACE. RECEIVED s[P281989 Gas ConS. Anchom.ee Fracture MPU We' February 24, 1989 Page 3 Frac Rate: 25 BPM Maximum Allowable Surface Pressure: 6,000 psig @ 25 BPM Anticipated Surface Pressure: 4,500 psig to 5,000 psig Gel Diesel Cum Sand Cum Fluid Pump Time Stage :(gal)_ (gal)_ _p_p_g lbs. (lbs.) ~ Minutes P-Pad 13,000 13,000 12.4 Pad 38,000 2,000 53,000 50.5 I 3,730 196 0.5 ],963 1,963 57,000 54,3 2 5,745 302 2.0 ]2,094 14,057 63,500 60.5 3 5,370 283 4.0 22,613 36,670 70,000 66.7 4 3,103 163 6.0 19,597 56,268 74,000 70.5 5 2,924 154 8.0 24,624 80,891 78,000 74.3 Flush 2,487 Flush ],100 Totals 74,359 4,198 80,891 80,891 81,587 77.7 Cum fluid=gel+diesel+sand Pre-Pad and Pad should contain 50#/lO00gal. fluid loss additive. Surfactant and non-emulsifier added on the the fly to all gel ~except flush. 11) Shut down. Allow the pressure to bleed off into the formation. Record the ISIP, 5minute, 10 minute and 15 minute pressures. Close all surface valves and leave the well shut-in over night. Leave the SCSSV open. Have the service company monitor the break time of the last sample collected. Rig down service company. 12) Allow the fracture to heal for 24 hours and rig up to flow back. 13) Rig up slickline. Run in the hole and tag fill. If fill is above 9,752' (bottom perf), rig up coil tubing and clean out to 9,840' PBTD. Rig down coil tubing. If necessary, engineering will provide a coil tubing procedure. 14) Return the well to production very slowly. Begin with the choke set at 6/64" and increase the choke size by 4/64" every 2 hours to a maximum of 24/64". 15) Monitor for proppant returns. If after 300 bbls. of recovery, there is no proppant return and load recovery is less than 20%, open the choke to 64/64" and obtain a stabilized post-frac flow test on the Lower Kuparuk. 16) Shut-in the well and rig up slickline. Run in the hole and pull dummy valves and re-run gas lift valves. Open the selective interval by pulling the dummy valves and return the well to full rate production from both the MK and LK intervals. RECEIVED SF P281989 Alaska 0il & Gas Cons. Commissio Anchorage Fracture MPU Well February 24, 1989 Page 4 MATERIAL DETAIL Clean MPU injection water KCL (2%) Gelling Agent (40#/lO00gal Hydroxypropylguar) Nonionic Surfactant (2 gal./I,000 gal) Non-Emulsifier (2 gal/lOOOgal) Cross Linker (3#/lO00gal) Anti-Foamer (Sgal/tank) B ioc i de (500 ppm) FLA (50#/lO00gal Pad and Pre-Pad only) Breaker Diesel '16-20 Intermediate Strength Prop 84,000 gal. 14,280 lbs. 3,360 lbs. 150 gal. 150 gal. 186 lbs. 20 gal. 42 gal. 2,650 lbs. As recommended by service company. 4,190 gal. 80,891 lbs. Note: Diesel and prop should not be included in service company bid. Service company should be prepared to supply either Adomite Aqua or OAP fluid loss additive at Conoco's discretion. TREATMENT HYDRAULICS Maximum Rate: 25 BPM Average Anticipated Pressure: $,000 pstg ..... ..... Estimated Hydraulic Horsepower: 3,064 hhp (An additional 5(7Y~ hp'capactty is... ...... required on location) Backside pump capable of maihtaining 2,000 pstg'stattc-surface pressure-is required. The following backup equipment is required: 1) 50% backup on primary injection pumps. 2) 100% blender backup. 3) 100% backup on diesel and crosslinking pumps. Prepared by: Steve Rossberq Production Engineer Approved by :~~/~~..~ Super~ising Production Engineer Field Superintendent RECEIVED s P281989 Alaska Oil & Gas Cons. C;ommissio. Anchorage ... MILNE POINT UNIT 0-7 ACTUAL COMPLETION SKETCH COMPLETED ON' '3- 1 1-85 NOTEB: .. FMC TUBINO HANG(R e/ 3 I/I' 'H' PROFILE AR mellurlmtnll Ifa horn KgB el Alaska United ~S KDI - 8L ' t. KgB - (IL · Mil. eagle ~L5° et 6OT9' MO KOP et 5(30' I. Ilenl lype hole YES ,. Miff. angle 4&e FM~ 3 I/1' APl tO00, tree w~h I I/1' (10, 2?50"} APt No, 60-C~-212G~ 1t. Caaplellon timid 10.2 KR~RAT~ ~E K~ ~72'- 94'~' MO Tilt'- 71E2' TYO L-I 99~'- ~0'- 9~8' MO 7186'- ~190' T~. LK-e . 972~- 9752' MO 7~8~'- 7~3' T~ 4 ~F, LK-I 7259'- 7272' TVD ' FRACTUR[ STIMULATtON: 8-16-g$ Lower Kul) (2) ACIO STIMULATION l-2-1S Middle Kup / L-a/L-~ 900 ~1, 1200 got. f2-S Idv4 Acld 30 pl. IO°/e Acetic Acid I/2", 9.2~ L-80 Outtrtea tvbln~ (2.992:"10, 2.6eT'DHfl) 191~' 3945' 4794' 5622' 628~' . CAMCO WPDPI TRDP IA SSA SCSSV (2.912" ID) Nol locked but o/WROP-I- TRDP- IAEL fit piece (I. 562' I0) OLM .. OLM ' .' CAMCO 3~" KBU0 OLM · OLM ~M , GLM · m 80T 8' PBR gaol Ammbly (~.CX)" I0) 901' 'H8~ pQC~M (2.89' ID) , -, 9560~ (~AMCO 'W-I~ Sdectlvt Nlppte (E.81'2"10) " -- 9593* CAMCO 'MM~-~' (3~e Lift Mo~drd {GCAI)· LgZelD, I.S"valvll - 943~ OLM ' -947~' Bloat Joint (S20') 4.2~O"OO, LgP'Z"IO BIo.t Joint (4.250"(30~ E,992" I0) · 120' 61oel Joint (4.250" 00, t.992" ID) , I 2~ % 9598' 60T Lo¢o~, Seal A~ (3.~' ~ ~' 80T '26' ~m~t ~ker (5.870'~ 4~" I~, with ~lf~ RECEIVED CAMCO 'O' H11:,~e (2.750'" O) Alask Oil & Gas Cons. ComCs Anchorage 9840' PBTO ( Celln4 meae~rement ) 99~f' T' Z6,4~ L-CO BTRg (8. ZTl'lO, g.151~drlfl) -TBS. Vo L. PILNE POINT C-7 (P) OPERATOR: CONOCO INC. , SL~.FACE LOCATION: 1009' FSI., 2396' FEL, Section 10, TI3N, RIOE BOTTOH HOLE LOCATION: 6149' FNL, 5032' FFL Section 3, TI3N, RIOE SPUD DATE: 02/25/85 13 3/8" 68~ H-40 at 115' 9 5/8" 36l K-55 Bits. at 5860' Est. TOC at 8300'a* ECP 9623' ECP 9643' 7I' 261 L-80 Btrs. at 9921' NOTES: {. All measurements from KDB of Alaska United ~3 2. KDB - SL - 52' 3. KDB - GL = 35' &. Hax. avg]e - 51.5' @ 6079' 5. KOP at 500' 6. Slant Type Bole - YES 9 5/8" Surface Casin~ 1. Pumped 60 Fbls of 11 ppg Sepiolite spacer for pre-flush. 2. Pumped 552 Bbls (1575 sx) of 12.3 ppg Permafrost "E" cement. '3. Pumped 56 Bbls (275 sx) of 15.8 ppg Class "O" cement vtth 3~ NaCl and 12 CFR-2. &. Displaced with 443 Bbls 9.3 ppg mud. NOTE: No cement returns to surface. 5. Downsqueezed 9 Bibs of 15.6 ppg Permafrost Type "C" down annulus Centralizers: I per 80' surface - 5355* I per 40' 5355' - 5860' 7" Productten Casing 1. Pumped 60 Bbls of 8.3 ppg Desco pref]ush. 2. Pumped 76 Bbls (375 sx) Class "O" cement vith 1~ CFR-2 and 0.32 Ralsd-26. 3. Displaced with 376 Bbls of 10.2 ppg NaCl-~aBr. NOTE: Nud returns lost while circu- lating near end of displacement a. Pumped 60 sx of 12.3 ppg Permafrost Type "E" for top Job. 7" x 9 5/8" Annulus 1. Pumped 33 Bbls (200 sx) of 15 ppg Permafrost "C" followed by 60 Bbls 7.7 ppg Arctic Pack. Cement/Arctic Pack interface at 2020' 1933' TVD. * Based on I002 excess in 8¥' hole. RECEIVED sEP28i989 .Alaska 0il & 6as Cons, OomCSs.io', Anchorage Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 March 30, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. B-9, B-lC, and C-7. If you require additional information concerning these well histories, please contact Don Girdler at 564-7637. Yours very truly, E. D. Wilson Sr. Administrative Coordinator DRG/vv B-9, B-lC, C-7 RECEIVED fvlAR 1 1987 Alaska Oil & Gas Cons. Commission Anchorage Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.7- CONFIDENTIAL (9,940'-Kuparuk River) AFE 10-61-1088 API No. 50-029-21280. Ak. Permit No. 85-2. Elevation: 59' KB. Location: 1009' FSL, 2396' FEL, Sec. 10, T13N, RIOE, Umiat Meridian 02-26-85: Accept rig 1730 hrs. Skid rig, rig up collar. NU diverter system. PU BHA, RU. Test diverter system, function; pressure test 100+ psi. Both diverter lines warmed & verified ice-free. PU BHA (motor & MWD & DOT sub) service & orient, electronics & venting valve. Spud in @ 93'. Drlg f/93' - 137'. Bit plugged, 2 jets. Trip r/137', clean jet, repair float. Drlg f/137' - 291'. Navi-drill washout mach 1 8". Trip f/291', change Navi-drill to mach 3, re-orient. Drlg. f/291' - 315'. 02-27: Drlg. 315' - 1411'. Trip 1411' - surface. Change BHA. Trip surface to 1411'. Drlg 1411' - 2668'. 02-28: Drlg. 2668' - 2729' w/wire line check shot. Trip ±2729'-sur- face, change BHA & PU motor and orient. Trip surface-2729'. Tight spot @ 1558'. Drlg. 2729' - 3531'. Trip 3531' - surface. MWD failure - service MWD, ck bit. Trip surface - 3531' w/test of MWD. Drlg 3531' - 3858'. 03-01: Drlg. to 5476' & pump pill. Trip 5476'-surface. Pulled tight @ 1050' to 540'. Unable to go down. Change BHA. 03-02: Trip surface - 5719', no bridges. Drlg to 5860'. Circ. bottoms up & drop survey. Trip 1860' - surface, SLM - no correction. RU & run 148 jts. of 9 5/8" 36# K-55 buttress csg. shoe @ 5840' & float collar @ 5760' w/80 centralizers. Circ. inside vol. of csg. & mix spacer. Pump 40 bbls 11 ppg Sepeolite preflush. Drop btm plug, pump 5 bbl/H20. Load & lock top plug. Test lines to 3000 psi. 03-03: Mix & pump 552 bbls 12.3 permafrost E cmt., followed by 56 bbls 15.8 ppg Class G cmt w/3% salt, 1% CFR-2. Displaced w/440 bbls of drlg mud, bumped plug w/2000 psi. Floats held-CIP @ 0930. No "CMT" returns to surface. ND diverter. Ran tbg into 13 3/8 X 9 5/8 annulus and pumped 9 bbls permafrost C cmt @ 15.6 ppg until cmt returned to surface & RD Halliburton. NU BOP & test 5" rams, choke manifold, HCR. All valves on stack, floor safety valves to 5000 psi & test. Blind rams to 5000 & annular to 2500 psi; test witnessed by AOGCC - B. Foster. Install wear ring & PU BHA. RIH w/bit to FC @ 5759' and test 9 5/8 to 1500 psi - 30 min. Drlg plugs & cmt & float collar & shoe @ 5839' & 30' new hole to 5890'. Circ btms up and balance mud wt. Pull leak off test @ 4746' TVD = 12.0 EMW. 03-04: Drlg 5890'-5920'. Trip 5920'-0'. Change BHA, PU Navi-drill & MWD. Trip 0'-5920'. Drlg 5920'-7693'. 03-05: Drlg. 7693'-9200'. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.7- CONFIDENTIAL (9,940'-Kuparuk River) AFE 10-61-1088 API No. 50-029-21280. Ak. Permit No. 85-2. Elevation: 59' KB. Location: 1009' FSL, 2396' FEL, Sec. 10, T13N, R10E, Umiat Meridian 03-06: Drlg 9200'- 9880'. Survey & circ. for short trip. Short trip to shoe @ 5839'. Circ. btms up & deep survey. POH f/logs - SLM. 03-07: Finished POOH from 9880' to surface. Service and laydown Navi-drill & MWD. RU Schlumberger, RIH to 9877' logged GR-SP-DIL from 9877' to 5837' CNL-LDT-Cal from 9877' to ~300' and 5837' to 4300', RD Schlumberger. RU Gearhart, RIH caliper, failed, POOH, changed calipers, RIH to 9885' hit bridges at 6878' 7200' 7300' 8960'. Logged GR-SP-DIL-CNL-Cal from 9885' to 9155' , RD Gearhart. PU BHA. RIH to 5890'. Cut 100' drlg line. RIH. 03-08: Work on SCR's, repaired one SCR. POOH w/5 stds (on 1 SCR) from 9780' to 9325'. Work on SCR's, repaired other two SCR's. RIH from 9435' to 9848', reamed 9848' to 9880'. Drld from 9880' to 9901'. Stabilizers trying to pack off and hole tite, ream and clean-out hole from 9850' to 9901'. Drld from 9901' to 9940'. Circ. and Cond. mud and hole. POOH laying down from 9940' to 0'. Changed rams, pulled wear ring, RU csg crew. Ran 83 jts at 7" 26# L-80 btrs. csg. 03-09: Ran 147 jts of 7" 26# L-80 btrs csg. with full returns (circ. @ jts. #83 and #166). Hit small tight spot @ 8819', ran free to 9053' and set down. PU and tried to break circ. and couldn't, layed down 1 jt. worked pipe 8972'-9013' and regained circ., couldn't circ. next jt. down (9013'-9053'). Worked 20 jts of 7" 26# L-80 btrs csg. to bottom (9053'-9920') with no returns, total jts 251, shoe @ 9920'. FC @ 9840'. ECP #1 @ 9643', ECP #2 @ 9622'. Total 35-centralizer, 38 standoffs. RU cementing head and tried to break circ. @ 1@ BPM w/no returns, then gradually got returns, tried moving pipe but well packed off each time, worked rate up to 3 BPM and circ. csg, had to adjust rate to keep well from packing off. Pumped 40 bbls of 8.33 ppg water w/2#/bbl of Desco as preflush. Cemented csg. with 375 sks Class "G" w/l% CFR-2 & 0.3% Halad 24 wt, 15.8 ppg. Now displacing w/10.2 ppg NaCl-BrC1 (376 bbls total). 03-10: Finished displacing cement w/376 bbls of 10.2 ppg NaC1-BrC1, full returns to 335 bbls, then well packed off and lost all returns. Rate 4 to 1 1/2 BPM. Pressure 500-1900. Bumped plug to 2000 psi and set ECP's. Floats held O.K. Cement in place. Pumped 60 sks of permafrost "E" cement for 9 5/8" top job , wt-12.3 ppg, RD csg tools, landing jt and test 7" packoff to 5000#. RU Dresser, run #1, ran GR, CCL, Temp log from 9826'-9000', Run #2, ran Gyro from 0-9800'. Run #3, perfed 9726'-52' Run #4 perfed 9580'-86' and 9546'-52' Run #5 perfed 9472'-86'. 624 holes, 12 shots/ft., Run #6, ran 6.125" GR and junk basket from 0 to 9752', Run #7, ran BOT 2-B permanent pkr w/millout extension, "D" nipple & shearout sub set @ 9591' WL measure- ment. RD Dresser. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.7- CONFIDENTIAL (9,940'-Kuparuk River) AFE 10-61-1088 API No. 50-029-21280. Ak. Permit No. 85-2. Elevation: 59' KB. Location: 1009' FSL, 2396' FEL, Sec. 10, T13N, R10E, Umiat Meridian 03-11: Displaced tbg. volume (+ 10 bbls) w/diesel (95 bbls) U tubed 10 bbls into 7" X 3 1/2" annulus. Landed tbg., tested pkr and tbg hanger to 1500 psi. Closed SSSV, backed out landing it. Lay down landing it., RD tbg tools & Camco. Installed back pressure valve. ND BOP's. 03-12: Finished RD Dresser. Changed top pipe rams to 3 1/2", tested rams to 3500 psi. PU tbg tools and control line, RU tbg. tools and Camco· Make up and run seal assembly, 3-20' blast jts., 299 jts of 3 1/2" 9.2# L-80 btrs tbg., BOT HB pkr, Camco SSV and the hanger, wireline set pkr @ 9600.11 tbg measurement, HB pkr @ 9322.04', D nipple @ 9621 78' W nipple @ 9360 04' Also ran gas lift mandrels · , · , · Stab-in bottom pkr, pressure up to 1200 psi, slow leak off into perfs, no communication, dropped ball pumped in @ 2 BPM @ 1700 psi, no communication, WO ball, pressured up to 3200#, set pkr, sheared shearout sub, pickup to 160,000#, sheared out of top PBR, spaced out. Make up hanger, control line and landing it. 03-12: NU tree. Test tbg, pack off to 5000#, test T-seals to 5000#. Test tree to 5000#, left BP valve in tree. RELEASED RIG. Telecopy No. (907) 276-7542 January 14, 1987 Mr. T. R. Painter Division Manager Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Dear Mr. Painter: The enclosed Administrative Approval (AA) No. 173.8 dated ' December 30, 1986 is a corrected copy that should replace the Administrative Approval No. 173.1, also dated December 30, 1986, which was recently sent to you. Please destroy all copies of AA No. 173.1 of that date. Sorry for this inconvenience, and please call me at 279-1433 should you have any questions. S~~ely, ~ Lonnie C. Smith Commissioner Enclosure LCS: j ob December 30, 1986 Telecopy No. (907) 276-7542 Re: ADMINISTRATIVE APPROVAL NO. 173.8 Exemptions from Conservation Order No. 17.3, Rule 9(a),' requiring production surveys. Mr. T, R. Painter Division Manager Conoco Inc. 3201 "C" Street, Suite, 200 Anchorage, AK 99503 Dear Mr. Painter We have received your letter of December 12, 1986, in which you requested exemptions to the resuirements of Conservation Order No. 173, Rule 9(a), for Conoco s Milne Point Unit wells B-10, C-I, C-2 and C-7. Due to impending shutdown of production and injection operations at Milne Point Unit (MPU), the Commission agrees that production profiles at this point would not provide data essential for monitoring reservoir depletion. Therefore, the production surveys required by Rule 9(a) of Conservation Order No. 173 for MPU wells B-10, C-I, C-2 and C-7 are suspended. When production operations resume at MPU, then the production surveys for these wells will be required within twelve (12) months after regular production, begins. Lonnie C. Smith CommisSioner BY ORDER OF THE COMMISSION jo/3.AA173.8 3'om Painter DivisiOn Manager Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Mi!ne Point. ACTIVE: B-iS ~-16 B-~, B-4A, B-6, B-9, B-10, B-il, B-13, , _ , C-l, C-2 C-3 C-4 C-5A C-7 C-9 C-13 C-14 C-16 STATIC: B-20, B-2!, B-22 C-17, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. !he annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-do~ operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all $CSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit ~-' ~- ~ '-~\~ ~ ~ ACTIVE: B-8, B-i2, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and nO additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used To carry the inhibitor. If you have any questions Don Girdler at 564-7637. on the shutdo~ procedure please contact Yours very truly, Painter sion Manager /¥-V STATE OF ALASKA ALAS, )OIL AND GAS CONSERVATION COMI, .~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other ~' f~...,~ 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. 59' KB feet 3. Add~l C Street, Ste. 200 Anchorage, Alaska 99503 6. Uni.t 9~Progkert~, n. aqqe .. , ~,~z±ne ~oznc unz~ 4. Location of well at surface 1009' FSL, 2396' FEL, Sec. At top_ of productive interval 4353' FNL, 4924' FEL, Sec. At effective depth N/A At t~tla~lpP~NL, 5032' FEL, Sec. 10, T13N, R10E, U.M. 3, T13N, R10E, U.M. 3, T13N, R10E, U.M. 7. Well number C-7 8. Permit number 85-2 9. APl number 50-- 029-21266 10..POO~uparuk River 11. Present well condition summary Total depth: measured 9940 true vertical 7429 Effective depth: measured N/A true vertical Casing Structural Conductor Surface I nte rmed iate Production Liner Perforation depth: feet Plugs (measured) feet feet Junk (measured) feet Length Size Cemented Measured depth 80' 16" To Surface 115' 5804' 9 5/8" 1850 Sxs 5840' 9887' 7" 375 Sxs 9921' measured true vertical True Vertical depth 115' 4725' 7416' 9726'-52'; 9686'-06'; 9580'-86'; 9546'-52'; 9472'-86' 7286'-03'; 7259'-72'; 7186'-90'; 7163'-67'; 7112'-22' Tubing (size, grade and measured depth) 3~"2 , L-80, 9630' Packers and SSSV (type and measuredTd~pRt'h)sCSS¥ @ 1912'; Ret.. Pkr. @ 9322'; Perm. Pkr. @ 9600' 12.Attachments Description summary of proposal.,~ Detailed operations progr,~ 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver 15. I herebyfc-z~tify that the foregoing is true and correct to the best of my knowledge Signed ~_~_~ ~~ Title ~. prm~,,~ ¢~ m~ ~.,g4 .... Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date Form 10-403 Rev 12-1-85 7/,/ Commissioner by order of :2/' " the commission Date/, .... 7 -. v'.¢""'"~> Submit in triplicate Tom Painter Conoco Inc. Division Manager 3201 C Street Suite 200 Anchorage, AK 99503 December 12, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 FILE: Dear Mr. Chatterton: Conservation Order No. 173 Rule 9 Conoco requests exemption from Conservation Order No. 173 Rule 9 for Milne Point Unit wells B-10, C-I, C-2, and C-7. These wells are currently being supported by water injection but production and offset injection will be suspended in early 1987. Considering the circumstances, production profiles in these wells can not be justified. If you should have any questions please contact Don Girdler at 564-7637. Division Manager DRG/vv 500.~4 ) STATE Of ALASKA '~i ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL;E] OTHER [] 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 4, Location of Well 1009' FSL, 2396' Elevation Ln_f~et (indicate KB, DF, etc.) 52 KB 99503 FEL, Sec. 10, T13N, RIOE, U.M. 6. LeaL~ez~e~nation and Serial No. 7. Permit No. 85-2 8. APl Number 50- 029,21266 9. Unit or Lease Name Milne Point IInit 10. Well Number 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought.on as an oil producing well on 12-3-85, and its suspended status should be removed. 14. I hereby certify that the fo.r~,going is true and cor~ct to the best of my The sP'~ce be[6~for Commission use Conditions o~Approval, if any: knowledge. Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate , · II~,L-[ FT. UNIT E~L"U~oAqY _ * ' ~J I f .................................................sT"'" <t,% V ~x,s,~.~ ~v~o~.~ ~ I. STATE PLANE CO.ORDINATES ARE Z~E 4. . ' . . .' .. ~ r _ z. ALL N.A.D. GEODETIC 19Z7. POSITIONS ARE BASED 3. OFFSETS TO SECTION LINES ARE COMPUTED : ' BASED-ON PROTRACTED VALUES OF ' SECTION CORNER POSITIONS. , ...... .. 4. L~ATED WITHIN ~CT. 1.0, T 13 N~ RIOE ~ ~M.~AK.. - i i iii i ii I ~CATION I~ SECTION STATE PLANE CO-ORDS. GEODETIC POSITION I DATE CHEC~E~ F~ELD WELL FROM~.~.IN ~ [. UN[ ....... ~RTHINGS lASTINGS LATITUDE LONGITUDE . , , .~ .. . ~ ,, I -~'~! '~" ~' ~,o~,~,;.~ ~,,~,.o~ ~"~,'~o.,o~". '~""~"~'"~;"~' I '' ~ ., _~-~ ] ,'~' .-z~.~'~,o~,~.= ~;,.s~.~ ~oz~, ~.~.... ,.¢~,'s~.o~".. ~ " . .... ' "-.' -. I ' C ' 7 1009' 2396' 6 ,029,290. ~ 558 , ~5.29 70°29' Z6.30f'N ~49° 31' 31.1~2"~. '~ ' C-8 7~' · 2~25' 6 ,029, ~2.~ 558,158.49 70°29' 24. 055 ~. 149° ~1' 29.060" W. .. " " . - I , ~ ,,, ,, i - ii i,, i , , , ~- ~ ~- C PAD CERTIFICATE OF .SURVEYOR : ~ ~ ~'l z~l/ '-..~_ ...... ~ ..-.> -..,.~ ,,. ~;~ ee .'~ -:e'-Lv,. c-~~. ~~ AS' BUILT WELL ~CATION I HEREBY CERTIFY THAT .I AM PROPERLY ~ ~ ,e· ~..:?'.~ LOC'T'ON SU"VE' ~O( 8V ~'~ O" UNO(" t~ ~ ~rn~rd t°mulich ~ ~ ~ ~ ~ /~ ~ ~ , %t' .. COMMENTS : . ... . ...... Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are the Sundry Notices for the Milne Point C-3, C-7, C-8, and C-9 wells. Conoco intends to stimulate the above referenced wells. If you have any questions, please call Don Girdler at 564-7637. Very ~ruly yours, ~ R. J. Francis Manager-Engineering DRG/vv cc: MP C-3, C-7, C-8, C-9 Files G.as i STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. CONOCO, INC. 84-2 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50- 029-21266 4. Location of Well 1009' FSL, 2396' FEL, Sec. 10, TI3N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KB I ADL 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-7 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject well is proposed for a 12-3 mud acid stimulation treatment to improve the productivity from the Middle Kuparuk formation. The 12-3 mud acid treatment has been successful on the Middle Kuparuk formation in offset wells. RECEIVED Alaska 0it & Gas 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed D~ ~'~~ ~'~!~¢,.) Title Sr. Production The space below for Commission use Engineer Date 10-28-85 Conditions of Approval, if any: tRI~IIIA[ Slllt£11 BY LOI'I,~IE C. SI~ITH Approved by. COMMISSIONER ,~pprovea Cop). Ret~rn~Kj By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: On August 19, 1985, we sent you the "Well Completion" forms #10-407 for Conoco's Milne Point Unit wells No. C-7, C-9, C-II, C-12, C-13, C-14, C-15, and C-16. On these forms, the true vertical depths at TD were inadvertently left off. The following data should be added to the submitted forms: WELL NO. TD (MEASURED DEPTH) TD (TRUE VERTICAL DEPTH) C-7 9,940' 7,429' C-9 10,881' 7,308' C-ii 8,990' 7,527' C-13 8,270' 7,313' We regret any inconvenience this may have caused you. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, R. J. Francis Manager - Engineering John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 19, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No. C-7, C-9, C-II, C-12, C-13, C-14, C-15, and C-16. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, J R Kemp~~''~ ~laskan Operations KJS 5/vv RECEIVED AUG 2. 0 198§ A~aska 0il & Gas Cons. Commission Anchorage " STATE OF ALASKA 0 RIG IN A IL .,~,r ~, i ~' ~' ALASKA. ._ AND GAS CONSERVATION C~, ,/IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 85-2 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50-029-21266 4. Location of well at surface 9. Unit or Lease Name 1009' FSL, 2396' FEL, Sec. 10, T13N, R10E, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 4353' FNL, 4924' FEL, Sec. 3, T13N, R10E, U.M. C No. 7 At Total Depth 11. Field and Pool 4149' FNL, 5032' FEL, Sec. 3, T13N, R10E, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 52' KB ADL 47434 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. No. of Completions 2-25-85 3-8-85 3-11-85II N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9940' (?~ 9840' (7363'TVD) YES~ NOFqI 1912' feetMD 1800+ 22. Type Electric or Other Logs Run GR-SP-D IL-CNL-Cal-CCL-Temp. -Gyro , . 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 36# K-55 0' 5840' 12~" 1575 sx Permafrost t 275 sx Class G. 9btils. Permafrost C 7" 26# L-80 O' 9921' Q~" ' o~. 375 Sx. Class G . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9726''9752' (LK-2) 12 spf, 120° phasing 3~".9.2~.L-R) 962~ 9372' 9600 ' 9580'-9586' (L-9) 12 Spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9546"'-9552' (L-8) 12 sPf, 120° Phasing DEPTH INTERVAL (MD) AMOUNT &'KIND OF MATERIAL USED 9472'-9486' (Middle Kup) 12spf, 120° Phasir..g 27. PRODUCTION TEST D~te First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED AUG 2 C) 1985 Alaska Oil & Gas Cons,. Corrlrnission , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '*'" ':: "" "' **"': GF-OLOG'tC',MARKERS ~' ........ ' ,- ........ ::;-!', :'i,~, :-L" ',:, F"'b~:~:~'ibN"LrE:S:i-~" · . : . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR. t and time of,each phase.. KA 4,426' 3,744' MA 4,819' 4,018' NA 5,187' 4,274' OA 5,412' 4,431' T/Kup. Interval 9,260' 6,966 ' Middle Kuparuk 9,472 ' 7,112 ' Laminated Zone 9,487' 7,122' Lower Kuparuk 9,686 ' 7,259 ' 31. LIST OF ATTACHMENTS . '32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~,___,~ Title .../Ot~J, ~---^~/1~¢J~ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 well 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 i'D 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. Item 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". Form 10-407 Eastman/ Whipstock A PETROLANE COMPANY SUB-SURFACE DIRECTIONAL CONOCO, INC. COMPANY '""~" :' :':' ?':'/ Pad 'Ci:~''' WeI1 Number: ¸7, WELL NAME Milne pOint, North Slope, 'Alaska LOCATION JOB NUMBER A0385G0179 SURVEY BY B JAHN TYPE OF SURVEY Gyro Multi-Shot DATE RECEIVE . , MAY o Alaska 0il & Gas Cons. Commission Anchorafl~ OFFICE Anchorage, Alaska Eas trn. a n ( ! Whtpstock A PETROLANE C~*~ANY Date: April 23, 1985 (907) 349-4617 P. O. Box 4-1970/Anchorage, A/aska 99509-1970 Conoco, Inc. 3201 C. Street ....... ~_ui.te 200 Anchorage, Alaska .... 9.9503 Well Number: Pad C, Well No: 7 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 08-MAR-85 Method of Computation: Radius of Curvature ,Surveyor: B JAHN 'Job Number: A0385G0179 Atten: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the original and one copy of the Gyro Multi- Shot survey run on the above mentioned well. ,. TO date, the following distribution has been accomplished: A. 1 copy delivered to drilling for' in-house. distribution. B. 9 copies noted for oil company representatives. C. 3 copies for E/W permanent well files. We ;~ish to take this opportunity to thank you for using E a s trna n Whi p s to'c ]<"'"~"~'d" I'~'~'~ ........ f~J"f~'a r d""~'t'~-'"be i n~" ~' ~ f ~'~"~v"f~'e~ in .the future. District Technical Coordinator cc/file cc: L.A. Dinges - Offshore Exploration Conoco' O.G. Kiel- P.E.S. Reservoir Section Conoco H.E. Gillilan¢~- P.R.D. Reservoir Section Conoco William Van Alen- Alaska Oil and Gas Conservation Commission J.L. Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S.A., Inc. Concord Office Dale Bossert - Champlin Petroleum Co. C.E. Seery, Jr. - Reading and Bates Petroleum Co. Neil Buttram - Cities Service Oil and Gas Corp. Directionai'Drillers/Sub-Surface surveyors/Instrument & Tool Rentals/Sales/Worldwide · o CONOCO~ INC:. . F'AD C:, WELL NO:- 7 GMS ,JOB MILNE PT., NORTH SLOPE, ALASKA GMS, 0-9800 MD, SURVEYOR: B ,_IAHN, DATE' RUN:(~',=,-MAR-,:,._,'-'~ VERTICAL SECTION CALC:ULATE1] IN PLANE OF PROPOSAL DIRECTIF~N:_ N ~'-'=._, L]EG. I MIN. W RECORD OF SURVEY RADIU'S OF CURVATURE METHOD Eastman CONOCO, INC, " .- .. - ... ::.: .'.'..-.]: COMPUTATION F'AGE NF~, ~. 1 .. ::'r..'.- - TIME DAI'E PAD C WELL NO: 2' GMS ,_lOB i',10: AO:38'="G(') 179 ': M I LNE P'r., NORTH .'=;LF~F'E, AI_AF;KA -- ' :~': 11 · ._,6: 16 o.:,_/,,f:,~,_,:,.~ -- -- . · ~ %.1 ri i i % i_1 ._ . . 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J: 1 - Eastman / CONOCO, INC, · PAD C, WELL NO: 7 GMS MILNE PT., NC~RTH 8LOPE, ALASKA dOB NO: AO385G017?/ COMPUTAT I ON TIME DATE · _ -' ,-, -- P'I I- I'~ ~,'~,.- PAC'iE NF~, , ~ _ _ TRUE ' MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C: T A N O 'U L A R C L 0 S LI R E DOGLE( DEPTH ANG[.E DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIREC~TION SEVERI] FEET D M D M FEET FEET FEET FEET FEET FFZET D h'l DG/100~ :30c) 0.. 44 :::~) N 24 0 W :=:10C~. 44 15 N 2:3 30 W :320(). 44 15 t:l 23 30 W .=.:300, 4-4 15 N 2:3 0 W :3400. 4:3 15 N 22 30 W :2:500. 42 45 N 22 0 W :3600. 4:3 15 N 20 0 W 3700. 4:_:: 15 PI 20 0 W :=:800. 45 0 N 20 0 W :3':-/0C~. 4-5 30 N 20 30 W 100. 272'.-?. 84 9:37.46 2677.84 912.32 N 1 () 0. 2801.31 105'7.38 274'.--.~. :31 976.34 N 100. 2872.95 1127.13 2820,'75 1040.33 N 100. 2'F/44,58 1196.88 2892.58 1104.44 N 100. 3016.81 1265. ?7 2':764.81 116:=:.21 N . o0,:, .~ .... 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W 0.6:J. 4000.' 45 45 N 21 0 W 4.10(]. 4/:. 0 N 21 :30 W 420£). 46 0 N 21:30 W 4300. 4/:. 0 N 22 0 W 4400. 45 45 hi 21 30 W 1 O0 · 3448.04 1681 · 77 :3:=::-?6 · 04 1558 · 28 N -'~'-' 42 '--'4/-~ 66 1~'-'= 100.._,° ...~ 17./:,/:, 1 / ._ .=, . ._, ..... . o .-' ...,. 1 ,_ N 100 · '-'.=l'-' ,-,.-,~ .-,~=.-,~ -z, /. · : ..... :, 7. 1 ._':" 1 ,:. -' .:,. 22 .=,._,.=,._,. I .;. 1 .... ~.. 11 N 100. :365/:,. 5'=? 18'P7.03 :3/:,04 · 59 17.~8. ?3 N 100. 3726.21 17~68.70 3/.:,74.21 18'25.60 N 637.76 W 1/:.8:3.74 N 22 15 W A/-,:::.'78 W l V~% ?,' ~."? ._ .L N 1:3 W /:.90. 14 W 1:327.4.4 I',i '2:2 11 W 716.79 W 18'T.~'=-/.:37 N 22 10 W 74:3. :39 W 1971.15 N 22 9 W 0.44 0.4':1- O. OC) 0. :::6, O. '.1-4. 4-500. 4-6 0 N 21:30 W 4600. 46 0 N 21 0 W 4700. 4.5:30 N 21 0 W 4800. 4.5 :_--:0 N 20 30 W 4-900. 4.5 45 N 20 30 W 100. 37:-.?5 · 83 2040.34 3743, 83 1892, 38 N 76'.=/,'70 W 2042. 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'='~'-' ;I. 9 N :.30 W ........ ,._-.., 22 374.7.'~ N 1 W 4,n, 5/_-, A'.'., '.':".-, 100. : / ~ ~ 9'-} 419,-} 23 ~ = c~ ~, 99 '-' ¢, ':,- .~7,.-~ o 43 132 7:2 '.-' ._,=,~._ ._-,o~ .~'-.-¢ N I W 4 N 2 40 W ._1._1 ~.._'~ · ._~ -- . · . ~. '-'~-' Cl '-~ "''~ 100 .~17o':.'¢. 09 4206.27 .~/-,.~17 rr;~ .:,,=,7.-. ~_A N 1/= ..... ~, ~' . ..... .............. · .'-6 W 4'2o9. :34 Iq 22 .~o W 1·21 O. 63 1.25 0.75 0.46 7500. 4'9 0 N :-41 30 W 7600. 4'~ 15 N 31 30 W 7700. 50 0 N 31 30 W 7:--:00. 47:30 I',1:32 0 W 7.90C). 4.7 15 N 3:2 0 W 100. 5773 2:7 4282 35 F,~ol 37 3944.70 N 1673 5/-, W 4..,= ..... 0:3 N 22 ~'.7., W 1 n,O .~c..':,,:, 81 4q'q7 48 ~ '-' ._7,:,6 81 4009 17 N 171:3 07 ~ 4:~5':¢ :::9 N 2:3 8 W . . n ._ ,_, ._1 t_, ~ ~ --- n I . . · I n -- -- .' I -- d-- 100. 5S~0:3.59 44:33. 17 5851.5S/ 4074.12 N 1752.88 W 44:B5.21 N 2:3 17 W 100. 576'9.52 4507.83 5'F* 17.52 4138.05 N 17'P2.44 W 450'~. 58 N 2:3 25 W 100. 60:37.24 4580.86 5985.24 4200.45 N 1831.43 W 4582.35 N 2:3 33 W 800o. 47:30 N :33 30 W 8100. 4:-] 15 N 23 30.'W 8200. 47 30 N :32 0 W 8:300 4. c"] 4._, N :31 .:.: .~ W :s:400. 4/_-, 30 N :'::1 :-4(') W 100, /_-, 104. '-"'-'.~.. _ 465:3 .77 . 6o52_ ,95 4262.3.3 N 1871 . '2:3 W q-"',...,...~'='._,. 0C) N 23 42 W 100,. 6172.03 4727.1:':: 6120.C)3 ·4324-. I N 1'91'2.17 W 4728. 10 N 2:Z.: 51 W 100. 623?. 10 4800 · 62 6187.10 4:386 · 56 N 1 '952 · 29 W 4:=',01 · :3'9 I',1 2-4. 0 W 100. 6307 7:=: 4:E:72 :--:0 /' "':-'~ . ~ . ..... . ..... 78 4448.36 N 1'99o ._4 W 4:E:7:3 42 N 24 /-', W 10o. /_-,:-477. o':.-.¢ 4?44.4:3 6:325.0? 450'9.8:3 N - 2028· 20 W 4'.-.-¢4-I.. '.~ 1N 24 1:3 W 1. 1 , 0.7.51 1. :'::4. 1.7? 8500. 47 0 N 32 0 W 100. 6445·60 5016.76 6393.60 457i·76 N ' 2066.53 W 5017.12: N 24 1'.-} W 8600. 46 15 N :3:3 0 W 100. 6514.28 5088.8:3 6462.28 4633.06 N 2105.58 W 50:"'":'.~'*.08 N 24 26 W :::700. 47 0 N 33 0 W 100. 6582.?6 5160.81 6530.'96 4694.02 N 2145.17 W 51/_.,,0.'97 N 24:34 W 8800. 47 15 N 33 30 W .100. 6651.00 5233.34 65'.-.-¢'.::¢.00 4755.31 N 2185..35 W 523:3.42 N 24 41 W :3'T/0 0 4/_-, 4-.~ N 34 o W 100 6719 20 '=. ,.-,('-"x ,:- 6 2 /~,6 67 2 o 4-,:'-: 16 1.¢ ~' N ..'- .... ~"-'.q.~... ':~':'.. ,., W 5:'::o~ G/.-, I',1 '-' 4 4:3 W 0.62 1.04 o. 75 0.44- O. 62 · "J-/-7 Eastman/ CONOCO, INC. -- =,. .. COMPUTATION PAOE NO. -' 4 ~ "4 '"" - _ F::'AD C WELL NO: 7 L M.:, , Ir]B NO: A .x=,,:,...,60179 . T I ME DATE PiI LNE F'T. , NORTH 'SLOF'E, ALASKA 11: 56:16 2:3--AF'R-85 TRUE =,_B.:,EA R E E: T A N MEA'.E;URED DR I FT I]R I FT COURSE VERT I CALVERT I CAL ~'11 ~- _ _ DEPTH ANGLE DIRECTION LENGTH DEPTH :E:ECTION TVD C 0 ID R Ii I N A T E S DISTANCE DIRI~{C:TION SEVERI"I FEET D M D M FEET FEET FEET FEET FEET FEET I3 M DG/100~ 9000.. 46 45 N 34 30 W 9100. 46 45; N 34 30 W 9200. 46 45 N :35 0 W 9:300. 46 :=:0 N :2:4 30 W ?.)400. 4/=, 15 N :35 0 W 9500, 46 0 N 35 30 W '?/=, 00. 4- 7 0 N.:,""._, = :30 W 9700. 4. '7 30 N 35:30 W 'F.';300, 4:3 0 Iq ._,._':'~ 20. W F:'RO,JECTED TO 9:::4.8 'P84:=:. 4:E: 0 N 35 :_=:0 W ="-'.51 ~'~ N 24 5/-, W 100 67:37.72 ._.=,77. 67-o._,. 72 46:76 '-~,2 N 2266 9:3 W 5:::77. ~'-" 100. 6,:,._ :.. 2:'=: 544'.=.-' .... :36 6:=:04 .-.:.:: 4.'~.',~3/:, '-"=:,._, N 2.3C:,:=:, ~3._ W 54.4'F.,'. :'::6_ N ...._':"3 4 W 0. (':,0. 1C:,0 ......... 6924 75 5521 .'t% 6872 75 49'7-'6 20 N 234'.-.--' 75 W ..... ?;.=;'-'.-' 1. 17 N "":..~, e' 11 W 0 . :3/_-, 100. 6'-}. 9..'=':_. 4:3 =._, =....,':¢.~ ,'-' .79 6'? 41 .4:2: ._, 0 ,_, ._,. ¢;. 2 N~.9 :::.. ,=;. 1 . 1 :E: W ._,~ ':._,':¢.'. ,;:'-'. :::_ 6 iq ._:) -~'~_ 19. W : 0 .44 100, 70/=,2.42 5664. 1'-4._ 7010.42 ...=;', 11Pi._. 40 N 24:32.44 W 56/:,4. ";'::~.__ N ,:'_"~'._, 2/-'. W '.,0 .44 100 71~: 1 73 5735 07 7079 7:'-': 5 I74 27 N 2474 05 W =-"-'~ '-.'F; ..... ,. ._,/.=,.~. :2:2 N =._ ::::2: W . 4-4 · 100. 7200.57 .=; :.=: 0 /-, 40 7 t 48.57 ='-"-"-' '="-' ...... · _, ..' .:,.:, .... .- N 2516, i 7 W ~:::()/-. 7 ;3 N :25 41 I,,j q.. oO .... :,7,:.. 61 721/=, 45 1 N 1 N .~2;87:-.-~. 1 ~ N ...._ 4.::: W 0 :-";0 100 7268.45 ~'-' '-' 100. 7.=,.=,._'-"-' ~. 68 ._,~"=¢=.._, '= 1, 2_ 9 72:=::3 . 68 ._,.=,='-'._5.=,'"', :37 N .,_'.~/-,_ o. 1 , :.=.: 0 W 5952 ,1 ._, '') N ~=...,'-' ~': ..... ~:~ ~=, W o.. ._P;c;_. 48 · 73/=,7. ~:0 .~ '.} ::: /-, 47 7315 ~:o ~13:::2 41 N 2/=22 .~, 1 W .~l'--/~' . 5.'5 ................. .'.,:,7 31 N ~'~; W -. 0. o0 FINAL CLO:=;URE - D!RECTION: D I STANCE: N- .-._ DEGS._,~'-;: MIN:3 W 59.'_--:7.31 FEET Eastman PAD C, WELL NO: 7 -' "'" .... L',M.=, dOB NO: AO?,85nO1 MIL. NE PT. , NORTH SLOF'E, ALASI<A t]:M'._:;, 0-$/:::00 MIl, '.::11RVEYEiR :_ _ B ,_IAHN, DATE RUN: ,r)¢'-~^'"'-c'-~,., , ,~,, ,.,._ RECORD OF INTERPOLATED F:IlRVEY - Eastman CONOCO, INC. PAD C, WELL NO: 7 GMS MILNE PT., NORTH SLOPE, ALASKA MEASURED DEPTH FEET TRUE VERTICAL DEPTH FEET dOB NO: AO385GO177 ' SLIBSEA VERTIC:AL DEFI'H FEET RECTANGULAR C 0 0 R B I N A T E S FEET . COMPUTATION 'TIME DATE 11257241 23-APR-85 C: L 0 S LI R E DISTANCE DIRECTION FEET D FI FIAISE iqO. ,~. 1 100. O0 200.00 300. O0 400. C) 0 500.00 600.01 700.08 800.4- 901.62 100222.67 100. O0 20C). 00 :300, 00 400.00 500.00 600.00 700.00' 800.00 ?00.00 1000.00 48.00 148.00 248.00 '.2:4 :--:. 00 448. A 0 548.00 648.00 748.00 848.00 948.00 0. O0 0. O0 0.00 0. O0 O. O0 O. O0 0.11 S 0.19 W 0.01 N 0.78 W 1.18'N 1.34 W 4.59 N 2.0? W 13.07 N 4.29 W 27.47 N 8.63 W 46.73 N 15.00 W O. O0 0 0 0.00 0 0 0. O0 0 0 0.22 ._,¢' z..,<'>_ _ 0 W O, 78 hi :~','P :3:3 W 1.78 N 48 :_::7 W 5.05 Iq 24 231 W 123.77 FI 12'--: 10 W 22--:. :":.20 N 17 27 W 49.07 N 17 42--': W 1106.76 1211.17 i316.8i' 14272.57 .... :,I.41 1100.00 1200.00 1300.00 1400.00 1500.00 1048.00 1148.00 1248.00 1348.00 1448.00 70.33 N 23.2? W 9::: ':'5 N 2224 06 W 129. ..., .-.~ N ;~ 7. :2:8 W 163. :::1 N ~/:,2.38 W 200.61 iq 72::.70 W 74.0':.? Iq 18 20 W 104. 0223 Iq 1 'P d, 1.4 1 :_:: 7. ':~.. :::. N 20 ._,= W 175.28 N 20 51 W 215.56 N 21 28 W 1637.57 1747. :37 1855.19 1764.17 2075.05 1600.00 1700. O0 1800.00 1900. O0 2000.00 1548.00 16423.00 1748.00 1848.00 1948.00 2238.36 N 75.47 W 275.30 N 111.44 W 312.10 N 127.85 W ':'.=,1 '--'?, N 146 11 W ._i ._ i ,_i._ i 3$/4.55 N 166.64 W 256.77 N 2.1 50 W 2?7.00 N 22 2 W :2::2:7,27 N 22 17 W 380.51 Iq 22 35 W 422:: :':('~ N ":'":' 54 W 21oo 2304.92- · .- 4...._,, 02 '.-]:681.45 2100. O0 2200. O0 2300. O0 2400.00 2500. O0 2048. O0 2148.00 2248. O0 2.'_::48.00 · .- 44,:,. 00 443.38 N 187.31W 4?7.62 N 213.26 W 558.71 iq 237.36 W 628.22 N 267.~2 W 707.50 N 2?8.54 W 48'.-",.., 11 Iq ,.._,'::'"~ 7 W 541.._,..-':"--'N 2 3 12 W 607. :"'":2 N 2:2:11 W 6:--: 2. 'P 7 N '.--.' :2: /.:, W 767. ?1 N 22 5:1.:: W 2818.66 · " .':-" .... :..~ · 1 '7 :2:0 9:::. 16 :2:237.77 :3376.73 2600. O0 2700. O0 2800. O0 2?00. O0 30('~ 0.00 2548.00 2648. O0 2748.00 2848.00 · -,,--//1 0 · -'..-r,_,, (')(') 7?5.48 N' 331.41W 885.44 N 368.38 W 975.16 N 407.71W 1064.55 N 446.46 W 1153.37 N 4-84.12 W 861.76 N 22 37 W 75'P.01 N 22:35 W 1056.76 Iq 22 4.1. W 1154.232--: N 2:2 45 W 1250.85 hi 22 46 W Wbi stoct F:F~NL-ICCI, INC. lC'AD ii:, NELL NA: 7 I":;MS MILNE PT. , NFiRTH SLFIPE, ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH FEET FEET ,.I 0 B N 0: A .).:,,:,,., I.: 017 .-Y SUBSEA VERTICAL DEPTH FEET · 2:513.75 3100. O0 3048. O0 :3650.6? 3200. O0 3148.00 :2: 789.2:--: :_--::':: C)0.00 :_--:24:3.00 :2:931. :2:2 3400.00 :3348.00 ,t. 074.64 .:,'-' .:, = C)' (.)'. 00 :34- 48 . A O. 4218.54 36,00.00 3548.00 4:362. '-'= .:,._, 3700.00 36, 48.00 4.506,. 00 3800.00 3748.00 4/, 49 73 :~: 900 00 '-"-' '-' _ ......... :,,:, 4,:,. 0 c) 4792.63 4000.00 ~":~ o; 4-,:,. 00 . . ' '., ,' COMPUTATION · . -. .- "' TIME DATE 11': 57: 41 '.~'.'--~-APA'-':~,~ ,. · . · . R E C' T A N 0 U L A R-' . C: L 0 .c: U R E C 0 0 R D I N A T E 8'. ' DISTANCE DIRECTION FEET 1240.09 N 519.53 W ' 1327.64 N 552.49 W' 1417.80 N 585.30 W 1512.37 N 620.36 W 1608.22 N 657.18 W FEE1- D M 1344.52 N 22 44 W 14:3:--:. 01 N. 22 :':-: 6 W 1.~'--'":'._ ._,..,. 86, N 2:2 26 W 16,34. /:-,6 N 22 18 W 17:37.31 N 2:2 14 W 17(.')4.50_ N /~i95.~'') "I~'I~,. cI W 1800.._U~' N 7:33.'38 W . 1896.41 N 771.26 W 1'~9'2.68 N 808.54 W 2088.08 N 844 o5 1840.78 N 2:2 11 W 1 '.-.-.'44.1:3 Iq 2:2 10 W 2047.24 N 22 8 W 2150.47 N 22 5 W 22.~2.52 N ..~.'-.'? 2 W PAGE NO. .~. 2 · 47F::5.84 4100. O0 4048. O0 5079.97 4200.00 4148.00 5223.87 4300.00 4248.00 5.'3/:, 7. C) 2 44 (:)C). 00 4:348.0 C) 5510. (:)6. 4500.00 4448.00 2184. 14 N 880.67 W 22::: 1.7(') h! 'F/16.12 W 2379.38 N 950.21 W 2476,. 46, N ~c,c,,_, .- . Sy4 W 2573.56 N 1015.04 W 2355.00 N 21 58 W 245:3.74 N 21 .5:3 W 2562.10 N 21 46 W 266.4.40 N 21:39 W 2766.50 N 21 31 W 5654.4o 46,00.00 .~ '-'. '-' 4.. 4 o 00 5:30';'. C)1 4'700. Fx} 4648.00 ._,~--o =-',; ._,/. 'F/44800.00 4748. o0 6117.50 4'.=700. C)0 4:::48.00 6,276,. 40 5000. cZ)C) 4948.00 6,434.1:3 5100. O0 5048. O0 c .... :, :. :--:7 · .=;'T-'eX'). 00 .=; 148.00 6747.61 5:300. O0 .5248. O0 6908.4-4 5400.00 5:2:48.00 7o6,'.-7~. 8:--: 550O. 0(} 5448.00 7227.88 5600. O0 5548.00 7..:,,:,._, ...... 5'-.--/ 57 (') ('). 00 ~':,6,4,=, ."" 00 · 7540 70 ~'- ..... .~ '-' .... :,~.)0 00 ._ 74,:,. (')0 76.'P4.46. 5'.~C)0. O0 5848.00 7845.02 60C)C). O0 tlF-~4',::. 00 2672.64 N 1047.05 W 2776.20 N 1079.50 W 28'.-7~0.._,':'.~5._ N 111.5.22 W 3007.38 N 1157. 11 W 3121.06 N 1205.27 W 2870.42 N 21 24 W 2978.6'~ N 21 15 W · 309E:.04 N 21 6 W 3222.30 N 21 :3 W 3345.70 N 21 7 W 3231.07 N 1257.86 W 3336.74 N 1313.46 W 3443.05 N 1373.27 W ~,='~, ~:,~ . .: ...... ~._. N 1434 92 W 3661.83 N 1472.55 W 3467.:30 N 21 16 W ':'.~,'--".:; ?4 hi 21 .... W .__l ._ I_i o_ · 3706.82 N 21 45 W 3:--:31,71 N 22 0 N :3'.~5/_-,.'.~7 N 22 16, W 3766.23 N 1563.4; W . 4077.84 N 22 2::3 W 3870.06 N i627.37 W .- 41'F~8.2'F~ Iq 2:2 48 W 37~70.94 N 1689.64 W 4315.46 N 2:3 '3 W 4070.53 N 1750.67 W 443I.(}:3 N 2:3 16, W 4166.14 ht 1809.99 W 4.542. :3:3 hi 2:":: 29 W Eastman./ CONOCO, IhlC. PAD C:, WELL NO: 7 GMS MILNE PT., NORTH SLAPE, ALASKA MEASURED DEPTH FEET TRUE VERTICAL DEP]'H FEET 7'P92.68 8141.7¢) 82:--:8.67 :=: 4:2::3.44 ,: .... / .': . 21 6100. O0 6200 · 00 6300.00 6400.00 6500. O0 :E:725. 05 8871 '-' = '.-} 017.93 91 ."_-. 3.8:=: ';"~:--:09.5:':-: 66£)0. O0 6700.00 6800.00 6'.::¢00.00 7000.00 ?454.22 'P59'~.18 9746.93 7100· O0 7200. ¢)0 7300.00 dOB NO: AO385G01 SLIBSEA VERTICAL DEF'TH FEET 6048. O0 6148.00 6248. O0 634-8.00 6448. O0 6548.00 664.8. O0 6748.00 6848. O0 6948.00 7048. O0 7148.00 7248.00 RECTANGULAR COORDINATES FEET 4257.81N 1868.32 W 4:35¢).1~ N 1728.'~0 W 4441·36 N 1986.21W 4530.54 N 204.1.02 W 4620.32 N 2097.46 W 4709.38 N 2155.24 W 4799.00 N 2214· 55 W 4887.09 N 2274.37 'W 4974.58 N 23:94.75 W 50/_-,1.59 PI 2395.11 W 5147.32 N 2455.00 W 525:2.83 N 2515.82 'W ~":' 91 '-"'-' · ._,,=. N "::'~?:=: 98 W COMPUTATION TI,ME DATE 11:57:41 23-APR-85 C L 0 S LI R E DISTANCE DIRECTION FEET El FI 4^4c,'_ ... 68 N x...-,' 4.2 W 47?]° 66 f,,I ~','-. ~ - -.. '-' ~ . ~ '-'.' ...~.W 4865.26 N 24 6 W 4-9/_-,'.-':'.,'. 0/.:, N 24 1 .':'"; W 5,n74_. .1 '":'.,:.. N 24 .,.'..""=_, W 5177.12 N 24 35 W ._.=; .-'~:'._,'::' 5. :32 N 24 4./_-, W 5:390.4.0 N 24 57 W 54':.75.22 N 25 9 W 55'.--/9./_-, 6 N '.F_' 5 1 ':.? W 570'2. :.5'0 tq 25 30 W 5806.20 N 25 4.1 W 5913.4.0 N '25 51 W PAGE NO. ', 3 · Eastman/ f i . · . ; , ~ . ~ ..-.. ~ ,, I - :' , , · ..,.:.; FINAL STATION,,-.'~'..,.; 3'.,:::*',:.~":;'~.'3:-r.'? ~-.. ~: NORTH 5382,41-WEST· 2622.51 ',..: ~*..CLOSURE 5987.31. N 25.58 : : ~ ~ · . . .;- ; · ;. ~,..' ~ - :.. ,: ~:. · : ,, , . . ,-.-~ · :h ..'. ' · ; . ;- '...:.; ; ' -' 'J' '"' ~ j "' ·-; ' ' ' "' · ; ' ""' · : * : - i · ' ; ,,-t,~t' ¢ ? · , , , r ';'t ~ I-:. , " i ' ; i . 1. ,-- ' .--,.,,-, .-~ .... ':--,---, .............. 'I---*:-~:'-: ~./c; ......... · ......... ~ .... :. ;.,,~., ...... _ ..: .~ .... ~ ............. ~ ..... ~ ......., ....... ~ . ......... ~- ',.-' . , r ...... ,-, -. -- . , - , . ¢ · . ~ , i -ri - . , i i : (-.' ~ : - ; J-' ,, '- · ~ -' ~ ' ~ ,-. ' ', } · -¢~*-' ' ~'4~ '~.' ' . i , · "/ ._. ..... .,. ,. .... ,:,PAD C. WELL NO,.T ;-_,.~ILNE PT., NORTH SLOPE ,: _-ALASKA ~% ....... ' ' '. .... :';7 '¢%;~~' '/":: d'~"*"-¢~-~--f'~-~*-r:'~r"~ ...... d **': ' ; - .'-~ %::~' - ~ i , ,-.. : . ,'.- -!-+-~.: ,.t-,.'-' '.-, :-,-~':--. -- ' " ....... ',,r %?' '~ '7.; ; , ' ' ', i . ":~ t.: ;i .... ":.1 ;: j ,,,"..ii : '! 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'. ~' · ~ I . - ..... i ~ ..... ; .= -,_,...;. ,..~ ~ . . ~ ....... i,~..c. .'. t J--~.;~,-,; ~"~:"~' '~'-~ ..... ~ ~ ' ~? ~ ~ ' '"- "~'~ '~ ' :' i"' '~ '~- ; .... "' ' .' · ~" "' ' ~ ~ /i f~" ' ~ , ' ' ' ''- -. .. t ' : . ~ -i--,'-' -;'. ;¢.~ :'-.,-.. ':~-I'-:; .... , ~ : - - .:'~--'~',-.....,..~"'~L~,..~.~.~ ' . .: ~ .... ~.~ ~--~;~:,' ~ ~--,--~.- .... [';' ~ "I ':.'' -I ~ ' · -~, .... ~ ...... ;: ........ ~';"-:~' "-'l''''-~ '~'"~-t"~ ~ :' :-'~'-:.~ ~ ,' . :?, .... ~'--'.~ ~,~:~:'~'~.;~'~'~ ~- ' '~ ' ~ ' ] ' ' ' ~'~ , · ~:..]:~ : i I' - ~ . ' ' ' ~ I ~ :- '. ' '~:~"~' ~ : - ; ' ' , , ' ,~ .... "~ ': ' , ' : i~'-~ ~ ~ ' "~ "' : ~ " '~ ' '*';~ ..... ' ' : "l ' ' ~' ~ ">' -' '~";~ .... "'~"'~ ~ ~' ~ ' ' * ' ' .... .~- ..~,.:,-.'~;~" ~o '". 4oo0 ."'~ ~-, ~ ~ . . ] ..~,~.4.j ~ . . .~ ''- - '- ~ ~ ;~' .' ~- ~---~-~- i--~- -- '-.~-: ; ~L -'~"; ' "" ' ~ ' ~'~"L"' '-~' ~' · : ........ ~'~" ' i ''-~c¥.'~ ' ' ~ ' ' ' ~ ' ' ; ~:~' 6000 " '"" '" .... ~ ,~-. ~' .... : -4-;~.~-~.~-~,-~,s- ~ ~' -';~1 I I~ ' ~ ..... ,-" -: -'~' ~ ~ ~- + .... . ' {'- :" '~ ~'' ";~ 'F ....~ ' ~'';' '~' '" ' ~ . : : .... .~ ......... 8000' " :-'- : ' ~.~ ., ".:;~-, ~ ~-- : -'.: ' ::-'~-'--:, '-~'~ :. '~-: ~ ~-'~'--~'~-,~ -~'¥~?~,:'~ ~' 'I'~ , ~' ' · ': ~' ' o 2ooo ~ ~"' ~' '' · ,~ I .... r-'~' ~'" +" ~ ' ~ ' ' ' ' ' ' ' ' ' ' ~ : : ' ' OSURE 598T,31~N~25~58 ...~.,~ .......... ~ ' ~ ....... -~, , Suggested form to be inserted iv each "Active" well folder to check for timely compliance with our regulations. PEKATOR, I~ELL' N~IE AND NUMBE--i - Reports and Materials to be received by: Date Required Date Received Remarks · Completion Report Well History Mud Log .,.~ ...... Registered Survey Plat Inclination Survey .,. ,..A/d ~~~. ,, ....Dire c ti°hal Survey _, , Digitized Data ,.~,? . , , ~.~ _, STATE OF ALASKA ALASKA( .L AND GAS CONSERVATION C~...,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Conoco Inc. ~Ferm i¢ No. I "~. A~P I-N umber 3. Address 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 4. Location of Well SURFACE: 1009' FSL, 2396' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 10, T13N, RIOE I 6. Lease Designation and Serial No. ADL 47434 50029-21266 9. Unit or Lease Name Milne Point Unit 10. Well Number C-7 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Aba ndonment Repair Well [.~ Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-7 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistantly with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post co~pleti°n flow test left significant fill in the casing. Prior to the fracture treatment each well is to be checked for fill. If the C-7 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. E (]' E E D J U N 2 0 19, 5 Alaska Oil & Gas Cons. £;ommission Anchoraq~ 14. I hffrc~.~ertify that the foregoi.ng is true and correct to the best of my knowledge. ~ ~ ~' ~0~. Sr. Production Engineer Signed ~ L~ ~.~ Title The space below for Commission use Conditions of Approval, if any: ', IIIIRIIAL SIGNED BT LO~i~i~. C. Approved by COMMISSIONER Approved Copy l~®turned By Order of the Commission Date 6-17-85 Date, Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,. STATE OF ALASKA ALASKA ~'". AND GAS CONSERVATION Cq' 'MISSION MONTHLY REPORT DRILLING AND WOR OVER OPE;RATIONS · Drilling well [~[X Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc.. 85-2 3. Address 8. APl Number 200, Anchorage, AK 99503 50-029-21266 3201 C Street, 4. Location of Well at surface 1009 ' FSL, 2396 ' FEL, Suite Section 10, T13N, RiOE, U.M. Kuparuk 5. Elevation in feet (indicate KB,. DF, etc. j t 6. Lease Designation and Serial No. 52' KBt ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNn. 7 11. Field and Pool Kuparuk River Field River For the Month of May , 19 85 12. De, th at end of monzh, foot'~je driilieci, fishing jobs, directional drilling problems, spud date, remarks None. 13. CasJ~j or ~.~ne~ run and c~u~ntitiies of, c~e~[, results of pressure tests None. 14. Corim:j resame a,cl b~ef description None. 15. L~S run a.d dapCh None. 16. DST data. pe~orat~ng dal.a, shows of H2S, m;isce;t]aneous data None. Well suspended. Completion report to follow. ~noh. ' · '""' .. ' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with tl~e Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEAI£ REPI..Y TO 1,9 APR. 85 CONOCO, INC. 3201 "C" STREET ANCHORAGE, AK 99503 Attention: DAN ROBERTSON POUCH 340069 PRUDHOE ~Y, ~ 99734 ATTN: B~B~A ~RISON Gentlemen: Enclosed are 2 prints of the 2" & 5" DIL, LDT/CNL Comp~¢~ny CONOCO. INC. , Well C'7 " Field%?~ ~ILNE ' POINT , County NORTH SLOPE .. PAGE 1 OF 2 '~ska C!l & ~L: Cc:;,~. Commission A: .c. hur~.,[,,.. ,State ALASKA on: / Additional prints are being sent to: 1B_L__prints & 1RF [S-~-NO-0-~O, INC. OFFSHORE EXPLORATION E.W.A. DIVISION, P.O. BOX 4444 HOUSTON, TX 77252 ATTN: L.A. DINGES C/O RANDY ALTOBELLI 1BL prints & 2RF CHEVRON U.S.A., INC. P.O. BOX 107839 ANCHORAGE, AK 99510 ATTN: J. L, WEAVER 1BL prints & 1RF CONOCO, INC. P.E.S. RESERVOIR SECTION OFFSHORE BUILDING P.O. BOX 2197 HOUSTON, TX 77252 ATTN: O.G. KIEL 1 BI~_Drints CONOCO, INC. P.O. Box 1267 PONCA CITY, QK 74_603 ATTN: H.E. GILLILANJ2hZ63'56 l~W 1BL prints & 1 RF ~V~-~O~ ~--~MMISSION. 3110 PORCUPINE DRIVE ~ANCHORAGE, AK 99501 ATTN: WILLIAM vAN AI,E'N The film is returned to CONOCO We appreciate the privilege of serving you. 1BL prints & 1RF CHEVRON U.S,A., INC. P.O.._BOX 8200 CONCORD, CA 94524 ATTN: 'ER-NIE--rE'F~P~HEID ~'"'-'~";'" ~/-~",'_ ' ,7 ~L,*,~ c r/~ C/O LOUIS KLO~kY ~ ' 1BL .prints & 1RF CHAMPLIN PETROLEUM COMPANY P.O. BOX 12.57 ENGLEWOOD , CO 80150 ATTN: DALE BOSSERT 1BL prints & 1RF READING & BATES PETROLEUM CO. 3200 MID CONTINENT TOWER TULSA, OK 74103 ATTN: C.E. SEERY, JR. Very truly yours, SCHLUMBERGER OFFSHORE SERVICES A.D. HUFFMAN DISTRICT MANAGER SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEAgE REPLY TO CONOCO, INC. 3201 "C" STREET ANCHORAGE, AK 99503 Attention: DAN ROBERTSON Gentlemen' Enclosed are 2 nrints of the, Company CONOCO, IN(~. 'Field_ MILNE POINT POUCH 340069 PRUDHOE BAY, AK 99734 ATTN: BARBARA HARRISON PAGE 2 OF 2 ~,~s. CO.~T,!SSJOll Alaska Oil & Oc~s ¢"-' An~,,orag~ 2" & 5" DIL, FDC/CNL , Well C-7 .,County NORTH SLOPE C;tateALASKA Additional prints are being sent to: 1BL _prints & 1RF ~-f;~'IES SERVICE OIL AND GAS CARP· P.O. BOX 939 BAKERSFIELD, CA 93302 ATTN: NEIL BUTTRAM C/O JIM QUINN prints prints prints prints ~prints prints prints ']'he film is returned to CONOCO We appreciate the privilege of serving you. ~ECEI~D BY: ,,.'~', -- / Very truly yours, SCHLUMBERGER OFFSHORE .SERVICES A.D. HUFFMAN DISTRICT MANAGER - ~,,,, STATE Or: ALASKA ~, ' ALASKA ..AND GAS CONSERVATION CO(' /IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc 85-2 3. Address 3201 "C" Street, Suite 200, Anchorage, AK 4. Location of Well at surface 1009' FSL, 2396' 99503 FEL, Section 10, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB J6. Lease Designation and Serial No. ADL 47434 8. APl Number 50-029-21266 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 7 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of, March ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 9880' TD, 6342' drilled, TD on 3/5/85 13. Casing or liner run and quantities of cement, results of pressure tests Si ze Wt Grade From To 9 5/8" 36 # K-55 O' 5840' 7" 26# L-80 O' 9920' Cement ,. 552 bbls, 12.3 Permafrost E cmt, 56 bbls, 15.8 G cmt, Top job 9bbls, Permafrost C cmt 375 sks, Class G cmt 14. Coring resume and brief description NONE 15. Logs run and depth where run Dual Induction - SFL- GR Density-Neutron - GR GR - Neutron (in casingO 5837' - 9871' 8300' - 9844' 4300' - 5837' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perforations 9726' - 9752' 9580' - 9586' 9546' - 9552' w/ 12 JSPF 9472' - 9486' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED. ~)' /' '~ ~'~' TITLE '~'~-~¢'*'~/£~ /~"~ ~(/' ~'~}'~" DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the A'laska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following material which was transmitted via C ~'.~'~/~'~"~ '/"~-' ~ is hereby acknowledged- QUANTITY DE S CR I PT I ON DATED- Copy sent to sender YES ~ NO SCHLUMBERGER OFFSHORE SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 COMPANY ' ,/~ LOCATION' ATTENTION· · NAME · ~~'??"~' 2_~ WELL NAME ' WELL SERVICES · /- .,~./z//(/~ SERVICES - COMPUTING CENTER PRINT C ENTER"~ NO OF BOXES' ' ..... ADD'L TAPES NO. OF BoxEs· JOB NO. ' ADD'L TAPES ' WELL NAME ' WELL NAME ' . SERVICES · SERVICES ,~ · NO.JoB NoOF BoxES ' v~ ~~-~~~ ~": ~'"-~~NoNO OF BOXES' · · ~ ~1},~ In~= · ADD'L TAPES ' WELL NAME ' WELL NAME ' SERVICES - SERVICES · NO. OF BOXES' NO. OF BOXES' JOB NO. ' JOB NO. ' ADD'L TAPES ' ADD'L TAPES ' SCHLUMBERGER COURIER DATE DELIVERED RECEIVED BY STATE OF ALASKA ALASKA O( ~,ND GAS CONSERVATION COI~' ISSION (~ ~-~ "-MONTHLY REPORT OF DRILLING AND WORKUVER OPERATIONS 1. Drilling well [~ Workover operation [] 2. Name of operator CONOCO 'fnc. 3. Address 3201 "C" Street, Suite 200, Anchorage, AK 4. Location of Well at surface 99503 1009' FSL, 2396' FEL, Section 10, T13N, R10E, U.M. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 52' KB ADL 47434 For the Month of February ,19 7. Permit No. 85-2 8. APl Number 50-- f~?Cl-?l ?R~, 9. Uni~ ~r-Le~s~J~r~e Milne Point Unit 10. Well No. CNo, 7 11. Field and Pool Kuparuk River Field Kuparuk Ri vmr 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 3538' Spud Date 02/26/85 13. Casing or liner run and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 1 6. DST data, perforating data, shows of H2S, miscellaneous data NONE RECEIVED MAR 2 6 1985 Alaska Oil & Gas Cons. CDq]mi.~si, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Arllchorag6 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COM~fISSION To: C. ~.'~~terton DATE: March 4, 1985 '. FILE NO: D.BDF. 18 THRU: Lonnie C. Smith Cormnis s ioner TELEPHONE NO: · FROM: Bobby Fo s ter~.~2~'' Petroleum Inspector SUBJECT: Witness BOPE Test on Conoco's C-7, Sec. 10, T13N,R10E,IR,{, Permit No. 85-2 ~, }.~arch 1, 1985: I traveled this date to Prudhoe Bay to witness th~ upcoming MOPE test on Conoco s C-7. ~aturday,. March 2, 1985: The BOPE test began at 7:30 pm and was ~'6nclUded at' I0:00 pm. As the attached MOPE test report shows there was one failure which was repaired. In summary, I witnessed the BOPE test on Conoco's C-7. Attachment 02-00IA(Rev. 10/79) 0&G ft4 5/84 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report ;,') '-. / ' Operator / Sec/ ,rillin~ Cont fac t o ~W~Z~ ~p. / <./Ri[ Location, General ~f Well Sign~Z" General Housekeeping ~ .... Rig Reserve Pit. Mud S~stems Visual Audio Trip Tank Pit Gauge ~-'"' Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Date '~ ': ':'~? ' .... Representat~ive ~/'~~ Permit ~t! ~~_.~ ~~'Casing Set @~¢~_ ft. 3 Representative ~,~ :/~Z~'~,J~.C..,~' ACCUMULATOR SYSTEM Full Charge Pressure ~,/~'~ psig . Pressure After Closure'/& 7~ psig Pump incr. clos. pres. 200 psig ~ '~.' min~'~'seco. . Full Charge Pressure Attained: ~.. min/~ sec. N2 & C~~Z~ ~ ~9/.~,~"'.b psig Controls: Master ~~ Remote[~5 Blinds switch cover~ Kelly and Floor Safety. Valves Upper Kelly Lower KellM / Ball Type / Inside B0? .} .. Test Pressure Test Pressure Test Pressure Test Pressure ~,~ Choke Manifold ~ Test Pressure No. Valves //' No. flanges ~ & Adjustable Chokes ~ Test Results: Failures Repair or Replacement of failed equipment to be made within Hydrauically operated choke Test Time~ VP"?hrs. days and Inspector/ Commission office notified.~ . ,-~ _ ., Distribution orig. - A0&GCC cc - Operator ~ .... 9~ ..... :::.~ ~ ,~ .r,~~ ,f~ .:~-..~,.,,,~;..~' cc - Supervisor Ins' February 22, 1985 Mr. Daniel J. Robertson Supervising Production Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. C-7 Conoco Inc. Permit No. 85-2 Sur. Loc. 1009'FSL, 2396'FEL, Sec. 10, T13N, R10E, UM. Btmhole Loc. 3913'F~IL, 5027'FEL, Sec. 3, T13N, R10E, U~.~. Dear ~fr'. Robertson: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log ~information shall be submitted on all logs for copying except experimental logs, welocity surveys and dipmeter surveys. Many rivers in Alaska and their .drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereUnder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Daniel J. Rob~.c. tson Milne Point Unit C-7 -2- February 22, ].985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. ~. V. Chatterton Chairman. of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery John R. Kemp Manager of Alaskan Operations Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 February 20, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and. Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the original, and two copies of the Permit to Drill applica- tion for Milne Point C-7. A $100 check has a].ready been submitted with a previous permit application to fulfill the permitting fee requirement. If you have any questions, please call. Dan Robertson at 279-0611. Very truly yours, John R. Kemp Manager of Alaskan Operations DRG/kr cc: MP C-7 Correspondence File RECEIVED F'E B 2 2 1985 Alaska Oil & Gas Cons. Commission Anchorage la. Type of work. DRILL REDRILL DEEPEN .., STATE OF ALASKA ALASKA( L AND GAS CONSERVATION C ..,MISSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY ~ SERVICE DEVELOPMENT OIL DEVELOPMENT GAS 2. Name of operator Co~oco ~uc. 3. Address 2525 C Street, SuSte I00, Anchorage, ~ 99503 4. Location of well at surface 1009' FSL, 2396' FEL, Sec, 10, T13N, R10E, U,M, At top of proposed producing interval 4400' FNL, 4800' FEL, Sec. 3, T13N, R10E, U,M. At total depth 3913' FNL, 5027' FEL, Sec. 3, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) KDB 52' Pad 17' I 6 . Lease designation and serial no. ADL 47434 11. Field and pool Kuparuk River 12. Bond information (see 20 AAC 25.025) Type Blanket surety and/or number 8086--15--54 Amount 8200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 33 mi. NW of Deadhorse miles 1009' @ Surf. feet C-lOwell 120' @ Surf. feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10205' MD(7708' TVD) feet 2560 2-24-85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 600 feet. MAXIMUM HOLE ANGLE 4'5°I (see 20 AAC 25.035 (c) (2) 3000 psig@____ Surface 3800 psig@ 6q?~ ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole 17~" -- . 2 !2¼" Casing !3 3/8' 9 5/8' 7" Weight 26 CASING AND LINER Grade Coupling Length ~--A~ ~T~ 0~1 v_~ 5820' 22. Describe proposed program: MD TOP TVD I 35' i o~ MD BOTTOM TVD Ih9h~'j, 77h9' (include stage data) onoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River Field. Mud system will e a non-dispersed low solids with a minimum mud weight in surface hole of 9.0 ppg and a maximum of 9.8 ppg. Mud Weight at TD will be 10.2 ppg. A 20" 2000 psi diverter will be installed on the 13 3/8" conductor for drilling the surface hole. A 13 3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be lone as per state regulations. Maximum surface pressure is based on a fluid column at TD of 80% gas and 20% oil. acing will be tested to 1500 psi. C-7 is no closer than 120' from another wellbore. The closest wellbore will be the C No 10 well which will parallel this wellbore at a distance of 120' to the C-7 kickoff point at 600'. C-10 kicked off at 2800'. C-7 will then progress away from C-10 as it is drilled in a northwest direction. Arctic Pack will be placed in the 7" x 9 5/8" annulus after disposing of test oil and excess drilling fluids. The well Will be perforated and completed before releasing the drilling rig. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~r~~ ~c~.~¢~¢~-~a~ TITLESupervising Production EngineerDATE The space below f°~'~-~mission use 2-22-85 CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required APl number [--]YES /(~.O [[]YES Ep;NCq._ ES r__qNO ' 50- 0 2 9- 21 2 6 6 ._ Permit number Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS 85- 2//~ /) ~_~_ 2 / 22~/8~ I APPROVED BY ~ /9// /~,COMMISSIONER DATE FebT'u~'ry ??; ]98_5 ~./~//- ~%~._~~~ by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 SUPPLEMENTAL DATA SHEET APPLICATION FOR PERbIIT TO DRILL Conoco et al - Milne Point No. C-7 Conoco Inc. 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 I. CEMENTING PROGRAM A. The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. B. The 9-5/8" surface casing will be cemented with 15503 sacks of Permafrost "E" cement followed by 275± sacks of Class "G" cement. The top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The primary cementing job will consist of 350± sacks of Class "G" cement pumped around the casing shoe (estimated 1300' of annular cement, assuming 100% excess). The secondary cement job will consist of 200± sacks of permafrost type "C" cement followed by 60± barrels of Arctic Pack, pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, slit and sand sequences. Estimated base of permafrost at 1700'±. 4500' - TD Predominately shale until the Kuparuk Sands - expected at 7117'± subsea TVD. III. FORMATION EVALUATION A. Sidewa].l cores to be taken as determined by onsight geologist. Bo Wire].ine logs for the 8~" hole from T.D. to the 9-5/8" shoe will include: Dual Induction I, aterolog; Sypherically Focused Log; Formation Compensated Density with CNL and GR-ca].iper. IV. DRILLING FLUIDS A high viscosity gel-fresh water (non-dispersed) mud system Low solids non-dispersed gel/water mud system O' - 1000' 1000' - T.D. V. DIRECTIONAL PROGRAM The well has a proposed KOP of 600', then build angle in a north. 25° west direction. The closest that the C-7 will come to another well- bore is from surface to 600' where the proposed C-7 will be 120' northwest of the existing C-10 well. An MWD tool is to be run while ErE! VE~rilling for surveying purposes. Final hole angle will be 45°. i' 2 2 ..911!{ ~la$~a 0ii c~ b~ 0o~, o~,,.. ......... ion Anchorage PAD c. wELE NO, 7 REV!SED PROPOSAL MILNE PT.. NORTH SLO~,~, ALASKA EASTMAN WHIPSTOCK. INC. 0 . SURFACE 1000 _ 2000 _ .... 3000_ ,< 4000 _ ,m~ 5000_ 6000 _ 7OOO_ 8000 KOP TVD=600 TrlD-600 DEP-O PER ! O0 FT 13 DEP-681 ' '"'~ 9 5/8' CS(; PT ................ ' _ __ ........... ~ '~D-4650 TMD-5855 DEP-3128 AVERAGE AN'GEE . ii-: ' ~,.i Alaska 0il & Gas Cons Co . 'TENTATIVE' TD TVD=7567 TMD'"IO005 DEP-60?9 ........ I I I I I I [ 1 000 2000 3000 4000 5000 6000 700( VERTICAL SECT[ON ' ... .... · .... :z'_X':.---:'-~ .... .~/." ':u:a_.:X'a4~' 'ah~ .... '_2; ":. z~, .... r ............ -':~ :'~:-~';:==U~~-='~-'~- .. ..~.I.~.-~ ~ . . " ~.. . l~r*~ ' · ..... ~ ....... ;..~ ........ ~_~_¢.~...: : _ ~ . ~ ~.,.-} .... ~ ......... , -.-., ~ ,. '. ....... =~t ......... X'~ :~ ........... N,-~;~.:--.~-:.',:I ....... I-: ':: . " - -~ ....... ~-~ ..... ~:- . ,~= . ..... ,---~- ~ -- ~~ ..... -~, ,!~.~''- ................ ~ ..... ~ ....... ....... :-:~-:~.;'/::~;:~-'. =4~:;~~-~:'-~.~ ......... ~ .?,~, ........ , ~ , .. . :':..:.' ~: h.. ~ X ,S+~-.,PAD,. ~EL~ NO, 7 PROPOSED ...... "~ : t~4 ~ .............. ~ ......... ~-:~ -.- ~IL~E PT ~ . SOO __ - ............................. ~ ........................... * ......... ........... ... ............................................ . ................................... 400 .... "~ ............................... . .... ; ,- .... -. . . . . '. : . . 4260 300 ........................................................................ .......... .. ......................................... 1657 ~ _~' 1275 .... , . . . ........ , 200 ......... ~ 14?6 ................... ; ~ ............... .. : ....... x .................................................... ,,. ................. 1 O0._. ~ ....... ' .... ' ............ . .............................. " 'RECEIVE 0 .. ~190~ Alas~ Oil & Gas Cons.. Oommission. ~~ P- ~a~' .... 3602 _100 ............... ~ ............................... ..... : EASTMAN WHIPSTOCK. INC. '2 NOTE~ WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 6692 HOR }~ONT^L PROJE~T I ON ',-..,ALE 1 IN. = 1000 FEET ' ,, CONOCO, INCo '- PAD C. WELL NOt T REVISED PROPOSAL MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. 6000 ................................... 5000 _ .............................. z 3000 · ~ 4000 3000 I WEST-EAST 2000 1000 I I 1 000 TD IARGET LOCAT[ONt 4400' FNL (880' FSL) 4800' FEL (480' FWL)- SEC- 3. T13N. RIOE TARGET TVD=?177 THD=94SO DEP=,5~84 NORTH 5151 WEST 24O4 = ..... 2000 ....... 1000 1000 . N 25 DEG 1 MI N W 5684' (TO TARGET) R Ei VE'D .... ; ......... Alaska Oil & Gas Cons. Commlsslor~ Anchorago -, SURFACE: SURFACE LOCAT ! ON t 1009' FSL (4271' FNL) 2396' FEL (2884' FWL) SEC- 10. TI3N. R1CE CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK Fill,up Line Y------- 20" Nipple -j~Flow Line 120" 2000 psi ~ Annular .~.~ . .~. ' . , , /L] HCR Valve ~ ~ . Valve , , ~~~ Drilling ~ ~ 6" Relief Valve 6" Relief Line ~ _ ~ _) Spool ,, - / 2000 vs~ C- .I , ~ Connect Assembly Saver Sub . . .Assembly ,= ~ ~'-, ~- S-tArtan 13 3/8" .~ ~ Casing 1. Relief lines from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with AP1 specifications and AOGCC regulations. 3. Both ttCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-I7-84 CONOCO INC. MILNE POINT UNIT BOP STACK Fill-up Line Flow Line lAnnuiar reventer (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. .. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic contr61 system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet AP1 RP 53 class 5M requirements. 13 5/8" - 5000 13 5/8" - 5000 2" - 5000 Side Outlets 3" - 5000 Side Outlets 3" - 5000 Side Outlets 13 5/8" - 5000 · 11"- 5000 3 318 '; .~ ~.'.' '.' '~- ALASFJ~ UH]TED RIG HO. 3 DRILLING CHOKE MANIFOLD' LIQUID MUD SYSTEM Active pits Solids removal function 4 each: 6"x 6"centrifugal pumps, 75 hp Reserve pits 16 each: Lightnin' mixers, 5 hp Working Pressure Choke (1) Type Choke (2) Type 10,000 psi w/ (2) Manua 1 (1) Automatic CAPACITIES ACflV£ I Sand trap I Degasse~' tank I DtHIlel ~,scha~ge SUg[O[AL Mud ~ank NO. I &~ud ~n~ No ~ Rete~V,lg Discharge &Iud rank NO. 3 ~UfO[AL IRIP TANK 6 bbl 56 S4 $5 bbf 66 38 DUI 122 bbl 184 bhl 240 768 lC)OS bbl I SO SURFACE VOtU&tE GRAND [ORAL I I SS ICalculaled 4' below tank topi (2) HCA valves ALASKA UriITED RIG f]O. 3 DRILLING '-L. I] UTTE/'~FL y L VALVE "- .~. . $1JCTION -~_~.. CLOSED Flow path ~-~--._.._~ Solids removal [:---_::3 DEGA$SIAIG FLOW PATH Flowline (in) & pass shaker screens Shaker discharge into sand trap [ditch to pit room closed) Sand trap overflow into degasser suction (desander suction closed] Degasser discharge into ditch Overflow returns to degasser suction (under flow butterfly closed) Switch desander suction out of degasser t~ank Desilter SuClion [Normal) Cleaned mud to treatment pit U~]derflow from treatment to suction pit Gravity-flooded s[~ction N RECEIVED FEB 2 2 198§ S 1 ~l' ~ N LAGOON MILNE PT. UNIT I,,x sc~u[ m ~s CONOCO MILN[ POINT UNIT E~ISTIN6 DEV[LOP~E NT Oii& Gas Cons. Anchorage NOTES-' I. STATE PLANE CO.ORDINATES ARE ZONE 4. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. J LOCATION Itl SECTION I WELL FROMS. LINE FROM E. UNE i - C- I 1168' 2256' C- 2 I 1229' 24.59' C''5 I 1395' 23,26' C-4 I 1344' 2494' c.s I SSI' 'zzS4' c-6 ! 6&S' c.g I ~o' z~zs' $ 94' 23 Go' c-,71 4,oo9' c-C/ I ~1~4' z4z$' STATE PLANE CO-O RDS. NORTHINGS 029, '450. ,029,510. 1:3 EASTINGS 558, 203.55 557,999.90 GEODETIC POSITION LATI T u D E 70029` 27. 868" N. 70°29' 28.473" N. LONGITUDE I DATE 149°31' 27.056" W. 149° 31' 53.036' W. 4 - 20 '82 CHECKED LK. 12- 8 -82 L.K. 6 ,O29,677.35 558 , 1':51 .12 70°29' 30. S ,O29,624.35 577,963.21 70°29' 29. 599'"N. 149° 31'34.089"W. 2-20-B3 B.T. 7o'. z?- z;. ~l j 70'- z~. 2 z.Szz, ~' 5Sb, 17~. Et 55B, l$&. 59 7o'- Z9- 2,4. 7o- zg- ZS. 14 9'--31- E 9. OS7w 149' 31-3o. 5D8, OGCj. 34 7o"-7.9-z~,.3o5u 5S8 051.77 7°°'Eg-Z7.5'4o~: 149"'-'~!-.57_. IZ5'~ &, or_&. 947.7o II - ! - 2,4- II -I -$4 II -I -$4 ti -, - 84- Il-I- 84 I1-1 - 64- 6.oz? DSt.% (,:,. OZ~, i7G.z2 g. Oz9 ,zg,a 4~ &,oz9 395,22 J.H. FIELD BOO) I0- 82 I0- 82 I0 -82 IO -82 24-84 24-$z CERTIFICATE OF SURVEYOR : I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ~-ND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PL&T REPRESENTS A LOCATION SURVEY MADE BY hie OR UNDER MY SUPERVISION, AND THAT ALL D~MENSIONS AND OTHER C[TAIL{ ARE CORRECT. ENGINEERS AND LAND SURVEYORS 'C' PA D BUILT WELL LOCATION CONOCO sc,,E: I SHEET I' · 400' I OF 2 COMI~ENTS: V, JE_t..L. C-5 TN~O{JC;H NA~----LI_ C - lC:' A~.~_. I::~_o~- ~.'~.J ,~--. LL-- LOCATIONS 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. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /~ ~ O( C-) ITEM APPROVE DATE (2) Loc .... 2. (2 thrd 8) 3. 4. 5. 7. (8) , (3) Admin ~~. ~-~~ .... 9. (10 and 12. (4) C asg ff_.f// .~,'~'.7~/'~...,~-- (13 thru~21--y' (22 thru 2~) (6) Add: /~T~J' 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. Is the permit fee attached ........................... Is well to be located in a defined pool ........ '...iiiiiiiiiiI Is well located proper distance from property line Is well located proper distance from other wells .. Is sufficient undedicated acreage available in this . Is well to be deviated and is wellbore plat included ......... YES NO Is operator the only affected party ................................. Can permit be approved before ten-day wait ............... . ........... Does operator have a bond in force , ..................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface . .. Will cement tie in surface and intermediate or production st;i;~; ~.. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this 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 ....................................... Are='necessary' diagrams '.of'..divert='~f,,, ahd' BOP ~quipment 'at.tached. ....... /~ Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks :./~'4A REMARKS _Geology: .Engineering: WVA~JKT / HJH /./y/./t POOL CLASS STATUS rev: 10/29/84 , 6. CKLT GEO. AREA UNIT NO. l/Z 8 ON/OFF SHORE CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. , /~ ~ ITEM APPROVE DATE (2) Loc - (2 thru 8) ( ' (3) admin ~.'1~ 9. (9/thru 12) 10. (10 and 12)z 12. (4) Casg (13 thru 21) (5) BOPE (2'2 thru 2'6) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23, 24. 25. 26. 1. Is the 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 and is wellbore plat i~ii~~~~~i!ii 'iiiiii 7. IS operator the only affected party ....... [ii ~ 8. Can permit be approved before ten-day wait i .ii. ' Does operator have a bond in force ............................ Is a conservation order needed ............ 11~.~ .... i · Is administrative approval needed .................................. Is the lease number appropriate .................................... YES NO · Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ...................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst'. Is this 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 ........................................ ~J-~ Are.neeessa.ry::.diag~rams..:of. dive;rterand:.BOP...equ, ipment..a.t.~ached~ ,...,.... Does BOPE have sufficient pressure rating - Test to ~Z~ psig ..~ Does the choke manifold comply w/API RP-53 (Feb,78) .................. Is the presence of H2S gas probable ................................. REMARKS (6) Add: Geology: HWK LCS WVA JKT JAL~~-.~ I~M Engineering: BEW HJH rev: 10/29/84 6.CKLT 27. Additional requirements Additional Remarks: ~ POOL INITIAL GEO. CLASS STATUS AREA UNIT NO. llfZ~ ON/OFF SHORE CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc le e 3. 4. 5. 6. 7. 8. (3) Admin I-'~' ~J" 9. ~9 thru 12) 10. (10 andI2~ 12. (4) Casg (13 thru 21) (s) (22 thru/ ~6,)~ 13. 14. 15. 16. 17. 18. 19. 20. 21. YES NO Is the permit fee attached ............... : ........................ Is well to be located in a defined pool ............................ Is well located proper distance from property line ................. Is well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool ........... pl · Is well to be deviated and is wellbore at included ............... Is operator the only affected party ................................ Can permit be approved before ten-day wait .......................... Does operator have a bond in force ' . ~'___ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ..... Will cement cover all known productive horizons Will surface casing protect fresh water zones ..... Will all casing give adequate safety in collapse~ ;;~ii~ ~ ~J;;;~~o~ ' Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed eeeeeeeeeeeeeeeeeeeeeeeeeeee REMARES 22. Is a diverter system required ....... ' ......................... ~!~7~ ~ 24. Does BOPE have sufficient pressure rating- Test to 3, ~ ; psig .'~' 25. 26. 27¸. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Is the presence of H2S gas probable , , Additional requirements ............................................. , ~-~/ , Additional Remarks: f~ ~/~ ? WVA JKT JAL~ ~ rev: 10/29/84 Geology: Engineering: LCS BEW , HJH ,,, FOOL INITIAL I GEO. CLASS STATUS! AREA UNIT ON/OFF NO. SHORE --7 DIRECT DIG'ITAL LOGGING COHPUTER Alaska OJt & ,.~ PROCESSED ANALYSIS Company CONOCO Well MILNEPOINT UNIT C-~ Field KUPARUK RIVER County NORTH SLOPE Stmtm ALASKA Country USA CL I ENT FORMAT DATA TAPE LOG INFORMATION STANDARD FOR'MAT ( L . I . S . l Well No.: CONOCO C-7 Depths: 9155.00 to 9906. O0 Name: HiLNEPOINT UNiT Field: KUPARUK RIVER Date: 22 MAR., 198~ Timm~ 10:09 AM FRI. Pagm: 1 k t I. S, TAPE RECORDS REEL HEADER **** Pr~viou= reel: Comm~ntz: HEADER Origin: RECORDS Reel name: 7612 Page Continuation #: 01 TAPE HEADER **** Service name:. ~GSF01 Pr.mvious Da'tm: 85103/22 Commmnt=: Origin: Tape namm: 76!2 Continuatior, #: 01 EOF File name: &GSFOf,:-O0! Maximum I~ng~h: '1024 Service-name: HEADER RECORDS File type: LO Version Previ°u~ ?iie: Date: MNEM 'ON WN FN COUN STAT CTRY SECT TOWN RANG EK8 EOF EQL PD LMF RUN LOC -SON LUN LUL .EN~I WITN DD DL TLi BLt TCS TLA8 8HT MT MViS RM RMF MF.ST MFSS RI'lC MOST HCSS I NFORMAT I ON RECORDS CONTENTS UNIT CONOCO MILNEPOiNT UNIT C-7 KUPARUK RIVER NORTH SLOPE ., ALASKA .. USA ,. '13N ....... ............ 1.0E ................... 52,000 ................ 5:1,'0'00 ................ t2,.00.0 ................ K8 ' 301llJlJllllJilllllllllllllllllllllJllillllllllJ%/Itlll 7612 .......... ! .................................. ............................................ NORTH SLOP~ ................................... NORTH SLOPE ................................... HUPP .................................. 8RADSHAW ................................. 9888.808 .............................................. 9885,040 ............................................. 91.55, 9881' 600 000 ~4 ? 0 O0 15:0 000 ! 8EL .................................. FLO~LINE ........... , ...................... O. ~0 ................................................ 2 800 t ~, 70 g ................................................ 73 '000 HERS .......................................... 3,1.00 ........................................ ~t ,400 ............................................... MERS .......................................... J|lllJJillJJlllI jjllJJljlJJJJJJJJlJWlJl, lJJJJJJJJJ ;llllllJllillll$ · I ; FT FT FT ! FT , FT , FT HR HR , DEGF , DEGF -,. CP , OHHM . OHHM DEGF , OHHH . DEQF TYPE CATG SIZE CODE 0 0 40 65 0 O 4 0 65 0 0 40 65 0 0 20 65 0 0 20 65 O 0 20 6..5 0 0 2 65 0 0 3 65 0 0 3 65 0 3 4 0 3 4 68 O 3 4 68 0 3 2 0 3 2 6,5 0 3 2 65 0 0 2 79 0 0 2 79 0 0 JO 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 6:" 0 3 4 68 O 3 4 68 0 3 4 68 0 3 4 68 0 2 4 68 0 4 4 68 O 1 4 68 0 1 4 6, 8 0 2 20 65 0 2 20 65 O 2 4 68 O 2 4 68 0 2 4 68 0 2 4 68 0 2 12 65 0 2 4 68 0 2 4 68 0 2 i2 65 Page COMMENT RECORD This LIS tape was writtmn bp Gmarhart induztrims Wir¢iinm Smrvicmz. All cur.vm and tool mnmmonicz u~m.d arm thosm which most c!ozml? match Gmarhart curve, and ~tool mnmmonicz. GEARHART TO SCHLUMBERGER MNEM SERVICE UNiT MNEM SERVICE UNIT DEPTH FEET DEPT SP MERGE APl SP GR MERGE GAPI GR ILD MERGE OHMM ILD RAT COMPUTED RAT ILM MERGE OHMM ILM LL3 MERGE OHMM LL3 NPHI MERGE PU NPHi NPHD . MERGE ~ DOL NPHI NPHS MERGE X SAND NPHI CILD MERGE MMHO CILD NCNL MERGE CPS NCNL FCNL MERGE CPS FCNL TENS MERGE MM TENS FT MERGE APl MERGE G.APi MERGE ONMM MERGE OHMM MERGE OHMM MERGE PU MERGE PU MERGE PU MERGE MMHO MERGE cps MERGE CPS MERGE MV Pagm DATA ************************ ENTRY 8LOCKS **** ENTRY ENTRY BLOCK LEGEND TYPE DESCRIPTION 0 Tmrminator ( no more ~ntrimz ) FORMAT TYPE SIZE :=PECIFICA CODE 0 i 66 TIONS Pmg~ QATA FORMAT m.m. DATUM SPECIFICATION oLU_.Ko SERVICE SERVICE AP1 AP1 AP1 APl MNEM iD ORDER # UNIT LOG TYPE .CLASS MOD DEPT 76'1 2 FT SP MERGE 7Gl 2 AP i GR MERGE 761 2 GAP I ilo MERGE ?Gl2 OHMM RAT ?Gi2 .... iLM MERGE 7612 DHMM LL3 MERGE 7612 OHMM NPHI MERGE ?Gi2 PU NPHi MERGE 7Gi2 PU NPNI MERGE 76i2 PU CiLD MERGE ?Gi2 MMHO NCNL MERGE ?GI~ CPS FCNL MERGE 7612 CPS TENS MERGE 76i2 MV :0 0 0 :0 20 JO i 0 20 54 i 0 20 i 20 46 0 0 0 0 0 20 i20 44 0 '20 220 G 0 20 i 22 2 0 2.0 68 i .O 20 68 3 0 20 68 46 '0 20 78 30 0 20 78 3 i '0 20 O 0 0 SPEr'IFiCATIONS,_. FILE PRC % SIZE LVL SMPL 0 4 0 I 68 0 4 0 i 68 0 4 0 t 68 0 4 0 i 68 0 4 0 1 68 0 4 0 i 68 0 4 0 i 68 0 4 0 i 68 0 4 0 i 68 0 4' 0 1 68 0 4 0 1 68 0 4 0 i 68 ~ 4 0 i 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00001j 001) 000 Oljljljljlj 000000 000000 Oiji]O00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 OliO000 000000 000000 000000 Page D TA RECORDS DEPT NPHi SP NPHi ~R CiLD ILD NONL RAT FCNL I LH TENS LL3 NPHi 9906,000 3.40i 9806,000 29,909 9706,000 2 i, i 78 9606,000 30,39? 9506.-000 2.5,699 9406.-000 34,536 9306,000 -34,411 9206,000 39.565 O. 000 9.890 6-0,1 O0 36,540 53.500 28.160 58,900 36,990 66.700 32,570 59.200 4O. 720 5~. 800 40.610 51 . 200 45. '030 0,000 lO00,00.0 86.4O0 53.9.00 42, 170 85, '0'.00 i 51 . 0:08 88.800 i45.2i 1 98.300 393. 550 11 6,70-0 336.512 135.400 473.15i i, 000 0,000 6,745 29i ,600 2.3.714 380. 000 6,622 263.300 6,887 26i.300 2,541 22:3,900 2.972 222. i :00 2,113 i90.500 -999,250 0,000 2.271 i32.200 I , 78'9 2t4,500 2.360 ii3,iO0 2,146 i28.700 2.450 9! .600 2.396 93,600 2.750 69,400 '2.500 3i03.000 7063 4606. 000 26,424 49i 4,000 6,577 4660,000 6,902 47i8,00-0 2,723 4387. 000 3.251 4640. 000 2,296 4260.000 1 .000 7. 499 36,644 6,730 6,745 2,685 3,112 2.421 32 24- ."3'2 28 36 36 4i 540 160 570 720 610 030 FiLE TRAILER Fitm nmm¢: &GSF'01 ,:001 Haximum imngth: 1024 TRAILER RECORDS Fi!m t~pe: LO Next ~iie: Date: P a g ,=' EOF *~ ************************ **** TAPE TRAILER Service name: ~GSF01 Ne>ct tape Date: 85?03/22 Commmnts: origin:~ Tape name: Conti'nuation #: 01 REEL TRAILER Service name: .~GSF01 Next reel:- TRAILER Da~e: 85?03?22 Comments: Origin: RECORDS Reel name: Continu.:mtion ~: 0i 1 0 EOF EOF ~ .... SCHLUMbeRGER .... ~ LIS T~PE C V~RZFiCATI~.~ LISTiNS LVP OlO.HOg VERIFICATION LISTING PA~E DATr'- OR -TGiN~. . REEL NAME ,.,wNT~NUATZ gN COMMENTS ~, TAPE HEADER '"'~ SERVICE NAM:~ :}ATE OR'iG~N :0000 ~APE NAM~ :0176 CONTiNUATi3N ~ :01 PR~VIOOS T~PE : ~OMM~NIS I'~ NANE .'EDIT .001 SERV'"C-~ NAME : VERSZ~N ~ : ~ATE : MAXiMU~ LENGTH : ~iLE TYPE : ~REViOdS FIL~ ~NF~RMA~iON REC!3R3S ~ CONTENTS CN : CO~OC~3 ~N : MPJ C-7 MN : KUPARUK RANG: T2~N: t3N SECT: i0 CCdN: N,SLOP~ STAT: ALASKA CTRY: ~SA AgASKA MNEM C 0 ~'~T ;E N'T S ~RES: ~ CGM~ENTS JNiT ~YPE 000 000 000 000 000 000 000 000 000 TYPE CATE 000 000 000 000 000 O.O0 GO0 000 C AT E OOO SIZE 0.13 007 OO7 OO3 003 OO2 OO7 0O6 OO3 SIZE CODE 06~ 065 065 OO5 065 0~5 065 CODE LV? OIO,HOZ VEPiEIC~Ti~N L~STiNG PAGE ALASKA DiViSiPN CPMPUT.ING CENTE~ ~,G.qPAN¥ : CONDCg ALASKA WELL : MPU C-7 EIELD : K~P.4RUK 20UNTY : N.SLOPE STAT~ = ALASK SECTION = I0 TOWNSHIP = RANGE = TAPE DENSITY : 800 62i JO5 m 7017.5 LOG: OIL , RUN ~ i ,}ATE LOGGED a MAR BOTTOM LDO INTERVAL : 9871 ET. TOP LOG 2NTERVAL : ~837 FT. CASiNG-LDGGER = g.625 iN. ~ 5~37 FT. GIT SIZF : 5.500 iN. TYPE HSL: ~LUiO = P~LYMER/LOW SOL.iDS 2ENSZTY VISCSSiT¥ PH FLUID LOSS RM ~ MEqS. TEMP. RMF ~ ME~S. TEMP. 2MC ~ ME&S. TEMP. MATRIX 10.30 36.00 9.00 5.aO ~ 930 @ 1.550 ~ 68 F 3. ~00 @ 65 F 1.3i5 ~ 160 F ~ANDSTON: DATA FORMAT R6C3RD ENTRY TYPE SIZE REPR CODE ENTRY 2 I 65 8 4 73 60 9 4 65 .lin 16 1 0 I 65 0 2ATOM SPEC!FiCATI3N 5LOCKS MN~M S2RVICE SERVICE UNiT AP1 AP1 API :~P! FILE SiZE SPL REPR IO ORDER ~ LOG TYPE CLASS 3EPT FT O0 003 O0 SF~W OIL OHMM O0 2ZO Ol .ILO OIL OHMM O0 120 ~ iLM OIL OHMM GO 120 44 SP DiL MV O0 010 Ol JR ~iL GAPz. ~ O0 310 O1 jR LDT GAPI O0 ~10 O1 CALl LOT IN O0 280 Oi RHOB LGT G/C3 O0 350 02 DRHO LDT G/C3 O0 356 O1 4RAT LCT O0 ~£0 01 2NRA LOT O0 000 O0 ~PHI LOT ?U O0 890 O0 ~EF LOT O0 358 O1 qCNL LDT CPS O0 330 31 _ u~-~SS CODE (OCTAL) i 68 00000000000000 I 58 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 0000000000000~ I 58 00000000000000 I ~8 0000000000000~ ! 58 00000000000000 i 68 00000000000000 ! 66 00000000000000 I 08 00000000000000 I 68 00000000000000 1 68 00000000000000 1 66 0000000000000~ i 68 00000000000000 LYP CiO.HOZ VE21FiCATI2N LISTING P.Aj2 4 2EPT 9911.5000 SFLU SP -12.843T GR RHJB -999.2500 JRHD NP~I -999.2500 PEP GR -999.Z500 NRAT OEPT 9900.0000 SFLU SP -1~.5469 GR RHSB 1.3~04 DRHO NP~I 37.98~3 PEF &R -~9~.2500 NRAT 2EPT 9800.0000 SFcU SP -5.5938 GR RHOB 2.39~5 DRHG ~PHI Z9.4~4 PEF SR -~99.2500 NRAT 3E?T 9700.0000 SFLU SP -41.3750 GR ~HO6 2.53~2 OR~G ~PHi 20.45~0 PEF GR -999.2500 NRAT SEPT 9500.0000 SFLU SP -20.7188 GR 2H08 2.3965 ORHO NPHI 30.5176 &R -~99.2500 NRAT 3EPT 9500.0000 SFLU SP -18.~231 GR RHOB 2.3594 ORH~ NPHI 27.1484 PEF SR -999.2500 NRAT D~PT 9~00.0000 SFLU SP -20.7198 GR RHOB 2.48~3 DRHO ~PfiI 37.5977 PEF ~R -~99.2500 NRAT SEPT 9~00.~0~0 SFL0 SP -19,328i GR ~HOB Z. ~6~8 ORHO MPHI 29.3~57 PEF SR -999.2500 NRAT 330 310 420 99. -999. -999. - 999. 99. O. 2. -999. '7. 81. O. 1. -999. 34. 56. O. 2. - 99 '9. 5. 89. O. 2. -999. 2. - 99'9. 2. O. -999. 3. i16. O. 2. -999. 30 Oi 01 9883 9375 2500 2500 9922 9375 0015 0605 2500 ~453 3750 0073 97~6 2500 6563 4688 0015 5273 2=00 6484 9375 0034 5059 2500 3008 ~750 0010 1738 2500 687'3 0542 £500 1641 8750 0112 6758 2500 NR~T NCNL ILO ~R NRAT NC~L SR NR4T NCNL iLC GR NRAT NCNL ILO &R NR~T ~CNL iLO GR NR4T NCNL GR NR4T NCNL ILO GR NRAT NCNL 4.8125 -999.2500 -999.2500 -999.2500 2.9219 99.9375 2.9199 2556.0000 6.6953 81.3750 ~. Z89~ 3062.0000 2i.0625 56.%688 2.1445 4356.0000 6.3359 89.9375 2322.0000 6.5719 85.5750 2.5977 2598.0000 2.%961 108.6875 3.2930 23~0.0000 3.0254 116.8750 Z.$027 2093.0000 68 O00000000OO000 ~uO0000000000 68 000n~ O0 ~00000~ ~ O~ ~LM CA~.I RNRA FCNL -999.2500 -999.2500 -99'9.2500 ~rALI RNRA MCNL 3.0449 3.8320 3.0723 799.0000 iLM ~ALi RNRA ~CNL 9.5625 ILM CALi RNRA FCNL 23.4375 2.%707 1762.0000 .ILM CALi RNRA MCNL 6.5898 9.~313 3.0996 313.5000 CALl RNRA FC N~,. CALi RNRA FCNL RNRA ~CNL 6.7969 9.05~7 2.-~035 3.3281 703.0000 3.0605 9.~8i3 2.6855 ]8.i.O'OOO LVP OiO.HOZ VERiF~CATION LISTING PAGE OEPT SP NPHi SP RHOB OEPT SP RHOB NPHi GR DEPT SP NPH[ SP NPHI SP NPdi GR DEPT SP RHD~- NP Hi SP NPHi SR OEPT SP NPHI 9200.0000 SFLO -!5.73~ 2.38~7 40.B691 PEF -999.2500 NR~T 9100.0000 SF~U -18.6563 GR 50.0488 PEF -999.2500 NR4T 9000.0000 SFLO -21.5958 -~R 2.~00~ ORmO 3.,3.96~.8 PEF -999.2.500 MR AT 8900.0000 SFLU -1.85-55 GR l.~OZ3 9RHO -999.2500 NRAT -2~.~688 ~R Z.~55i DR~O 39.0625 P~F -999.2500 NRAT 8700.0006 SFLU -25. 4688 GR 2.4375 ORHO 33.8379 PEF -999. 2500 NRAT 8500.0000 SFLU 4.0977 ~R 2. ','375 3RHO 3~. 91Z1 PEF -~9~.2500 NRAT 8500 .DO00 SFLU 4.5547 GR Z. ',~92 ORHD 39.9902 PEF -~99.2500 NRAT -~.1211 GR 2.5000 DRHG 31.~9~1 PEF -99~.2500 NRAT 133. O. 2. -99~. O. -~99. J 135. O. - 999. -4. ;82 O. Z. -999. 191. O. -999. .t 07. O. 2. -99 ~. ~3. O. -999. . 135. O. 3. -999. . 131. O. 2. -999. 8750 03~2 7773 2500 8877 7500 0083 9434 2500 7109 1250 0410 8~77 2500 6094 2500 0615 9~73 2500 9756 000 0229 0430 2500 3164 .-i250 0200 5352 2..500 ,652! 3750 0269 7949 2500 5195 2500 0283 1328 2500 5234 3750 03~2 :8945 2500 iLO NR~T NCNL .ILO 2R NRAT NCNL G R NRAT NC.'~ L ILO ~R NR~T NCNL & ~.R~T NC~L IL0 NRAT NCNL iLD gR NR&T NCNL iLO SR NRAT NCNL iLD GR NRAT NCNL Z.1699 133.8750 3.48~4 1857.0000 1.8330 130.1500 3.9219 1798.0000 ;.7090 !35.1250 3.3~57 1827.0000 3,8262 .! 82. Z 500 3.54~I0 1502,0000 2.0957 !91..0000 3.3672 2122.0000 2.2617 I0~.i250 5.0801 2318.0000 2.0566 123.3750 3.1406 2254.0000 1.6426 135.2500 3.4336 2230,0000 3.~727 13i.3750 235~.0000 CALI RNRA FCNL iLM CALI RNRA FCNL CALl RNRA FCNL iLM CALI RNRA ECNL iLM CAL· RNRA ~CNL iLM RNRA ~CNL CALi RNRA ILM CA~-i RNRA FCNL .CALi RNRA FCNL 3.7383 ~9~-.7500 1.8701 9.0625 4.¢I80 ~06.7500 2.7928 9.4297' 3.5000 522.0000 3.9512 9.5859 3.5664 505.2500 2.357~ 9.6094 3.2852 705.5000 2.1953 9.6250 3.35!6 572.5000 3.64~5 3.5133 lO. O000 3.1660 743.5000 cVP OID.HOZ VERIFICATION LISTiNO PASE 6 DEPT SP RH08 NPriZ SR OEPT SP RH08 NPHI GR 2EPT SP NPHi SR DEPT SP NP~I GR OEPT SP SP RHOB DEPT RH2B NPHI GR DEPT SP RHOB NPHi 6R O:PT,. SP ~PHi ~R 8500.0000 SELU -11.6953 GR 2.4727 ORHO 33.1543 PEF -99~.Z500 NRAT 8200.0000 SFLU 0.9229 GR -999.2500 -99~.Z500 -99~.Z500 NRAT 810O.OOOO SFLU -10.218T GR -999.2500 ORmO -999.2500 PEF -999.2500 NRAT 8000.0000 SF~U -1~.0703 GR -999.2500 ORHO -399.2500 PEF -999.2500 NRAT 7900.0000 SFCU --6.3438 GR -~99.Z500 ORHO -999.2500 PEF -999.2500 NRAT 7,~00.0000 SFLU -22.9375 GR -999.2500 ORHG -999.2500 PEF -999.Z500 NRAT 7?00.0000 SFcU -27.2187 GR -~99.2500 ORHO -999.2530 PEF -999.2500 NRAT 7500.0000 SFLU -8.9453 SR -~9).2500 ORHD -999.2500 PEF -~9~.2500 NRAT 7500.0000 SFCU -$o~516 OR -~99.250C ORHO -99~.2500 PEF -~99.2500 NR~T 5.5000 iL2 103.1250 GR 0.0049 NR&T i.?OiZ NC~L -999.2500 2.8516 iLO 96.6250 GR -999.2500 NR~T -999.2500 NCNL -'999.2500 3.~359 102.1875 ~R -'999.2500 NRAT -999.2500 NCNL -999.2500 3.8145 iLO 111.i250 ~R -999.2500 NR~T -999.2500 NCNL -999.2500 Z.~727 iLO [00.5000 GR -999.2500 NRAT -999. 2500 NCNL -999. 2500 3.3469 iLO !ZS.00OO SR -'999.2500 NRAT -999.2500 NCNL -999.2500 2.9473 ILO ~Z5.3750 GR -999.2500 NR~T -999.2500 NCNL -999. 2500 3. t6~i 105.4375 OR -999.2500 NR~T -99'9.!500 -99'9.Z500 Z.~512 iL~u 89.1875 GR -999.2500 ~RAT -999.2500 NCNL -999.2500 i03. i250 3.0762 Z%35.0000 Z.$O~? -999.2500 -999.2500 -999.2500 3. 7461 -999.Z500 -999.2500 -999.2500 3.~164 -999.2500 -999.2500 -999.2500 2.7383 -999. Z500 -999.2500 -'999.2500 3.~17Z -999.2500 -99~.2500 -999.2500 3.0762 -999.Z500 -999.2500 -999.2500 3.2500 -999.2500 -999.Z500 -999.2500 2.71~8 -999.Z5~0 -999.2500 -9'99.2 500 ~LM CALT RNRA ~CNL ~LM RNRA FCNL RNRA FCNL tALl RNRA ~CNL iLM CALi RNRA FCNL CALI RNRA FCNL CALi RNRA FCNL iLM CALk RNRA MCNL 3.~527 i0.0234 3.2949 739.~000 -999.Z~00 -999.2500 -999.2500 3.8398 --999.2500 -=999.2500 -999.!500 3.93~6 -999.Z500 -999.2500 -999.2500 2.8105 -999.2500 -999.2500 -999. 2500 3.65~3 -999.2500 -999.2500 -999.2500 3.0137 -999.~500 -999.2500 -999.Z$00 3.330i -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 cVP OIG.H02 VERIFI'ATi2N LISTING PAGE JEPT SP RHOB NPHi ~R JEPT SP RHOB ~PHI .~EPT SP RH08 '4PHI &R 3~PT SP ~H36 ~P H.i ~,R JEPT SP jR OEPT SP ~H3B ~PflI GR DEPT SP NPHI 3R 3EPT SP NPHI SP RHOB NP~i ?~00,0000 SFLU -6,5859 GR -999,2500 DRHO -~99.2500 PEF -'-~99, ZSO0 NR~T 7300,0000 SFLU 0,1426 GR -999,2500 DRHO -~99,Z500 PEF -~9'~,Z500 NRAT 7ZO0,O000 ~FgU -2.ZZ%6 GR -~9~,2500 3RHG -~99,2500 PEF -99~,Z500 NRAT 7100,0000 SFLU -3,0859 GR -999,2500 DRHO -'}99,2500 PEF -999.2500 NRAT -9.9922 GR -99~,2500 ORHG -~99, Z500 PEF -99'9.2500 NRAT 6~O0,OOOC SFLU -5.72Z7 GR -999,2500 ORHC -~99,2500 PEF -~99o2~00 NRAT 6~00,0090 SFLU -5.0977 GR -999,25~0 ORHO -~99,2500 PEF -999.2500 N~AT 6~00.0000 SFLU -2,21Z9 GR -999,2500 DRHO -99'~.Z500 PEF -~99.2500 NR~T 6500,0000 SFLO -4,9414 GR -999. 2500 ORHO -999,2500 PEF -999.2500 NRAT 102. -999. -999. -999. ? j 79. -999. -999. -999. Ii0. -999. -999. -999. ~J -999. -999. -999. 112, -999. -999. -999. 96. -999. -999. -999. -99'~. - '99 '9. -999. 85. - 99 9. -999. -999. 97. --999. -99-~. - 99'9. 91 93 25 93 ~7 O6 25 92 7_5 25 25 7O 37 2.5 76 75 .25 37 .i. 8 Z5 2.5 ~6 25 ~9 75 O0 O0 O0 ~2 75 O0 O0 O0 15 2.5 O0 O0 97 '~0 O0 O0 5.1 50 O0 O0 O0 80 50 O0 O0 O0 37 O0 O0 O0 O0 30 75 O0 O0 O0 48 O0 O0 O0 ZL'~ GR NR~,T NCNL 'iLO NRAT NCNL ~R NRAT NCNL GR NR&T NCNL iLD ~R NRAT NCNL ILS GR NRAT NCNL iLO GR NRAT NC~L iLO GR NR4T NCNL ILO GR NR4T NCNL 3.i6OZ -999.2500 -999.Z500 -999.2500 -999,Z590 -99'9.2500 3.~844 -999.2500 -999.Z500 -999.2500 3,05Z7 -999,2500 -999.,2500 -999,2500 2,9062 -999,Z500 -999,2500 -999,2500 2.9180 -999.2~00 -999.Z500 -999.2500 3.0723 -999.2500 -999,2500 .-999.2500 2.6133 -999.2500 -999. Z500 3.Z793 -999.2500 -999. Z~00 -999. Z500 CALI RNRA FCNL iLM CALi PCNL .I LM CALi RNRA PCNL iLM CALI RNRA PCNL !LM CALi RNRA FCNL iLM CALI RNRA FCNL RNRA FCNL I:LM CALl RNRA FCNL ILM CALi RNRA FCNL 3.i855 -999.2500 -999.2500 ~,947.3 -999,2500 -999,2900 -999,2500 -999.2500 3.0996 -999.2500 -999.2500 -999.2500 2.92.97 -999.250'0 -999.Z~00 -99'9.2500 Z.~336 -999.Z500 -999.2500 -999.2500 3.0957 -999.2500 -999.2500 2.5781 -999.2500 -999.2500 -999.Z500 3.Z578 -999.2500 -999.Z500 -999.2~00 iVP 010.M02 VERIFICATIgN LZSTIN6 PACE 8 SP 2H0 8 ;IPH,I 3R )EPT SP ;tPHi 3R JEPT SP 3R 3EPT SP ,iPflI GR 3EPT SP RHOB NPHZ GR n~-PT SP NPHi OEPT 5P 2HOB NPml GR DEPT SP RH~ NPH~ GR DEPT SP RHO6 NPHi 6~03.0000 SF~_U -l.i. 5938 GR -~99.2500 .ORHO -99).2530 PEF -99~.Z500 NRAT 6~00.0000 SFLU -11.7~22 GR -999.2520 2RHO -999.Z520 PEF -999.2500 NRAT 6300.0000 SFLU -17.2281 GR -999.2500 ORHG -399.2500 PEF -999.2500 NRAT 6ZO0.O000 SFLU -~5.g687 GR -399.2500 PEF -~99.2500 NRAT 5£00.0000 SFLU -14.3750 -999.2500 3RHC -~93.Z500 PEF -999.2500 NR4T 6000.0000 SFLU -7.~922 GR -999. 2500 9R~0 -~99.2500 PEF 153b.0000 NRAI" 5300.0000 SFLU -16.q, 531 GR -999.2500 DRHO - 99':~. 2500 PEF 95.6250 NRAT 5800.0000 SFLU -999.Z500 DRHO -g99. Z500 PEF 5~.8437 NR~T 5700.0000 SFcU -999.Z500 ORHO -~99.2500 P6F 55.6563 NR~T 99.3750 ~R -99~.Z500 NR~T -99~.Z500 NCNL -999o2500 1.7500 iLD 91.31Z5 ~R -999.2500 NRAT -999.2500 NCNL -99'9.2500 2.8281 iLD 82.0000 -999.2500 NRAT -999.Z500 NCNL ¢.02'73 IL~ 5~.7500 ~R -999.25O0 ~R4T '-999.2500 NCNL -99~.2500 97.~000 GR -999.2500 NRAT -999.2500 NCNL -99'9.2500 3.3926 ILg ~9.8750 SR -999.2500 NRAT -999.2500 NCNL Z.8477 I.~789 fLg 92.0625 GR -999.2500 NR~T -99~.2500 NCNL 3.3535 5.8203 ILO 50.8750 SR -999.2500 NRAT -9g~.ZSOO NCNL 3.3008 -'999.2500 ILD -999.2500 SR -999. Z500 NRAT -999.2500 NC~L 3.~496 2.94~3 -999.2500 -999..Z~00 -999.2500 2.1!il -999.2500 -999.2500 -999.2500 2.8750 -999. Z500 -999.2500 -999.2500 3.287! -999. Z500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 3.0556 -999.2500 -999.Z500 -999.2500 1.9629 -999.2500 -999.2500 -999.ZSOO t~.62~0 -999.2500 -999.2500 -999.2500 -999.Z500 -999.250O -999.2500 -999.2500 i L M ~,A~-~. RNRA FCNL CA' T RNRA FCN'L CALI RNRA FCNL ILM CALI RNRA FCNL ZLM CAL? ~N~A ~CNL ,-M CALi RNRA FCNL iLM CALI RNRA ~CN:L iLM CALl RNRA PCNL iLM RNRA FCNL -999.2500 -999.2500 -999.Z$00 2.0996 -999.2500 -999.2500 -999.2500 2.9062 -999.2500 -99;9. i500 --99:9.2500 .3.~629 -999.2500 -999.25~0 -999.2500 -999.2500 -999 -999.~u 3.1504 -999.2500 -999.2500 -999.2500 I.~613 -'999.2500 -999.2500 -999.2500 2000..0000 -999.2500 -999.2500 -999.2500 --999.2500 -999:.2500 -999.2300 --999.Z500 LVP 010.H0£ VERIfICATiON LISTING PAGE 9 OEPT SP RH~6 NPHI OEPT SP 4PHI ~R OEPT SP NPHi GR DEPT SP RHOB NPHi 2EPT SP NPH£ DEPT SP GR 2EPT SP NPHI &R OEPT SP RHOB NPHi ~R DEPT SP NPHI GR 5500.0000 SFLIJ -999. 2500 GR -999.2.500 DRH[~ -99-). 2500 PEF 72.0000 NRAT 5JO0.O000 SFLU -}99.2500 GR -999.2500 -999.2500 PEF 6~.~875 NRAT 5~.00.0000 SFcU -99'9.2.5O0 f.,R -~99.250G ORHO - ~,9-9. 2500 PEF 64. 5625 NRAT 5300.0000 ~FLU -999.2500 GR -999.2500 OReO -999.£500 PEF 5Z.'1562 NRAT :5200.0000 SF~_U -'-)9 ~. 2.500 '3R -999.2.500 ORHC -99 ;~.2500 PEF 47.8437 NR~T 5100.0000 SFLU -999.2500 GR -999.2500 DRHG -999.2500 PEF 41.1562 NRAT 5000.0000 SFLU -999.2500 GR -~99.2500 DR~O -~99.2500 43.8750 NRAT 4900.0000 SFLU -999.2500 .3R -99:9.2500 ORHO -99'~.2500 PEP 42.0938 NRAT 4500.0000 'SFLU -~99.£500 GR -999.2500 ORilO -999.2500 PE~= 55.2a13 -999.2500 IL~ -999.2500 ~R -999.2500 NR~T -999.2500 NCML 3.6270 -999.2500 -999.2500 -999.2500 NRAT -'999.2500 NCNL 3.9~12 -999.2500 iLO -'999. 2500 GR -999. 2500 NRAT -'~99. 2500 NCNL 3.9512 - 99 9. _P 500I L ~ -' -999.2500 ~R -999.2500 NR~T -9'99.2500 NCNL -999.2500 -999.2500 GR -999.2500 NRAT -999.2500 NCNL 3.8105 -999.2500 iLD -999.2~00 ~R -999.2500 NRAT -999.2500 NCNL 3.4063 -999.2500 iLO -999.2500 GR -999.2500 NR~T -999. Z500 NCNL 4.0625 -999.2500 ILO -'999.2500 GR -999.2500 NR4T -999.2500 NC~L 3.9648 -999.i500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL 3.~1~5 -999.2500 -'999. 2500 -999.2500 -999.2500 -'9'99.~500 -999.25'00 -999.2500 -999.2500 · -999. 2500 -999. 2500 -999.2500 -999.2500 -999.!500 -999.2500 -999.2500 -999.25O0 -999.Z500 -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.Z$00 -999.Z500 -999.2~00 -999.2500 -999.2500 -999.2500 ILM CALl RNRA FCNL iLM RNRA ECNL CALi RNRA FCNL ZLM CALl RNRA FCNL CALl RNRA FCNL iLM CALl RNRA FCNL CALl RNRA FCNL iLM CALI RNRA FCNL iLM CALl RNRA FCNL -999.2500 -999.Z50'0 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.'250'0 -999.2500 -999.2500 --999.Z5~0 -999.2500 -999.k500 -99~.15~'~uv -999.2500 -999.25,90 --99~. 2500 -999.2500 -999o2500 · -999. 2500 -999.2500 -999.2500 -999.2500 --999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.~= -999.2500 LV? OlO.MOi VERifICATiON LiSTiNG PA~E 3EPT z,?O0.O000 SFLU ~.HOB -~g~.zSO0 ORHO ~PHI -999.25O0 PEF SR 36. 1875 N~AT DEPT 4500.0000 SFLU SP -99~.2500 GR tHO~ -)99.2530 DRHO ~PMI -'~99.2500 PEF GR 35.0000 NRAT ~EPT 4500.0000 SFUU SP -99'9.2500 SR RH2~ -999.2500 DRHG ~PMi -999.2500 PEF 3R 2~.2031 NRAT DEPT ~0~.0000 SFLU SP - 99'~. 2500 GR '~HOB -999.2500 DRHO '~PH~ -~99.2.500 PEF ~R 3~. 8437 NRAT 3EPT ~Z90.O000 SFLU SP -999.2500 RHOE -999.2500 ORHO NPHI -999.2500 PEF ~R ~4.G375 NRAT -999.2500 ILg -999.2500 GR -999.2500 NRAT -999.2500 NCNL 3.7559 -999.2500 tL~ -999.2500 GR -999.2500 NRAT -999. 2500 NC~L ~.9375 -399.2500 iLD -~99.Z500 GR -999.2500 NRAT -99~.2500 NCNL 4.i9t4 -999.2500 iLO -999.2500 ~R -999.2500 NRAT -999.2500 NCNL ~.1~06 -999.2500 iLO -999.2500 SR -999.2500 NRAT -~99.2500 NCNL ~.0195 -999.2500 ILO -999.2500 GR '-999.2500 NRAT -999.2500 NCNL 3.8457 ~.- FiLE TRAILCR~ ~'~' FiLE NAME :'..:OiT .001 SERVIC2 NAME : VERSION ~ : DATE : MAXIMUM ~E;~GTH : 1024 FiLE TYPE : ~EXT FiLE NAME : ~"~ TAP~ TRAILER SERVICE NAME DATE :85/0S/21 ORIGIN :OOOO -999.2500 -999.2~00 -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 -99~.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 CAL~ RNRA MCNL ILM CALl RNRA FCNL CALl RNRA FCNL ~LM CALl RNRA FCNL iLM CALI RNRA FCNL ILM CALl RNRA FCNL -999.2900 -999.2500 -999.Z590 -999.2500 --999. -999.2500 -999.Z500 --999= -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 -999.25~0 -999.2~00 -999.2500 -999.2500 -999.1500 -999.!500 LVP OIO.HOZ VERIFICATION LISTING PAGE TAPE NAME :0176 CCNTiNgATiDN ~ :Oi NEXT T4PE NAME : COMMEN~ : ~, R~EL TR41LER SERVIC~ NAME DATE :~5/03/Zi 2RIGiN : IEEL NAME : ~ONTINUATI2N # ~EXT REEL NAME -OMMENTS :
