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Home My WebLink About199-091Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/10/2025 InspectNo:susSTS250729141016 Well Pressures (psi): Date Inspected:7/25/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:7/13/2003 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Chris Casey Date AOGCC Notified:7/18/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT C-12A Permit Number:1990910 Wellhead Condition Well head was clean and valves turned easily. Surrounding Surface Condition Clean and free of trash or debris. No subsidence Condition of Cellar Dry and Clean Comments Location verified by pad map and well sign Supervisor Comments Photos (3) attached Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Wednesday, September 10, 2025 9 9 9 9 9 9 9 9 9 9 9 2025-0725_Suspend_MPU_C-12A_photos_ss Page 1 of 2 Suspended Well Inspection – MPU C-12A PTD 1990910 AOGCC Inspection Rpt # susSTS250729141016 Photos by AOGCC Inspector S. Sullivan 7/25/2025 Well Sign 2025-0725_Suspend_MPU_C-12A_photos_ss Page 2 of 2 Tubing, IA and OA Pressure Gauges Well Cellar 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 9,106 feet 8,738 & 8,796 feet true vertical 7,089 feet N/A feet Effective Depth measured 8,738 feet 6,751 feet true vertical 6,757 feet 5,112 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)7" x 4-1/2" Baker LTP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5280 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 0 000 0 00 0 0 true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 108' Size 108' 4,677' Length 2,029' Casing N/A TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-091 50-029-21373-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0047434 measured MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-12A Plugs Junk measured measured Conductor 6,801'8,784' 7,067' 6,067'Surface Intermediate Liner 13-3/8" 9-5/8" 7" 108' 6,067' 7,500psi 3,520psi 7,240psi 8,430psi 7,067' 5,295' 5,410psi Burst N/A Collapse N/A 2,020psi yy e a LLLLLLL GGGGG Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov N/A By Grace Christianson at 2:46 pm, Aug 15, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.08.15 10:07:39 - 08'00' Taylor Wellman (2143) DSR-9/11/25J.Lau 11/4/25 RBDMS JSB 081925 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 psi IA 0 psi OA 0 psi Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None. Location verified by Pad map WBS Pictures Area map Yes Yes Onshore 07/18/25 Subsequent No well house, tree is weathered, no visible leaks, cellar is dry & clean, IA & OA valves function and open to gauges. Clean location. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Sully Sullivan 07/25/25 Yes Chris CaseyMPU C-12A 907-242-1021 chris.casey@hilcorp.com Follow Up Actions Needed: Hilcorp Alaska, LLC 199-091 Condition of Surrounding Surface Location: 07/13/03 303-208 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPC-12 Suspended Well Inspection Form 2025 9 5/8", 36 #/ft, K-55 Btrc. DATE REV. BY COMMENTS Tree: 4-1/16" - 5M CIW/WKM Wellhead: 11" 5M FMC w/ 4-1/2" FMC Tubing Hanger, NSCT lift threads, 4" CIW H BPV profile MILNE POINT UNIT WELL C-12A API NO: 50-029-21373 BP EXPLORATION (AK) ( PBTD ) KOP @ 500' Max. hole angle = Hole angle thru' perfs = 7" float shoe 13--3/8" , 48 #/ft , H-40 MPU C-12a 108' 7" 26 #/ft , L-80, BTRC Casing. ( drift id = 6.151", cap. = 0.0383 bpf ) 6,067' Cased hole and completion /RWO Completion 4ES Size SPF Interval (TVD) Middle Kup LK-1 LK-2 5” 12 10,416’-10,438’ 7,289’-7,301‘ 2-1/8” 4 10,708’-10,732’ 7,445’-7,457’ 5” 12 10,750’-10,796’ 7,466’-7,489’ 10,956’ 10,876’ See old diagram for details of completion Window cut 7,060’-7,110’ 7”x 4.5” Baker HMC hanger 6,771’ Orig. KB Elev. = 52.0’ Orig. GL Elev. = 35.0’ RT To Tbg. Spool =33.95' 4.5” 12.6 #/ft , L-80, IBT mod casing ( drift id = 3.958” , cap.= .0152 bpf ) Baker landing collar Baker float Baker shoe 8,924’ 8,879’ 8,838’ EZ Packer @ 7310’ Size SPF Interval (TVD) Perforation Summary Ref log: 7/31/85 /10/21/89 MDO Sidetrack prep / plug & window 4ES 11/09/99 Window cut 8784’- 8787’ Baker whipstock Baker bridge plug 8784’ 8796’ Cast iron bridge plug Top of 2-3/8” coil @ 8747’ top of ctu BHA 8754’ - btm. 8839’ 8738’ TD @ 9601’ 3.75” open hole through kalubik & kuparuk D 4/13/01 MDO Attempted sidetrack w/ Nabors 3 MeOH 60/40 2,600’ Sea Water 9/20/99 Drilled sidetrack & Liner Nordic #3MDO Hilcorp Alaska ã26ã2604ã2H95ã26Cã26Aã26B19422253610283986151743262313144149247312140522161218Well Lines0 120 240 360 48060FeetGas InjectionGas LiftMiscible InjectionProduced OilProduced WaterSea WaterLegendSEA WATER INJECTION#SEA WATER INJECTIONwith MISICIBLE INJECTION#NO WELL#PRODUCER#GAS CAP INJECTION#PRODUCER withGAS LIFT (or POWERFLUID @ MILNE POINT)#MISCIBLE INJECTION ONLY#PRODUCED WATER INJECTION#OUT OF SERVICE#PRODUCED WATER INJECTIONwith MISICIBLE INJECTIOIN (or GASINJECTION @ MILNE POINT)#MPU_C New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 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6L]H 1$ 7XELQJ*UDGH 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/ +LOFRUS$ODVND//& 0,/1(3781,7&$ 7XELQJ0'IW GJRUP#KLOFRUSFRP &200,66,2186(21/< $XWKRUL]HG1DPH SVL )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO &KDG$+HOJHVRQ By Jody Colombie at 3:51 pm, Jan 08, 2021 DSR-1/21/21SFD 1/12/2021MGR16FEB2021 &RPP 2/18/21 dts 2/17/2021 JLC 2/17/2021 RBDMS HEW 2/25/2021 3DJH_ DŝůŶĞWŽŝŶƚhŶŝƚǁĞůůDWͲϭϮ dĞĐŚŶŝĐĂů:ƵƐƚŝĨŝĐĂƚŝŽŶĨŽƌƉƉůŝĐĂƚŝŽŶĨŽƌZĞŶĞǁĂůŽĨ^ƵƐƉĞŶƐŝŽŶ^ƚĂƚƵƐ KĐƚŽďĞƌϭϱ͕ϮϬϮϬ tĞůů^ƚĂƚƵƐ͗ DŝůŶĞWŽŝŶƚhŶŝƚǁĞůůDWͲϭϮ;WdηϭϵϵͲϬϵϭͿǁĂƐƐƵƐƉĞŶĚĞĚŽŶϳͬϭϯͬϮϬϬϯĂĨƚĞƌĂ ĨĂŝůĞĚĂƚƚĞŵƉƚƚŽƌƵŶĂůŝŶĞƌƚŽdĚƵƌŝŶŐĂƐŝĚĞƚƌĂĐŬŽƉĞƌĂƚŝŽŶ͘ĐůĞĂŶŽƵƚƌƵŶǁĂƐ ƉĞƌĨŽƌŵĞĚ͕ĚƵƌŝŶŐǁŚŝĐŚĐŽŝůŐŽƚƐƚƵĐŬĂŶĚǁĂƐĐƵƚ͘ƌŝůůŝŶŐŽƉĞƌĂƚŝŽŶƐǁĞƌĞ ĂďĂŶĚŽŶĞĚ͕ĂŶĚƚŚĞǁĞůůǁĂƐƐƵƐƉĞŶĚĞĚǁŝƚŚĂ/WƐĞƚĂƚϴ͕ϳϯϴ͛D͘dŚĞ/WǁĂƐ ƉƌĞƐƐƵƌĞƚĞƐƚĞĚƚŽϭ͕ϴϬϬƉƐŝĨŽƌϭϱŵŝŶƵƚĞƐ͘ dŚĞǁĞůůŝƐŵĞĐŚĂŶŝĐĂůůǇƐŽƵŶĚĂƐĞǀŝĚĞŶƚďǇƚŚĞƉƌĞƐƐƵƌĞƚĞƐƚƉĞƌĨŽƌŵĞĚŽŶƚŚĞ/W 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Ϯϱ͘ϭϭϮ;ŝͿƚŽĂůůŽǁƚŚĞǁĞůůƚŽƌĞŵĂŝŶĂƐƐƵƐƉĞŶĚĞĚŝŶŝƚƐĐƵƌƌĞŶƚĐŽŶĚŝƚŝŽŶ͘ůů ŚǇĚƌŽĐĂƌďŽŶŝŶƚĞƌǀĂůƐĂƌĞŝƐŽůĂƚĞĚĂŶĚƚŚĞƌĞĂƌĞŶŽƵŶĚĞƌŐƌŽƵŶĚƐŽƵƌĐĞƐŽĨĨƌĞƐŚǁĂƚĞƌ ŝŶƚŚŝƐĂƌĞĂ͘ 0DWW+HUUHUD 9 5/8", 36 #/ft, K-55 Btrc. DATE REV. BY COMMENTS Tree: 4-1/16" - 5M CIW/WKM Wellhead: 11" 5M FMC w/ 4-1/2" FMC Tubing Hanger, NSCT lift threads, 4" CIW H BPV profile MILNE POINT UNIT WELL C-12A API NO: 50-029-21373 BP EXPLORATION (AK) ( PBTD ) KOP @ 500' Max. hole angle = Hole angle thru' perfs = 7" float shoe 13--3/8" , 48 #/ft , H-40 MPU C-12a 108' 7" 26 #/ft , L-80, BTRC Casing. ( drift id = 6.151", cap. = 0.0383 bpf ) 6,067' Cased hole and completion /RWO Completion 4ES Size SPF Interval (TVD) Middle Kup LK-1 LK-2 5” 12 10,416’-10,438’ 7,289’-7,301‘ 2-1/8” 4 10,708’-10,732’ 7,445’-7,457’ 5” 12 10,750’-10,796’ 7,466’-7,489’ 10,956’ 10,876’ See old diagram for details of completion Window cut 7,060’-7,110’ 7”x 4.5” Baker HMC hanger 6,771’ Orig. KB Elev. = 52.0’ Orig. GL Elev. = 35.0’ RT To Tbg. Spool =33.95' 4.5” 12.6 #/ft , L-80, IBT mod casing ( drift id = 3.958” , cap.= .0152 bpf ) Baker landing collar Baker float Baker shoe 8,924’ 8,879’ 8,838’ EZ Packer @ 7310’ Size SPF Interval (TVD) Perforation Summary Ref log: 7/31/85 /10/21/89 MDO Sidetrack prep / plug & window 4ES 11/09/99 Window cut 8784’- 8787’ Baker whipstock Baker bridge plug 8784’ 8796’ Cast iron bridge plug Top of 2-3/8” coil @ 8747’ top of ctu BHA 8754’ - btm. 8839’ 8738’ TD @ 9601’ 3.75” open hole through kalubik & kuparuk D 4/13/01 MDO Attempted sidetrack w/ Nabors 3 MeOH 60/40 2,600’ Sea Water 9/20/99 Drilled sidetrack & Liner Nordic #3MDO +LOFRUS$ODVND 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect well Hilcorp Alaska 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 9,106 feet 8,738 feet true vertical 7,089 feet 8,747 feet Effective Depth measured 8,765 feet N/A feet true vertical 6,782 feet N/A feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)4-1/2" Kill string L-80 2,684' 2,382' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 5,410psi7,067' 6,067' 108' 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,430psi Collapse N/A 4,677' 108' Burst 7,500psi 5,295' 1,730psi 3,520psi 7,240psi 740psi 2,020psi 5,112' - 6,797' 6,067' 7,067' Surface Intermediate 13-3/8" 9-5/8" 7" N/A Production Production Casing Conductor Liner 2,029' Length 108' MILNE PT UNIT C-12A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-091 50-029-21373-01-00 Plugs ADL0047434 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Oil-Bbl measured true vertical Packer 4-1/2" WDSP2 WAG Water-Bbl MD 6,751' - 8,780' TVDSize PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 8:13 pm, Jul 21, 2020 Chad A Helgeson 2020.07.21 16:45:32 -08'00' SFD 7/22/2020 RBDMS HEW 7/23/2020 DSR-7/22/2020MGR22JUL2020 Matt Herrera C-12A Suspended Well Inspection Review Report InspectNo: susMFH200620145814 Date Inspected: 6/20/2020 Inspector: Matt Herrera Well Name: MILNE PT UNIT C -12A Permit Number: 1990910 Suspension Approval: Completion Report Suspension Date: 7/13/2003 Location Verified?❑ 170 If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 6/19/2020 Operator: H ilcorp Alaska, LLC Operator Rep: Josh McNeal Wellbore Diagram Avail? O Photos Taken? ❑ Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: 170 VR Plug(s) Installed? ❑ Wellhead Condition Good. No leaks on anyflange connections or lock down screws. No SSV. All Valves operational. Gauges installed and in working order to note tubing and annulus pressures Condition of Cellar Good. Clean with no standing water or sheen or subsidence Surrounding Surface Condition Good. Clean with no standing water or stains or subsidence Comments Well location verified per MPU C -Pad Location Map. Photos taken by Operator available upon request Supervisor Comments � JPlIZ2ttZr Thursday, July 23, 2020 , STATE OF ALC OIL AND GAS CONSERVATION COMMISSION , GI r{ • REPORT OF SUNDRY WELL OPERATIONS Stl' 0 $ 201 1.Operations Abandon U Plug Perforations U Fracture Stimulate Pull Tubing U ° ' e o s s utdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Inspect Well ❑Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 199-091 • 3.Address: Stratigraphic❑ Service Q 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-21373-01-00+ 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047434 • MILNE PT UNIT KR C-12A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ., N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured - 9,106 feet Plugs measured 8,738 feet true vertical • 8,215 feet Junk measured N/A feet Effective Depth measured 8,738 feet Packer measured N/A feet true vertical 7,897 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 13-3/8" 108' 108' 1,730psi 740psi Surface 6,067' 9-5/8" 6,067' 5,590' 3,520psi 2,020psi Intermediate 7,060' 7" 7,060' 6,450' 7,240psn— 5,410psi Production 2,013' 4-1/2" 8,784' 7,937' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet SA$$EP Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 2,684' 2,614' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A ' ' N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A . Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q ,4 SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Stan Porhola Email sporholahilcorp.corn Printed Name Stan Porhola Title Operations Engineer Signature A4' L —__ Phone 777-8412 Date 9/8/2015 Form 10-404 Revised 5/2015 2E 71/ 1.y: SEp 10 2.015 Submit Original Only • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hilcorp.LLC Well Name: MPC-12A Oper.Rep: Bill Kruskie PTD No.: 199-091 Oper.Phone: 1-907-670-3387 Location Verified? Yes Oper.Email: wkruskieahilcorn.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Date AOGCC Notified: 08/21/15 Suspension Date: 07/13/03 ✓ Type of Inspection: Subsequent Sundry No.: 303-208 Wellbore Diagram Avail.? Yes Photos Taken? Yes Well Pressures(psi): Tubing 0 IA 170 OA 0 Condition of Wellhead: Good,No visable lecks and all gauges are installed, Well guard installed,Well head sign inplace. Condition of Surrounding Surface Location: Good Follow Up Actions Needed: None. Comments: Map on location. Attachments: Pictures REVIEWED BY: Area map Insp.Supry WBS Comm PLB 12/2014 MPC-12A 2015 Suspended Well Inspection Form • • • Tree: 4-1/16"-5M CIW/WKM MPU C-12a Orig. KB Elev.=52.0' n; Wellhead: 11" 5M FMC Orig. GL Elev. =35.0' w/4-1/2" FMC Tubing Hanger, RT To Tbg. Spool=33.95' NSCT lift threads, 4" CIW H BPV profile 13--3/8" ,48#/ft, H-40 108' McOF- 60/40 Ititr ►»;%Ia4.n,t.t,t. KOP @ 500' ij 11 .627 Max. hole angle= Hole angle thru' perfs= K,)l s-}.ci nek Sea Water n.wN °J 2,6114 9 5/8", 36#/ft, K-55 Btrc. 6,067' , 7" 26#/ft , L-80, BTRC Casing. (drift id=6.151", cap. =0.0383 bpf) 7"x 4.5" Baker HMC hanger 6,771' Window cut 7,060'-7,110' 4.5" 12.6#/ft , L-80, IBT mod casing (drift id=3.958" , cap.=.0152 bpf) Cast iron bridge plug 8738' Top of 2-3/8"coil @ 8747' Window cut 8784'-8787' top of ctu BHA 8754'-btm.8839' Baker whipstock 8784' N3.75"openhoIethroukaik; &kuparuk D IIIIII TD @ 9601' Perforation Summary Ref loci Size SPF Interval (TVD) Baker landing collar 8,838' Baker float 8,879' Baker shoe 8,924' EZ Packer @ 7310' Size SPF Interval (TVD) 171 Middle Kup See old diagram for details of 5" 12 10,416'-10,438 7,289'-7,301 LK-1 2-1/8" 4 10,708'-10,732' 7,445'-7,457' LK-2 5" 12 10,750'-10,796 7,466'-7,489 MIL (PBTD) 10,876' __ 7"float shoe 10,956' DATE REV. 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",:ti,..14,=4=';',"-•'',..."'..,,,--t:,•:::;,..;_ '-1:Tj'k,'..1-''''..L'-',',*7,,t7;"`ie*A-tr:44;;;,• -•---;:t,';'-5'''-';'-'•-•-••'-: .• - - -••- ` _..„.... . , . • • .. , . • _.,- - , -. _ • .. . . - - - • • . . .--:,.--. - .-'' - . . . . • ... . • ._ _ , _ _ ..-, . . ., . , . - .• • , _ . . , , • ... .. - .-:-. -. -- - .- . _... , - .• , , .- . . _„ • . - . . .. • , . , ,, ,, ...- - , , • _ . . - . , • -' . . • . . . , .... . , , , : .. • •,,. - . , . . . . .: . . . . . „ - . .., . ... - • ., . .. .. ., .., . , • .... ,..,,,„„, „,,,,,. • _ ,, ..... — ,.. - ' .. • . .. - '.: , . . . . - . . , .., . ,. . . . . • . CI�'—�i �$ .r. i^�e^'^',` m t ,w 'BCW „I 2 ,..... 5 x r ....,. „„„,..,.._ .. ,,,,.'-L.,----411%11 ! 11,i1' i ., , -___.;;;„.----' lb -! 1 .., ,, : ..„„ ,,� ., ,it _ , _T '111° r ..,,....., ,....,» iwP'w. i t'iii Z E WELL NAME MPC.12A OWNER Milne Point Unit "�- .-.-. OPERATOR BP Exploration ° ,,,, SUR.LOCATION SE N4,S .10,T73N,810E '' •'''''''‘'' " . 'a""""`^";'-'"` DRILLING PERMIT 199.0910 ' { ,. API NUMBER 00.029.21373.01.00 b r'`-77.,„,!"),... .,.4-,,),.It ,. wwC k x 3 % ';',:-,e,$:;4.:,4„..., ” � � '? *gym '�., ` . '''''...4.',..' tl r {moi " y ' -t" >. }fie. / )411 _ _ i. ' -.7-. x ;- °" z`; 'r '''.0,.',-':.,,,7-. -.,„:„.14-4-: q4 ,7.--ek 7, w' - 6•. :vr fir . r& rr ,.�. 2' . L. �p . - - . , ,,F. T - „,..--::g..---”' ar�sav .;" " t ' '' c. sr at t' ' --.',. . 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'„`- ._ _ a - , as .,,. . *{1 '!'C"<"": �eC g- '$,ie y T'9 a" 'K;4 h1.4.;":...-1,-"*.,.' t * r D' n .ems A .• ^ n m w • . \ r •' • IL! � . : ,amu + 2 eArmr- R Pah.= h +r.�. •.r y8s?',x xt • .--• + � • µ A CK �:b.,,. t Y:. .st } .� ,r + • ,tom i b8,i F4w -,-2'4k �w"Yi"`.$ ,� �'�ate. _ r ' ' ., -fir' ., ` • . 0.1.-- „.*: : ' .-,..4.01".-, -4,511,,,...wl....-2"te. . ...s.--„_„,,,,,,,,,,, w .*.dam' �° M Ott" n1. • . 'mss :"'.3 . fir... .. P`^r-. °vy & S. , , wo fir. 0 0 T IIMilne Point Unit - C Pad . Ilii "r ' Alit4kti,l,l,( MPU C Pad i , „, `"' July 25, 2006 Approximate Scale: 1"'=200' 2006-19c-4-51 t `P' . �_,, ' '''''' •' C.. , ,, . , _ _ C-19 : ' '''' ',- D ,„... , ,. .., . ,„__,-43 ,., „t„' \,-,,,• 1C-17 1:2J0 i 200 1 `C-42 _ Feet w C-''4 4 .�C C-25„C-25.A CC-I l C-23 01 * 1_-•Aliiu ;" C-36 1. C-I , C-20 + , e ji,..., _ 4,,t t• C-'1c0:.c...yeo „, '., ,,,i, 14,4,, c_14 •,,•,,,,,,,,,,x ,, ,• ,, ,.._ tel , C-6 , 4'. C-1 6 ,\ 6, C-22, t..-_,.•:..+-s. '` �" \ �i C-I i-12A — \ Elec.:. G,.Comp. 1,..10d-2g + , ,,.,r" -- H ' S- :�- " G co p Air Filter fv...)4.3..,,,. , , . ilt_ i, t mp `t er -- r c.. Y ., f Ele:tr.it tr. ` LAB '- , f e r � +. • 110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hillcorp ' Well Name: MPU C-12A Oper.Rep: Bill Kruskie PTD No.: 1990910 " Oper.Phone: 907-670-3387 Location Verified? Yes Oper.Email: Milne-WellsiteSupervisors(rDhi If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 07/13/03 Date AOGCC Notified: 08/20/15 Sundry No.: 303-208 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 " Photos Taken? Yes IA 0 ' OA 170 Condition of Wellhead: Single master valve only. ' Condition of Surrounding Surface Location: Good Follow Up Actions - Needed: None Comments: Location verified by site map. Photos taken by operator available upon request. AOGCC changed status of well from OpsSD to SUSP in a letter dated 8/4/2003 responding to Application for Sundry Approval 303-208 Attachments: none SCANNED SEP 1 5 2016 REVIEWED BY: Insp.Supry .._)C '`I Comm PLB 06/2014 2015-0823_Suspend_MPU_C-12A_cs.xlsx • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/12/10 Inspector: Chuck Scheve Operator: BPX Well Name: MPU C -12A Oper. Rep: Lee Hulme PTD No.: 1990910 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 07/13/03 Date AOGCC Notified: Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing N/A Photos Taken? Yes IA 0 • by Operator OA 120 • Condition of Wellhead: Barricade in place, single master valve. Well sign for C -12 not C -12A. Condition of OK Surrounding Surface Location: Follow Up Actions Update well sign. Needed: Attachments: None REVIEWED BY: Insp. Supry � to 1 7 '1l Comm . t [ 74 1, PLB 08/2010 2010- 0912_Suspend_MPU_C- 12A_cs.xls ) ~ ti v 'i~ DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 1990910 Well Name/No. MILNE PT UNIT KR C-12A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21373-01-00 MD 9106 TVD 7088 Completion Date 7/13/2003 Completion Status SUSP Current Status SUSP ~c~ ~--- - -- - - -- ~ - -~- ----- --"-- Directional~Ny0 REQUIRED INFORMATION Mud Log No Samples No -- --------- - ---- ~- - ------- DATA INFORMATION Types Electric or Other Logs Run: MWD (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI ~y- :~ M~_dl~l'JTIt Number Name Scale Media No Start Stop CH Received Comments : D C 9449 1 Case 2/25/2000 SCHLUM PDC/USIT lED D 10619 LIS Verification 7033 9079 Open 12/28/2001 LSD- T c.99449 6750 8825 Case 2/25/2000 6750-8825 : Rpt SRVY RPT 6980 8934 Open 2/15/2000 SPERRY Rpt Directional Survey FINAL 4/12/2001 Directional Survey Paper Copy ~ 10618 LIS Verification 7033 9079 Open 12/28/2001 og US IT 5 FINAL 6750 8825 Case 2/25/2000 BL(C) 6750-8825 ED D 10507 LIS Verification 7033 8894 Open 12/28/2001 ED D Directional Survey FINAL 4/12/2001 Directional Survey Digital Data t?o C tH--206 See Notes 7072 9106 Open 1/17/2002 Digital Well Log Data NOTE: No paper copies of logs were received MD U LrGo6 AND TVD C See Notes 7072 8934 Open 1/17/2002 PB 1 Digital Well Log Data NOTE: No paper copies of logs were received MD AND TVD - - - ------ --- -- --------- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 1990910 Well Name/No. MILNE PT UNIT KR C-12A Operator BP EXPLORATION (ALASKA) INC MD 9106 TVD 7088 Completion Date 7/13/2003 Completion Status SUSP ADDITIONAL INFORMATION vGJ Chips Received? ~ ~ Well Cored? Daily History Received? Formation Tops Analysis Received? - ------ -------- ----- Comments: -- ----- - -------- L \ _c ____ _"____ ___ Compliance Reviewed By: API No. 50-029-21373-01-00 Current Status SUSP ~N v'® Date: UIC V 21 :f~~~ .~ ) STATE OF ALASKA l ALASKA OIL AND GAS CONSERVATION COMMI6SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned a Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM Top of Productive Horizon: N/A Total Depth: 330' NSL, 2374' WEL, SEC. 03, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558439 y- 6028780 Zone- ASP4 TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 558043 Y- 6033892 Zone- ASP4 18. Directional Survey 0 Yes a No 21. Logs Run: MWD 22. 'CASINGI' :';: 1:$'I;z~II", 13-3/8" 9-518" Zero Other 5. Date Camp., Susp., or Aband. 7/13/2003 6. Date Spudded 3/15/2001 7. Date T.o. Reached 3/18/2001 8. Elevation in feet (indicate KB, DF, etc.) KBE = 47.95 9. Plug Back Depth (MD+ TVD) 8765 + 6783 Ft 10. Total Depth (MD+ TVD) 9106 + 7088 Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1b. Well Class: o Development 0 Exploratory o Stratigraphic a Service 12. Permit Number 199-091 303-208 13. API Number 50- 029-21373-01-00 14. Well Number MPC-12A 15. Field and Pool Milne Point Unit I Kuparuk River Sands 16. Lease Designation and Serial No. ADL 047434 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 'I".,".' ,"I, I'G~O~,'II'" H-40 K-55 L-80 L-80 CASING, LINER AND CEMENTING RECORD SE~tINGIDE~:rH""\'::i~'PL~',I:II:: . ':I,:':II,",':I,:¡li"",':", ,,': ",¡,:'"..' :', :i; ",';:,' . , 11,'.·,'1',:" ~,"b'p.',',",:","·"', ';;:'·B~"I7TO·"·I"·" ,"'::,"'" I"'C:'!"""I"'" .:C·· C:ME~I""''Î¡"","Rc:(!:oc[;) :"!,'",,:',,':'.:,I,,,'I,.,"',' ,', I '", 1'1. I I ,':'111,,11, ,'", ,v ~I ,I, lVI" .",1 'I" " ~~: II," III ,:" It'r- ~~ r:, ~ 'I' ~ ,~I~" II, I': ' " 'I.; ,I' I Surface 108~ Surface 6070' Surface 7067' 6751' 8780' 1'¡'iI I,:: " ",: :,' '" .,':; :1,'>., I : .IW,T'~'I:IP'Ë~'Rj; ..'.; : ,I: 48# 36# 26# 12.6# 7" 4-1/2" 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested (,:, ",'" "',:I:',,~,",II"'I, ,::> ;' :>1 "'AMOUNT' :PUU.:EQ 'I ' 12-1/4" 1625 sx PF 'E', 250 sx Class 'G' 8-112" 300 sx Class 'G' 6" 113 sx Class 'G' SIZE "'fÚE3INciiRËcORb'" , DEPTH SET (t.ID) PAGI<ER SET \".10) 24'.' 25,: Kill String 4-1/2", 12.6#, L-80 2684' N/A Acib,FRACTURE,CEMENTSaUEEZE, ETC. TVD DEPTH INTERVAL (MD) 2600' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 39 Bbls of MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oil -Bsl PRODUCTION FOR TEST PERIOD -+ flow Tubing Casing Pressure CALCULATED ........ Oll-Bsl Press. 24-HoUR RATE""'" GAs-MCF W A TER-BSl CHOKE SIZE GAS-Oil RATIO GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~;?f?~~ None Form 10-407 Revised 2/2003 _?~I5 :_0_3'· - _~:~'__..- ......---...............'......,.,....., ~\Bft ! ". " CONTINUED ON REVERSE SIDE ~ '., I I , . AUG 1/1. 1l1Jj i~ , - \., \::.. ì " 28. GEOLOGIC MARKEf ) 29. lFORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD None None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble -§~. ~ Title Technical Assistant Date 0 8 - 1:;("03 MPC-12A 199-091 303-208 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Permit No.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced. showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection. Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) 02-Apr-01 Re: Distribution of Survey Data for Well MPC-12A \£1Q..09\ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,685.13 I MD Window / Kickoff Survey: 8,780.00 I MD Projected Survey: 9,106.00' MD RECEIVED APR 12 2001 Alaska 0iJ & Gas Cons. Comrnt&s;on Anchorage (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) '- <'õ \f- 0- -.... Milne Point Unit Alaska Drilling & Wells "Milne Point MPC, Slot MPC-12 -MPC-12A Job No. AKMW10091, Surveyed: 15 March, 2001 -"~-- SURVEY REPORT 2 April, 2001 Your Ref: API-500292137301 Surface Coordinates: 6028780.41 N, 558438.70 E (70029' 21.1436" N, 149031' 20.3266" W) Kelly Bushing: 47.95ft above Mean Sea Level ~. spe...,......Y-5ufl DRILLING SERVices A Halliburton Company )" "r-F N' T"V" = ,;~)·C Survey Ref: svy9820 Sperry-Sun Drilling Services . Survey Report for MPC-12A Your Ref: API-500292137301 e- NrT"'VE Job No. AKMW10091, Surveyed: 15 March, 2001 Dr~ ' ~. ~ · ~ . · Alaska Drilling & Wells Milne Point Unit Milne Point MPC Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) ,-- 8685.13 17.840 351.070 6658.37 6706.32 4946.81 N 369.68 W 6033724.17 N 558030.16 E 4944.24 Tie On Point 8700.00 17.740 350.860 6672.53 6720.48 4951.30 N 370.39 W 6033728.65 N 558029.41 E 0.80 4948.78 8780.00 17.200 349.680 6748.84 6796.79 4974.97 N 374.45 W 6033752.28 N 558025.17 E 0.81 4972.79 Window Point 8813.00 17.280 349.800 6780.35 6828.30 4984.60 N 376.19 W 6033761.89 N 558023.35 E 0.27 4982.57 Int. AZ. 8843.00 18.900 352.200 6808.87 6856.82 4993.79 N 377.64 W 6033771.08 N 558021.83 E 5.94 4991.88 Int. AZ. 8873.00 22.590 355.000 6836.92 6884.87 5004.35 N 378.80 W 6033781.63 N 558020.58 E 12.73 5002.49 Int. AZ. 8904.28 25.580 359.000 6865.48 6913.43 5017.09 N 379.44 W 6033794.37 N 558019.84 E 10.89 5015.18 Int. AZ. 8935.38 27.880 4.860 6893.26 6941.21 5031.06 N 378.94 W 6033808.33 N 558020.23 E 11.24 5028.90 8965.48 29.620 10.730 6919.65 6967.60 5045.38 N 376.96 W 6033822.67 N 558022.10 E 11.01 5042.74 8994.20 30.940 19.340 6944.46 6992.41 5059.33 N 373.19 W 6033836.65 N 558025.76 E 15.79 5055.93 9024.00 31.460 18.460 6969.95 7017.90 5073.93 N 368.19 W 6033851.29 N 558030.64 E 2.32 5069.58 9055.00 31.460 16.700 6996.40 7044.35 5089.35 N 363.31 W 6033866.75 N 558035.41 E 2.96 5084.06 9078.80 32.260 16.880 7016.61 7064.56 5101.38 N 359.68 W 6033878.81 N 558038.94 E 3.38 5095.38 9106.00 32.260 16.880 7039.61 7087.56 5115.27 N 355.46 W 6033892.73 N 558043.05 E 0.00 5108.45 Projected to TD All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. ~ Magnetic Declination at Surface is 26.372° (13-Mar-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 351.070° (True). Based upon Minimum Curvature type calculations, at a Measured Depth öf 9106.00ft., The Bottom Hole Displacement is 5127.61ft., in the Direction of 356.025° (True). 2 April, 2001 - 16:50 · Page 2 of 3 DrillQuest 2.00.08.002 Milne Point Unit Comments .-- Measured Depth (ft) 8685.13 8780.00 8813.00 8843.00 8873.00 8904.28 9106.00 . Sperry-Sun Drilling Services Survey Report for MPC-12A Your Ref: API-500292137301 Job No. AKMW10091, Surveyed: 15 March, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6706.32 6796.79 6828.30 6856.82 6884.87 6913.43 7087.56 4946.81 N 4974.97 N 4984.60 N 369.68 W 374.45 W 376.19 W 4993.79 N 5004.35 N 5017.09 N 5115.27 N 377.64 W 378.80 W 379.44 W 355.46 W Survey tool program for MPC-12A From Measured Vertical Depth Depth (ft) (ft) ~ 0.00 2 April, 2001 - 16:50 0.00 Alaska Drilling & Wells Milne Point MPC Comment Tie On Point Window Point Int. AZ.. Int. AZ.. Int. AZ.. Int. AZ.. Projected to TD To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 9106.00 7087.56 MWD Magnetic (MPC-12APB1) Page 3 of 3 DrillQuest 2.00.08.002 Survey Ref: svy8953 - - A HALLJaURTON co.\œANY spe.......-.y-5un DRIL.L-I NG'SeRVI c:es . Ii ~ ;;o.:.;.._..,.~ -. ='" ~.::.:..-<:::.~~ 1\£?, ('~:~"!) ?':'~-::;::_~ if ¡ ~ .tr;:;:_y~ rF'~~~:} r~<~;¡ <'-,.,# .~~! ,f Ci-;¡ 'rS .-:.::..-, g ~~-! ~; C~i h1Æ ;:/ ~.~, C .f ¡~ ;¿c Sc¡) Your Ref: API-500292137301 Surface Coordinates: 6028781.55 N, 558438.05 E (70029' 21.2733" N, 149031' 20.3098" W) Kelly Bushing: 47.95ft above Mean Sea Level 5 January, 2000 SURVEY REPORT ORIGINAL oS\ J t I J C1 North Slope Alaska Alaska State Plane 4 MILNEPT MPC MPC-12A p1> l Surveyed: 3 November, 1999 Alaska State Plane 4 North Slope Alaska MILNEPT MPC Measured sub·Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth 'net. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) (ft) --- 6980.95 55.500 354.500 5197.95 5245.90 4141.57 N 237.36 W 6032921.12 N 558168.16 E 4148.22 Tie-on Survey 7072.00 55.500 353.770 5249.52 5297.47 4216.21 N 245.02 W 6032995.70 N 558159.90 E 0.661 4223.21 Window Point 7132.27 50.840 352.730 5285.64 5333.59 4264.10 N 250.68 W 6033043.55 N 558153.87 E 7.854 4271.37 7228.15 42.710 350.740 5351 .25 5399.20 4333.19 N 260.63 W 6033112.56 N 558143.37 E 8.612 4340.96 7326.25 39.590 348.440 5425.12 5473.07 4396.67 N 272.25 W 6033175.95 N 558131.25 E 3.534 4405.06 7422.69 33.140 345.560 5502.74 5550.69 4452.37 N 285.00 W 6033231 .54 N 558118.07 E 6.917 4461.48 7520.13 28.590 346.540 5586.36 5634.31 4500.86 N 297.07 W 6033279.94 N 558105.61 E 4.698 4510.66 7617.45 27.830 345.330 5672.12 5720.07 4545.49 N 308.25 W 6033324.47 N 558094.09 E 0.977 4555.91 7713.67 26.070 350.940 5757.90 5805.85 4588.10 N 317 .27 W 6033367.02 N 558084.74 E 3.212 4599.03 7810.19 25.210 352.590 5844.92 5892.87 4629.43 N 323.26 W 6033408.30 N 558078.42 E 1.158 4640.66 7907.10 23.690 351.790 5933.13 5981.08 4669.17 N 328.70 W 6033447.99 N 558072.67 E 1.605 4680.67 8003.35 23.260 352.860 6021 .42 6069.37 4707.17 N 333.82 W 6033485.95 N 558067.24 E 0.629 4718.92 8102.51 22.800 352.370 6112.67 6160.62 4745.64 N 338.81 W 6033524.38 N 558061.96 E 0.503 4757.64 8198.57 22.360 352.270 6201.37 6249.32 4782.19 N 343.74 W 6033560.89 N 558056.74 E 0.460 4794.43 8296.16 21.300 351.620 6291.96 6339.91 4818.12 N 348.82 W 6033596.78 N 558051 .38 E 1.114 4830.62 8392.14 20.4 10 350.980 6381.65 6429.60 4851.90 N 353.98 W 6033630.52 N 558045.95 E 0.957 4864.66 .-- 8490.25 19.670 350.320 6473.82 6521.77 4885.07 N 359.44 W 6033663.64 N 558040.23 E 0.789 4898.12 8586.90 18.720 350.490 6565.10 6613.05 4916.40 N 364.74 W 6033694.93 N 558034.69 E 0.985 4929.73 8685.13 17 .840 351.070 6658.37 6706.32 4946.81 N 369.68 W 6033725.31 N 558029.51 E 0.915 4960.40 8780.43 17.200 349.670 6749.25 6797.20 4975.10 N 374.47W 6033753.55 N 558024.49 E 0.804 4988.94 8934.00 17.200 349.670 6895.95 6943.90 5019.77 N 382.61 W 6033798.16 N 558016.00 E 0.000 5034.05 Projected Survey D r"(~r ~1,'''''''·'~ . '\ _.'n.. ,,-,,' <' ~. ~) ~ L~ ~~~{J t... ~ ~J1 C tv4. r- .--~- "'i ;'" ¡_ß t.J ¡ ~ t) (\;'10 ! :..._0 ~ \...f L .~)·I...r \I þf,..,/,,>!/-J.(W (J G~ ('\ . . ~t~~~i\~ ~ I {Â ":{.1S vens. CGn1r{;~:}sion AnchoraGe continued... ------------ 5 January, 2000 - 11: 14 ·2-- Dri/lQuest 1.05.04e . Sperry-Sun Drilling Services Survey Report for MPC-12A Your Ref: API..S00292137301 Surveyed: 3 November, 1999 .' Sperry-Sun Drilling Services Survey Report for MPC-12A Your Ref: API-500292137301 Surveyed: 3 November, 1999 . North Slope Alaska Alaska State Plane 4 MILNEPT MPC All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.909° (01-Nov-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 356.250° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8934.00ft., The Bottom Hole Displacement is 5034.33ft., in the Direction of 355.641° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6980.95 7072.00 8934.00 5245.90 5297.4 7 6943.90 4141.57 N 4216.21 N 5019.77 N 237.36 W 245.02 W 382.61 W Tie-on Survey Window Point Projected Survey c____- F(E{~El'¡E[) iF] l~) 20;;0 t¡ '<";(>L-!:) rVj' "G" f\ . C ., nJu.t.?n.~~: & ~·:iS \.ions, ornrrHSS!Oil Anchoraqe ----. - .----_._------~-._----. 5 January, 2000 . 11: 14 -3- DrillQuest 1.05.04e ) ) /O¡ o¡/o ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 17, 2001 RE: MWD Formation Evaluation Logs MPC-12A PB1, AK-MM-90177 1 LIS formatted Disc with verification listing. API#: 50-029-21373-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: Sign~l~ QoQ~ ~iE(~Ei\It:D Or.-:,' ? 8 "001 ~- \J '- f... .i.\iasKa Gii ii; '0d~, ,....un..:; ,w'" ii ~ :,1 d.~:,::::: \ ~~" :'\~:~'If )t'8!~~~~ ) ) t .a'~r;' ,"" "', "@,, Ft I,":' .". :'," "'!:':'~I:" ,. I .,~ ' 0,1 ..:.r.:~,':( ,,"' ,'~.:,' :~I::- :"';\:.I,::~~t:\~}'" :"':',!~~,:}:<i~;';~~ I.:r~,:¡, ':",. ' ",', ,,~"'\'" "," ".', '::'..' ':,:~ ',: ": WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 12,2001 RE: MWD Formation Evaluation Logs MPC-12AI, AK-MM-90177 1 LIS formatted CD Rom with verification listing. API#: 50-029-21373-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: Signe~ G- (k~ RECE"/ED DEC 2 8 2001 .4Jaska Oii.& Gas Cü!):). i...;(¡mmJ$Sior 4.n er<ìrzgl2 ) !~'~..~.") rE {k.\, fl· !'A'~. (::J [lrz· I ^.-:,-\ , 'q_1 I fj , ,0 . r' IlJ , .. I: ~ . ,:. ....,.' I . r"· \ ~) U L ì.J_""".J l J) J '0.IJ \.- ) A.I~A.~KA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI. GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 4, 2003 Ms. Danielle Ohms BP Exploration Alaska, Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 In Re: MPC-12Ai (PTD 199-091) Dear Ms. Ohms: The Commission has received your sundry application (303-208) requesting extension of the Operations Shutdown for the subject well. After reviewing the well file, your request to extend the Operations Shutdown is denied. Further, the Commission has determined that based on the operations history of the well that the correct well status should be Suspended with an effective date of July 13, 2003. In assessing your latest request to extend operations shutdown, we have examined the file. In late 1999, BP attempted to sidetrack MPC-12. This initial operation was not successful and the well was suspended pending additional work. Two subsequent attempts were made to sidetrack the well with the most recent attempt ending in March 2001. At that time BP requested that the well be considered in Operational Shut-Down, pending a further attempt to re-drill the well. No further attempts have been made to resume operations and an extension of the Operational Shut-Down was granted in July 12, 2002. Based on our review of the well history, we conclude that the correct well status for MPC-12Ai (PTD 199-091) as of July 12, 2003 was Suspended. Accordingly, we are editing our records to reflect the well status and effective date. The consequence of this action is that all well records for MPC-12Ai become eligible for release to the public August 13, 2005. Please contact me at 793-1250 or Steve Davies at 793-1224 if you have any questions. Sincerely, ¿~:1~ Sr. Petroleum Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging o Alter Casing 0 Repair Well 0 Pull Tubing o Change Approved Program II Operation Shutdown 0 Re-Enter Suspended Well '.~ ) 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval NIA At effective depth 186' NSL, 2392' WEL, SEC. 03, T13N, R10E, UM At total depth 330' NSL, 2374' WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 9106 feet 7088 feet 8765 feet 6783 feet Casing Length Size Structural Conductor Su rface Intermediate Production Liner 80' 13-3/8" 6034' 9-5/8" 10922' 7" 2173' 4-1/2" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) ) ~<6/L\ ~~Lt 5. Type of well: o Development o Exploratory o Stratigraphic 181 Service o Time Extension 0 Perforate o Variance II Other o Stimulate Extend Ops SID 6. Datum Elevation (DF or KB) KBE = 47.95' AMSL 7. Unit or Property Name Milne Point Unit x = 558439, Y = 6028780 8. Well Number MPC-12Ai 9. Permit Number 199-091 I 302-215 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit I Kuparuk River Sands x = 558026, Y = 6033747 x = 558043, Y = 6033892 Plugs (measured) Set CIBP at 8765' (03101) Baker TTRD Whipstock set at 8780' (top) 01/00 BHA Fish, Top at 8746' (03101) Junk (measured) Cemented MD TVD To Surface 108' 108' 1625 sx PF 'E', 250 sx Class 'G' 6070' 4679' 300 sx Class 'G' (Top of srr Window) 7067' 5295' 113 sx Class 'G' 6751' - 8780' 5113' - 6797' j\!\ ~~I ~;~ 2003 1.,) - 4-1/2", 12.6#, L-80 Kill String to 2684' Name of approver Date Approved Contact Engineer Name/Number: Danielle Ohms, 564-5759 17. ~~:~~y ~::~:~::: th~;;~ ~orre~ to;~t~e be~e~~~:a~:::::t~~~ . ..., . .... Qp~~i~$iQ~~.Qs!'Onl,.:- Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanicallntegri\y Test _ Subsequent form required 1 0- ßÎ~ Approved by order of the Commission ~~~ 'fì ~ , Gn' '" i \ L Form 10-403 Rev. 06/15/88 _ttrL r*) ì{ 2uJ3 Packers and SSSV (type and measured depth) None 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing operation 16. If proposal was verbally approved o Detailed Operations Program o BOP Sketch 15. Status of well classifications as: o Oil DGas 'Jsus~A' Service F"" /"fJ'" r ( '6/ f Prepared By Name/Number: Terrie Hubb/e, 564-4628 Date Dr¡.Á3.0~ I Approval NOSP5- ~I>t' ~'-JS~«'~~ ~<t\\ o..~t)~ Commissioner Date 7<1 q If5 Submit In Triplicate bp ) ) .,. ,\It.'~' -.......~ ~.~ ~~- ~~-- ...~ ~...... ·'i'~~I\~ ". Danielle Ohms Direct: (907) 564-5759 OhmsDH@bp.com Senior Petroleum Engineer MPU Production Optimization Team BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 July 23, 2003 Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Reference: M PC-12A, Permit to Drill, 199-091 Approval No. 301-071 To Whom It May Concern: MPC-12Ai is currently in an Operations Shutdown status due to complications during sidetracking operations in August of 1999. We arc requesting at this time that this status be continued. Plans arc presently being devdoped to possibly sidetrack this well to a bottom hole location, which would provide injector support for MPC-()3 and MPC-07. The earliest this sidetrack would most likdy occur would be in the fourth quarter of this year. Thank you very much for your assistance in this matter. Sincerdy, /Î > J/l ('~f1/Þ1/J~ U klA/?---- -....Danidle Ohms ) STATE OF ALASKA 1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~6A g-£ on 1/1t/D'L Î!ß(~ '7/L3 ì...·, I 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. o Suspend 0 Plugging o Repair Well 0 Pull Tubing II Operation Shutdown 0 Re-Enter Suspended Well 5. Type of well: o Development o Exploratory o Stratigraphic IBI SelVice 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive intelVal NIA At effective depth 1861 NSL, 2392' WEL, SEC. 03, T13N, R10E, UM At total depth 330' NSL, 2374' WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 9106 feet 7088 feet 8765 feet 6783 feet measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Size 80' 13-3/8" 6034' 9-5/8" 10922' 7" 2173' 4-1/2" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) o Time Extension 0 Perforate , o Variance II Other /' o Stimulate Extend Ops SID 6. Datum Elevation (DF or KB) KBE = 47.95' AMSL 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-12Ai 9. Permit Number 199-091 1301-071 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit I Kuparuk River Sands Plugs (measured) Set CIBP at 8765' (Uncorrected) (03/01) Baker TTRD Whipstock set at 8780' (top) 01/00 BHA Fish, Top at 8746' (Uncorrected) (03/01) Junk (measured) Cemented MD TVD To Surface 108' 108' 1625 sx PF 'E', 250 sx Class 'G1 6070' 4679' 300 sx Class 'GI (Top of srr Window) 7067' 5295' 113 sx Class 'G' 67511 - 8780' 5113' - 6797' ORIGINAL f.') r" f'" ~..... i ", .f g",- D ,,!,. ~.". Œ i·.., \If ~'W , ''\ t~.., \.,'" i.. : '= \ JPI rl t") r¡f1fj2 \...':- L L\J\; . 4-1/2", 12.6#, L-80 Kill String to 2684' Alaska on &. Gas Gons. Cormmssmfì Anchorage Packers and SSSV (type and measured depth) None 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing operation 16. If proposal was verbally approved o Detailed Operations Program 15. Status of well classifications as: o Oil 0 Gas 0 Suspended SelVice Water & Gas Injector o BOP Sketch Name of approver Date Approved Contact Engineer NameINumber: Michae/ Aivano, 564-5943 Prepared By NameINumber: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge SignedT":::.~U~~)"~;.i;Wt:\~il'!r;.:t~~~;~:f,~~'{¡i;n1¡;.,; Date 07- (~.:O ~ Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ On Sub~equent form required 10- . glnal ~Ignad By Approved by order of the Commission Cammy Oechsli Taylor Form 10-403 Rev. 06/15/88 I Approval No.3D'd-- - à \ S _tJ.,'P-~~ ':f1,~J{)~3 ~ Co~missioner Date 1· ~?~ (),J Submit In frirt ate . L " bp ) ) .,. ,\If.''I. -.......~ ~.....~ ~..- ~...~ ......~ F...... ·'1'·'1'- ". Michael Aivano Production Engineer MPU Production Optimization Team BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 . July 12, 2002 Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Reference: MPC-12A, Permit to Drill, 199-091 Approval No. 301-071 Direct: (907) 564-5943 AivanoMJ@bp.com To \Vhom It May Concern: MPC-12Ai is currently in a suspended status due to complications during sidetracking operations in August of 1999. It is requested to leave MPC-12Ai in its current state due to two different development options that exist for the well. The first option is to side track the well from its current bottom hole location to an area better slùted to support MPC-03 in the Kuparuk formation. The second option is to side track the well deeper into the Sag River to be an injector to support :N.IPC-23. Both are options in the development plans for the 2003 drilling program. Thank you very much for your assistance in tlus matter. " ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: II Operation Shutdown 0 Stimulate 0 Plugging 0 Perforate o Pull Tubing 0 Alter Casing 0 Repair Well II Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval NIA 5. Type of well: o Development o Exploratory o Stratigraphic IBI Service Approval Expires 05/01/02 6. Datum Elevation (DF or KB) KBE = 47.95' AMSL 7. Unit or Property Name Milne Point Unit 8. Well Number At effective depth 186' NSL, 2392' WEL, SEC. 03, T13N, R10E, UM At total depth 330' NSL, 2374' WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary Total depth: measured MPC-12Ai 9. Permit Number I Approval No. 199-091 301-071 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit I Kuparuk River Sands Effective depth: true vertical measured true vertical 9106 feet 7088 feet 8765 feet 6783 feet Plugs (measured) Set CIBP at 8765' (Uncorrected) (03/01) Baker TTRD Whipstock set at 8780' (top) 01/00 Junk (measured) BHA Fish, Top at 8746' (Uncorrected) (03/01) Casing Structural Conductor Su rface Intermediate Production Liner Length Size Cemented MD TVD To Surface 108' 108' 1625 sx PF 'E', 250 sx Class 'G' 6070' 4679' 300 sx Class 'G' (Top of SfT Window) 7067' 5295' 113 sx Class 'G' 6751' - 8780' 5113' - 6797' 80' 13-3/8" 6034' 9-5/8" 10922' 7" 2173' 4-1/2" Perforation depth: measured None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Kill String to 2684' RECEIVED MAY 0 :1 2001 Alaska Oil & Gas C ons. Commiss;()r: A, /(,1'Iorage true vertical None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments IBI Copies of Logs and Surveys run IBI Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ JV\.i.t ~ Title Technical Assistant 16. Status of well classifications as: o Oil 0 Gas 0 Suspended Service Water & Gas Injector Form 10-404 Rev. 06/15/88 ORfGJNt\! Date 05-~·OI Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate ~ ,I ) ) BP EXPLORATIO.N Operations Summary Report. Legal Well Name: MPC-12 Common Well Name: MPC-12A Event Name: REENTER+COMPLETE Contractor Name: NABORS Rig Name: NABORS 3S Gate From -To Hoûrs Task :Sub Phase .Codè. 3/12/2001 00:00 - 09:00 9.00 RIGU PRE 09:00 - 11 :00 2.00 BOPSUR INT1 11 :00 - 17:00 6.00 BOPSURTEST INT1 17:00 - 00:00 7.00 BOPSUR INT1 3/13/2001 02:00 - 06:00 4.00 STWHIP WEXIT 06:00 - 11 :00 5.00 STWHIP WEXIT 11 :00 - 15:30 4.50 STWHIP TRAN WEXIT 15:30 - 18:00 2.50 STWHIP WEXIT 18:00 - 20:30 2.50 STWHIP WEXIT 20:30 - 22:45 2.25 STWHIP WEXIT 22:45 - 23:00 0.25 STWHIP WEXIT 23:00 - 00:00 1.00 STWHIP WEXIT 3/14/2001 00:00 - 01 :30 1.50 STWHIP WEXIT 01 :30 - 03:30 2.00 STWHIP WEXIT 03:30 - 05:00 1.50 STWHIP CIRC WEXIT 05:00 - 06:00 1.00 STWHIP WEXIT 06:00 - 08:00 2.00 STWHIP WEXIT 08:00 - 09:30 1.50 STWHIP WEXIT 09:30 - 11 :30 2.00 STWHIP WEXIT 11 :30 - 14:00 2.50 STWHIP WEXIT 14:00 - 16:00 2.00 STWHIP WEXIT 16:00 - 18:00 2.00 STWHIP WEXIT 18:00 -18:15 0.25 STWHIP WEXIT 18: 15 - 18:45 0.50 STWHIP WEXIT 18:45 - 21 :00 2.25 DRILL INT1 21 :00 - 21 :20 0.33 DRILL INT1 21 :20 - 22:50 1.50 DRILL INT1 22:50 - 00:00 1.17 DRILL INT1 3/15/2001 00:00 - 06:45 6.75 DRILL INT1 06:45 - 07:30 0.75 DRILL INT1 07:30 - 09:15 1.75 DRILL INT1 09:15 -10:15 1.00 DRILL OCOL INT1 10:15 - 12:30 2.25 DRILL INT1 12:30 - 13:15 0.75 DRILL INT1 13:15 -18:15 5.00 DRILL INT1 18:15 - 00:00 5.75 DRILL INT1 3/16/2001 00:00 - 00: 15 0.25 DRILL INT1 Page 1 of 7 Start: 3/9/2001 Rig Release: Rig Number: Spud Date: 6/14/1985 End: 3/26/2001 Group: COIL Descripti9n ofQpetations Continue moving in return tanks. Modify supply tank dike. Move in Coil Unit #4 (w/o reel). Begin testing BOP. Witness waived by AOGCC Inspector Lou Grimaldi. Repair leaking valves on choke manifold. WO parts from PRB. Continue BOP test. Stab pipe into injector head. Rehead coil. Change out pack-offs Wait on MethlWater from PRB for PT lines. Test CTD surface lines .MU nozzel and stinger RIH and change well over to water. Tag at 8,780'. POH laying in 11.6 ppg mud Test Well bore to 1000 psi.Good Test. Lay down Nozzel BHA. Clear floor MU starter milling assy. RIH with milling assembly Switch to Dowell pump. Fuel transfer pump on engine faulty. Mill l' of casing with starter mill. POOH. LD starter mill. 1/16" UG. MU milling BHA #2 (WindowMaster and string mill). RIH. Kick drill. Tag whipstock and correct (-1') to 8781'. PU 39k. Free spin 2.5/3000. Mill window steady to 8787.5'. Stall here, then ROP picked-up. Should be in formation. Mill to 8798'. PU 41,000 SO 12,000 Free spin 2.2bpm @ 3700psi Dress window up and down. Pump 150k LSRV sweep. Dry tag clean. POOH. .PJSM Lay down milling BHA MU drilling BHA #3. Test Sperry Orienter O.K. RIH to 8700. SP Rate 112 bpm @ 1300 psi Orient to 45L. Tie-in with GR. 0 correction Try running thru window at 45L. Tag btm window 8787'. PU, get one click, RIH clean. Tag 8795'. Drill high side slow 2.2/3600' to 8817'. Showing about 1 deg drop in inclination. Easy, but strong stalls. Drill to 8832' at 30 FPH. Slow drilling again to 8842' with numerous stalls. TF wandering to right. Orient around Drill 2.2/3650/20R to 8858'. Frequent wipers show clean hole. SD pumps and pull into casing to repair roller on gooseneck. Orient around to get back where we were. Drill 2.2/3650/1 OL to 8865'. No more stalling probems. Continue drilling 15 - 20 FPH with negative wt. Kick drill 11 :30 hrs. Drill to 8875'. Start seeing higher off-bottom pump pressure 2.2/3750. Stalling again. 8k overpull on bottom. Slow wiper trip. Drill 2.2/3700. Got some pressure back and drilling with positive wt again. Drill slow to 8904' with frequent wiper trips to window. Try higher pump rate to 2.4 and 4100 psi. coil pressure. Directionally drill to 8931' Drill to 8931. Printed: 4/12/2001 9:33:47 AM ) ) BPEXPLORATION Page2of7 OperationsSunlmary- RepQrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-12 MPC-12A REENTER+COMPLETE NABORS NABORS 3S Date From - To Hours' --'Task Sub Phase Code 3/16/2001 00:15 - 03:30 3.25 DRILL WCON INT1 03:30 - 04:00 0.50 DRILL WCON INT1 04:00 - 07:30 3.50 DRILL WCON INT1 07:30 - 07:50 0.33 DRILL WCON INT1 07:50 - 08:05 0.25 DRILL WCON INT1 08:05 - 12:00 3.92 DRILL WCON INT1 12:00 - 12:30 0.50 DRILL INT1 12:30 - 13:00 0.50 DRILL INT1 13:00 - 17:30 4.50 DRILL WCON INT1 17:30 - 20:30 3.00 DRILL weaN INT1 20:30 - 20:50 0.33 DRILL WCON INT1 20:50 - 22:00 1.17 DRILL INT1 22:00 - 00:00 2.00 DRILL INT1 3/17/2001 00:00 - 10:00 10.00 DRILL INT1 10:00 - 11 :00 1.00 DRILL INT1 11 :00 - 12:30 1.50 DRILL INT1 12:30 - 13:00 0.50 DRILL INT1 13:00 - 13:15 0.25 DRILL INT1 13:15 - 15:15 2.00 DRILL INn 15:15-16:00 0.75 DRILL INT1 16:00 - 16:45 0.75 DRILL INT1 16:45 - 17:45 1.00 DRILL INT1 17:45 - 18:00 0.25 DRILL INT1 18:00 - 20:30 2.50 DRILL INT1 20:30 - 22:30 2.00 DRILL INT1 22:30 - 00:00 1.50 DRILL INT1 3/18/2001 00:00 - 01:15 1.25 DRILL INT1 01 :15 - 02:00 0.75 DRILL INT1 02:00 - 03:00 1.00 DRILL INT1 03:00 - 04:00 1.00 DRILL INT1 04:00 - 06:00 2.00 DRILL INT1 06:00 - 12:30 6.50 DRILL INT1 Start: 3/9/2001 Rig Release: Rig Number: Spud Date: 6/14/1985 End: 3/26/2001 Group: COIL Descri ptioh of:Operations Micromotion meter indicated slight increase in flow. Mud weight in had fall off to 11.4 . return mud weight was 11.2. Pull up to shoe and condition mud back to 11.6 ppg.while circulating thru choke. Shut well. SICTP=300psi. SIWHP=280. Circulate through choke 2.2 BPM, 3900 CTP, 300 WHP. Steady 11.6 ppg coming back. SI well again. SIWHP stable at 255 psi. Need 12.4 ppg to balance formation pressure Circulate on choke to warm-up pipe. Pressure well to 1000 psi (14.4 EMW) for leak-off/breakdown evaluation. Repeat tests. Continue circulating holding choke at 300 psi WHP. Determine well kill fluid type. Order-up barite for mixing into existing system to give us 12.7 ppg. Log tie-in. No correction. Safety meeting for weighting-up. Weight-up pit #2 to 12.7. Wait on more barite from Deadhorse. Mix. Bluid circulating volume. Kill well with 12.7ppg at 2.2 bpm. Monitor well OK. Orientate and RIH to 8931. NO fill. PU weight 42,000 free spin 4360 psi. Directionally drilling at 8939' Directionally drill 2.2/4300. 40k up. Losses with 12.7 ppg mud 5 - 10 BPH, but most of this is going over the shakers -- bar plugging the screens. Last night, when displacing well to new mud, we started seeing slight losses (0.1 BPM) shortly before new mud got back to surface. Drill to 8984'. Wiper to window. Slight motor work at 8873', cleaned-up easy and did not see it RIH. Drill right turn very slow to 8990'. Poor slide. CTP has gradually dropped to 4100 psi. MW has fallen to 12.3 ppg+. Wiper to window -- clean. PUH above window for flowcheck. No flow. Orient for left turn. Drill. Send new 12.7 mud downhole. Drill to 9000'. Stacking Wiper to window. Orient Drill to 9005'. Still averaging < 5 FPH. Check for flow at window. POOH to check tools, drop orienter, swap to straight motor. Call for more lubetex. Circulation rate 2.2 at 3790 psi. Continue to POH. Change out BHA. Bit in good over condition. One jet plugged. Some evidence of balling on BHA. Minor damage to cutter on bi-center gage cutter. RIH Circulation rate at surface 2.2 bpm at 3000 psi Continue to RIH. RIH to 9,005'. PU 43k; SO 10k. Free spin 3480 psi at 2.4 bpm. Drill to 9010 with 200 psi motor diff. Drill to 9017' 4070 psi at 2.5 bpm. PU 44k; SO 9k Drill to 9028'. 4070 psi at 2.7 bpm Coil WT 4750#. Drill to 9039. 4100 psi at 2.6 bpm. Drill 4200 psi at 2.6 bpm. Free spin 2.6/3750. Drill to 9102'. Increase in Rap last 2'. We're between 2' and 15' TVD from Kuparuk C (depending on which well's correlation is used). Call this TO. (Note: 2.2/3200 on bottom now vs 2.2/4200 on bottom with orienter and 11 Printed: 4/12/2001 9:33:47 AM ) ) BP EXPLORATION Page 30f 7 Operations Summa:ry· Report Legal Well Name: MPC-12 Common Well Name: MPC-12A Event Name: REENTER+COMPLETE Contractor Name: NABORS Rig Name: NABORS 3S . Date· From - To Hours Task· Sub Phase Code 3/18/2001 06:00 - 12:30 6.50 DRILL INT1 12:30 - 13:00 0.50 DRILL INT1 13:00 - 13:30 0.50 DRILL INT1 13:30 -14:15 0.75 DRILL INT1 14:15 - 15:00 0.75 DRILL INT1 15:00 - 17:00 2.00 DRILL INT1 17:00 - 17:30 0.50 DRILL INT1 17:30 - 18:00 0.50 DRILL INT1 18:00 - 18:45 0.75 DRILL INT1 18:45 - 20:00 1.25 DRILL INT1 20:00 - 21 :30 1.50 CASE INT1 21 :30 - 23:00 1.50 CASE INT1 23:00 - 23:30 0.50 CASE INT1 23:30 - 00:00 0.50 CASE INT1 3/19/2001 00:00 - 03:30 3.50 CASE INT1 03:30 - 05:00 1.50 CASE INT1 05:00 - 06:30 1.50 CASE INT1 06:30 - 07:30 1.00 CASE FILL INT1 07:30 - 10:30 3.00 CASE WCON INT1 10:30 - 18:00 7.50 CASE WCON INT1 18:00 - 20:30 2.50 CASE WCON INT1 20:30 - 00:00 3.50 CASE WCON INT1 3/20/2001 00:00 - 00:45 0.75 CASE WCON INT1 00:45 - 01 :10 0.42 CASE WCON INT1 01:10 - 03:30 2.33 CASE FILL INT1 03:30 - 05:30 2.00 CASE FILL INT1 05:30 - 06:00 0.50 CASE FILL INT1 06:00 - 06:30 0.50 CASE INT1 06:30 - 08:00 1.50 CASE FILL INT1 08:00 - 09:30 1.50 CASE FILL INT1 09:30 - 11 :15 1.75 CASE FILL INT1 11: 15 - 11 :45 0.50 CASE FILL INT1 11 :45 - 13:45 2.00 CASE FILL INT1 13:45 - 18:30 4.75 CASE STAB INT1 Start: 3/9/2001 Rig Release: Rig Number: Spud Date: 6/14/1985 End: 3/26/2001 Group: COIL Description of Operations internal orifice). Wiper to window. No overpull or motor work. Log tie-in. Correct depth (+4'). RIH to bottom. Motor work 8875' and 8905'. Ream these areas clean. Tag corrected TO 9106'. BHCT = 112 deg F. Wiper thru open hole. POOH. Wash 7300' - 5000' at high pump rate and slow speed (55 deg deviation and 7" liner). Repeat pass. Pump high vis pill. POOH. Safety meeting. EMS overview given by Ron Youngs Finish POOH. LD drilling BHA. Bit plugged with motor rubber. Only upper two jets were open. Circulate 1-5/16" drift ball, displacing coil to methanol. 52 bbls to bump. Clear floor. RU to run liner. Safety meeting. MU combo 3-3/16" TCII and 3-1/2" FL4S liner. BakerLock float equipment. MU intermediate liner string. PU Injector. Well starting to flow. SI. SIWHP = 160 psi. Stab inj. RIH holding 200 psi WHP. IN = OUT + coil disp. Density out = 10.5 ppg. Apparently barite has fallen out. Tag at 4-1/2" x 7" liner top 6745' CTM (53 deg inc). Clean PU. Wash up and down here. Acted like some solids on low side initially, but cleaned-up. consistent solid tag and clean PU. Circulate and condition mud on choke at 250 psi WHP. Inconsistent densites in and out, ranging from 11.3 - 12.0 ppg. Getting slugs of barite back. Densities slowly increasing. 12.2 in; 12.4 out. Circulating on choke at 300 psi. Discuss options with Anchorage. Order NaBr system from MI. Continue circulating at 1.0 BPM. Return densities continue to fluctuate between 11.5 and 14.0 ppg. Start 13.0 ppg NaBr + barite system downhole at constant WHP of 300 psi. 1.3/1875 initial CTP. lAP = 1050 psi. With new mud at bit, 1.2/1900. Circulate new mud to surface holding CTP constant. Final 1.1/1900 and 50 psi WHP (FOC). Circ 1.1/1900 FOC checking in and out densities. 13.0 ppg in/13.1 ppg out. lAP = 950; OAP = 127. Flow check. No flow. POOH. Flow check again halfway out. Standback inj, 3-1/2" drill collars. LD CTLRT. Standback liner. Safety meeting. Finish standing back liner. No tag marks on guide shoe. Hole stable. MU cleanout BHA #5 (straight motor; bicenter bit) RIH Tag hard and stall at 6721' CTM (about 30' CTM shallower than previous run). PU clean. 28k up; 8k down. RIH slow and stall at same spot. PU. Mill 2.6/4000 with ratty motor work for about 1', then fell thru. Wash down at 30 FPM. No other tags or motor work in cased hole until 8690'. About 100 psi increase in CTP here. Slow down running speed, wash to window. 13.0 ppg in/12.7+ ppg out. Run through window. Ream sticky shale 8790'. Stall 8832'. Work past Printed: 4/12/2001 9:33:47 AM ) ) BP EXPLORATION Page 4'of7 Ope,ratl()nsSummaryR~pprt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-12 MPC-12A REENTER+COMPLETE NABORS NABORS 3S 'Date Sub Task Code 4.75 CASE STAB INT1 Description ofOperatiohs From.;.To' 'Hours 3/20/2001 13:45 - 18:30 18:30 - 19:30 1.00 CASE STAB INT1 19:30 - 20:30 1.00 CASE STAB INT1 20:30 - 21 :40 1.17 CASE STAB INT1 21 :40 - 23:30 1.83 CASE STAB INT1 23:30 - 00:00 0.50 CASE STAB INT1 3/21/2001 00:00 - 00:50 0.83 CASE STAB INT1 00:50 - 01 :20 0.50 CASE STAB INT1 01 :20 - 02:00 0.67 CASE STAB INT1 02:00 - 02:30 0.50 CASE STAB INT1 02:30 - 06:30 4.00 CASE STAB INT1 06:30 - 15:30 9.00 CASE STAB INT1 15:30 - 16:30 1.00 CASE STAB INT1 16:30 - 17:30 1.00 CASE STAB INT1 17:30 - 21 :50 4.33 CASE STAB INT1 21 :50 - 22:30 0.67 CASE STAB INT1 22:30 - 22:45 0.25 CASE STAB INT1 22:45 - 23:30 0.75 CASE STAB INT1 23:30 - 00:00 0.50 CASE STAB INT1 3/22/2001 00:00 - 00:15 0.25 CASE STAB INT1 00: 15 - 00:35 0.33 CASE STAB INT1 00:35 - 03:10 2.58 CASE STAB INT1 03: 1 0 - 03:30 0.33 CASE STAB INT1 03:30 - 04:00 0.50 CASE STAB INT1 04:00 - 06:30 2.50 CASE STAB INT1 Start: 3/9/2001 Rig Release: Rig Number: Spud Date: 6/14/1985 End: 3/26/2001 Group: COIL to 8836'. Seeing some packoff and losses -- keep rate up. Ream down with ratty motor work to 8847'. Packing off. PU and stuck. Work pipe. Never fully packed-off. 2.5 BPM in; variable rate out from 0.3 - 2.7 BPM. Work pipe uphole about 8'. No further progress. Go to neutral wight and monitor in and out rates. Rates eventually stabilized at 2.5 in and out. Work pipe. Started packing off again. Mix lubetex pill. Pump 10 bbllubetex pill (one drum in 10 bbls of 12.8 ppg mud). Let 5 bbls go out bit, soak, work pipe. No go. Repeat. No go. Continue circulating. 2.5 in/2.5 out. Mix high vis pill. Pumped 5 bbls KCL water followed by 5 bbls mud then 20 bbl hi-vis pill. Work pipe pumping sweeps in openhole at 2.8 in/2.7 out. No movement observed. Shut-in well and pump down annulus holding 30K overpulll. No movement. Prep to pump 15/16" disconnect ball. Drop and pump 15/16" CT disconnect ball. Shear at 5300 psi. Unable to pick-up. Apparently still stuck above CT disconnect. Work pipe. Able to pump at 3 bpm w/4200 psi. Disconnect ports are open. Unable to work pipe as desired the CT life at the injector is 67%. Circulate and weigh options. Pump 5 bbls KCL water sweep at 3 bpm and keeping 30K pull over string weight. No affect seen. Circulate at 3.1 bpm. Full returns. Small amount of black shale continually coming across shaker. Keeping constant pull on CT. Continue working pipe. Full returns, no indications of packing off. 12.7 ppg in/12.8 ppg out. Pipe fatigue at 70%. Continued full steady returns. Pump 20 bbl nut plug pill for abrasion to cut clay/shale around us. Packed off at coil volume displacement, no returns. Bullhead nut plug into formation. Overdisplace pill by 30 bbls at 2.5 BPM; 4700 psi CTP. Pressure backside to 1500 psi. Solid. Bleed to surge. No luck. Pump down coil at 0.5 BPM. Pressure broke over at 3000 psi. Work pipe. Pump mud as needed to keep pipe warm. Wait on chemical cutting crew/equipment. Hold PJSM concerning CT cutting operation. Bleed off and check pressures on coil and annulus assure that well is dead. Displace surface portion of coil with methanol. Same time P/U to 43K and close pipe/slip rams. Slips not holding. Slack off to neutral weight and close rams. Disconnect and p/u injector. Install false table, hand slips and dog collar on CT. RIU and Hot-Tap CT. Pump additional 3 bbls methanol to opentop to clear coil of mud. Cut coil below hot-tap with hydraulic cutters. Trim ends and install CT connectors. Set back injector. RIU Schlumberger equipment and circulation lines PT lines on floor. Perform injectivity test with the new coil length. 2700psi/.5bpm vs. 3450psi/.5 bpm. Bleed-off all pressures. PJSM covering hazards with P/U of chemical cutter. Review operations and job assignments. P/U cutting tools. RIH wI same w/o pumping down. Stalled at 4900'. P/U on coil to 20K. Resume RIH w/tools. Tagged up on CTC at 8756' (uncorrected e-line depth). P/U check up weight 4000#. Confirm tag Printed: 4/12/2001 9:33:47 AM ) ) BP EXPLORATION' Påge50f7 .O,peratiónsSummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/22/2001 3/23/2001 3/24/2001 3/25/2001 MPC-12 MPC-12A REENTER+COMPLETE NABORS NABORS 3S 04:00 - 06:30 Sub' Task Code Phase 2.50 CASE STAB INT1 From- To Hours 06:30 - 07:30 1.00 CASE STAB INT1 07:30 - 08:30 1.00 CASE STAB INT1 08:30 - 09:30 1.00 CASE STAB INT1 09:30 - 13:30 4.00 CASE STAB INT1 13:30 - 16:00 2.50 CASE STAB INT1 16:00 - 19:00 3.00 CASE STAB INT1 19:00 - 19:30 0.50 CASE STAB INT1 19:30 - 21 :00 1.50 CASE STAB INT1 21 :00 - 23:00 2.00 TA ABAN 23:00 - 00:00 1.00 T A ABAN 00:00 - 01 :00 1.00 TA ABAN 01 :00 - 03:00 2.00 TA BARR ABAN 03:00 - 10:30 7.50 T A ABAN 10:30 - 00:00 13.50 TA STAB ABAN 00:00 - 08:30 8.50 TA STAB ABAN 08:30 - 11 :30 3.00 TA STAB ABAN 11 :30 - 18:00 6.50 TA OCOl ABAN 18:00 - 18:30 0.50 TA ABAN 18:30 - 19:30 1.00 TA STAB ABAN 19:30 - 21 :00 1.50 TA STAB ABAN 21 :00 - 22:00 1.00 TA STAB ABAN 22:00 - 23:30 1.50 TA STAB ABAN 23:30 - 00:00 0.50 T A STAB ABAN 00:00 - 01 :30 1.50 T A STAB ABAN 01 :30 - 02: 15 0.75 TA STAB ABAN 02:15 - 02:45 0.50 T A STAB ABAN 02:45 - 04:15 1.50 T A STAB ABAN 04:15 - 05:20 1.08 TA STAB ABAN 05:20 - 13:00 7.67 TA STAB ABAN 13:00 - 15:30 2.50 TA STAB ABAN 15:30 - 17:00 1.50 TA STAB ABAN Start: 3/9/2001 Rig Release: Rig Number: Spud Date: 6/14/1985 End: 3/26/2001 Group: COIL DescriþtionofOperations depth. P/U 5K over string weight to 45K. Clear floor. Position cutter at 8746'. Fire cutter. Check string weight. loss of 5K. P/U on e-line no problem coming off bottom with chemical cutter. TOH wI cutter assembly. RD E-line. PU pipe to verify free. Circulate 250 bbls at 2.9 BPM; 2100 psi. SD and check for flow. Splice coil with spoolable connector. POOH circulating and filling. 10k overpull for a few feet off bottom, then slowly broke back. Bottom 3000' of coil heavily coated with sticky mud, requiring increased pack-off. SI master. RU N2 truck. Blow down reel. Safety meeting -- RD ROC Unstab pipe, pull and secure to ROC. Send ROC to Deadhorse to re-spool. Change out 2 3/8" pipe/slips rams (slip rams not grabbing pipe -- barite caked??) Perform weekly BOP test. Witnessing wavied John crisp. Test BOPE. Rebuild choke manifold valve. Finish BOP test. Wait on ROC to re-spool. LID 3 1/2" De's. Clean out cuttings tank. General rig service/maintenance. Wait on ROC to be re-spooled. General rig maintenance. RU ROC. Stab pipe. Trolley chain broke. Call for mechanics. Replace chain. Safety meeting. PU injector Change out pack-off and install CTC. PT hard line to ROC. Pump 1 5/16" brass ball rabbit and fill coil wI methanol. PT inner reel valve to 4000 psi. Retrieve ball but was dropped downhole. Put injector on deck. RIH with liner standing in derrick and LID same. Finish LID of liner from derrick. P/U injector and M/U motorhead assembly. PT to 3000 psi. Displace coil w/12.8 mud. M/U BHA #6 18.22'. RIH w/ undereamer. Tagged up at 6779' (uncorrected) top of 4.5" liner. Pump at .5 bpm and work through top. Wash and ream 2.4 bpm 3850 psi fair amount of motor work seen fl 6791' and down. Slugs of barite over shakers on BU. Ream with zero weight to 6910, then started getting some weight back. Stalls 6871' and 6904' (collars??). lost motor work at 7050' CTM (start losing inclination here). Continue washing in hole 5 FPM 2.4/3800 with no resistence. Clean PU's on wt checks. No significant barite over shaker - just shale. Tag and stall 8779' CTM. Ream and backream bottom 20'. Backream up thru liner top at 30 FPM. RIH dry and tag 6760' CTM. Clean PU. Repeat. Same tag. Required minimum pump to get thru. Continue RIH. Did not see anything at 6779' CTM. Backream at full pump rate. Dry tag again at same spot; with minimum pumps didn't see a bobble. Continue backreaming liner top area and RIH dry. Got thru dry only once. Getting CIBP in will be a crap shoot. Flag pipe 6702' EOP. POOH. Printed: 411212001 9:33:47 AM ) ) BP EXPLORATION Page 60f 7 Q,perationsSummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-12 MPC-12A REENTER+COMPLETE NABORS NABORS 3S Date From-To Hours' Tàsk Sub Phase Code 3/25/2001 17:00 - 18:30 1.50 TA STAB ABAN 18:30 - 22:15 3.75 TA STAB ABAN 22:15 - 23:00 0.75 TA STAB ABAN 23:00 - 23:25 0.42 TA STAB ABAN 23:25 - 00:00 0.58 TA STAB ABAN 3/26/2001 00:00 - 00:30 0.50 TA STAB ABAN 00:30 - 01 :00 0.50 TA STAB ABAN 01 :00 - 02:00 1.00 TA STAB ABAN 02:00 - 03:30 1.50 TA STAB ABAN 03:30 - 05:15 1.75 TA STAB ABAN 05:15 - 05:30 0.25 TA STAB ABAN 05:30 - 06:00 0.50 TA STAB ABAN 06:00 - 07:00 1.00 TA STAB ABAN 07:00 - 08:15 1.25 TA STAB ABAN 08:15 - 08:30 0.25 TA STAB ABAN 08:30 - 10:00 1.50 TA STAB ABAN 10:00 - 10:30 0.50 TA STAB ABAN 10:30-11:15 0.75 TA STAB ABAN 11: 15 - 11 :30 0.25 TA STAB ABAN 11 :30 - 14:00 2.50 RIGD STAB ABAN 14:00 - 14:15 0.25 RIGD STAB ABAN 14:15 - 15:15 1.00 RIGD STAB ABAN 15:15 - 18:00 2.75 RIGD STAB ABAN 18:00 - 21 :30 3.50 RIGD STAB ABAN 21 :30 - 00:00 2.50 RIGD POST Start: 3/9/2001 Rig Release: Rig Number: Spud Date: 6/14/1985 End: 3/26/2001 Group: COIL Description of Opèr~tions LD tools. Underreamer packed with shale and 1-5/16" ball was wedged in blade opening. MU Baker CIBP and setting tool on MHA RIH w/ CIBP. No problem going through liner top but tagged at 6825'. Increase pump to 1.5 bpm and work through. Continue RIH. Taking weight and pushing until hole angle breakover at +1- 7050' then gaining steady weight back. Tagged CT stump a 8774' (uncorrected). Pull up to 8770' and drop setting ball. Pump setting ball 61.5 bbls 1.5 bpm /1600 psi. Set CIBP at 8765' MD (uncorrected). Pull to 8854' circulate. Have additional 1000 psi pump pressure after setting CIBP. Positive pressure test CIBP 1800 psi 115 min. Pump 35 bbl seawaterl Bio-Zan sweep 1.2 bpm 1 2500 psi. Will follow with seawater to displace casing. Continue pumping 35 bbl seawater / Bio-zan sweep followed with seawater @ 1.7 bpm 2700 psi. After pumping 17 bbl coil pressures increased steadly to 4900 psi rate down to .1 bpm. (differential pressures during displacement should not have exceeded 4000 psi). Unable to further pump at acceptable rate. TOH. Circulate across top of annulus to fill. Start to pull tight, 20K over, at 7525'. Work tight hole. Shutdown to freeze protect surface lines Freeze protect surface lines. Work tight hole from 7525' to 7425'. Unable to pump down coil. TOH still overpull 1 0-15K above string weight. Progressively better to top of 4.5" liner then pulling normal. UD Baker setting tool. Plugged with nutplug. M/U nozzle to MHA TIH to top of liner 6790'. Displace mud with SW inhibited with 0.4% Safe Scav NA (MI product) corrosion inhibitor. Flowcheck. No flow. lAP = 180; OAP = 200. POOH: freeze protect to 2600' with 39 bbls 60/40 methanol. Flowcheck to open top. Flowing, gradually increasing in rate. SI well. Monitor pressure buildup. No buildup. Must be coming from coil. Leaking valve to N2 truck. Unstab inj, close HCR, watch fluid level in stack. No flow. SUCCESSFUL 1100 psi NEGATIVE PRESSURE TEST ACROSS CIBP. Blow down reel with N2. Start RD while bleeding. Do one more flowcheck. Dead. RU BPV lubricator and set BPV. Clean pits, unstab and secure CT to ROC. Send ROC and Unit #4 to Deadhorse. N/D BOP stack. N/U wellhead cap and PT 3500 psi /10 min. Rig Released at 2130 hrs 3-26-01 Continue RID. Printed: 4/12/2001 9:33:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BPEXPLORATIO'N Page,7:of 7 Operations'Summary,.Report MPC-12 MPC-12A REENTER+COMPLETE NABORS NABORS 3S Date Sub From:" To Hours Task Code Phase 3/10/2001 10:00 - 22:00 22:00 - 00:00 00:00 - 10:30 3/11/2001 3/13/2001 10:30 - 18:00 18:00 - 19:30 19:30 - 00:00 00:00 - 02:00 12.00 MOB 2.00 MOB 10.50 RIGU PRE PRE PRE 7.50 RIGU 1.50 RIGU 4.50 RIGU 2.00 BOPSUR PRE PRE PRE INT1 Start: 3/9/2001 Rig Release: Rig Number: Spud Date: 6/14/1985 End: 3/26/2001 Group: RIG Description ófOperatibns Move rig from OS 16-05a to Milne Point Unit C-12A. Spot rig over well. Continue Rig up of 3S. Rig accepted 3/11/01 @ 10:30 Hrs. N/U stack. Prepare tank dikes. Attend ATP meeting with MPU Operations group. Move in return tanks. CompleteBOP test Printed: 4/12/2001 9:33:47 AM Mi1ne Point C-12A CTD Suspension ) ) /19-09 ( Subject: Milne Point C·12A CTD Suspension Date: Tue, 17 Apr200118:51:25 -0500 From: "Kara, Danny Tn <KaraDT@BP.com> To: "Tom Maunder (E-mail)..<Tom_Maunder@admin.state.ak.us> CC: "Stanley, Mark J (AN C)" <StanleMJ@BP .com>, "Nitzberg, Katie E" <NitzbeKE@BP .com> Tom, My best estimate for returning to Milne Point C·12A would be sometime this fal!l September/October time frame. Options for sidetracking this well are still under consideration, some of which may defer re-entering C-12A beyond this faU. I'll have a better idea of timing once a plan is formulated. I will keep you informed. Dan Kara BP Coiled Tubing Drilling 564-5667 (office) 240...8Q4 7 (cell) 564-5193 (Fax) karadt@bp.com - 1 of 1 4/17/01 4:16 PM RE: MPC-12Ai Forward Plans ) Subject: RE: MPC·12Ai Forward Plans Date: Thu, 29 Mar 2001 10:22:23 -0600 From: "Stagg, Ted 0 (ORB IS)" <StaggTO@bp.com> To: lilT om Maunder'" <tom_maunder@admin,state.ak.us> Will do. Ted ..·..·,..0 rig inaf Message-.._·.. From: Tom Maunder [mailto:tom maunder@admin.state.ak.us) Sent: Thursday, March 29, 2001 6:10 AM To: Ted Stagg Subject: MPC...12Ai Forward Plans Ted, Would you check with the asset regarding the timing for returning to MPC...12Ai? We need a return date estimate in order to finalize the sundry approval. Also please keep us advised regarding what report will be generated regarding the incident. If I remember correctly, a series of meetings were held following Nordic 3's problems on the original sidetrack and we would like the same to occur for this event. We see a need to work to raaHy understand what the pressure source and transmission mechanisms are. Your experience ¡sonly the most recent of several through the years in thé C pad area. Please keep us informed. I look forward to your replies. Tom Maunder 1 of 1 3/29101 7:53 AM \ STATE OF ALASKA ) ALASK, . JIL AND GAS CONSERVATION COM."..ðSION APPLICATION FOR SUNDRY APPROVAL ~ t~t"\, ðV~~Cor 1. Type of Request: D Abandon D Suspend 0 Plugging D Time Extension 0 Perforate D Alter Casing D Repair Well D Pull Tubing 0 Variance 0 Other D Change Approved Program 181 Operation Shutdown D Re-Enter Suspended Well D Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 289' NSL, 2348' WEL, SEC. 03, T13N, R10E, UM At effective depth At total depth 455' NSL, 2349' WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary Total depth: measured (Planned) Effective depth: true vertical measured true vertical 9106 feet 7096 feet 8740 feet 6762 feet Casing Structural Conductor Surface Interme.diate Production Liner Length Size 80' 13-3/8" 6034' 9-5/8" 10922' 7" 2173' 4-1/2" Perforation depth: measured None true vertical None 5. Type of well: o Development o Exploratory o Stratigraphic 181 Service 6. Datum Elevation (DF or KB) KBE = 47.95' AMSL 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-12Ai 9. Permit Number 199-091 I 300-027 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit I Kuparuk River Sands Plugs (measured) Set CIBP at 8740' (03/01) Baker TTRD Whipstock set at 8780' (top) 01/00 Junk (measured) BHA Fish, Top at 8746' (03/01) Cemented MD TVD To Surface 108' 108' 1625 sx PF 'E', 250 sx Class 'G' 6070' 4703' 300 sx Class 'G' (Top of SIT Window) 7067' 5295' 113 sx Class 'G' 6751' - 8780' 5143' - 6797' RECEf\/E[) Tubing (size, grade, and measured depth) 4-1/2",12.6#, L-80 Kill String to 2684' MAR 2 7 2001 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing operation March 23,2001 16. If proposal was verbally approve~~. Tom Maunder Æt,):..~ ~þ.~ 3/23/2001 Name of approver Date Approved Contact Engineer Name/Number: Dan Kara, 564-5667 17. I ~erebY certify tha~oreg~true and correct to the best of my knowledge Signed DanKara ~-1 "-...:t,- Title. CT Dri iii n9 En9ineer ,COntmlsslonlj8e OIi.1y Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required 1 0- ~ Q '-\ '7f" f1ppr¿I\,Bf 0}lpÎ rtð tì'\cA-\.{ i., 2002- Approved by order of the Commission 1t-<(iJN^L SIGNE~Y ..... Form 10-403 Rev. 06/15/88 D Taylor Seamo~ R. \ G \ \\J A L Packers and SSSV (type and measured depth) None Alaska Oil & Gas Cons. Commission Anchorage o Detailed Operations Program o BOP Sketch 15. Status of well classifications as: o Oil 0 Gas 0 Suspended Service Water & Gas Injector Prepared By Name/Number. Terrie Hubb/e, 564-4628 Date ~ \1- î \ 0 l I Approval No. 3P l- 07 ¡ Commissioner Date LI/ftJ I Submit In Triplicate ) ) bp Date: March 23,2001 Subject: Milne Point C-12Ai Temporary Abandonment Procedure This procedure covers the plug and abandonment of the 4-1/8" Kalubik/Kuparuk D openhole and suspension of the MPC-12Ai drilling operation. Borehole failure in the Kalubik/Kuparuk D shale resulted in stuck pipe. The top of fish is at -8746' (uncorrected) which is above the 4-1/2" liner window at 8780'. Plans are to install a CffiP in the 4-1/2" liner just above the fish to isolate the high pressure (12.8 ppg EMW) openhole and rigging down to evaluate options for re-drilling this sidetrack. 1. Coil was cut at an uncorrected depth of 8746'. The 4-1/2" liner window is at 8780' leaving approximately 34' of pipe above the window. The openhole section penetrated the Kalubik and Kuparuk D shales only. The lost BRA consists of a bit, motor, 2 joints PH6 tubing, motor head assembly, coil connector and an estimated 5' of 2-3/8" CT. 2. Prior to pulling coil fish out of hole, circulate 1.5 times well bore volume to ensure consistent 12.8 ppg in and out. Monitor well for flow. 3. Splice coil to reel, pull coil out of well filling from backside. RU new spool of CT. RIH to clean out wellbore. 4. MU CIBP to coil. RIH, install CffiP at -8740', just above fish. 5. PT CffiP to 1000 psi with 12.8 ppg in wellbore. Displace well to inhibited seawater. Freeze protect upper 2000'. Monitor pressure on well for 30 minutes to ensure CIBP has isolated pressure from below. 6. Install BPV. ND BOPE leaving master valve on tree. RD CTD. Options for re-sidetracking this well will be evaluated. Please contact Dan Kara with questions or concerns. \1~' D ..-' \ ....... ""- RECEiVED Dan Kara BP Coiled Tubing Drilling 564-5667 (office) 240-8047 (cell) 564-5193 (Fax) karadt@bp.com MAR 2 7 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ) ) Wellhead: 11" 5M FMC wI4-1/2" FMC Tubing Hanger, N S CT lif¡1fl r9la1JB1,64""- 61YW C~M profile MPU C-12Ai Proposed Suspension Orig. KB Elev. = 52.0' Orig. G L Elev. = 35.0' RT To Tbg. Spool =33.95' 13--3/B", 48 #/ft, H·40 ~ ~ KOP @ 500' Max. hole angle = Hole angle thru' perfs = ~ 141/2" Tubing Kill String to 2684' I 9 5/8",36 #/ft, K-55 Btrc. I 6,067 ï J ~ 7"26 #/ft ,L-80,BTRC Casing. ( drift id = 6.1 51 " , cap. = 0.0383 b p f ) I Displaced well to Inhibited Seawater I ~ "S ~ ~ 7" x 4.5" Baker HMC hanger I 6,771' Win dow cut 7,060 '-7,110' 4.5" 12.6 #/ft, L-80, IBT mod casing (drift id = 3.958", cap.= .0152 bpf) ~ Installed CIBP @ -8740' MD Top of existing whipstock 8780' TD @ 9106' MD Baker landing collar Baker float Bakershoe RECEiVED 3/22/2001 per MAR 2 720n1 \'.1 I Alaska Oil & Gas C A h Ons. Commission nc Drage Re: Milne C...12Ai SU$pension of Operations ) Subject: Re: Milne C·12Ai Suspension of Operations Date: Fri, 23 Mar 2001 15:32:36 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Kara, Danny T" <KaraDT@BP.com> CC: AOGCC North Slope Office <aogcc....prudhoe_bay@admin.state.ak.os> ) Dan, C..12A is really tough on people. Your proposal is appropriate. Since you plan in the not too distant future to return and get this well to TD, just placing the BP is appropriate. When the sidetrack is ultimately drilled, the cement from the liner operation will provide additional isolation above the BP. Good luck. Tom Maunder, PE Petroleum Engineer AOGCC "Kara, Danny Tn wrote: > Tom, > As we discussed on the phone, the shales fell apart on the BHA in Milne > C-12Ai. We had to cut and pull coil to get out of the well. We would like > to isolate the openhole with a CIBP and rig down from this well for a while > so we can re...think 8 drl1ling plan. Enclosed is the verbage/proposed > schematic that will be shipped to you. > > Thanks > > «MPC-12A Temp Abandon.doc» > > Dan Kara > BP Coiled Tubing Drilling > 564..5667 (office) > 240..8047 (cell) > 564...5193 (Fax) > karadt@bp.com > > __.......___..........___-........____....._____...__.___IfIf'_..._...________........______...--....-..... > > > Name: MPC~12A Temp Abandon.doc MPC-12A Temp Abandon.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder(ã2admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 10f2 3/27/01 12:37 PM ) ~:~~E : FfÆ~!Æ~~~!Æ I ALASKA. OIL AND GAS / CONSERVATION COlWllSSION \;' J ~ TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara , CT Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit :MPC-12Ai BP Exploration (Alaska) Inc. Permit No: 199-091 Sur. Loc. 496'NSL, 2027'WEL, Sec. 10, TI3N, RI0E, UM Btmhole Loc. 455'NSL, 2349'WEL, Sec. 03,TI3N, RI0E, UM Dear Mr. Kara: Enclosed is the approved revised application for pennit to drill the above referenced well. The revision is for a change in bottom-hole location. The provisions of the original approved permit dated October 14, 1999, are in effect for this revIsIon. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this c::;-M day of March, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA 1 AND GAS CONSERVATION COMM '}ION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill II Redrill 1 b. Type of well ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 289' NSL, 2348' WEL, SEC. 03, T13N, R10E, UM At total depth 455' NSL, 2349' WEL, SEC. 03, T13N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 047433,2349' No Close Approach 16. To be completed for deviated wells Kick Off Depth 8790' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole CasinQ Weiaht Grade Couplina Lenath 4-1/8" 3-3/16" 6.2# L-80 TC II 509' 3" 2-3/8" 4.6# L-80 FL4S 508' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casi ng 8933 feet 6943 feet 8838 feet 6852 feet Length Size Structural Conductor Surface Intermediate Production Liner 80' 13-3/8" 6034' 9-5/8" 10922' 7" 2173' 4-1/2" Perforation depth: measured None true vertical None k'$' ~~ \ REVISED: February 5, 2001 o Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool KBE = 47.95' AMSL Milne Point Unit I Kuparuk 6. Property Designation River Sands ADL 047434 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-12Ai 9. Approximate spud date 03/15/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9548' MD /7452' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 26 0 Maximum surface 3160 psig, At total depth (TVD) 7452' I 3325 psig Setting Depth Top Bottom MD TVD MD TVD 8580' 6559' 9089' 7035' 9040' 6978' 9548' 7452' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantitv of Cement (include staae data) 29 sx Class 'G' Uncemented Slotted Liner Plugs (measured) Baker TTRD Whipstock set at 8780' (top) 01/00 Junk (measured) Drilling BHA fish left at 8836' 01/00 Cemented MD TVD To Surface 1625 sx PF 'E', 250 sx Class 'G' 108' 6070' 108' 4703' 300 sx Class 'G' (Top of SIT Window) 7067' 113 sx Class 'G' 6751' - 8924' RECEiVED 5295' 5143' - 6934' FES 0 6 2001 20. Attachments Alaska Oil & Gas Cons. Commission Anchoraç¡e II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubb/e, 564-4628 Contact Engineer Name/Number: Dan Kara, 564-5667 21. I hereby certify that t~e f~~u;;;;;;l correct to the best of my knowledge . Signed Dan Kara \ ~ -;~ Title CT Drilling Engineer , "~I11I.i~,.t:J84t~i.Qhly' ' ',.' , , API Number 50- 029-21373-01 Samples Required 0 Yes ;81 No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: OR\Gi!~f-,,- S~CJ¡\EO :2'.,' o T 8'ýlor SAarnour~( Permit Number 199-091 I 300-027 Conditions of Approval: Approved By Form 10-401 Rev. 12-01-85 :¿/os/o I Date ~proval Date &.-q- 01 Mud Log Required Directional Survey Required o 4K 0 5K 0 10K D 15K See cover letter for other requirements DYes ~No 18) Yes DNa ~5K psi for CTU Commissioner by order of the commission Date ~ -7 - 8 { Submit In Triplicate (".'( :", I ¡' . ' .,; , ' LI t \ 1 L> t ¡ \~: i ~\ L. ') ') bp MPC-12ai Sidetrack Su mmarv of Operations: Well MPC-12a is scheduled for a through tubing sidetrack with the Schl./Nabors 3S coil drilling rig. The sidetrack will kick off from a window milled in 4 %" liner in the Kalubik interval. The MPC-12ai target is the Kuparuk C formation. MPC-12ai will initially produce but will be converted to an injector in the future. MPC-12a was a rotary rig sidetrack that cemented 4 Y2" liner across the Kalubik and into the Kuparuk D. Trouble in milling out the 4 Y2" shoe track resulted in a fish lodged in the shoe track. A whipstock was then set just above the fish with the intent of sidetracking and drilling to the Kuparuk C target. However, the slim hole drilling required for this operation was determined to be a better candidate for coil drilling. A schematic diagram of the proposed sidetrack completion is attached for reference. The window and initial 300 ft of drilling will be done with 11.0 ppg drilling fluid in the overpressured Kalubik and Kuparuk D intervals. A 3 3/16" drilling liner will then be run and cemented to the top of the Kuparuk C. A Tiny Tool drilling assembly will then be used to drill the 3 3/16" shoe track and the target Kuparuk C interval with 9.2 ppg fluid. The Kuparuk C will then be completed with a 23/8" slotted liner. No prep work is required as the whipstock is currently in place for the sidetrack. Schl./Nabors 3S is expected to move onto MPC-12a on March 15,2001. Mud Program: '1\1<;;" ~\~\--..~<::''Ç'.~~\- · ~' hole through overpressured Kalubik and Kuparuk D: 11.0 ppg · 2 %" hole in Kuparuk C: 8.6 ppg Disposal: · All drilling and completion fluids and all other Class II wastes will go to KRU-1 R pad facilities. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 3 3/16" 6.2# L-80 TC II will be cemented from the base of the Kuparuk D (9089' MD, 7035'ss) to approx. 8580' MD (6559'ss). This will put the top of 3 3/16" approx. 200 ft above the window. · 23/8" 4.6# L-80 FL4S slotted liner will be run from TD (9548' MD; 7452ss) to approx. 9040'MD (6978ss) to overlap the 3 3/16" by 50 ft. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan. BHL (State Plane): 558,066; 6,034,016. Max. hole angle is 26 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A Memory Induction log will be run in the Kuparuk C interval.. R~"""" ~'''''~En -r~mD"'" l:: l., ! V t:; , FES 0 6 2001 Hazards · The highest H2S recorded to date on Milne C Pad is 20 ppm in May, 2000. Alaska Oil & Gas Cons. Commission Anchorage Reservoir Pressure · Reservoir pressure in the Kalubik and Kuparuk D intervals may be as high as 11.0 ppg at 7000'ss. In this case max. surface pressure with gas (0.12 psi/ft) to surface is 3160 psi. · Reservoir pressure in the Kuparuk C interval will be below 8.6 ppg and could be as low as 6.9 ppg. Lost circulation in the Kuparuk C is a possibility. * ) Tree: 4-1/16" - 5M GIW/WKM Wellhead: 11" 5M FMC MPU C-1~i Proposed Completion wI 4-1/2" FMG Tubing Hanger, NSCT lift threads, 4" GIW H BPV profile 13--3/8" ,48 #/ft , H-40 [ïQ§J ~ KOP @ 500' Max. hole angle = Hole angle thru' perfs = 95/8",36 #/ft, K-55 Btrc. '6,067' ,j 7" 26 #/ft , L-80, BTRG Casing. ( drift id = 6.151", cap. = 0.0383 bpf ) Window cut 7,060'-7,110' 4.5" 12.6 #/ft , L-80, IBT mod casing ( drift id = 3.958" , cap.= .0152 bpf ) Top of existing whipstock 8780' ---.. Baker landing collar 8,838' Baker float 8,879' Baker shoe 8,924' . ) Orig. KB Elev. = 52.0' Orig. GL Elev. = 35.0' RT To Tbg. Spool =33.95' .. 4 1/2" Tubing Kill String to 2684' i I I 7"x 4.5" Baker HMC hanger I 6,771' I 3.75" open hole through Kalubik & Kuparuk D completed with cemented 3 3/16" liner 3" open hole completed with 2 3/8" slotted liner RECE~ t~,·, ): bw. :il...,,· FES 0 6 ?iJ01 Alaska Oil & Gas CC"~I" C'o~'r'" I, ,. ¡ ",¡liSS;O;1 Anchomge rei M5 MPC-12A Vertical Section o Path Distance (Feet) 500 1.000 I 1,500 6500 MPC-12bi case 1 01 6600- Ted x4694 6700 - kick off from whipstock at 8780' MD ~ Angle @ K.O.= 17 deg MD:8790 6800 - ~ Marker Depths OOrig Wellbore 7,0151 7,0151ftND 7,4451 7,445/ft ND 01 Olft ND 01 Oft ND Kick Off 6,758 ft ND 8,790 ft MD Deprtr@KO 5,007 ft 6900 - f:: MD KO pt m MD New Hole ~ 7000 - Q --7,015 ~ Total MD TVDTD 7100 - .-- Hole angle = 26 degrees 7200 - 7300 - Tot Drld:758 ft 9548 TD 7400 - - -7,445 '!' 7500 - Curve 1 Curve 2 Curve 3 Curve 4 -' 8,790 758 9,548 7,452 DLS deg/100 Tool Face Length 6 ° 20 10 45 59 10 90 220 10 -90 459 ~' » W en ;0 ;;<:" 0) 2 =r¡ IT-> p. ' [ yo rr\ ¡¡ l 758 » 0 c:ü () ;::¡ !l) 0 (") ef) m =r () ç::) 0 @ 0 m ~:::: =' CD ~ < ro () r---J 0 c:> ITl 3 ~ 3 c: (!, þ (J) g' Drawn: 2/1 /2001 16:40 Plan Name: Case 122 o o .... ~ E ,g CD o II: .5! ~ :c > I - 1 ,000 MPC-12A MPC-12bi Case 10 1 Ted x4694 r55~~69ro~~:~:7::~) I v I -500 ° X distance from Sfc Loc 0 I 500 6,000 - 5,500 - 5,000 - 4,500 1,000 IWell Name CLOSURE I ~tance NEW HOLE Kick Off TD State Plane Surface Loc Curve 1 Curve 2 Curve 3 Curve 4 MPC-12A 5,249 ft 356 deg E/W (X) -414 -373 558,066 558,439 DLS deg/1oo 6 10 10 10 Drawn: 2/1/2001 16:40 Plan Name: Case 122 N/S (y) 4,975 5,236 6,034,016 6,028,780 Tool Face o 45 90 -90 Length 20 59 220 459 758 » ro en =- s:\.) 2 !<o »0 :::! Q) g.cn 00 W Q 'ß ~ o o :;-¡ 3 w" r..n ~r "-- ..~ ''ì fïl co ;0 m F~ ~ ;:j m C;::¡ 0';) r--.v c::::> C) ~_-.z.-~ "', f11 c:~ ~abors 3S BOP Stack /UI I Methanol Injection ~ .MA Otis 1'1 WLA Quick Connect -,...- I I r ') o~ ~ '-CT Injector Head I 1 -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure -... 7" Riser I' I I "' Annular BOP (Hydril),7-1/16" ID ............. 5000 psi WP '--- ~ Alignment Guide Flange ~ I I I~ 0.~9' (3.5") 7-1/16", 5M Ram Type Dual L.r--' CJ=I 3-112" Slip Rams Gate BOPE - ~ , Flanged Fire Resistant ~ =J=t 2-3/811 Pipe Rams Kelly Hose to Dual HCR ManLaïVaTve Choke Manifold _@_ I I I Manual Valves Drilling spool 7-1/16", 5M " ~ 0 Jill 1JØIJfBffi ~bY 7-1/16", 5M I l ::::I --fill'" 7-1/16", 5M Ram Type Dual ~ 2" Pump-In F Gate BOPE c ~ Blind/Shears -I ~ r::::l i r- 2-3/8" Pipe/Slip Rams ~ 'I I I I 1/ Tubing Hanger L -.J ~ @ = ~ Upper Annulus -, I ~ @ = ~ Lower Annulus c: Manual Master Valve 0.458' (5.5") I I \ Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold R·~_··o.'·'F·"'· t: (,.; ~ ' ~\"i F:,""..: Qþ 101 I!i~,.:..~"" FES 0 6 2001 Alaska 0,'/ & Gas r',..,~ '~'. '. '-'\),;;;, vOiìlÍlÎ/SSIOr¡ A.nchOré4g8 Milne Point C-12Ai ) Subject: Milne Point C..12Ai Date: Thu, 1 Mar 2001 13:06:39 ...0600 From: "Ksra, Danny Tn <KaraDT@BP.com> To: "Tom Maunder (E-mail)..<Tom_Maunder@admin.state.ak.us> Tom, Per our phone conversation on available rams for well control, we will plan on running -10 joints of 3..1/2" liner to the window, crossed over to 3-3116" outside the window. This will put the top of liner ,...100' above what is listed on the Permit to Drill. Liner depths will now be: 3..1/2" 9.2# L-80 FL4S 8480'...8780' md (liner lap) XO 3-1/2" x 3-3/16" just above window 3..3/16" 6.42# L...80 TCII 8780-9089' md (4-11811 open hole) The BOP stack will be as indicated in the application for Permit to Drill. Please call with questions. Dan Kara BP Coiled Tubing Drilling 564-5667 ( office) 240...8047 (cell) 564...5193 (Fax) karadt@bp.com 1 of 1 3/1/01 11 :01 AM ) H 180969 DATE i2/28iOO CHECK NO. 00180969 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 122100 CK1221001 PYMT COMMENTS: HANDLING INST: 100.00 100.00 Pernit To Drill ~ee 8tH - Terrie HubJle X4628 mf~- IAA- (~ ìsed~ IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 .::;êP·,§~FLq~A11<?~ (ALASKAh)N~:¡ ':,.:.·::,:~q~gA~å~~'~LAS~:::: 99519-6612 \j·:l!;!'::-;:;::- :j;.'jRSTNATIONA:L::SANK:ÓF AS~II;¡;ÀND .: ::": ,', '.;.:' ,Aij:Å~'IAT'Ej~~ ,<::::< ,:-''::.:.'' NÀ"ttöN~'¢ITY:l?ÀNK' ,', CtEVELÄND. OHio NQ:. :,:H : ,:::.::~,8,:.Q9:ß:·::~ CONsoÓbÂfÉo 2dMMêRCI.àÙACCÒ(JNt:": . " '·'·:::\:\:'~~~389.::::,·:::' , 412 ' , " \:''':60 ~'~:å'~6~':'::: ... , PAY O~F·:-::~uNQ~Eß;:::· &'~ ;.db.ll oo***·~*.~**:~¡~*~~~~~********~*4t¡~~~~*~;~* . US:: DOLLAR ...;..:.;.;...- DATE '" 12/28/00 .' ',,: ..,.... t:': ,···:::AMOUNT $100.00 " , '! Þ Th~:· :(]f3D~~ '·'Of',:"':"" "~~~~!~~~ ~ ~~~\~~~!~I ~~l~~';' 100 NqTv~pD AFTER 120 D~YS ..' ....... " , /:.: \7",.>:::.....:,:: :·c':,..~i'..,:.::': :::,:/: .::..::.:;> <·:·:'·':·ß· :.... ::,:.~:':::...: :: ,:.::\J:.'. ':: ',C' .:'.' , , "111\.:""" .,:,:'.; "'.c" :::, ",. ,.' :c .' :';"C,'" .... '. ~ t..... ~ __~'.: :". . ,,::,?:' , .,-,. . ANCHORAGE AK 99501 III ~ 8 0 g b g III I: 0... ~ 2 0 j 8 g 51: 0 0 8 ...... ~ g III \ #/y¿, . WELL PERMIT CHECKLIST COMPANY ~¡tJ X WELL NAM~.f'r:. - /Z.4;'PROGRAM: exp _ dev _ redrll ~ serv ~ well bore seg _ann. disposal para req _ ~~~~N~S::~ION·<Ç.2..t ~:~nfeeattached~N.I~C~~~ . ~ ~~!. . . . . . . . . . G~LNAREA f9rJ UNIT# /132'1 ON/OFF SHORE ",,) 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 7'/ // / / ) /1 r 5. Well located proper distance from drilling unit boundary. Y N 7;,:\ ~~____AY I?¡tJt"'......J~J;:.(/... Ù "-"'A'~~/?,,:·Ó'~~-;):,v. 6. Well located proper distance from other wells.. . . . . . . . . Y N n / ¿ ¿ / ,/ 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N. ~""("I~-:'/,;''''__I_<'" ~ J'-?~¡'4.5 .... /'.<1' /-<,/~_<' I ~¿,7 ~-'\íi--¥?~ 8. If deviated. is wellbore plat included.. . . . . . . . . . . . . . Y N -:;'/' / / .ð "1( -I Þ , /« Î 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 4~. c;/"" J-í../ /hs" fl'1~u .;" 'p H .zk-~ c" .r:>Q 5'í Þ"4¿¡ ,þ>"'\ 07 10. Operator has appropriate bond in force. . . . . . . . . . Y N ~ / // ð ð <-0 / / 11. Permit can be issued without conservation order. . . . . . . . ~y N (01"" /~~ e.-/l ø A- f 4""-/ r::::e..//#; Ít. -- T'i'..-r A,N'í "Pz W A~ _D~~ / 12. Permit can be issued without administrative approval.. . . . . Y N . Þ ¿ Y ~ ð"~ -4 ý/ ~ ~ / ./J '1;1''é> ¥¿,~",,) 13. Can permn be approved before 15-day wait. . . . . Y N 5", /4<.T /' c-.-? C. c::r- .r_ / /' ~?ð 7¿,.c ;::9"th9"7 ENGINEERING 14. Gonductorstringprovided . . . . . . . . . . . . . .. ... ~1Y ~~/~~d ,k~~, *' A 15. Surface casing protects all known USDWs. . . . . . . . .€.~ Y / J../ / ß / / // J) / '( 16. GMT vol adequate to circulate on conductor & surfcsg. . .~. Y A-ð"'t"~ /4'f'ì"- 5"¿r-l/.c-- /,<:1 /...../I./l/Vg<t!' .é'G;;;;~/~_ /I?r 'PJ 17. GMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ / / / -4 / / / .? J - / II 18. GMT will cover all known productive horizons. . . . . . . 'St\Q~\;~c Y (N)/~< AH c.P -,.... -y....._ ~ &.-:7 c5 bO /t¡r- ('"")j?e;/(·..;r;,r (~ 19. Casing designs adequate for G, T. B & permafrost. . . . .. .. 0 N /" / /' ( /' f) ß / , -I / I / 20. Adequate tankage or reserve pit.. . . . . . . . . ~...~~\'\~~~toO&Cò N~ r-Ø-r.:?/f-Jr- JY 70<:::.- r?' ~ 4í /'Gr'Á ú./7"/ò/"-c/ .hI} 21. If a re-drill, has a 10-403 for abandonment been approved. . . \.)~ -¥--4oJ / /1. c- .L:?/) _ J./!, / 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 0 N ¡.I '¡z a, _ S¿./i1 .k¥"'/~/j I ~~ 277£/ /:J ) 23. If diverter required, does it meet regulations. . . . . . . . . . ~~~ _ t...r. ~ 24. Drilling fluid program sChema. tic & equip list adequate. i N \o\,~ ~~~-...)~ç; ~~,,~,,~ \. ~::c~~t.ù 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . N ~ 1n~-fATE 26. BOPE press rating appropriate; test to "!t;Cr'\ psig. N '""~~~ ~~~~~,,-~"ù q, ~ \'cl\ 'V~,. ¡¿J"'~ 1-.-0\ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdöwn. . . . . . . . . . . J:l ,,~ . \...\_ ~ . t _ _ ~..l. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ® ~ ~~~\.~~c:...~\.-a. o.~ '~.> ~ !.~~Cë-. \ ~'\~ '~C2: \. u\ \>9~.c)",wl ~'< ~~~ G\\<:a..~ > 30. Permit can be issued w/o hydrogen sulfide measures. . . .. Y N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . APPR _ DJ:7 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~¿ :y'.?"Ÿ'&) 34. Contact namelphone for weekly progress reports [exploratory 0 ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will.contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEO~AGY: ENGINEERING: UIC/~nnular COMMISSION: ~~8V' ~ ~~W WM ' 8~s Ld( TË~9?JVl -S¡",-Ö \ JMH dM+1 3-/q}(5) GEOLOGY APPR DATE c o z o ~ :e ::0 ~ m till,!' \. z ~ J: en :Þ ::0 m :Þ \ Y N Y N o ~~~\u, ~'\",>~<:::.c:.... \ ~ Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ¡qc, .o9l .~ ~¡.mmii ..~,.,~~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A TIN: Sherrie Well Log Description Job# M PC-12A -1:I- 0 L.( L1 4 MPC-12A 20060 USIT PDC GR 20061 US IT COLOR PRINTS Date 000125 000125 2/15/00 NO. 121194 Company Alaska Oil & Gas Cons Comm Aftn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Color Prints Sepia CD '--' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED fEB 25 2000 Date Delivered: Alaska Oil & Gas Cons. Commission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd Anchorage. AK 99503 ATTN: Sherrie 1. Operations performed: fZ] Operation Shutdown D Stimulate D Plugging D Perforate D Pull Tubing D Alter Casing D Repair Well D Other 5. Type.of. well: U Development D Exploratory D Stratigraphic fZ] Service 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 289' NSL, 2348' WEL, SEC. 03, T13N, R10E, UM At effective depth 208' NSL, 2405' WEL, SEC. 03, T13N, R10E, UM At total depth 235' NSL, 2410' WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION CLIIV1MISSION REPORT OF SUNDRY WELL OPERATIONS 99519-6612 6. Datum Elevation (DF or KB) KBE = 47.95' AMSL 7. Unit or Property Name Milne Point Unit (Planned, Target Not Reached) 8. Well Number MPC-12Ai 9. Permit Number I Approval No. 199-091 300-027 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit I Kuparuk River Sands (Current PBTD) (Current TD, Planned TD Not Reached) 8933 feet 6943 feet 8838 feet 6852 feet Baker TTRD Whipstock set at 8780' (top) 01/00 Plugs (measured) Junk (measured) Drilling BHA fish left at 8836' 01/00 Length Size Cemented MD TVD 80' 13-3/8" To Surface 108' 108' 6034' 9-5/8" 1625 sx PF IE', 250 sx Class 'G' 6070' 4703' 10922' 7" 300 sx Class 'G' (Top of SIT Window) 7067' 5295' 2173' 4-1/2" 113 sx Class 'G' 6751' - 8924' 5143' - 6934' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Kill String to 2684' t{ECEI'¡ED Packers and SSSV (type and measured depth) None FCp 1 r~ 2='\no 1.... ._J v '" \l 13. Stimulation or cement squeeze summary Intervals treated (measured) Alaska Oi, & Gas Gems. Commiss.iQ.l1 Anchorage Treatment description including volumes used and final pressure Subsequent to operation: 15. Attachments fZ] Copies of Logs and Surveys run fZ] Daily Report of Well Operations 17. I hereby certify that4)he fa egoing is true an Signed /} A ' Terrie Hubble '<lINt 14. Prior to well operation: Form 10-404 Rev. 06/15/88 ORIGINAL Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 16. Status of well classifications as: D Oil D Gas D Suspended Service correct to the best of my knowledge Title Technical Assistant III Prepared By Name/Number: Date O~... fS'CiJ ~.~ Terrie Hubble, 564-4628 . Submit In Duplica Facility M Pt C Pad DatelTime 14 Sep 99 12:00-18:00 12:00-18:00 Duration 6 hr 6 hr 18:00 18:00-01:00 18:00-01:00 7 hr 7 hr 15 Sep 99 01 :00 01 :00-03:30 01 :00-03:30 2-1/2 hr 2-1/2 hr 03:30 03:30-05:00 1-1/2 hr 03:30-05:00 1-1/2 hr 05:00 05:00-06:00 1 hr 05:00-06:00 1 hr 06:00 06:00-08:30 2-1/2 hr 06:00-08:30 2-1/2 hr 08:30 08:30-12:00 3-1/2 hr 08:30-12:00 3-1/2 hr 12:00 12:00-14:30 2-1/2 hr 12:00-14:30 2-1/2 hr 14:30 14:30-15:30 1 hr 14:30-15:30 1 hr 15:30 15:30-05:00 13-1/2 hr 15:30-18:00 2-1/2 hr 18:00 18:00-20:30 2-112 hr 20:30 20:30-22:00 1-1/2 hr 22:00 22:00-05:00 7 hr 16 Sep 99 05:00 05:00-06:00 1 hr ) ) Progress Report Well MPC-12A Rig Nabors 4ES Page Date 1 01 December 99 Activity Derrick management Rigged down Drillfloor I Derrick Prep rig for move . Equipment work completed Move rig Rig moved 100.00 % move & spot rig on C-12 & Berm & trim rig. raise derrick & slip sand line & scope derrick. At well location - Slot Wellhead work Removed Hanger plug Rig lubricator & remove bpv. & read Pressure. tbg. psi. = 1200 psi. annulus = 500 psi. rig lines in cellar & take on water & spot tiger tank & load pipe shed with drill pipe. Equipment work completed Flow well Monitor wellbore pressures let well V-tube to tiger tank until psi. to 0 & set twc. bleed back a total of 8-bbl. Observed well static Wellhead work Removed Tubing head spool Nipple down tree. Stopped: To hold safety meeting crew change. Wellhead work (conL.) Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi test waived by aogc Larry Wade. Wellhead work Retrieved Hanger plug Equipment work completed Pull Single completion, 3-1/2in O.D. Removed Tubing hanger rig floor & bolds & work tbg. to get hanger to floor & lay dn hanger work tbg. to 135 k pu wt = 87 k Equipment work completed Laid down 2100.0 ft of Tubing 67 joints laid out Circulated at 7310.0 ft displace well bore fluids with fresh water. Hole displaced with Water - 125.00 % displaced Laid down 10173.0 ft of Tubing recovered all tbg. & seal assy. (tbg. cut was 50 % effecti ve Completed operations 3-1I2in. Drillpipe workstring run 1< f: ( F 1\ ,k ,r.:" f): ·~"·...u lrw ..... l!,. I" 1 f)' f):I'¡;1,O \.~ (V'...] lJaska Oil & e:;,"" ('''''''''~ C . \ .JJ,_\...."Þ Vi..n:Iv rr1'":·rï:~,{!¡t:t.!1"4..'l'~ AncJ,n r;'~M~,~ .: ~~ ",.,;;r.!j¿~J ''''' ~·'tiG Facility M Pt C Pad DatelTime 05:00-06:00 Duration 1 hr 06:00 06:00-23:00 06:00-07:30 07:30 07:30-08:00 08:00 08:00-12:30 17 hr 1-1/2 hr 1/2 hr 4-1/2 hr 12:30 12:30-13:30 1 hr 13:30 13:30-16:00 16:00 16:00-17:00 2-1/2 hr 1 hr 17:00 17:00-20:00 3 hr 20:00 20:00-23:00 3 hr 23:00 23 :00-06:00 7 hr 23:00-02:00 3 hr 17 Sep 99 02:00 02:00-06:00 4 hr 06:00 06:00-06:00 24 hr 06:00-06:45 3/4 hr 06:45 06:45-14:00 7-1/4 hr 14:00 14:00-15:00 1 hr 15:00 15:00-00:30 9-1/2 hr 18 Sep 99 00:30 00:30-03:30 3 hr ) ") ,I' Progress Report Well MPC-12A Rig Nabors 4ES Page Date 2 01 December 99 Activity Rigged up Drillstring handling equipment clean floor & rig up same to run HOWCO EZ drill Stopped: To hold safety meeting crew change 3-1/2in. Drillpipe workstring run (cont...) Rigged up Drillstring handling equipment Equipment work completed Installed Bore protector Equipment work completed Ran Drillpipe to 5000.0 ft (3-1/2in OD) mu Hes EZ drill cmt. retainer plug. & rih on singles Stopped: To hold safety meeting Held safety meeting safety stand down with nabors & bpa personell. Completed operations Ran Drillpipe to 7310.0 ft (3-1/2in OD) Stopped: At sub-assembly Set packer at 7310.0 ft with 4200.0 psi Set hes ez drill & set dn 25 k & psi. test to 4200 psi. ok. Packer set at 7310.0 ft Circulated at 7310.0 ft displace well bore fluids with section milling fluid. & spot 10-bbl. of 18.0 ppg. Hole displaced with Water based mud - 120.00 % displaced Pulled Drillpipe in stands to 0.0 ft Completed operations BHA run no. 1 R.I.H. to 7060.0 ft Make up Baker NO.5-section mill with ..572 TFA +bit sub+jars+8-4.75" dc's At Top of new hole section: 7060.0 ft Made up BHA no. 1 locate collar @ 7073' & begin section milling @ 7060' Initial cut out =1-Hr. Monitor well (stable) first cuttings to surface in 45-min 4720 strks. mill csg. 7060-7064' 15-# of iron recovered. Stopped: To hold safety meeting crew change. BHA run no. 1 (cont...) Serviced Mud pumps Equipment work completed Milled Casing at 7084.0 ft mill 7" csg. F/7064' to 7084' Observed 25.00 klb drag on connections Worked toolstring at 7084.0 ft circ. 7& work tool string Completed operations Milled Casing at 7110.0 ft mill ssection F/7084' to 7110' Completed operations Circulated at 7110.0 ft cÌre. & run sweeps of low vis & hi-vis fluid to l)r~ ~ ~ l'",t''' ^ .", t i.,'4. l r .þ r:-.-~ II /I ~ r-) A/ . cD ì' l... ¿þ .a$ý~ ¡ ~ .... Dr/ -" \..) ? 1., '..." r; ....v' '0 ~':"~C... "-'¡ 4.7,,..,( ,ll}", v, 7(;.,..." ..... Ct'.,. I q.fa V¡/¡ì;?:S:~"j01} Facility M Pt C Pad DatelTime 03:30 03:30-06:00 06:00 06:00-09:00 06:00-08:00 08:00 08:00-09:00 09:00 09:00-06:00 09:00-12:45 12:45 12:45-16:30 16:30 16:30-18:00 Duration 2-1/2 hr 3 hr 2 hr 1 hr 21 hr 3-3/4 hr 3-3/4 hr 1-1/2 hr 18:00 18:00-19:00 1 hr 19:00 19:00-19:45 3/4 hr 19:45 19:45-21:00 1-1/4 hr 21:00 21 :00-02:00 5 hr 19 Sep 99 02:00 02:00-06:00 4 hr 06:00 06:00-14:00 06:00-06:30 06:30 06:30-12:30 12:30 12:30-13:00 13:00 8 hr 1/2 hr 6 hr 1/2 hr ) ) Progress Report Well MPC-12A Rig Nabors 4ES Page Date 3 01 December 99 Activity clean section for sidetrack plug. Rec. total of Hole swept with slug - 300.00 % hole volume Pulled out of hole to 1329.0 ft on trip out of hole have only had one spot that had 15k over Stopped: To hold safety meeting crew change. BHA run no. 1 (cont...) Pulled out of hole to 321.0 ft & lay dn section mill & drill collars & jars. At BHA Pulled BHA BHA Laid out 3-1/2in. Cement stinger workstring run Ran Drillpipe in stands to 7110.0 ft rih & break circ. to confirm drillpipe not plugged. Observed 25.00 klb resistance Washed to 7118.0 ft eirc. & wash with kelly in to csg. stub. & would get down as much as 30 ' plus and was unable to keep . set mule shoe @ 7118' & prepare to set plug. Observed 35.00 klb resistance Batch mixed slurry - 22.000 bbl set plug. 5 bbl. h20+test +20 bbl. h20 +22 bbl. cl. g. 17.0 ppg.+6-bbl. h20 & put in place with 32 bbI. mud & sht dn pump & use C pump to pump 3.75 bbl. mud to balance plug. cemtn in place 1738 hrs. 9/18/99 Completed operations Pulled Drillpipe in stands to 5700.0 ft Completed operations Circulated at 5700.0 ft circ. 2-bottoms up @ 6.5 bpm 1100 psi. Hole displaced with Water based mud - 200.00 % displaced Injectivity test - 3.000 bbl injected at 800.0 psi Perf. hesitation sqz. in 200 psi. increments to 800 psi. & hold I-hr. & bleed back 2 bbl.s Unable to inject fluid Circulated at 5700.0 ft Circ. & wait on cmt. to build compression strenght for top tag. & test. Obtained req. fluid properties - 100.00 %, hole vol. Singled in drill pipe to 6949.0 ft run to 6450 ' in stands & start single in with slow pump looking for cmt. top observed increase in pump @ 6750' & pumped bottoms up & observed no cmt. single in to 6949 & found hard cmt. & set compression to 15 k & increase of 400 psi. indicate gøq.,¡ Observed 15.00 klb resistance ç ~ ¿:C' /"""'"}.., 3-1/2in. Cement stinger workstring run (cont...) t ./'1> i'I!' . .... ....... .:.' (!.Þ Ctrculated at 6949.0 ft .1/.." ·':~.~·ì .;- ¡¡;-" /./::, ) Hole displaced with Water based mud - 125:00;~..-ø.isplacêd },'~, "l' Laid down 6949.0 ft of 3-1/2in OD drill pipe . //~~ ,', . v' [.., 234 joints laid out .(/ ::·~s i~" V(~? ',': ,., l (..',0", ,..... Removed Bore protector'·c-.'.Î¡'::.¡;~>:;; (~;. Equipment work completed ',:;..::) "'::¡ij;;.:.(:,,¡~ "..;:~q,~~. Facility M Pt C Pad Date/Time Duration 13:00-14:00 1 hr 14:00 14:00-19:00 5 hr 14:00-17:00 3 hr 17:00 17:00-18:00 1 hr 18:00 18:00-19:00 1 hr 19:00 19:00-20:30 1-1/2 hr 19:00-20:30 1-1/2 hr 20:30 20:30-21:00 1/2 hr 20:30-21:00 1/2 hr 21:00 21 :00-22:30 1-1/2 hr 21 :00-22:30 1-1/2 hr 22:30 22:30-06:00 7-1/2 hr 22:30-23:30 1 hr 23:30 23:30-00:00 1/2 hr 20 Sep 99 00:00 ) ) Progress Report Well MPC-12A Rig Nabors 4ES Page Date 4 01 December 99 Activity Serviced BOP stack Wash iron out of bop stack Equipment work completed 3-1/2in. Surge string workstring run Ran Tubing to 2015.0 ft (3-l/2in OD) ran 65-jts. tbg. for kill string. At Setting depth: 2015.0 ft Installed Tubing hanger Tie-down bolts energised Serviced Multipurpose tool repair rilds Equipment work completed Nipple down BOP stack Removed BOP stack set twc & rig dn bop's Equipment work completed Wellhead work Serviced Hanger plug Change out 4- RILDS & test. Equipment work completed Wellhead work Installed Xmas tree Install tree & test same to 5000 psi. & pull twc & set bpv. Equipment work completed Fluid system Freeze protect well- 75.000 bbl of Diesel Completed operations Cleared Circulating head FLlush out & blow dn lines & secure tree & cellar. Equipment work completed Rig Released @ 0000 hrs. 1/19199 ¡I) t>~ ¡ l (~!..~l ! ' · ,/ ""f¡ iÌ" fe... ,{~' ~¿j' 4.{?N "". v . ~. ,-,," ,~7 ~~ .\::~ (ì,'I" _c - . L} ~,,,,\ l. ._ " ( L{?:) ~lj~:t~~i: CQ;;;'êS~!,_ '~dl ) Facility M Pt C Pad DatelTime Duration 31 Oct 99 02:01-06:00 3-3/4 hr 02:01-06:00 3-3/4 hr 06:00 06:00-08:30 2-1/2 hr 06:00-08:30 2-1/2 hr 08:30 08:30-09:00 1/2 hr 08:30-09:00 1/2 hr 09:00 09:00-14:00 5 hr 09:00-13:00 4 hr 13:00 13:00-14:00 1 hr 14:00 14:00-16:00 2 hr 14:00-15 :00 1 hr 15:00 15:00-16:00 1 hr 16:00 16:00-17:30 1-1/2 hr 16:00-17:30 1-1/2 hr 17:30 17:30-18:00 1/2 hr 17:30-18:00 1/2 hr 18:00 18:00-21 :00 3 hr 18:00-21 :00 3 hr 21:00 21 :00-21 :30 1/2 hr 21 :00-21 :30 1/2 hr 21:30 21 :30-22:00 1/2 hr 21 :30-22:00 1/2 hr 22:00 22:00-23:00 1 hr 22:00-23:00 1 hr 23:00 23:00-01 :30 2-1/2 hr 23:00-01:30 2-1/2 hr ) Progress Report Well MPC-12A Rig Nordic3 Page Date 1 30 November 99 Activity Move rig Rig moved 100.00 % Move rig fl MP L-16A to MP C-12A. Rig accepted @ 0600 10/31/99. At well location - Cellar Move rig (conL.) Rig moved 100.00 % PJSM waite on pad operater wi Unit pennit. Move rig over C-12Ai. Beann liner arouuund rig. At well location - Cellar Wellhead work Removed Hanger plug Equipment work completed Fluid system Fill pits with Fresh water Completed operations Circulated at 2020.0 ft Displace diesel with water. Hole displaced with Fresh water - 100.00 % displaced Wellhead work Installed Hanger plug Install BPV and test to 1000 psi from bottom Equipment work completed Rigged down Xmas tree ND tree Equipment work completed Nipple up BOP stack Rigged up BOP stack NU BOP 11" 5000 psi BOP Equipment work completed Wellhead work Retrieved Hanger plug Pull BPV and install TWC Equipment work completed Nipple up BOP stack Tested All functions Test BOP 250/3500 Ann 25/2500 Test TPR 250/5000 Witness waived by AOGCC Chuck Schieve Function test completed satisfactorily Planned maintenance Serviced Top drive Service top drive and replace saver sub Equipment work completed Wellhead work Removed Hanger plug Pull TWC. PU landing jt. PU tbg hanger to rig floor. Up wt. 35k Equipment work completed Fluid system Circulated at 2020.0 ft Circ. 70 deg fresh water to warm up wellbore Hole displaced with Fresh water - 150.00 % displaced Pull Tubing, 3-1/2in O.D. Laid down 2020.0 ft of Tubing LD 65 jts '"1';:r. r._ s~ (¡') ::""" µ Q 12° þQ -~ cu ë, tn ~- f.-l J'~ ;:;:~ (Î) (") ~1 ::õ ~¡:'¡,. CD "\6' :;J ---.\ :;;;;~, TI"'':t1 \~-'"\ UJ ~!~"'laq) ~~ C1 ¡''''T''1 r..:_-~;,.a~' ..' .1~"·I..:.II ......."".." I.....:> c> <.~'.. ~I' ~ r""~" ,'""""'ì'I ~.::; Facility M Pt C Pad DatelTime Duration 01 Nov 99 01:30 01 :30-02:30 1 hr 01 :30-02:30 1 hr 02:30 02:30-06:00 3-1/2 hr 02:30-06:00 3-1/2 hr 06:00 06:00-05:30 23-1/2 hr 06:00-06:30 1/2 hr 06:30 06:30-09:00 2-1/2 hr 09:00 09:00-10:00 1 hr 10:00 10:00-13:00 3 hr 13:00 13 :00-14:00 1 hr 14:00 14:00-14:30 1/2 hr 14:30 14:30-15:30 1 hr 15:30 15:30-16:00 1/2 hr 16:00 16:00-20:00 4 hr 20:00 20:00-23:00 3 hr 23:00 23:00-03:00 4 hr 02 Nov 99 03:00 03:00-05:30 2-1/2 hr 05:30 05:30-06:00 1/2 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 2 30 November 99 Activity Completed operations Wellhead work Installed Wear bushing Loading 3 1/2" DP in shed, change out tbg tongs. RU DP spinner Equipment work completed BHA run no. 1 Made up BHA no. 1 PU BHA and load/strap DP in pipe shed BHA no. 1 made up BHA run no. 1 (cont...) Serviced Top drive Service rig, block, crown & top drive Equipment work completed Singled in drill pipe to 4005.0 ft P/U DP RIH to 4005' Stopped: To circulate Circulated at 4005.0 ft Circulate out Milling fluid with SWat 4 bpm. Obtained req. fluid properties - 100.00 %, hole vol. Singled in drill pipe to 6863.0 ft Continue P/U 3.5" DP Stopped: To circulate Circulated at 6863.0 ft Circulate out Milling fluid wI SW Obtained req. fluid properties - 100.00 %, hole vol. Drilled cement to 6950.0 ft CIO cement stringers fl 6863 to 6950' Completed operations Tested Casing - Via annulus and string Test bottom pipe rams to 250/3500 psi. Bled off change to top pipe rams & test 7" csg to 4500 psi fl 30 min O.K. Pressure test completed successfully - 4500.000 psi Held drill (Kick (well kill» D5 drill 39 sec AMAS 1 min 2 sec Completed operations Drilled cement to 7076.0 ft Continue to CIO Firm cmt fl 6863' to 7076' 9' below top of 7" section. Completed operations Circulated at 7076.0 ft Pump Hi-vis sweep 30 bbl. Change oover fl Sw to ~ Drlg fluid @ 5 bpm. Up wt 105K, Dn wt 70K, RT *1" U) 95K ~.~ s;... Hole displaced with Water based mud - 120.00 % displ~d Pulled out of hole to 805.0 ft ;;; POOH stand back 65 stands of 3.5" DP. G" 2: n Ú.'j At BHA 2f C) Singled in drill pipe to 3041.0 ft j~ ~~ PIU 93 jts of 3.5" Dp RIH (", C~ 93 joints picked up ~:~ Repair "'-\: ~~:~ 1:;:;" ~,:~ ~;~ ; I:'" .*-..ø r-I'-: [::"1 ,,- ~ ·"~""'h __.1 s=r~·ti C¡ r',.~¡ ~:~::~: c> , , ft"¡"1 Ç) i I~::·.:;;ß Facility M Pt C Pad DatelTime 05:30-06:00 06:00 06:00-11 :00 06:00-07:00 07:00 07:00-11 :00 11:00 11 :00-06:00 11:00-14:30 14:30 14:30-15:30 15:30 15:30-20:30 20:30 20:30-01 :30 03 Nov 99 01 :30 01 :30-02:30 02:30 02:30-06:00 06:00-01 :30 06:00-23:30 23:30 23:30-00:00 04 Nov 99 00:00 00:00-01 :30 01:30 01:30-06:00 01 :30-02:00 02:00 02:00-02:30 Duration 1/2 hr 5 hr 1 hr 4hr 19 hr 3-1/2 hr 1 hr 5 hr 5 hr 1 hr 3-1/2 hr 19-1/2 hr 17 -1/2 hr 1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 3 30 November 99 Activity Repaired Drillstring handling equipment Repair tong line Equipment work completed BHA run no. 1 Serviced Top drive Service top drive, blocks, and crown. Equipment work completed Pulled out of hole to 0.0 ft POOH. LID bit and B/S. At top of check trip interval BHA run no. 2 Made up BHA no. 2 PIU bit, motor, and MWD. Oreint motor and MWD and test same. OK. Conitnue GIH with BHA. BHA no. 2 made up Held safety meeting Hold pre-spud meeting with all personnel associated with well. Completed operations R.I.H. to 7076.0 ft Finish GIH with drill pipe and tag cement kick-off plug. On bottom Drilled to 7350.0 ft Orient motor and kick off of plug (3 1/2 hrs). Detected casing stub with resistivity tool after getting kicked off. Continue drill/slide to 7350' . Top drive failed - Pull back to shoe Serviced Top drive Top drive saver sub started leaking. Change out same. Equipment work completed Drilled to 7400.0 ft Continue to drilllslide from 7185' to 7400'. BHA run no. 2 (cont...) Drilled to 8834.0 ft (cont...) Continue to drilllslide from 7185' to 7400'. Stopped: To circulate Circulated at 8834.0 ft Circulate hole clean. MW at 9.6 ppg Hole swept with slug - 100.00 % hole volume Drilled to 8933.0 ft Observed well flowing while taking SPR after making' connection. Well shut in. In 0.08 hr had 12.000 bbl Gain - closed in well Well control Monitor wellbore pressures Well shut in on the annular ,~, \'7t ~:1 1?, ~[' .~'" ¡d~" ,. ."'") Observed pressures - string: 630.000 psi, annulus: 860.000 psi Bit depth 8933' MD 6943' TVD Estimated top of Kuparuk D Shale 8942' MD Cleared Kelly/top drive hose Begin weighting up to KWM 11.6 ppg. Attempt to circulatc. Standpipclkclly hose frozcn. ,,<'\ .-> .",\\ ~"S\~.\ .P' d~.,~,,\ /""""\ \....'\.., .,.=~::: - ':,) ~. ) -j Q ~'I~':'I~~"\ ' t ' ,:'1. Facility M Pt C Pad DatelTime 02:30 02:30-06:00 06:00 06:00-06:00 06:00-09:30 09:30 09:30-14:30 14:30 14:30-16:00 16:00 16:00-16:30 16:30 16:30-17:30 17:30 17:30-06:00 05 Nov 99 06:00 Duration 3-112 hr 24 hr 3-112 hr 5 hr 1-112 hr 1/2 hr 1 hr 12-112 hr 06:00-13: 15 7-1/4 hr 06:00-06:30 1/2 hr 06:30 06:30-07:00 1/2 hr 07:00 07:00-08:30 1-1/2 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 4 30 November 99 Activity Began precautionary measures Cleared Standpipe manifold Close upper / lower kelly cocks to remove kelly hose. RID kelly hose. Begin thawing kelly hose. Equipment work completed Well control (cont...) Cleared Kelly/top drive hose Finish RID kelly hose and start thawing out same. RID 2" high pressure circulating hose to top drive and test to 4500 spi. OK. Equipment work completed Cleared Kelly/top drive hose Attempting to thaw out top drive and top drive kelly cock valves. No success. Weight up mud in pits from 10.6 to 11.6 while thawing out. Equipment work completed Cleared Kellyltop drive hose RID HB&R and attempt to pump methanol thru frozen lines I valves while continuing to attempt to thaw lines with steam. Equipment work completed Held safety meeting Perform a risk anaylsis regarding the forward planes) to thaw out the top drive. Completed operations Cleared Kellyltop drive hose RID and pump 3 bbls mud down annulus. Pump in at 13.6 EMW. Equipment work completed Cleared Kellyltop drive hose No success with steam thawing operations. Shut down same. Remove 2" high pressure hose and re-fill with fresh neet methanol vs the 50:50 blend. Install air ducting around drill pipe from rig floor to elevators. Equipment work completed Wrap visqueen around from elevators to the top of the top drive. 2 portable tioga heaters and 1 rig floor heater are supplying the hot air. By 0600 hrs the 2 kelly cock valves are thawed out and open. Continue pumping heat and attempting to pump methanol Well control (cont...) Cleared Kellyltop drive hose Top drive actually thawed out at 0530 hrs. SICP 930 Hel~~!t.~~;~~~O !o%p1eted f? t C t ¡ V r. ! Hold PJSM on well kill. Review procedure and ~ L define responsibilities of crew. ,.:"/' 7 ,'" cir~~~}:i!;~!;~~~~r~~t ~~Ot~u the choke. IC~ ':~.~~ GiÎ ~~~%Z;':1:~ :;;:~l'M' psi. Csg press 930 psi. The initial circ press was ; ~ --.... higher than calculatcd because the SPR had been ) Facility M Pt C Pad DatelTime 08:30 Duration 08:30-09:00 1/2 hr 09:00 09:00-11 :30 2-1/2 hr 11 :30 11:30-12:00 1/2 hr 12:00 12:00-13:00 1 hr 13:00 13:00-13: 15 1/4 hr 13:15 13:15-06:00 16-3/4 hr 13:15-14:00 3/4 hr 14:00 14:00-14:30 1/2 hr 14:30 14:30-16:00 1-1/2 hr 16:00 16:00-17:30 17:30 17:30-18:00 1-1/2 hr 1/2 hr 18:00 18:00-19:30 1-1/2 hr 19:30 19:30-21:00 1-1/2 hr 21:00 ) Progress Report Well MPC-12A Rig Nordic3 Page Date 5 30 November 99 Activity taken with the kelly hose, and the well kill was done Began precautionary measures Stopped to weight up surface system. Unable to keep up with a 2 1b (9.6 to 11.6) weight up while circulating. Monitor well bore pressures SI well at 4317 stks to wt up surface system to 11.6 ppg SIDPP 470 psi SICP 510 psi Freeze protect top drive Observed pressures - string: 470.000 psi, annulus: 510.000 psi Circulated closed in well at 8933.0 ft Continue well kill. Circ a total of 2 btm up. Unable to ever get 11.6 MW out. Max circ rate of 2 bpm lose returns. Experience barite sag. MW out ranged from 11.3 to lOA. Began precautionary measures Monitor well bore pressures Shut well in to monitor pressures Observed pressures - string: 210.000 psi, annulus: 280.000 psi Circulated closed in well at 8933.0 ft ICP 520 psi. Csg press 10 psi. Shut down and bleed off pressure. No flow. Stopped: To flowcheck well Monitor wellbore pressures Observed well static BHA run no. 2 Pulled out of hole to 8840.0 ft Rig down thawing equipment. Break out stand and stab TIW. Blow down top drive. PU single. Shorten the 2" hose being circulated through to allow movement of the top drive. Began precautionary measures Held safety meeting Hold PJSM on opening the well and moving the pipe. Completed operations Circulated at 8873.0 ft Pipe free. Initial up wt. 140k. Down wt. 95k Hole packing off while circ. Locate free point and circ. staging pump to 45 SPM Began precautionary measures Pulled out of hole to 8255.0 ft Stopped: To circulate Circulated at 8255.0 ft Hole was taking the correct amount of fill, but began u-tubing back up the drill pipe side. PumJ?.25 bb1s. Flow up drill pipe stopped. ~~\~.> Broke circulation "'';:',.., c.~.... Pulled out of hole to 6800.0 ft '/d' )' PuI,1 into casing: Hole in good condition. Hole ~<'{~~ "'c,-;'- taking correct fill. '\1.'-, S\ <':>..\ . At Window: 7076.0 ft '-;.~~'·~')ð .. 2;) Circulated at 6800.0 ft . (9 (!;>, Circulate and condition mud. Attempt to increase ....<~.;; "'\.)~l" rate to reduce barite sag. 108 bbls lost. .:¿;"" Broke circulation " ',"'\ /~~t t . "'\ ("".""", t ..','\ {'..... ~.,'~ '" ..:'-\..~ /?- ~~ /.~'''''' '- ,,,"tt>< ,/ ","-", Facility M Pt C Pad Date/Time 21:00-22:30 Duration 1-1/2 hr 22:30 22:30-01:00 2-1/2 hr 06 Nav 99 01:00 01 :00-03:00 2 hr 03:00 03 :00-04:00 1 hr 04:00 04:00-06:00 2 hr 06:00 06:00-08:30 2-1/2 hr 06:00-07:00 1 hr 07:00 07:00-08:30 1-1/2 hr 08:30 08:30-04:30 20 hr 08:30-12:30 4 hr 12:30 12:30-14:30 2 hr 14:30 14:30-15:00 1/2 hr 15:00 15:00-04:30 13-1/2 hr 07 Nov 99 04:30 04:30-06:00 04:30-05:30 1-1/2 hr 1 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 6 30 November 99 Activity Flow check Monitor well. Constant rate of influx 0.6 bbl/5 min. Well is "flowing or breathing" not sure which. Lost 108 bbls lost while attempting circulate 11.6 mud around. Observed 7.500 bbl gain in annulus in 1.00 hr Pulled out of hole to 3481.0 ft POOH slowly monitoring well. Next 20 stds gained 17 bbls. Hole started taking mud at 1.6, 0.8, 2.1 bbls /5 stds respectively. At top of check trip interval Circulated at 3481.0 ft Circulate 11.6 mud around at 4 bpm with no losses. Initial MW out was 10.4. Obtained clean returns - 100.00 % hole volume Rigged up Kellyltop drive hose RID 2" high pressure circulating hose and R/U kelly hose. Able to trip and rack back drill pipe much easier with kelly hose. Equipment work completed Pulled out of hole to 882.0 ft Continue to POOH. Hole taking inconsistant hole fills. Monitor well each 5 stds pulled. No gain/loss. At BHA BHA run no. 2 (cont...) Pulled out of hole to 882.0 ft Finish POOH to BHA. At BHA Pulled BHA Download MWD /PWD and rack back BHA. Completed operations Run Liner, 4-1/2in O.D. Installed Well control Pull wear bushing. Change top rams to 4 1/2". Set test plug and test rams to 250-3500 psi. OK. Pull test plug. Set wear bushing. Well static. Equipment work completed Rigged up Casing handling equipment Clean rig floor area from wet trip. RlU 4 1/2" casing tools. Well static. Equipment work completed Held safety meeting Hold pre-job for running 4 1/2" liner and well control issues. Completed operations Ran Liner to 8924.0 ft (4-1/2in OD) PIU 52 jts 4 1/2" 12.60# L-80 IBTMod liner and run on 3 1/2" DIP. TOL 6751'. Shoe 8924'. Tag btm 8926'. Full returns running inside 7" csg. Lost 26 bbls running liner in open hole. Well static. while running liner. On bottom Cement: Liner cement Circulated at 8924.0 ft Establish injection/cireulation rate. Initial rate 4' l ...,«<\ ~'\'\'" ',\ ,,;,"'",,, (. ."'\ -.::,""\¡. " ...",,\ .".:.(.... ~~ ~"'.... ..{~ ..~'.~\ \2;. ...... \ ,- 'Ö~, çt' 6'" ...~ ~"") "c,"'"\ O\~~~i, ";1 ~~::;:: ..~~~:' .... '\'~... < Facility M Pt C Pad DatelTime 05:30 05:30-06:00 Duration 1/2 hr 06:00 06:00-09:00 06:00-09:00 3 hr 3 hr 09:00 09:00-09:30 1/2 hr 09:00-09:30 1/2 hr 09:30 09:30-13:00 3-1/2 hr 09:30-13:00 3-1/2 hr 13:00 13:00-00:00 11 hr 13:00-21:30 8-1/2 hr 21 :30 21 :30-00:00 2-1/2 hr 08 Nov 99 00:00 00:00-01 :30 1-1/2 hr 00:00-01 :30 1-1/2 hr 01:30 01 :30-02:00 1/2 hr 01 :30-02:00 1/2 hr 02:00 02:00-04:00 2 hr 02:00-04:00 2 hr 04:00 04:00-06:00 2 hr 04:00-06:00 2 hr 06:00-06:30 1/2 hr 06:00-06:30 1/2 hr 06:30 Activity 004 bpm at 2900 psi. Pressure broke back. Continue Obtained reg. fluid properties - 15.00 %, hole vol. Mixed and pumped slurry - 23.600 bbl 15 bbls 12.1 B45 spacer. Batch slurry 113 sks, 23.6 bbls, Wt 15.8, Yield. Displace with 11.6 mud at 4.6 bpm 1800 psi. Bump plug with 3200 psi and set hanger. 50% returns during job. Pressure to 4200 psi to set liner top packer. Check BPV. OK. Tail cement pumped Cement: Liner cement (conL.) Circulated at 6751.0 ft Release from hanger and circulate out. No cement in returns. Got back oil wet barite. Continue to circulate till clean with 1104 in lout. Obtained reg. fluid properties - 200.00 %, hole vol. Perform integrity test Tested Liner Pressure test liner top packer to 2000 psi for 15 minutes. Test OK. Pressure test completed successfully - 2000.000 psi Fluid system Circulated at 6751.0 ft Swap well out to corrosion inhibited seawater. RID liner swivel and blow down lines. Obtained reg. fluid properties - 200.00 %, hole vol. Pull Drillpipe, 3-1/2in 0.0. Laid down 6350.0 ft of 3-1/2in 00 drill pipe POOH amd LID drill pipe used for running liner. Baker liner running tool OK and intact. 198 joints laid out Laid down 882.0 ft of Dril1 collar LID BHA out of derrick. Completed operations Run Drillpipe, 3-1/2in 0.0. Ran Dril1pipe in stands to 2900.0 ft Run 30 stds drill pipe back in hole for freeze protect. On bottom Perform integrity test Tested Casing Test 7" and 4 1/2" casing strings to 3500 psi for 30 minutes. Test OK. Pressure test completed successfully - 3500.000 psi Fluid system Freeze protect well - 85.000 bbl of Diesel ~ R/U HB&R and freeze protect well with 85 bbls ~~... diesel (2200' MD). RID HB&R. Y;1 Completed operations ~ Pull Oril1pipe, 3-1/2in 0.0. Laid down 2900.0 ft of 3-1/2in 00 dril1 pipe POOH and LID drill pipe. Pull Oril1pipe, 3-1/2in 0.0. (conL.) Laid down 2900.0 ft of 3-1/2in 00 drill pipe (conL.) POOH and LID drill pipe. 93 joints laid out ) ) Progress Report Well MPC-12A Rig N ordic3 Page Date 7 30 November 99 '-',\ ~.;"'j. ","'<\.ul :"'{''l (,.,') 'I,,""H'î ·t\~:,~:Lt ¿.:;:~~~ Ç,1'" \~~:'!'-\ Y' (;") \.,,~ f~:~l ~~ c.r) I...~~ ~::~'~;1 r;t\. 0> t',...~"\ \.:.:::; ~:', ~.~:~ . Facility M Pt C Pad DatefTime 06:30-09:00 06:30-09:00 09:00 09:00-10:00 09:00-10:00 10:00 10:00-12:00 10:00-12:00 12:00 12:00-17:30 12:00-17:30 17:30 17:30-18:30 17:30-18:30 18:30 18:30-06:00 18:30-20:00 20:00 ) Duration 2-1/2 hr 2-1/2 hr 1 hr 1 hr 2 hr 2 hr 5-1/2 hr 5-1/2 hr 1 hr 1 hr 11-1/2 hr 1-1/2 hr ) Progress Report Well MPC-12A Rig N ordic3 Page Date 8 30 November 99 Activity Fluid system Freeze protect well- 15.000 bbl of Diesel Toped off well with 15 bbls disesel. Used test pump to diesel. Pulled wear ring Completed operations Wellhead work Installed Tubing hanger Install tbg hanger w/ T.W.C inplace. Equipment work completed BOP/riser operations - BOP stack Removed BOP stack NID 11" BOPE Equipment work completed Wellhead work Installed Xmas tree N/U Adapter flange, Test pack off . No good remove and clean rings. Reinstall Test to 5000 psi O.K. Thaw out tree and install test 500 & 5000 psi O.K. Equipment work completed Wellhead work Rigged up Hanger plug Pull T.W.C and install BPV Equipment work completed Move rig Rigged down Drillfloor / Derrick Move rig off well. Pick up pit liner & clean around well cellar. Release rig @ 2000 hrs 11/8/99 Equipment work completed Facility M Pt C Pad DatelTime 18 Jan 00 12:00-22:00 12:00-22:00 Duration 10 hr 10 hr 22:00 22:00-06:00 22:00-06:00 8 hr 8 hr 19 Jan 00 06:00 06:00-06:30 1/2 hr 06:00-06:00 o hr 06:00-06:30 1/2 hr 06:30 06:30-12:30 6 hr 06:30-12:30 6 hr 12:30 12:30-13:30 1 hr 12:30-13:30 1 hr 13:30 13:30-17:00 3-1/2 hr 13:30-17:00 3-1/2 hr 17:00 17:00-03:30 10-1/2 hr 17:00-20:00 3 hr 20:00 20:00- 21 :00 1 hr 21:00 21 :00-00:00 3 hr 20 Jan 00 00:00 00:00-02:30 2-112 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 1 15 February 00 Activity Move rig Rig moved 100.00 % Remove 11" drilling spool fl BOP and set back. Move rig fl MP H pad to MP C pad. Lay pit liner & mats, Move rig over MP C-12Ai At well location - Cellar Accept rig @ 2200 hrs 01/18/2000 Nipple up BOP stack Installed BOP stack Continnue to lay pit liner under rig due to high winds. N/D Tree & set out side. NIU 11" 5M 3 gate BOP stack. Change middle ram to 3-1/2" Equipment work completed Wellhead work Rigged up BOP stack Removed Tubing hanger PJSM Pull TBG hanger, Set Test plug Equipment work completed BOPlriser operations - BOP stack Tested BOP stack Change top rams to 3-1/2", NIU BOP test 200 Lo & 3500 psi, Annular 200 Lo & 2500 psi. Also loading pipe shed wI 2-3/8" DP 103 jts. Pull test plug & set wear ring. Pressure test completed successfully - 3500.000 psi Lower pipe rams will be tested after PIU & RIH wI 3-1/2" DP. Derrick management Serviced Crown block Slip & cut drill line. Check crown-a-matic. Load Sperry-Sun BHA in ppipe shed. Equipment work completed Run Drillpipe, 3-1/2in O.D. Racked back Drillpipe Load 3-1/2" DP in pipe shed 215 joints Required components racked in derrick Run Drillpipe, 3-1/2in O.D. Ran Drillpipe to 3232.0 ft (3-1I2in OD) PIU & RIH 3.5" Mule shoe jt & 100 jts 3.5" DP Stopped: To circulate Circulated at 3232.0 ft R/U & circulate out Diesel freeze protection 120 spm @ 500 psi wI 2100 stk's had H2s alarm 4 ppm at shakers. Circ till clean. Obtained bottoms up (100% annulus volume) Ran Drillpipe to 6624.0 ft (3-1/2in OD) Conitnue to PIU & RIH wI 3.5" DP to 6624' 127' off 4.5" liner top @ 6751' Stopped: To circulate Circulated at 6624.0 ft Broke circualte @ 120 spm 700 psi. WI 2800 sks had H2s at shakers 17 ppm. Shut in and circualted through poor boy degaser. Alert DSO and Nabors rig #4. Continue to clear well bore of H2s wI 32 ppm at shaker. Opcn all doors and vented rig. ) Facility M Pt C Pad Date/Time Duration 02:30 02:30-03:30 1 hr 03:30 03:30-06:00 2-1/2 hr 03:30-06:00 2-1/2 hr 06:00-06:00 24 hr 06:00-07:00 1 hr 07:00 07:00-09:00 2 hr 09:00 09:00-14:30 5-1/2 hr 14:30 14:30-15:30 1 hr 15:30 15:30-17:30 2 hr 17:30 17:30-01 :30 8 hr 21 J an 00 01:30 01 :30-03:30 2 hr 03:30 03:30-05:30 2 hr 05:30 05:30-06:00 1/2 hr 06:00 06:00-06:00 24 hr 06:00-08:30 2- 1/2 hr 08:30 08:30-10:00 1-1/2 hr 10:00 10:00-13:00 3 hr ) Progress Report Well MPC-12A Rig Nordic3 Page Date 2 15 February 00 Activity Obtained clean returns - 300.00 % hole volume Rotate and circ. Max torque 5100 ft/1b 85k rotating weight. Up Wt. 90k, Dw Wt 75k No rotation. Tested Pipe ram Test lower pipe ram & 7" Csg to 3000 spi for 5 min O.K. Retest valve after servicing same O.K. Function test completed satisfactorily Pull Drillpipe, 3-1/2in O.D. Pulled Drillpipe in stands to 3.5 ft POOH stand back 3.5" Dp BHA run no. 1 Held safety meeting Hold PJSM on BHA and RlU for 2-3/8" DP. Completed operations Made up BHA no. 1 BHA no. 1 made up Downloaded MWD tool Attempt to Load MWD tools. Cannot establish communication between tools. Trouble shoot MWD tools. Stopped: To service drilling equipment Pulled BHA LID EWR, reconfigure tools. Completed operations Made up BHA no. I RIH wi flex D.C.'s, Jars, 1 jt DP, no EWR. POH and layout tubulars. P/U EWR and orient. BHA no. 1 made up R.I.H. to 6714.0 ft At Top of liner: 6714.0 ft Held safety meeting Wait 1 hour for Rig Nabors 4-ES to clear pad. Held 1 hour PJSM on H2S operations and contingency plans. Completed operations Circulated at 6714.0 ft Begin circulating at 60 spm, 2400 psi. Circulate b/u; no H2S readings in shaker room. Obtained bottoms up (100% annulus volume) Serviced Top drive Take torque readings. Set Top Drive to correct mlu torque. Equipment work completed BHA run no. 1 (conL.) R.I.H. to 8650.0 ft RIU circulating hose and close annular. Stopped: To circulate Circulated at 8650.0 ft Circulate old mud out through choke @ 60 spm, 2200 psi. No H2S observed. Obtained clean returns - 100.00 % hole volume Circulated at 8650.0 ft MIU Top drive, pump spacer pill and displace seawater with 11.6 ppg mud. ) Facility M Pt C Pad Date/Time 13:00 13:00-13:30 Duration 1/2 hr 13:30 13:30-15:30 2 hr 15:30 15:30-05:00 13-1/2 hr 22Jan 00 05:00 05:00-06:00 1 hr 06:00-18:00 12 hr 06:00-06:30 1/2 hr 06:30 06:30-12:00 5- 1/2 hr 12:00 12:00-13:00 1 hr 13:00 13 :00-14:00 1 hr 14:00 14:00-18:00 4 hr 18:00 18:00-06:00 18:00-21 :00 12 hr 3 hr 21:00 21 :00-00:00 3 hr 23 Jan 00 00:00 00:00-01 :30 1-1/2 hr ) Progress Report Well MPC-12A Rig Nordic3 Page Date 3 15 February 00 Activity Hole displaced with Water based mud - 100.00 % displaced R.I.H. to 8830.0 ft Wash and ream to bottom, tag at 8820'. Continue through soft cement to 8830' . On bottom Functioned downhole tools at 8830.0 ft Cycle pumps and try diferent pump rates and combinations in an attempt to function Sperry Sun tools. Reduce pump pulse-dampener pressure to 300 psi. Equipment work completed Drilled to 8838.0 ft Drill float equipment. Drilling very slowly through wiper rubbers, likely due to spinning rubber on bottom. Attempting to drill through by using various weights and rotary RPM's. . Began precautionary measures Unable to drill through float equipment. Pulled out of hole to 8838.0 ft Decision made to POOH to check bit and motor. Pump dry job and POOH. BHA run no. 1 (cont...) Circulated at 8838.0 ft Pump dry job, blow down TD, prepare to POOH. Heavy slug spotted downhole Pulled out of hole to 280.0 ft POOH wet. Tried to stand back 2-3/8" DP, but it was too wigley and wild. Laid out 2-3/8" DP. At BHA Pulled BHA LID BHA, lost bit, bit box, and motor shaft. BHA Laid out Downloaded MWD tool Lay down motor and download MWD. Mud motor failed - End BHA run Serviced Top drive Send motor to shop for disassembly to verify fishing tool size. Wait on fishing mud motor and fishing tools Clean floors, service top drive, Eckles and rig. Equipment work completed BHA run no. 2 Made up BHA no. 2 P/D & m/u Baker fishing tools (overshot, oil jars, bumper sub). PIU and RIH with 6 jts 2-3/8" Flex DC's + 66 jts 2-3/8" DP. BHA no. 2 made up R.I.H. to 8837.0 ft Change out elevators and Eckles, RIH wI 3-112" DP in stands to 8784'. K/U on stand #68 and tag fish at 8837' . At Top of fish: 8837.0 ft Fished at 8837.0 ft Tagged fish, pumping at 20 stkslmin, 10 I 0 psi. Pressure jumped up 100 psi upon swallowing fish. ') Facility M Pt C Pad Date/Time 01:30 01 :30-04:00 Duration 2-1/2 hr 04:00 04:00-06:00 2 hr 06:00-15:30 9-1/2 hr 06:00-10:30 4-1/2 hr 10:30 10:30-15:30 5 hr 15:30 15 :30-06:00 14-1/2 hr 15:30-20:00 4-1/2 hr 20:00 20:00-22:00 2 hr 22:00 22:00-22:30 1/2 hr 22:30 22:30-05:00 6-1/2 hr 24 Jan 00 05:00 05:00-06:00 1 hr 06:00 06:00-08:30 2-1/2 hr 06:00-08:30 2-1/2 hr 08:30 08:30-09:00 1/2 hr 08:30-09:00 1/2 hr 09:00 09:00-09:30 1/2 hr 09:00-09:30 1/2 hr ) Progress Report Well MPC-12A Rig Nordic3 Page Date 4 15 February 00 Activity Began precautionary measures Circulated at 8837.0 ft Pump dry job, break off top drive. Mud U-tubing from last dry job. Allow well to U-tube down annulus and up DP. Began precautionary measures Pull out of hole wet. Pulled out of hole to 7000.0 ft Pulling out of hole at report time. BHA run no. 2 (cont...) Pulled out of hole to 0.0 ft POH wet, LID 2-3/8" DP and collars. At Surface: 0.0 ft No fish recovered. Serviced Drillfloor I Derrick Service rig. Wait on Fishing tools. Equipment work completed BHA run no. 3 R.I.H. to 8800.0 ft MIU overshot and motor. RIH for 2nd fishing trip. Began precautionary measures Circulated at 8800.0 ft Cirulate to condition mud. Obtained req. fluid properties - 100.00 %, hole vol. Fished at 8835.0 ft RIH to TD, tag up on fish at 8835' md, pick up and break circulation. Mill over fish, motor stalled. PIU, break circulation and mill over fish, motor stalled. Pull 20 klb over, jars bled off. Pull 25 klb over, came free. Blow down top drive. On bottom Decision made to pull out of hole. Pulled out of hole to 0.0 ft POOH wet. Did not pump dry job. At Surface: 0.0 ft Pulled BHA Lay down fishing tools. No fish at surface. Inside of the grapple was not marked up. Marks were observed on the outside of the 3-5/8" guide shoe. BHA Laid out BHA run no. 3 (cont...) Serviced Drillstring handling equipment Wait on orders: Service Eckles, air tugger, top drive and drawworks. Equipment work completed Run Drillpipe, 2-3/8in O.D. Ran Drillpipe to 330.0 ft (2-3/8in OD) PIU mule shoe and 10 stands DP and RIH to circulate mud to fresh water. Stopped: To pick up/lay out tubulars Decided to POOH and run US IT log on wireline. Pull Drillpipe, 2-3/8in O.D. Pulled Drillpipe on retrieval string to 0.0 ft rOOII and lay down 10 jts 2-3/8" Dr and mule shoc. Facility M Pt C Pad DatelTime Duration 09:30 09:30-22:00 12-1/2 hr 09:30-14:30 5 hr 14:30 14:30-15:00 1/2 hr 15:00 15:00-15:30 1/2 hr 15:30 15:30-17:30 2 hr 17:30 17:30-21 :30 4 hr 21:30 21 :30-22:00 1/2 hr 22:00 22:00-06:00 8 hr 22:00-02:00 4 hr 25 Jan 00 02:00 02:00-04:30 2- 1/2 hr 04:30 04:30-06:00 1-1/2 hr 06:00-12:30 6-1/2 hr 06:00-08:00 2 hr 08:00 08:00-10:30 2-112 hr 10:30 10:30-12:30 2 hr 12:30 12:30-00:00 11-112 hr 12:30-21 :00 8-112 hr 21:00 ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 5 15 February 00 Activity At Surface: 0.0 ft Electric wireline work Conducted electric cable operations Wait on wireline. Began precautionary measures Held safety meeting Held PJSM with wireline crew and rig personnel. Completed operations Installed Logging/braided cable equipment Equipment work completed R.I.H. to 6751.0 ft RIH w/ USIT log. Unable to get through liner lap. POOH to adjust stabilizers.. Unable to re-enter hole R.I.H. to 8865.0 ft Were able to enter 4-1/2" liner, but making very slow progress through 55 degree section. Mud seems to have jelled up. Decision made to POOH to change mud to fresh water. At Surface: 0.0 ft Removed Logging/braided cable equipment Equipment work completed BHA run no. 4 R.I.H. to 8830.0 ft M/U mule shoe, RIH with 2-3/8" X 3-1/2" tapered string. On bottom Circulated at 8830.0 ft Break circulation at 60 spm, 1520 psi. Circulate blu at 13.4 ppg out, 60 spm, 1920.psi. After blu, pressure = 1140 psi at 60 spm. Wait on trucks. Obtained bottoms up (100% annulus volume) Reverse circulated at 8830.0 ft Line up to reverse circulate and off load mud from pits. Displace mud with fresh water. BHA run no. 4 (cont...) Reverse circulated at 8830.0 ft Finish reverse circ well to fresh water. Clean surface equioment. Hole displaced with Water - 110.00 % displaced Pulled out of hole to 2175.0 ft Blow down. POH w/ 3.5"DP. At BHA Pulled BHA LD 2 3/8" DP. BHA Laid out Electric wireline work Conducted electric cable operations RU SOS. RIH w/ US IT. Logged fl8825' -6750'. TOC @ -8510' . Evaluate options wI Anchorage. Completed logging run with Cement evaluation tool from 8825.0 ft tc 6750.0 ft ) Facility M Pt C Pad Date/Time Duration 21 :00-21 :30 1/2 hr 21:30 21:30-00:00 2-1/2 hr 26 Jan 00 00:00 00:00-06:00 6 hr 00:00-05:00 5 hr 05:00 05:00-05:30 1/2 hr 05:30 05:30-06:00 1/2 hr 06:00-04:30 22-1/2 hr 06:00-14:00 8 hr 14:00 14:00-16:30 2-1/2 hr 16:30 16:30-17:00 1/2 hr 17:00 17:00-18:00 1 hr 18:00 18:00-01:30 7-1/2 hr 27 Jan 00 01:30 01:30-04:30 3 hr 04:30 04:30-06:00 04:30-05:00 1-1/2 hr 1/2 hr ') Progress Report Well MPC-12A Rig Nordic3 Page Date 6 15 February 00 Activity Held safety meeting PJSM on running wireline packer. Completed operations Conducted electric cable operations PU & MU Baker bridge plug. RIH. Tie in. Set @ 8796'. POH. Completed run with Bridge plug from 8796.0 ft to 0.0 ft BHA run no. 5 Made up BHA no. 5 PU & MU Baker Thru Tubing Whipstock assembly. Single in 2 3/8" DP. BHA no. 5 made up Rigged up Drillstring handling equipment RU to run 3.5" DP. Equipment work completed R.I.H. to 3500.0 ft BHA run no. 5 (conL.) R.I.H. to 8793.0 ft Continue in hole with whipstock. Tag at 8793' , set at 8795'. No clear indication that whipstock set. Set down 10klb and felt whipstock shear. P/U and circulate at 1.5 bpm to confirm that whipstock was set. On bottom Functioned Circulating sub Drop vinyl ball to open PBL sub. Pump ball down, pressure up to 3500 psi. Bleed off. Circulate mud at 3 bbls/min. Pump 150 stks and pressured up to 4000 psi, blowing popoff. Reset popoff to 4500 psi, pressure up to 4000 psi. Began precautionary measures Could not establish circulation. Attempted to reverse circulate. Could not reverse. Decided to POOH and inspect PBL sub and motor. Pulled out of hole to 8370.0 ft Began precautionary measures Serviced Block line Slip and cut 4875' of block line. Line slipped and cut Pulled out of hole to 0.0 ft POOH wet. At BHA Pulled BHA Break PBL sub. Vinyl ball was in ball catcher. MID new PBL sub, ran motor below rotary and tested. Pressured up to 1000 psi, could not establish circulation. Pulled Motor, broke bit. Jets were plugged with metal shavings and bar. BHA Laid out BHA run no. 6 Made up BHA no. 6 M/U bit, motor and PBL sub. RIH and test motor, 30 spm, 340 psi. Drop vinyl ball, PBL sub circulated at 60 psi from 310 psi at 24 spm. Dropped steel ball, closed rDL sub. POOII and remove balls from Facility M Pt C Pad Dateffime Duration 05:00 05 :00-06:00 I hr 06:00-06:00 24 hr 06:00-06:30 1/2 hr 06:30 06:30-08:00 1-1/2 hr 08:00 08:00-08:30 1/2 hr 08:30 08:30-10:30 2 hr 10:30 10:30-13:00 2-1/2 hr 13:00 13:00-14:00 1 hr 14:00 14:00-15:00 1 hr 15:00 15:00-15:30 1/2 hr 15:30 15:30-16:00 1/2 hr 16:00 16:00-16:30 1/2 hr 16:30 16:30-20:00 3-1/2 hr 20:00 20:00-20:30 1/2 hr 20:30 20:30-22:00 1- 1/2 hr 22:00 22:00-23:00 I hr 23:00 23:00-03:30 4- 1/2 hr 28 Ian 00 03:30 03:30-04:00 112 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 7 15 February 00 Activity PBL. Completed operations R.I.H. to 5000.0 ft RIH wI BHA, drop vinyl ball, RIH. BHA run no. 6 (cont...) Serviced Crown block Equipment work completed Singled in drill pipe to 2255.0 ft 69 joints picked up Rigged up Drillstring handling equipment RU to run 3.5" DP. Fire Drill-OS-45 sec. Equipment work completed R.I.H. to 6800.0 ft At Top of liner: 6772.0 ft Circulated at 6770.0 ft Shift PBL open & CBU @ 3.5 bpm. Obtained bottoms up (100% annulus volume) Circulated at 6800.0 ft Shift PBL closed & circ DP volume. String displaced with Water - 100.00 % displaced R.I.H. to 7752.0 ft Stopped: To circulate Circulated at 7752.0 ft Circ DP volume. String displaced with Water - 100.00 % displaced R.I.H. to 8700.0 ft Stopped: To circulate Circulated at 8700.0 ft Circ DP volume. String displaced with Water - 100.00 % displaced Circulated at 8783.0 ft Tag top of whipstock. Shift PBL closed. Pump 35 bbls spacer. Displace around wI 11.6# mud @ 3.5 bpm while rotating & reciprocating. D2 Drill-OS-I mm. Hole displaced with Water based mud - 110.00 % displaced Tested Liner - Via string Test casing & liner to 1500 psi-OK. Pressure test completed successfully - 1500.000 psi Circulated at 8783.0 ft Shifted PBL closed. Pressure @ 2100 psi wi 2 bpm. Pressure fluctuating some. Could not see any motor differential. Work pressure up to as high as 4500 psi. Pressure dropped slightly overall. Shifted PBL open. Ball seated in Circulating sub Circulated at 8783.0 ft Shifted PBL closed. Pressure @ 1650 wi 2 bpm. Appears either DP or PBL seat is washed. Pressure changed from 2100.0 psi to 1650.0 psi in 1.50 hr - Downhole washout Pulled out of hole to 2225.0 ft Stopped: To change handling equipment Rigged up Drillstring handling equipment RU f/2 3/8" DP. ') Facility M Pt C Pad Date/Time Duration 04:00 04:00-06:00 2 hr 06:00-09:00 3 hr 06:00-07:00 1 hr 07:00 07:00-07:30 1/2 hr 07:30 07:30-09:00 1-1/2 hr 09:00 09:00-12:00 3 hr 09:00-09:30 1/2 hr 09:30 09:30-12:00 2-1/2 hr 12:00 12:00-12:45 3/4 hr 12:00-12:45 3/4 hr 12:45 12:45-13:00 1/4 hr 12:45-13:00 1/4 hr 13:00 13 :00-15:00 2 hr 13:00-15:00 2 hr 15:00 15 :00-06:00 15 hr 15:00-17:00 2 hr 17:00 17:00-17:30 1/2 hr 17:30 17:30-20:30 3 hr 20:30 20:30-00:00 3-1/2 hr 29 Jan 00 00:00 00:00-03:00 3 hr 03:00 03:00-06:00 3 hr 06:00-14:00 8 hr 06:00-11 :00 5 hr ) Progress Report Well MPC-12A Rig N ordic3 Page Date 8 15 February 00 Activity Work completed - Drillstring handling equipment in position Laid down 1000.0 ft of 2-3/8in OD drill pipe BHA run no. 6 (cont...) Laid down 2100.0 ft of 2-3/8in OD drill pipe (cont...) At BHA Pulled BHA PBL sub washed out @ port. BHA Laid out Serviced Crown block Serv rig & clean floor area after wet trip out. Equipment work completed Test well control equipment Installed BOP test plug assembly Pull wear ring & set test plug. Equipment work completed Tested BOP stack Test BOPE to 250/3500 psi; annular to 250/2500 psi. Witnessed by John Crisp-AOGCC Field Inspector. Pressure test completed successfully - 3500.000 psi Perform integrity test Tested Liner Test 7" casing & 4.5" liner to 2000 psi f/30 min-OK. Pressure test completed successfully - 2000.000 psi Wellhead work Rigged up Wear bushing Equipment work completed BHA run no. 6 Pulled BHA Break down Sperry tools & ship out. BHA Laid out BHA run no. 7 Singled in drill pipe to 2200.0 ft PU mule shoe & 69 jts 23/8" DP. 69 joints picked up Rigged up Drillstring handling equipment RU f/3.5" DP. Equipment work completed R.I.H. to 8784.0 ft RIH. Tag whipstock. On bottom Circulated at 8784.0 ft CBU @ 3 bpm taking mud samples. Rotate & reciprocate. Clean pits. Stopped: To circulate Reverse circulated at 8784.0 ft Take on 300 bbls sea water. Reverse 35 bbls spacer followed wI 300 bbls seawaterl corrosion inhibitor. Hole displaced with Inhibited brine - 125.00 % displaced Laid down 2000.0 ft of 3-1/2in OD drill pipe BHA run no. 7 (cont...) Laid down 6770.0 ft of 3-1/2in OD drill pipe Service rig. Continue to lay down all 3.5" DP total of 215 joint's ) Facility M Pt C Pad Date/Time 11:00 11 :00-14:00 Duration 3 hr 14:00 14:00-20:00 14:00-20:00 6 hr 6 hr 20:00 20:00-23:00 3 hr 20:00-23:00 3 hr 23:00 23:00-01 :30 2-1/2 hr 23:00-01 :30 2-1/2 hr 30 Jan 00 01:30 01 :30-04:00 2-1/2 hr 01 :30-04:00 2-1/2 hr 04:00 04:00-06:00 2 hr 04:00-06:00 2 hr 06:00-14:00 8 hr 06:00-14:00 8 hr 14:00 14:00 14:00-15:00 1 hr 15:00 15:00-18:00 3 hr 18:00 18:00-05:30 11-1/2 hr 31 Jan 00 05:30 ) Progress Report Well MPC-12A Rig N ordic3 Page Date 9 15 February 00 Activity Stopped: To change handling equipment Laid down 2838.0 ft of 2-3/8in OD drill pipe Change handling equipment. Conintue to lay down 2-3/8" DP total of 90 joints 90 joints laid out Run Tubing, 4-1/2in O.D. Ran Tubing to 2684.0 ft (4-1/2in OD) Load pipe shed wi 65 joints of 4.5" 12.6# L-80 IBT Tbg. P/U & run same as a kill string to 2684'. Install two way check in hgr on rig floor. Drain stack and land RILDS. Hanger landed BOPlriser operations - BOP stack Rigged down BOP stack NID BOP stack, LID mouse hole, Bails for inspection & Clean pits Equipment work completed Wellhead work Installed Tubing on landing string Install 4-1/16" adapter flanger & tree. Fill tree wi diesel Test to 250 - 5000 psi O.K., Pull 2 way. Equipment work completed Chemical treatment Circulated at 2500.0 ft RiU HB&R Test lines. Pump 90 bbls diesel down annulus @ 2 bpm taking returns fl tbg, RiD HB&R , install BPV , Remove HCR & Choke valves. Slips, elevators, pups and landind jt fl floor. Obtained bottoms up (100% annulus volume) "0" psi ON tbg and annulus Fluid system Cleared Trip tank Wait on vac truck. Clean pit 1, waste tank & trip tank. Empty out drum warner. Fluid system Cleared Trip tank Clean Tank I and trip tank. Clean surface equipment in preparation for move to Kuparuk. Equipment work completed Move rig Removed Additional services Move rig off MPC-12Ai. Remove rig matting boards and clean up around cellar. Equipment work completed Serviced Trip tank Continue cleaning tanks. Equipment work completed Release Rig @ 1800 hrs 1/30/2000. Rig moved 100.00 % Moved rig from Milne Point to Kuparuk 1 D Pad. Note: Move camp from Milne Point to Kuparuk from 14:15 to 17:30 hrs. At well location - Cellar Rig on ID Pad @ 05:30. 18 mile move. ) STATE OF ALASKA ) ALASKA ùlL AND GAS CONSERVATION ClJ,V'fMISSION APPLICATION FOR SUNDRY APPROVAL 4s ~ 'ó C:Ð 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging 0 Time Extension 0 Perforate o Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other o Change Approved Program t:8J Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 289" NSL, 2348" WEL, SEC. 03, T13N, R10E, UM At effective depth 5. Type of well: D Development D Exploratory D Stratigraphic IZJ Service 6. Datum Elevation (DF or KB) Plan KBE = 45.60" 7. Unit or Property Name Milne Point Unit (Planned) 8. Well Number MPC-12Ai 9. Permit Number 199-091 1399-234 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands At total depth 4611 NSL, 2350' WEL, SEC. 03, T13N,·R10E, UM 12. Present well condition summary (Planned) Total depth: measured true vertical Effective depth: measured true vertical 8933 feet Plugs (measured) 6943 feet 8838 feet Junk (measured) 7603 feet Baker TTRD Whipstock set at 8780" (top) 01/00 Drilling BHA fish left at 8736101/00 Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 80" 6034' 13-3/8" 9-518" To Surface 1625 sx PF lE", 250 sx Class "G' 1081 6070' 108" 47031 10922" 21731 7" 4-1/2" 300 sx Class IGI (Top of SIT Window) 113 sx Class IGI 7067" 67511 - 89241 5291" 5143' - 69261 Perforation depth: measured None OR\G\NAL ~.. 1.'"" ~'"~ ~ I.m, ~ \.~ \, l~ ~' .... t·... ' 'I ':" )~ E!"": ïr"¡ '..,.. l,/ true vertical None q Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Kill String to 2684" Packers and SSSV (type and measured depth) None .Ai~4sKa ~k Ga~, CO!'J5" ,Anchora~\I8: 13. Attachments IZJ Description summary of proposal D Detailed operations program D BOP sketch Approved by order of the Commission Form 10-403 Rev. 06/15/88 14. Estimated date for commencing operation January 28, 2000 16. If proposal was verbally approved r. eÒ Blair Wondzell~'µ 1/28/2000 Name of approver Date approved ~~~~:::ecr N.;~m~~::e~~ f~t<~O;. r~i:::;;J4~:ct 10 the best of my knowledge Prepared By NameINumber: Terrie Hubble, 564-4628 Signed -' 'ìÙVLr [..:Y ( iJ l\,,4./~A... \.... .. . . 1- ') ! - ÛL; ares11ìallary i ~ Title Senior Drilling Engineer Date /' , \ Commission Use Only . Conditions of Approval: Notif~ Com~ission so repr~sentative may witness . I Approval No. i /j(J- Od? Plug integrity _ BOP Test...L...- Location clearance ,-,' L '- Mechanical Integrity Test _ Subsequent form ~'Q1Id 10- t..c Or :JRIGINAL SIGNED BY:v'Ç~o~e l.~~þ \ Robert N. Christenson ~ ~e\'J. /~ Commissioner 1~Y 15. Status of well classifications as: DOil DGas D Suspended Service Water & Gas Injector Date,} /'10 ·~f[} Submit In Triplicate ) ) hared ervlces rilling Alaska BP Exploration I ARGO Alaska Inc. To: Blair Wondzell AOGCC Subject: MP C-12A Permit No. 99-091 Operation Shutdown Blair: This letter is in regards to the condition and forward plan for well MPC-12Ai. The Nordic 3 operation on well MP C-12A has encountered several downhole tool failures and the Asset has requested that drilling operations be suspended at the present time. The well will be evaluated for a future drillout with coiled tubing. Operations on the well were resumed 10 days ago on January 18, with the intention of drilling out the 4-1/2" float equipment and cement, drill to TO, and complete the well in the Kuparuk reservoir. While attempting to drill out the landing collar the downhole motor broke leaving a fish on top of the landing collar. Two fishing trips to recover the fish were unsuccessful in getting over the fish and additional fishing work was deem to be futile. The decision was made to set a whipstock above the fish and mill a window to allow drilling to TO. A cement bond log was run which verified good cement at the window and good zonal isolation above the window. The whipstock was then set at 8780·. Two trips were made to attempt the window milling but both trips failed and no window milling was done. The first run failed due to a plugged mill and the second trip failed due to a washout in the PBl circulating sub. Operations on the well were shutdown on January 30, 2000. The float equipment and cement have not been drilled out and the window has not been milled. The 7" casing and 4-1/2" liner have been pressure tested. The well has been left full of inhibited seawater and freeze protected. A kill string was run to 2684'. Tubing hanger with back pressure valve and tree were installed and tested. Verbal approval for a "Operation Shutdown" was received from Blair Wondzell onþ January 28. ø ~("2.l~ Respectfully, Fred Johnson Operations Drilling Engineer Shared Services Drilling RECEiVED FE8 (j 1 2000 A1aSIèI 011 & Gas Cons. CoaIIDIIån Anchorage ,~ ) ) DRAFT 1/28/00 MPC-12Ai Operations Summary The decision has been made to suspend operations on this well at the present time. The well will be suspended with a 2500' of 4-1/2" kill string after displacing the well back to inhibited seawater. This operation has been verbally approved by Blair Wondzell with AOGCC on Jan 28, 2000. Snapshot of Well Pro~ram 1. Finish testing BOP. 2. Pressure test 7" casing and 4-1/2" liner against blind rams to 2000 psi with 11.6 Iblgal mud in hole to verify casing integrity for well suspension. 3. RIH open ended with tapered 3-1/2"/2-3/8" drill pipe to displace mud out of hole. 4. Displace mud out of hole with seawater. Final displacement should contain Corexit corrosion inhibitor. 5. POOH. Lay down drill pipe. 6. RIH with 4-1/2" 12.6 Iblft L-80 IBT tubing to 2500'MD (2200'TVD) for kill string 7. MU and land 11"x4-1/2" FMC tubing hanger 8. Install TWC. NO BOP. NU 11"x4-1/8" tubing head adapter and 4-1/8" tree. Test tubing head adapter and tree to 5000 psi. Pull TWC. 9. Freeze protect well to 2500' MD with warm diesel 10. Install BPV. Secure well. 11. Rig down and prepare to move rig to KRU. RECEiVED FE8 C 1 2000 AIda 011 & GlaCont. 0Hmn1lalQn Anchorage WAllhp.;ul: 11" 5M MP FMC Phase 1 w/11" x 4.5" NSCT pin x NSCT lift threads Tubing Hanger w/4" CIW H SPV Installed 4" 5M Tree Installed 133/8",48#, H-40, BTC I 108' 4.5" 12.61b/ft L80 IBT Tbg Kill String 1 2684' 1 DIRECTIONAL PLAN (PROPOSED PLAN Wp7) KOP @ 7,100' Max. hole angle = 55° at KO Window MPC-12Ai ACTUAL SUSPENSION Cellar Box Elevation: 17.1' Rig RKB Elevation: 30.00' Operations Shutdown Jan 30, 2000 . 1 ~ a.. u. ã) UJ Q) is RECEiVED rES (, 1 2000 _1I1_C«Is.~ RnChorage 1 6,751' 1 7" x 41/2" Baker Liner Hanger Pkr Cement KO Plug Halliburton EZSV Window Section, 7,067' TO 7,117' 110,228'1 Baker PBR Seal Assy. 10,242'1 BOT 7", 'HB' Packer 4-1/2", 12.61b/ft, L-80 IBT-Mod BOT 7", '2-B' Packer Pumped 23.6 bbls (113 sx) cement Tubing Tail 10,876'1 PBTD (wireline tag) HOLE ANGLE at TO: 1 SO DATE 1/31/00 REV. BY FJ Baker TTRD Whipstock set at 8780' (top) Top of Fish 8736' PBTD 1 8,838' 1 Liner depth 1 8,924' 1 TD I 8,933' I COMMENTS Mil NF POINT II NIT W~II ~-1?Ai API Nn: ~n-n'Q-'1 ~73-n1 Actual Suspension BP EXPLORATION AK Re: MP C-12A Shutdown of Operations Permit 99J ') ) k Subject: Re: MP C-12A Shutdown of Operations Permit 99-091 Date: Mon, 31 Jan 2000 12:20:00 -0900 From: Blair W ondzell <blair _ wondzell@admin.state.alcus> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Johnson, Frederick C (ARCO)" <JohnsoFC@BP.com> Fred, Thanks for the e-mail. Will look forward to the 403. Blair "Johnson, Frederick C (ARCO) " wrote: > Well: MP C-12A > Drilling Permit: > > > > > > > > > > > > > > > > > > > > > > > > > > > 99-091 Operations Update As discussed on the telephone today the Nordic 3 operation on well MP C-12A has encountered several downhole tool failures and the Asset has requested that we suspend our drilling operations at the present time. We moved back on to the well 10 days. ago with the intention of drilling out the 4-1/2" float equipment and cement, drill to TD, and complete the well in the Kuparuk reservoir. While attempting to drill out the landing collar the downhole motor broke leaving a fish on top of the landing collar. Two fishing trips to recover the fish were unsuccessful in getting over the fish and additional fishing work was deem to be futile. The decision was made to set a whipstock above the fish and mill a window to allow drilling to TD. A cement bond log was run which verified good cement at the window and good zonal isolation above the window. The whipstock was then set at 8780'. Two trips were made to attempt the window milling but both trips failed and no window milling was done. The first run failed due to a plugged mill and the second trip failed due to a washout in the PBL circulating sub. The float equipment and cement have not been drilled out and the window has not been milled. The 7" casing and 4-1/2" liner have been pressure tested. We will be suspending operations on the well and leaving the well full of seawater and freeze protected. A kill string is planned to be run to 2500'. Verbal approval for a "Opera tion Shutdown" was recei ved today and we will submit a 403 Sundry. MtE'VED L' þ,Í,! 3 1 2000 A1aIka Oö & GasCœs. CommiIion AndØa98 lofl 1/31/00 ) 2:2) PM ) ~- ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Robert Christensonf ~O Chairman DATE: January 28, 2000 TO: THRU: Blair Wondzell, ~ P. I. Supervisor { { "if /00 Cte John Crisp, c...-. Petroleum spector SUBJECT: BOP Test Nordic 3 MPU C-12AJ PTO 99091 FROM: .Januarv 28. 2000: I traveled to BPX Milne Point Unit C pad well # 12AJ to witness the weekly BOP test on Nordic 3. Testing started 2 ~ hours after my arrival @ Rig. One failure was witnessed, the manual valve on the choke line failed to hold pressure. Lighter than air & heavier than air gas detectors were tested. Lower pipe rams were not tested due to test plug to test joint cross over problems. The Rig was notified during the final stage of testing that Nordic 3 would do no further work on this well after casing was tested. This Rig is scheduled to move to Kuparuk for next well. AOGCC test sheet is attached for reference. 24 hour notification for this weekly test was not given. SUMMARY: I witnessed weekly BOP test on Nordic 3 for BPX @ MPU C-12AJ. Tested BOPs on Nordic 3. One failure witnessed. Test time 3 hours. Attachments: BOP Nordic 3 1-28-00jc cc; NON-CONFIDENTIAL BOP Nordic 3 1-28-00jc I,t ) ~- STATE OF-ÁLASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 4 1/2" Test: Initial Workover: Nordic Rig No. 3 PTD # 99091 Rep.: Rig Rep.: Location: Sec. 10 T. BPX MPC-12AJ Set@ Weekly X 9,509 Other TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: ~ (Gen) PTD On Location YES Standing Order Posted YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Well Sign Dr!. Rig Hazard Sec. FLOOR SAFETY VALVES: Upper Kelly IIBOP Lower Kelly IIBOP Ball Type Inside BOP ') DATE: Rig Ph.# Tom Anglen Shane McGheehan 11N R. 10E 1/28/00 659-4163 Meridian UM YES OK YES Quan. Test Press. P/F 1 250/3,500 P 1 250/3,500 P NOT TESTED 1 250/3,500 P 1 250/3,500 F 1 250/3,500 P 2 250/3,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Nitgn. Btl's: Test Quan. Pressure P/F 1 250/3,500 P 1 250/3,500 P 2 250/3,500 P 2 250/3,500 P Test Pressure P/F 11 250/3,500 P 36 250/3,500 P 1 Functioned YES - - 1 Functioned YES 2 3,000 1,650 minutes 28 sec. minutes 2 sec. Remote: X Visual OK OK OK TESTED TESTED Alarm OK OK OK TESTED TESTED Master: X 4 btls. @ 2000 psi. ave. Psig. TEST RESUL T8 Number of Failures: 1 ,Test Time: 3.0 Hours. Number of valves tested ~ Repair or Replacement of Failed Equipment will be made within N/U BOP days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Test BOPs while BPX decides to continue well or abandon for coil Tbg. Drilling. Well cased & tested, will move off for coil tbg. drilling. Distribution: orig-Well File c - Oper.lRig c - Database c - Trip Rpt File c - Inspe~æ~1L (Rev.12194) STATE WITNESS REQUIRED? YES X NO Waived By: Witnessed By: 24 HOUR NOTICE GIVEN YES X NO cn!:) ",. 'die 3 1-28-00je John Crisp .f ) STATE OF ALASKA ) ALASKA ùlL AND GAS CONSERVATION COI\IÎ'MISSION APPLICATION FOR SUNDRY APPROVAL ~ \()i-ro {3 Cü 1. Type of Request: D Abandon D Suspend D Plugging D Time Extension D Perforate D Alter Casing D Repair Well D Pull Tubing D Variance D Other D Change Approved Program D Operation Shutdown ¡g] Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4961 NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 2891 NSL, 2348' WEL, SEC. 03, T13N, R10E, UM At effective depth 5. Type of well: D Development D Exploratory D Stratigraphic ¡g¡ Service 6. Datum Elevation (DF or KB) Plan KBE = 45.60' 7. Unit or Property Name Milne Point Unit (Planned) 8. Well Number MPC-12Ai 9. Permit Number 199-091 / 399-234 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands At total depth 4611 NSL, 23501 WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary (Planned) Total depth: measured 8933 feet Plugs (measured) true vertical 6943 feet Effective depth: measured 8838 feet Junk (measured) true vertical 7603 feet Casing Length Size Cemented Structural Conductor 80' 13-3/8" To Surface Surface 6034' 9-5/8" 1625 sx PF 'EI, 250 sx Class 'G1 Intermediate Production 109221 7" 300 sx Class 'G' (Top of srr Window) Liner 21731 4-1/2" 113 sx Class 'GI MD TVD 108' 60701 108' 4703' 7060' 6751' - 8924' 52911 5143' - 69261 true vertical None RECEIVED DEC 29 1999 0RI,"", !(~,/" Alaska Oil & Gas Cons. comll\ll8ln'''''' /i'" ~!/11 Anchorage t' /'1 <. Perforation depth: measured None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments ¡g¡ Description summary of proposal 14. Estimated date for commencing operation January 5, 2000 16. If proposal was verbally approved D Detailed operations program 15. Status of well classifications as: D BOP sketch DOil DGas ¡g¡ Suspended Name of approver Contact Engineer Name/Number: Date approved Service Water & Gas Injector 17. I ~erebY ceZZi hat t Signed ,. Ch "' Fred Johnson, 564-5427 oing ¡rand correct to the best of my knowledge Prepared By Name/Number: Terrie Hubble, 564-4628 Title Senior Drilling Engineer Commission Use Only Notify Commissi 0 representative rt'jY witness I Approval N0·.J7f -eJ.t1Lk Plug integrity _ BOP Test -À- Location clearance _ 7 Mechanical Integrity Test ~ Subsequent form re~ed 10- 4."0'\ (\ GO .JRiGtNAl SIGNED BY ..xo...¡e eÒ . . . . ilobort N. Ghristenson 1~...9'Q ~0\\).~~/ Commissioner Xy Date IZ/z. c¡ /t 'l Conditions of Approval: Approved by order of the Commission Form 10-403 Rev. 06/15/88 Date / -;l-OÕ Submit In Triplicate ) ) MPC-12Ai Operations Summary Pre-RiQ Operations None Snapshot of Well Pro~nam 1. MIRU Nordic 3 2. ND tree. NU and test BOP 3. MU 3-3/4" BHA , RIH tag cement. 4. Displace well to 11.6 Ib/gal mud. 5. Drill out cement and float equipment. Drill 20' of new hole and perform FIT. 6. Drill to planned TO. 7. Run and set 2-7/8" slotted liner. 8. Run 3 Y2" NSCT tubing and packer completion 9. ND BOPE, NU tree. 10. Set packer. Displace mud out of tubing and annulus. Freeze protect well. 11. Release rig 12. Run CBL thru tubing after rig release I11BE'VED DEC 291999 ,.01 & GasQlns· CommieIion AndØ8!J8 )) I Well Name: IMPC-12Ai Well Plan Summary I Type of Well (producer or injector): IIWAG Injector I Surface Location: Target Start: Intermediate Target End: I AFE Number: 496' NSL, 2027' WEL, Sec. 10, T13N, R10E, UM X = 558,438.05 Y = 6,028,781.55 289' NSL, 2348' WEL, Sec. 3, T13N, R10E, UM X = 558,069.11 Y = 6,033,850.38 Z = 7,015' TVDss 461' NSL, 2350' WEL, Sec. 3, T13N, R10E, UM X = 558,065.20 Y = 6,034,022.79 Z = 7,446' TVDss 1337160 I Rig: 1 Nordic 3 I Estimated Start Date: I Jan 5, 2000 1 Operating days to complete: I 6 I MD 19,504' 1 TVDrkb: 17,482' I KBE: 147.9' Well Design (conventional, slim hole, etc.): Pre-produced Injector Objective: Drill out of existing 4-1/2" liner into the Kuparuk Formation, directionally drill 3-3/4" hole thru the Upper Kuparuk formations to Kuparuk 'c' & 'A' sands target, TD well 150' into the Miluveach Shale Formation. Run and set 2-7/8" slotted liner, complete with 3 Y2", L-80, premium thread tubing and gas lift mandrels. Run cement bond log post riQ. Well Name: API Number: Well Type: Current Status: Last H2S Sample: Cement: TD / PBTD: BHP: BHT: Is this well frac'd? Mechanical Condition: MP C~ 12A Wellhead: Nordic 3: Tubing: Liner: Casing: Casing Head: Casing Hanger: Current Well Information MP C-12AI 50-029-21373-01 Pre-produced IWAG Injector 4-1/2" Liner set at top of Kuparuk at 8924'MD o ppm Estimated TOC behind the 4-1/2" production liner is 7924' 8933' I 8838' 4,100 psi at Kick zone Calculated from SIDP pressure (11.34 Ib/gal equivalent) 170°F@ 7,500' ss Estimated No ÀÏCE\VED Cellar Box MSL = 1704' r :: (' 29 1999 KB / MSL = 47.9' .. I..V ~~~: A1aIÞOö & Gas<'Aos· Comm\IIiOn Surface: 108' 133/8",48#, H-40, BTC Andlor898 Intermediate: 6,070',9-5/8",36# , L-80 BTC Production: 10,956',7",26#, L-80, BTC \-c~oç ~"~'ðc'Ñ Q '"\0 CoD' ~~ Liner: 6,751 '-8,924' 4-1/2", 12.6 Ibltt, L-80, IBT FMC 11" 5M FMC 10 %" BTC thread 7" Packoff: Tubing Head Adapter: Tbg. Hanger: Tree: Open Perfs: Casing Fluids: Target Estimates: Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Materials Needed: L-80 Intermediate: L-80 Production: L-80 Completion: ) Mandrel type FMC 11", 5M x 3 1/8" FMC 10" x 3 V2" BTC Pin x EUE lift threads C.I.W. 3", 'H' type BPV profile FMC 5M,3 1/8", 3 1/8" 8rd Treetop connection P&A'd on pre-rig 11.6 Ib/gal mud in 4-1/2" liner, Seawater with 2200' diesel cap in 7" casing ) Injector to sweep 1,210 MSTBO Injection rate: 1,000 bid Injection rate: 1,000 bid 800' 2-7/8" 15 2-7/8", 6.2Ib/ft, L-80, STL slotted liner Halliburton HPDJ float shoe Integral Blade Rigid Centralizers STL 7,000' 7" x 3-1/2" 3-1/2" x 1-1 12" Will run 'X' nipple 1 - 3 V2" 2 - 3-1/2" 3-1/2" 2 Each - 3-1/2" 3.5",9.3# , L-80 NSCT tubing Baker 'S-3' production packer Gas Lift Mandrels SSSV 'XN' nipple 'X' Nipple WLEG 10', 8', 6', 4', 2' NSCT space out pups ReCEIVED LEC 2919~9 A1a1D Oil & Gas Cœs. CommieIion AndKdge ) DrillinQ Hazards and ContinQencies ) 1) Well Control MANDATORY WELL CONTROL DRILLS: Drill D1 D2 D3 D4 D5 Type Tripping Drilling Diverter Accumulator Well Kill Frequency (1) per week, per crew (1) per week, per crew Prior to spud, per crew Prior to spud or RWO Prior to drill out, per crew Comments Conducted only inside casing. Either in cased or open hole. DO NOT shut-in well in open hole. Once per week per crew while drilling with diverter in place. Approx. every 30 days, thereafter at convenient times. Prior to drill out the intermediate and production strings. Never carry out this drill when openhole sections are exposed. · IN ALL CASES, ENSURE THAT THE DRILLS ARE CAREFULLY CARRIED OUT AND DO NOT EXPOSE EQUIPMENT, CASING OR FORMATION TO EXCESSIVE PRESSURES AND LOADS. · See BP Well Control Manual for all details of these drills. 2) Hydrogen Sulfide · MP C Pad is not designated as an H2S Pad. 3) Kick tolerance · The kick tolerance for the 3-3/4" open hole section would be infinite assuming an influx at the 9300', in the Kuparuk formation. This is a worst case scenario based on a 11.5 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 13.0 ppg below the 4-1/2" liner shoe with a 11.6 ppg mud in the hole. · FIT test to 13.0 Ib/gal minimum will be required. 4) Breathing · There have been several instances of 'breathing' under C pad. On Well C-39 'breathing' started while drilling the Kuparuk production zones. 'Breathing' occurred after cementing the 7" production casing on the same well. 'Breathing' often occurs in the Seabee Formation at Milne Point. The Seabee formation has been cased off in this well and breathing is not be expected. However, read and follow the 'breathing' RP to handle any 'breathing' problems. Losses and breathing did occur on this well while circulating the 11.6 Ib/gal mud. 5) Lost Circulation · There is a possibility for lost circulation on this well while drilling the Kuparuk sands with the 11.6 Ib/gal mud. The Kuparuk sands may be underpressured (8 Ib/gal) and loss circulation could occur due to the mud weight and ECD hydrostatic pressures. · Follow the LOST CIRCULATION DECISION MATRIX if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 6) Differential Sticking · There is a good possibility of differential sticking on this well. If the Kuparuk sands are at the prognosed 8 Ib/gal equivalent pressure, the mud will be 3.6 Ib/gal overbalanced to the formation pressure. This equates to 1350 psi differential pressure at 7200' TVD. · Keep the drillstring moving as much as possible. Minimize the time the drillstring or liner is not moving. 7) Faults · No faults predicted along directional well path. RittE\VED r:,C 29-,999 ~01t&GasCons. Conm\Ì8Sion And1ol398 ) ) 8) Hydrocarbons · Will be drilling out in the Kuparuk interval. Hydrocarbons should be expected in the Kuparuk IC' ,'B','A' sands. 9) Unexpected High Pressures · It is unlikely there will be higher pressures then already experienced on this well. The source of the higher pressure is thought to be from injection operations. There is a good posibility that the Kuparuk sands could be under-pressured. Hold a D2 kick drill prior to drilling into the Kuparuk Formation. 10) Shale Sticking and Bit Balling . Possible shale sticking problems drilling the rat hole in the Miluveach Shale. If shale sticking does occur use whatever time necessary to circulate the hole clean, wiper trip through the shale if needed and condition the mud as needed. 11) Pad Data Sheet . Please Read the Pad Data Sheets thoroughly. ReŒIVED [ E ~ 29 1999 AlllkaOìt.. Gal cœs. CommiIeion ~ ) ) Drillin~ Pro~ram Overview Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPC-12Ai. Close Approach Wells: Well Name None NONE - All wells may flow. There are no risky close approach issues. Current Status Production Priority I Precautions Well Control: Expected Formation Pressures & BOPE Test Pressures Production Mud Properties: LSND Density (ppg) Funnel vis 11 .6 45 - 55 Expected BHP 4200 psi, 7,200' TVD (estimated) Mud Program Max Exp Surface Pressure 3372 psi (.115 psi/ft gas gradient) BOPE Rating 5,000 psi WP (entire stack & valves) Planned BOPE Test Pres. 3,500/250 psi Rams and Valves 2,500/250 psi Annular 13-3/4" hole section YP HTHP 20 - 30 1 0 - 12 I API Filtrate 4-6 pH 8.5-9.0 Solids < 6% LG NOTE: See attached Baroid mud recommendation LCM Restrictions: None Waste Disposal: NO ANNULAR INJECTION. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Formation Markers Formation Tops THRZ BHRZ MK-19 TKUD TKUC TKUB TKUA TKA3 TKA2 TKA1 Miluveach MD 8,700 8,769 8,821 9,052 9,094 9,230 9,240 9,261 9,313 9,354 CasingfTubing Program TVDss Pore Psi EMW (ppg) Comments 6,665 6,730 6,875 7000 7,040 7170 7,180 7,200 7,250 7,290 rL.\ '1-;' \\"Q.(" t:¡ 2,900 7.97 2,916 7.96 2,966 7.96 2,970 7.96 2,978 7.95 2,998 7.95 %<;~~ ....... ~ b<:;rl.~' -\~ú ... u..~' ':.. b '6""\~ I.\,,~ ~) Kuparuk sands could be at the higher pressure already encountered above the Kuparuk interval AEŒ\VED [. ::..: 2 9 ",999 A1atb0\\ &; GasCOl\S· CommiII\on And\0t898 ) Hole Size Csgl Wt/Ft Grade Tbg O.D. 3-3/4" 41/2" 6.2# L-80 Tubing 31/2" 9.3# L-80 Conn length ) Top MDrrVD Btm MDrrVD STL NSCT 750' 6.920' 8,774'/6,792' 30'/30' 9,504'/7,482' 6,725'/5,125' Cement Calculations Liner Size 12-7/8" STL Basis None, Slotted liner to be run Total Cement Volume: Spacer Tail Temp BHST -1700 F from SOR, BHCT 1300 F estimated by Dowell Centralizer Placement: 1. Run (1) rigid integral blade centralizer per joint in open hole. Other Cement Considerations: 1. None Survey and logging Program 3-3/4" Section: Open Hole: MWD or ESS 1 GR 1 Res 1- Over entire interval. Sample Catchers - None! Cased Hole: CCll GR 1 CBT - static pressure. Bond log to be run Post Rig. Perforating: None, slotted liner completion. locations Perf Interval: Gun Size 1 Type: Delivery: Under Balance: BHP: BHT: ~'VED l':'.;: 2 9 ~\999 ..tli.Gasc.ts. ComnRBion Anchorage Bit Recommendations BHA Hole Size Number and Section Depths (MD) Bit Type Nozzle 1 Flow Rate K-Rev's Hours 3-3/4" 8,933' - 9,504' PDC 13-13-13: 100+ gpm Note: WAllhA~d: 11" 5M Milne pt. phase 1 wI 10" x 3.5" BTC pin x EUE lift threads Tbg. Hng. 3" CIW "H" BPV profile MPC-12Ai PROPOSED COMPLETION Cellar Box Elevation: 17.1 Rig RKB Elevation: 30.00' J . 133/8" 48#, H40, BTC I 108' I - ì 2,200' I 31/2" 'X' nipple, ID 2.750" J 3-1/2" X 1-1/2" Gas Lift Mandrels (6 each) Note: The completion tubing will be used for IWAG service. 95/8", 36#1ft, K-55, BTC. I 6,070' I / 7",26#, L-80, BTC 31/2" 'X' nipple, 2.750" ID Note: 3 1/2" WLEG will be stabbed into the 4 1/2" liner top. 31/2",9.3#, L-80, NSCT 7" x 31/2" Baker Production Pkr 7" x 41/2" Baker Liner Hanger Pkr Cement KO Plug Halliburton EZSV Window Section, 7,060' TO 7,110' DIRECTIONAL PLAN (PROPOSED PLAN Wp7) KOP @ 7,100' Max. hole angle = 55° at KO Window Hole angle thru' perfs = 8°- 6° 110,228'1 Baker PBR Seal Assy. 10,2421 BOT 7", 'HB' Packer 41/2 ", 12.6#/ft, L-80 IBT-Mod , ' , , ,I.. 4-1/2" Liner Shoe at 8,924' ',- , KUPARUK'C'SANDS RECE. .., IVeD Injection/Production Intervals < l, \ KUPARUK'A'SANDS r ::.... 2 9 í999 . L - \, 2-7/8", 6.16#1ft, L-80 STL Slotted Liner , , A1aIå Oil & Gas Cons. Commi8sion \ \ Anchorage PBTD 9,522' ~ HOLE ANGLE at TD: 5-10° TD 9,522' BOT 7", '2-B' Packer Tubing Tail 10,876'1 PBTD (wireline tag) DATE 9/01/99 12/27/99 REV. BY RMK FJ COMMENTS Proposed Injector Completion Proposed Open Hole Producer/Injector Completion .MII NF POINT II NIT W~II ~·1 'Ai API Nn: 50.0'9·'1373.01 BP EXPLORATION A ) ) C-12A slotted liner The reasoning behind running slotted liner and not cemented solid liner in C-12A is as follows: A cemented liner is not needed for hole stability. The sands are considered competent and the slotted liner should be sufficient to support any unstable shale. We want to inject into or produce from all sands. In other producers or injectors in the Kuparuk, these sands are all perforated. The liner size that can be run in the well is 2 7/8" or smaller. This limits economic techniques for profile modification if we should need to do any. We can shut off the deepest sands with a sand or cement plug with both cemented and slotted liner. In larger liner sizes we would have the option of shutting off shallower sands using a mechanical straddle if cemented. We cannot do so in this liner size as the tools do not exist. The only way to shut off shallower sands in this liner size is by cement squeezing. We can cement squeeze both slotted and solid liner, the solid liner being the more reliable, however the high cost of cement squeeze would not be economically justifiable for this well with either liner type. The slotted liner should have a higher PI than a cemented, perforated well if we decide to make it a producer. Since either liner type will allow us to operate the well, the cheaper option is preferred. REGE'VED L :.:: 29 í999 A1aIka OU & Gas Cons. CommiII\on Anc,torage IJ ) STATE OF ALASKA) ALASKA ulL AND GAS CONSERVATION COnti'MISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 1. Operations performed: D Operation Shutdown D Stimulate D Plugging D Perforate D Pull Tubing D Alter Casing D Repair Well fZI Other Temporary Suspension of Well 5. Type.o1 well: 6. Datum Elevation (DF or KB) U Development Plan KBE = 45.60' o Expl~rato~ 7. Unit or Property Name o Stratigraphic Milne Point Unit fZI Service 99519-6612 At total depth 461' NSL, 2350' WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary (Planned) 8. Well Number MPC-12Ai 9. Permit Number I Approval No. ''''''' 199-091 399-234 ~ 10. API Number ~ 50-029-21373-01 11. Field and Pool Milne Point Unit I Kuparuk River Sands 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 289' NSL, 2348' WEL, SEC. 03, T13N, R10E, UM At effective depth (Planned) Total depth: measu red 8933 feet Plugs (measured) true vertical 6943 feet Effective depth: measured 8838 feet Junk (measured) true vertical 7603 feet Casing Length Size Cemented MD TVD Structu ral Conductor 80' 13-3/8" To Surface 108' 108' Surface 6034' 9-5/8" 1625 sx PF 'E', 250 sx Class 'G' 6070' 4703' Intermediate Production 10922' 7" 300 sx Class 'G' (Top of srr Window) 7060' 5291' Liner 2173' 4-1/2" 113 sx Class 'G' 6751' - 8924' 5143' - 6926' Perforation depth: measured None true vertical None ORIGINAL Tubing (size, grade, and measured depth) None Treatment description including volumes used and final pressure ,,,. '.'"' ' .v 'I"'" r· ~." ..", ',' ~ I~ \R ~fç\i: \1 J'f Ð "'C.¡ \~~ t.} ,J." '0 . ,',,-', ¡i')\"" . "'.. ,CùO" CrrmO\;:);) '-'f': < r~l;;'$.K4. Ÿ,II ,~!-;t,Y~ I ,,<~~ \..:Ôm\mSSiQ.~;., p.,~~;!'" . tincnOTa:ùa -; <'.1ïc: Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments D Copies of Logs and Surveys run fZI Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed / . ~ . l' n ß £J ~ .. TerrieHubble/l.e~J~ Title Technical Assistant III Prepared By Name/Number: 16. Status of well classifications as: o Oil 0 Gas fZI Suspended Service Water & Gas Injector Form 10-404 Rev. 06/15/88 Date \2- 00-99 Terrie Hubble, 564-4828 ~ Submit In Duplicat~ Facility M Pt C Pad Dateffime 14 Sep 99 12:00-18:00 12:00-18:00 18:00 18:00-01:00 18 :00-0 1 :00 15 Sep 99 01:00 01 :00-03:30 01 :00-03:30 03:30 03:30-05:00 03:30-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-08:30 06:00-08:30 08:30 08:30-12:00 08:30-12:00 12:00 12:00-14:30 12:00-14:30 14:30 14:30-15:30 14:30-15:30 15:30 15:30-05:00 15:30-18:00 18:00 18 :00- 20: 30 20:30 20:30-22:00 22:00 22:00-05:00 16 Sep 99 05:00 05:00-06:00 Duration 6 hr 6 hr 7 hr 7 hr 2-1/2 hr 2-1/2 hr 1-112 hr 1-1/2 hr 1 hr 1 hr 2-1/2 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr 2-1/2 hr 2-1/2 hr 1 hr 1 hr 13-1/2 hr 2-1/2 hr 2-112 hr 1-I/2hr 7 hr 1 hr ) ') Progress Report Well MPC-12A Rig Nabors 4ES Page Date 1 01 December 99 Activity Derrick management Rigged down Drillfloor / Derrick Prep rig for move. Equipment work completed Move rig Rig moved 100.00 % move & spot rig on C-12 & Berm & trim rig. raise derrick & slip sand line & scope derrick. At well location - Slot Wellhead work Removed Hanger plug Rig lubricator & remove bpv. & read Pressure. tbg. psi. = 1200 psi. annulus = 500 psi. rig lines in cellar & take on water & spot tiger tank & load pipe shed with drill pipe. Equipment work completed Flow well Monitor well bore pressures let well U-tube to tiger tank until psi. to 0 & set twc. bleed back a total of 8-bbl. Observed well static Wellhead work Removed Tubing head spool Nipple down tree. Stopped: To hold safety meeting crew change. Wellhead work (cont...) Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi test waived by aogc Larry Wade. Wellhead work Retrieved Hanger plug Equipment work completed Pull Single completion, 3-1/2in O.D. Removed Tubing hanger rig floor & bolds & work tbg. to get hanger to floor & lay dn hanger work tbg. to 135 k pu wt = 87 k Equipment work completed Laid down 2100.0 ft of Tubing 67 joints laid out Circulated at 7310.0 ft displace well bore fluids with fresh water. Hole displaced with Water - 125.00 % displaced Laid down 10173.0 ft of Tubing recovered all tbg. & seal assy. (tbg. cut was 50 % effective Completed operations 3-1I2in. Drillpipe workstring run RECEIVED DEC 10 1999 Alaska Oil & Gas Cons. Comrni8stan Anchorage Facility M Pt C Pad Dateffime 05:00-06:00 Duration 1 hr 06:00 06:00-23:00 06:00-07:30 07:30 07:30-08:00 08:00 08:00-12:30 17 hr 1-1/2 hr 1/2 hr 4-1/2 hr 12:30 12:30-13:30 1 hr 13:30 13:30-16:00 16:00 16:00-17:00 2-1/2 hr 1 hr 17:00 17:00-20:00 3 hr 20:00 20:00-23:00 3 hr 23:00 23:00-06:00 7 hr 23:00-02:00 3 hr 17 Sep 99 02:00 02:00-06:00 4 hr 06:00 06:00-06:00 24 hr 06:00-06:45 3/4 hr 06:45 06:45-14:00 7-1I4hr 14:00 14:00-15:00 I hr 15:00 15:00-00:30 9-1/2 hr 18 Sep 99 00:30 00:30-03:30 3 hr ) ) I' Progress Report Well MPC-12A Rig Nabors 4ES Page Date 2 01 December 99 Activity Rigged up Drillstring handling equipment clean floor & rig up same to run HOWCO EZ drill Stopped: To hold safety meeting crew change 3-1/2in. Drillpipe workstring run (conL.) Rigged up Drillstring handling equipment Equipment work completed Installed Bore protector Equipment work completed Ran Drillpipe to 5000.0 ft (3-1/2in OD) mu Hes EZ drill cmt. retainer plug. & rih on singles Stopped: To hold safety meeting Held safety meeting safety stand down with nabors & bpa personell. Completed operations Ran Drillpipe to 7310.0 ft (3-l/2in OD) Stopped: At sub-assembly Set packer at 7310.0 ft with 4200.0 psi Set hes ez drill & set dn 25 k & psi. test to 4200 psi. ok. Packer set at 7310.0 ft Circulated at 7310.0 ft displace well bore fluids with section milling fluid. & spot 10-bbl. of 18.0 ppg. Hole displaced with Water based mud - 120.00 % displaced Pulled Drillpipe in stands to 0.0 ft Completed operations BHA run no. 1 R.I.H. to 7060.0 ft Make up Baker NO.5-section mill with ..572 TFA +bit sub+jars+8-4.75" dc's At Top of new hole section: 7060.0 ft Made up BHA no. 1 locate collar @ 7073' & begin section milling @ 7060' Initial cut out =I-Hr. Monitor well (stable) first cuttings to surface in 45-min 4720 strks. mill csg. 7060-7064' 15-# of iron recovered. Stopped: To hold safety meeting crew change. RECEIVED BHA run no. I (cont...) Serviced Mud pumps Equipment work completed C F.C 1 0 1999 Milled Casing at 7084.0 ft mill 7" csg. F/7064' to 7084' AlakaOtl&GasCons.eomm:ssion Observed 25.00 klb drag on connections Anchorage Worked toolstring at 7084.0 ft circ. 7& work tool string Completed operations Milled Casing at 7110.0 ft mill ssection F/7084' to 7110' Completed operations Circulated at 7110.0 ft cire. & run SWCC¡)S of low vis & hi-vis fluid to Facility M Pt C Pad Dateffime 03:30 03:30-06:00 06:00 06:00-09:00 06:00-08:00 08:00 08:00-09:00 09:00 09:00-06:00 09:00-12:45 12:45 12:45-16:30 16:30 16:30-18:00 Duration 2-1/2 hr 3 hr 2 hr 1 hr 21 hr 3-3/4 hr 3-3/4 hr 1-1/2 hr 18:00 18:00-19:00 1 hr 19:00 19:00-19:45 3/4 hr 19:45 19:45-21 :00 1-1/4 hr 21:00 21 :00-02:00 5 hr 19 Sep 99 02:00 02:00-06:00 4 hr 06:00 06:00-14:00 06:00-06:30 06:30 06:30-12:30 12:30 12:30-13:00 13:00 8 hr 1/2 hr 6 hr 1/2 hr ) ') Progress Report Well MPC-12A Rig Nabors 4ES Page Date 3 01 December 99 Activity clean section for sidetrack plug. Rec. total of Hole swept with slug - 300.00 % hole volume Pulled out of hole to 1329.0 ft on trip out of hole have only had one spot that had 15k over Stopped: To hold safety meeting crew change. BHA run no. 1 (cont...) Pulled out of hole to 321.0 ft & lay dn section mill & drill collars & jars. RECEIVED At BHA Pulled BHA BHA Laid out 3-1/2in. Cement stinger workstring run Ran Drillpipe in stands to 7110.0 ft Alaska Oil & Gas Cons. Commission rih & break circ. to confirm drill pipe not plugged. Anchorage Observed 25.00 klb resistance Washed to 7118.0 ft circ. & wash with kelly in to csg. stub. & would get down as much as 30 ' plus and was unable to keep . set mule shoe @ 7118' & prepare to set plug. Observed 35.00 klb resistance Batch mixed slurry - 22.000 bbl set plug. 5 bbl. h20+test +20 bbl. h20 +22 bbl. cl. g. 17.0 ppg.+6-bbl. h20 & put in place with 32 bbl. mud & sht dn pump & use C pump to pump 3.75 bbl. mud to balance plug. cemtn in place 1738 hrs. 9/18/99 Completed operations Pulled Drillpipe in stands to 5700.0 ft Completed operations Circulated at 5700.0 ft circ. 2-bottoms up @ 6.5 bpm 1100 psi. Hole displaced with Water based mud - 200.00 % displaced Injectivity test - 3.000 bbl injected at 800.0 psi Perf. hesitation sgz. in 200 psi. increments to 800 psi. & hold I-hr. & bleed back 2 bbl.s Unable to inject fluid Circulated at 5700.0 ft Circ. & wait on cmt. to build compression strenght for top tag. & test. Obtained reg. fluid properties - 100.00 %, hole vol. Singled in drill pipe to 6949.0 ft run to 6450 ' in stands & start single in with slow pump looking for cmt. top observed increase in pump @ 6750' & pumped bottoms up & observed no cmt. single in to 6949 & found hard cmt. & set compression to 15 k & increase of 400 psi. indicate good t Observed 15.00 klb resistance 3-1/2in. Cement stinger workstring run (cont...) Circulated at 6949.0 ft Hole displaced with Water based mud - 125.00 % displaced Laid down 6949.0 ft of 3-1/2in OD drill pipe 234 joints laid out Removed Bore protector Equipment work completed F"; ;~c C 1 0 1999 l" I., 0# Facility M Pt C Pad Dateffime Duration 13:00-14:00 1 hr 14:00 14:00-19:00 5 hr 14:00-17:00 3 hr 17:00 17:00-18:00 1 hr 18:00 18:00-19:00 1 hr 19:00 19:00-20:30 1-1/2 hr 19:00-20:30 1-1/2 hr 20:30 20:30-21:00 1/2 hr 20:30-21:00 1/2 hr 21:00 21 :00-22:30 1-1/2 hr 21 :00-22:30 1-1/2 hr 22:30 22:30-06:00 7-1/2 hr 22:30-23:30 1 hr 23:30 23:30-00:00 1/2 hr 20 Sep 99 00:00 ) ) Progress Report Well MPC-12A Rig Nabors 4ES Page Date 4 01 December 99 Activity Serviced BOP stack Wash iron out of bop stack Equipment work completed 3-1/2in. Surge string workstring run Ran Tubing to 2015.0 ft (3-1/2in OD) ran 65-jts. tbg. for kill string. At Setting depth: 2015.0 ft Installed Tubing hanger Tie-down bolts energised Serviced Multipurpose tool repair rilds Equipment work completed Nipple down BOP stack Removed BOP stack set twc & rig dn bop's Equipment work completed Wellhead work Serviced Hanger plug Change out 4- RILDS & test. Equipment work completed Wellhead work Installed Xmas tree Install tree & test same to 5000 psi. & pull twc & set bpv. Equipment work completed Fluid system Freeze protect well - 75.000 bbl of Diesel Completed operations Cleared Circulating head FLlush out & blow dn lines & secure tree & cellar. Equipment work completed Rig Released @ 0000 hrs. 1/19/99 RECEIVED [:'cC 10 1999 Alaska 01\ & Gas Cons. Commission Anchorage Facility M Pt C Pad Dateffime 31 Oct 99 02:01-06:00 02:01-06:00 06:00 06:00-08:30 06:00-08:30 08:30 08:30-09:00 08:30-09:00 09:00 09:00-14:00 09:00-13:00 13:00 13:00-14:00 14:00 14:00-16:00 14:00-15:00 15:00 15:00-16:00 16:00 16:00-17:30 16:00-17:30 17:30 17:30-18:00 17:30-18:00 18:00 18:00-21:00 18:00-21:00 21:00 21 :00-21 :30 21:00-21 :30 21:30 21 :30-22:00 21 :30-22:00 22:00 22:00-23:00 22:00-23:00 23:00 23:00-01:30 23:00-01:30 Duration 3-3/4 hr 3-3/4 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 5 hr 4 hr 1 hr 2 hr 1 hr 1 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 2-1/2 hr 2-1/2 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 1 30 November 99 Activity Move rig Rig moved 100.00 % Move rig fl MP L-16A to MP C-12A. Rig accepted @ 0600 10/31/99. At well location - Cellar Move rig (cont...) Rig moved 100.00 % PJSM waite on pad operater wI Unit pennit. Move rig over C-12Ai. Beann liner arouuund rig. At well location - Cellar Wellhead work Removed Hanger plug Equipment work completed Fluid system Fill pits with Fresh water Completed operations Circulated at 2020.0 ft Displace diesel with water. Hole displaced with Fresh water - 100.00 % displaced Wellhead work Installed Hanger plug Install BPV and test to 1000 psi from bottom Equipment work completed Rigged down Xmas tree ND tree Equipment work completed Nipple up BOP stack Rigged up BOP stack NU BOP 11" 5000 psi BOP Equipment work completed Wellhead work Retrieved Hanger plug Pull BPV and install TWC Equipment work completed Nipple up BOP stack Tested All functions Test BOP 250/3500 Ann 25/2500 Test TPR 250/5000 Witness waived by AOGCC Chuck Schieve Function test completed satisfactorily Planned maintenance Serviced Top drive Service top drive and replace saver sub Equipment work completed Wellhead work Removed Hanger plug Pull TWC. PU landing jt. PU tbg hanger to rig floor. Up wt. 35k Equipment work completed Fluid system Circulated at 2020.0 ft Circ. 70 deg fresh water to warm up wcllborc Hole displaced with Fresh water - 150.00 % displaced Pull Tubing, 3-1/2in O.D. Laid down 2020.0 ft of Tubing LD 65 jts RECEIVED [:~~c 10 1999 Alaska Oil & Gas Cons. Commission Anchorage mi Facility M Pt C Pad Date/Time 01 Nov 99 01:30 01 :30-02:30 01:30-02:30 02:30 02:30-06:00 02:30-06:00 06:00 06:00-05:30 06:00-06:30 06:30 06:30-09:00 09:00 09:00-10:00 10:00 10:00-13:00 13:00 13:00-14:00 14:00 14:00-14:30 14:30 14:30-15:30 Duration 1 hr 1 hr 3-1/2 hr 3-1/2 hr 23-1/2 hr 1/2 hr 2-1/2 hr 1 hr 3 hr 1 hr 1/2 hr 1 hr 15:30 15:30-16:00 1/2 hr 16:00 16:00-20:00 4 hr 20:00 20:00-23:00 3 hr 23:00 23:00-03:00 4 hr 02 Nav 99 03:00 03:00-05:30 2-1/2 hr 05:30 05:30-06:00 1/2 hr ) ") Progress Report Well MPC-12A Rig Nordic3 Page Date 2 30 November 99 Activity Completed operations Wellhead work Installed Wear bushing Loading 3 1/2" OP in shed, change out tbg tongs. RU OP spinner Equipment work completed BHA run no. 1 Made up BHA no. 1 PU BHA and load/strap OP in pipe shed BHA no. 1 made up BHA run no. 1 (cont...) Serviced Top drive Service rig, block, crown & top drive Equipment work completed Singled in drill pipe to 4005.0 ft P/U OP RIH to 4005' Stopped: To circulate Circulated at 4005.0 ft Circulate out Milling fluid with SWat 4 bpm. Obtained req. fluid properties - 100.00 %, hole vol. Singled in drill pipe to 6863.0 ft Continue P/U 3.5" OP Stopped: To circulate Circulated at 6863.0 ft Circulate out Milling fluid wI SW Obtained req. fluid properties - 100.00 %, hole vol. Drilled cement to 6950.0 ft CIO cement stringers fl 6863 to 6950' Completed operations Tested Casing - Via annulus and string Test bottom pipe rams to 250/3500 psi. Bled off change to top pipe rams & test 7" csg to 4500 psi fl 30 min O.K. Pressure test completed successfully - 4500.000 psi Held drill (Kick (well kill» 05 drill 39 sec AMAS 1 min 2 sec Completed operations Drilled cement to 7076.0 ft Continue to CIO Firm cmt f/6863' to 7076' 9' below top of 7" section. Completed operations Circulated at 7076.0 ft Pump Hi-vis sweep 30 bbl. Change oover f/ Sw to Orlg fluid @ 5 bpm. Up wt 105K, On wt 70K, RT wt 95K Hole displaced with Water based mud - 120.00 % displaced Pulled out of hole to 805.0 ft POOH stand back 65 stands of 3.5" OP. At B HA Singled in drill pipe to 3041.0 ft PIU 93 jts of 3.5" Op RIH 93 joints picked up Repair RECEIVED f\;':r 1 0 1999 ".' .'. ~ ItS Alaska Oil & Gas Cons. Comnission Anchorage mi Facility M Pt C Pad Dateffime 05:30-06:00 06:00 06:00-11 :00 06:00-07:00 07:00 07 :00-11 :00 11:00 11 :00-06:00 11 :00-14:30 14:30 14:30-15:30 15:30 15:30-20:30 20:30 20:30-01 :30 03 Nov 99 01:30 01 :30-02:30 02:30 02:30-06:00 06:00-01:30 06:00-23:30 23:30 23:30-00:00 04 Nov 99 00:00 00:00-01:30 01:30 01 :30-06:00 01:30-02:00 02:00 02:00-02:30 Duration 1/2 hr 5 hr 1 hr 4 hr 19 hr 3-1/2 hr 1 hr 5 hr 5 hr 1 hr 3-1/2 hr 19-112 hr 17-112 hr 1/2 hr 1- 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr ) ) Progress Report Well MPC-12A Rig N ordic3 Page Date 3 30 November 99 Activity Repaired Drillstring handling equipment Repair tong line Equipment work completed BHA run no. 1 Serviced Top drive Service top drive, blocks, and crown. Equipment work completed Pulled out of hole to 0.0 ft POOH. LID bit and B/S. At top of check trip interval BHA run no. 2 Made up BHA no. 2 PIU bit, motor, and MWD. Oreint motor and MWD and test same. OK. Conitnue GIH with BHA. BHA no. 2 made up Held safety meeting Hold pre-spud meeting with all personnel associated with well. Completed operations R.I.H. to 7076.0 ft Finish GIH with drill pipe and tag cement kick-off plug. On bottom Drilled to 7350.0 ft Orient motor and kick off of plug (3 1/2 hrs). Detected casing stub with resistivity tool after getting kicked off. Continue drill/slide to 7350'. Top drive failed - Pull back to shoe Serviced Top drive Top drive saver sub started leaking. Change out same. Equipment work completed Drilled to 7400.0 ft Continue to drilllslide from 7185' to 7400'. BHA run no. 2 (conL.) Drilled to 8834.0 ft (conL.) Continue to drilllslide from 7185' to 7400'. Stopped: To circulate Circulated at 8834.0 ft Circulate hole clean. MW at 9.6 ppg Hole swept with slug - 100.00 % hole volume Drilled to 8933.0 ft Observed well flowing while taking SPR after making connection. Well shut in. In 0.08 hr had 12.000 bbl Gain - closed in well Well control Monitor wellbore pressures Well shut in on the annular RECEIVED r.~EC 1 0 1999 Alaska Oil & Gas Cons. Com nis$ion Anchorage Observed pressures - string: 630.000 psi, annulus: 860.000 psi Bit depth 8933' MD 6943' TVD Estimated top of Kuparuk 0 Shale 8942' MD Cleared Kellyltop drive hose Begin weighting up to KWM 11.6 ppg. Attempt to circulatc. Standµipc/kcIly hosc frozcn. Began precautionary measures Cleared Standpipe manifold Close upper / lower kelly cocks to remove kelly hose. RID kelly hose. Begin thawing kelly hose. Equipment work completed Well control (conL.) Cleared Kelly/top drive hose Finish RID kelly hose and start thawing out same. RID 2" high pressure circulating hose to top drive and test to 4500 spi. OK. Equipment work completed Cleared Kelly/top drive hose Attempting to thaw out top drive and top drive kelly cock valves. No success. Weight up mud in pits from 10.6 to 11.6 while thawing out. Equipment work completed Cleared Kelly/top drive hose RID HB&R and attempt to pump methanol thru frozen lines / valves while continuing to attempt to thaw lines with steam. Equipment work completed Held safety meeting Perform a risk anaylsis regarding the forward planes) to thaw out the top drive. Completed operations Cleared Kelly/top drive hose RID and pump 3 bbls mud down annulus. Pump in at 13.6 EMW. Equipment work completed Cleared Kelly/top drive hose No success with steam thawing operations. Shut down same. Remove 2" high pressure hose and re-fill with fresh neet methanol vs the 50:50 blend. Install air ducting around drill pipe from rig floor to elevators. Equipment work completed Wrap visqueen around from elevators to the top of Alaska Oil & Gas Cons, Commission the top drive. 2 portable tioga heaters and 1 rig Anchorage floor heater are supplying the hot air. By 0600 hrs the 2 kelly cock valves are thawed out and open. Continue pumping heat and attempting to pump methanol Well control (cont...) Cleared Kellyltop drive hose Top drive actually thawed out at 0530 hrs. SICP 930 psi. SIDP 630 psi. Equipment work completed Held safety meeting Hold PJSM on well kill. Review procedure and define responsibilities of crew. Completed operations Circulated closed in well at 8933.0 ft Begin circ 11.6 ppg KWM thru the choke. ICP 1580 psi. Csg press 930 psi. The initial circ press was higher than calculated because the SPR had been Facility M Pt C Pad Dateffime Duration 02:30 02:30-06:00 3-1/2 hr 06:00 06:00-06:00 06:00-09:30 24 hr 3-1/2 hr 09:30 09:30-14:30 5 hr 14:30 14:30-16:00 1-1/2 hr 16:00 16:00-16:30 1/2 hr 16:30 16:30-17:30 1 hr 17:30 17:30-06:00 12-1/2 hr ) ) Progress Report Well MPC-12A Rig Nordic3 Page Date 4 30 November 99 Activity RECEIVED 05 N ov 99 06:00 r ' :': t" 1 0 1999 ..' ..,. \,.1 06:00-13: 15 7-1/4 hr 06:00-06:30 1/2 hr 06:30 06:30-07:00 1/2 hr 07:00 07:00-08:30 1-1/2 hr Facility M Pt C Pad Dateffime 08:30 Duration 08:30-09:00 1/2 hr 09:00 09:00-11 :30 2-1/2 hr 11:30 11 :30-12:00 1/2 hr 12:00 12:00-13:00 1 hr 13:00 13:00-13: 15 1/4 hr 13:15 13:15-06:00 16-3/4 hr 13:15-14:00 3/4 hr 14:00 14:00-14:30 1/2 hr 14:30 14:30-16:00 1-1/2 hr 16:00 16:00-17:30 17:30 17:30-18:00 1-1/2 hr 1/2 hr 18:00 18:00-19:30 1-1/2 hr 19:30 19:30-21 :00 1-1/2 hr 21:00 ') ) Progress Report Well MPC-12A Rig Nordic3 Page Date 5 30 November 99 Activity taken with the kelly hose, and the well kill was done Began precautionary measures Stopped to weight up surface system. Unable to keep up with a 2 lb (9.6 to 11.6) weight up while circulati ng. Monitor wellbore pressures SI well at 4317 stks to wt up surface system to 11.6 ppg SIDPP 470 psi SICP 510 psi Freeze protect top drive Observed pressures - string: 470.000 psi, annulus: 510.000 psi Circulated closed in well at 8933.0 ft Continue well kill. Circ a total of 2 btm up. Unable to ever get 11.6 MW out. Max circ rate of 2 bpm lose returns. Experience barite sag. MW out ranged from 11.3 to 10.4. Began precautionary measures Monitor well bore pressures Shut well in to monitor pressures Observed pressures - string: 210.000 psi, annulus: 280.000 psi Circulated closed in well at 8933.0 ft ICP 520 psi. Csg press 10 psi. Shut down and bleed off pressure. No flow. Stopped: To flowcheck well Monitor wellbore pressures Observed well static BHA run no. 2 Pulled out of hole to 8840.0 ft Rig down thawing equipment. Break out stand and stab TIW. Blow down top drive. PU single. Shorten the 2" hose being circulated through to allow movement of the top drive. Began precautionary measures Held safety meeting Hold PJSM on opening the well and moving the pipe. Completed operations Circulated at 8873.0 ft Pipe free. Initial up wt. 140k. Down wt. 95k Hole packing off while circ. Locate free point and circ. staging pump to 45 SPM Began precautionary measures Pulled out of hole to 8255.0 ft Stopped: To circulate Circulated at 8255.0 ft Hole was taking the correct amount of fill, but began u-tubing back up the drill pipe side. Pump 25 bbls. Flow up drill pipe stopped. Broke circulation Pulled out of hole to 6800.0 ft Pull into casing. Hole in good condition. Hole taking correct fill. At Window: 7076.0 ft Circulate,d at 6800.0 ft .. .AlaskaOil&GasCons.Commieltan Circulate and condition mud. Attempt to Increase Anchorage rate to reduce barite sag. 108 bbls lost. Broke circulation RECEIV:,D ,-, .~.:: 1 0 19ý9 Facility M Pt C Pad Dateffime 21:00-22:30 Duration 1-112 hr 22:30 22:30-01:00 2-112 hr 06 Nav 99 01:00 01:00-03:00 2 hr 03:00 03:00-04:00 1 hr 04:00 04:00-06:00 2 hr 06:00 06:00-08:30 2-112 hr 06:00-07:00 1 hr 07:00 07:00-08:30 1-1/2 hr 08:30 08:30-04:30 20 hr 08:30-12:30 4 hr 12:30 12:30-14:30 2 hr 14:30 14:30-15:00 1/2 hr 15:00 15:00-04:30 13-1/2 hr 07 Nov 99 04:30 04:30-06:00 04:30-05:30 1- 1/2 hr I hr ') ) Progress Report Well MPC-12A Rig N ordic3 Page Date 6 30 November 99 Activity Flow check Monitor well. Constant rate of influx 0.6 bbl/5 min. Well is "flowing or breathing" not sure which. Lost 108 bbls lost while attempting circulate 11.6 mud around. Observed 7.500 bbl gain in annulus in 1.00 hr Pulled out of hole to 3481.0 ft POOH slowly monitoring well. Next 20 stds gained 17 bbls. Hole started taking mud at 1.6, 0.8, 2.1 bbls /5 stds respectively. At top of check trip interval Circulated at 3481.0 ft Circulate 11.6 mud around at 4 bpm with no losses. Initial MW out was 10.4. Obtained clean returns - 100.00 % hole volume Rigged up Kelly/top drive hose RID 2" high pressure circulating hose and R/U kelly hose. Able to trip and rack back drill pipe much easier with kelly hose. Equipment work completed Pulled out of hole to 882.0 ft Continue to POOH. Hole taking inconsistant hole fills. Monitor well each 5 stds pulled. No gainlloss. At BHA BHA run no. 2 (cont...) Pulled out of hole to 882.0 ft Finish POOH to BHA. At BHA Pulled BHA Download MWD /PWD and rack back BHA. Completed operations Run Liner, 4-1I2in O.D. Installed Well control Pull wear bushing. Change top rams to 4 1/2". Set test plug and test rams to 250-3500 psi. OK. Pull test plug. Set wear bushing. Well static. Equipment work completed Rigged up Casing handling equipment . Cle.an rig floor area fr~m wet trip. RlU 4 1/RECEIVE) casmg tools. Well statIC. Equipment work completed Held safety meeting r:E.C 1 0 1999 Hold pre-job for running 4 1/2" liner and well - control issues. Alaska Oil & Gas Cons. ComrÞission Completed operations Anchorage Ran Liner to 8924.0 ft (4-1I2in 00) P/U 52 jts 4 1/2" 12.60# L-80 IBTMod liner and run on 3 1/2" O/P. TOL 6751'. Shoe 8924'. Tag btm 8926'. Full returns running inside 7" csg. Lost 26 bbls running liner in open hole. Well static. while running liner. On bottom Cement: Liner cement Circulated at 8924.0 ft Establish injcction/circulation ratc. Initial ratc (i Facility M Pt C Pad Dateffime 05:30 05:30-06:00 Duration 1/2 hr 06:00 06:00-09:00 06:00-09:00 3 hr 3 hr 09:00 09:00-09:30 1/2 hr 09:00-09:30 1/2 hr 09:30 09:30-13:00 3-1/2 hr 09:30-13:00 3-1/2 hr 13:00 13 :00-00:00 11 hr 13:00-21 :30 8-1/2 hr 21:30 21 :30-00:00 2-1/2 hr 08 Nav 99 00:00 00:00-01:30 1-1/2 hr 00:00-01:30 1-1/2 hr 01:30 01 :30-02:00 1/2 hr 01 :30-02:00 1/2 hr 02:00 02:00-04:00 2 hr 02:00-04:00 2 hr 04:00 04:00-06:00 2 hr 04:00-06:00 2 hr 06:00-06:30 1/2 hr 06:00-06:30 J /2 hr 06:30 ') ') Progress Report Well MPC-12A Rig Nordic3 Page Date 7 30 November 99 Activity 0.4 bpm at 2900 psi. Pressure broke back. Continue Obtained req. fluid properties - 15.00 %, hole vol. Mixed and pumped slurry - 23.600 bbl 15 bbls 12.1 B45 spacer. Batch slurry 113 sks, 23.6 bbls, Wt 15.8, Yield. Displace with 11.6 mud at 4.6 bpm 1800 psi. Bump plug with 3200 psi and set hanger. 50% returns during job. Pressure to 4200 psi to set liner top packer. Check B PV. OK. Tail cement pumped Cement: Liner cement (cont...) Circulated at 6751.0 ft Release from hanger and circulate out. No cement in returns. Got back oil wet barite. Continue to circulate till clean with 11.4 in / out. Obtained req. fluid properties - 200.00 %, hole vol. Perfonn integrity test Tested Liner Pressure test liner top packer to 2000 psi for 15 minutes. Test OK. Pressure test completed successfully - 2000.000 psi Fluid system Circulated at 6751.0 ft Swap well out to corrosion inhibited seawater. RID liner swivel and blow down lines. Obtained req. fluid properties - 200.00 %, hole vol. Pull Drillpipe, 3-1/2in O.D. Laid down 6350.0 ft of 3-1/2in OD drill pipe POOH amd LID drill pipe used for running liner. Baker liner running tool OK and intact. 198 joints laid out Laid down 882.0 ft of Drill collar LID BHA out of derrick. E\VED Completed operations RE C .. Run Drillpipe, 3-1/2in O.D. Ran Orillpipe in stands to 2900.0 ft i.'" f" 1 0 1999 Run 30 stds drill pipe back in hole for freeze f'~. '''' On 1~~~~~' Alaska on & Gas Cons. Conmission Perform integrity test Anchorage Tested Casing Test 7" and 4 1/2" casing strings to 3500 psi for 30 minutes. Test OK. Pressure test completed successfully - 3500.000 psi Fluid system Freeze protect well - 85.000 bbl of ~iesel R/U HB&R and freeze protect well with 85 bbls diesel (2200' MO). RID HB&R. Completed operations Pull Orillpipe, 3-1/2in 0.0. Laid down 2900.0 ft of 3- J/2in 00 drill pipe POOH and LID drill pipe. Pull Orillpipe, 3- I/2in 0.0. (cont...) Laid down 2900.0 ft of 3- J/2in 00 drill pipe (cont...) POOH and LID drill pipe. 93 joints laid out mi Facility M Pt C Pad Dateffime 06:30-09:00 06:30-09:00 09:00 09:00-10:00 09:00-10:00 10:00 10:00-12:00 10:00-12:00 12:00 12:00-17:30 12:00-17 :30 17:30 17:30-18:30 17:30-18:30 18:30 18:30-06:00 18:30-20:00 20:00 Duration 2-1/2 hr 2-1/2 hr 1 hr 1 hr 2 hr 2 hr 5-1/2 hr 5-1/2 hr 1 hr 1 hr 11-1/2 hr 1-1/2 hr ') ) Progress Report Well MPC-12A Rig Nordic3 Page Date 8 30 November 99 Activity Fluid system Freeze protect well- 15.000 bbl of Diesel Toped offwell with 15 bbls disesel. Used test pump to diesel. Pulled wear ring Completed operations Wellhead work Installed Tubing hanger Install tbg hanger w/ T.W.C inplace. Equipment work completed BOP/riser operations - BOP stack Removed BOP stack N/D 11" BOPE Equipment work completed Wellhead work Installed Xmas tree NIU Adapter flange, Test pack off. No good remove and clean rings. Reinstall Test to 5000 psi O.K. Thaw out tree and install test 500 & 5000 psi O.K. Equipment work completed Wellhead work Rigged up Hanger plug Pull T.W.C and install BPV Equipment work completed Move rig Rigged down Drillfloor / Derrick Move rig off well. Pick up pit liner & clean around well cellar. Release rig @ 2000 hrs 11/8/99 Equipment work completed RECE\VED í\ ~:,... 1 0 1999 . ..... '\.., Ala.a 0\\ & Gas Cons. Commisßion An~orage · -....- ) ') - .0 ," TONY KNOWLES, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 2, 1999 Bill March Development Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Dear Mr. March: The Alaska Oil and Gas Conservation Commission (AOGCC) appreciates the time that you, Katie Nitzberg, Dennis Urban, Matt Kissinger, and Brian Huff spent with us on November 22nd discussing the C-12A well control situation. We are all interested in better understanding the geology and pressure regimes in the Milne Point Unit (MPU) C-Pad area, and your presentations were impressive and very helpful. Bob Crandall and I reviewed the AOGCC's files for the MPU C-22A, C-25 and L-07 wells. Unfortunately, these files do not contain the level of information that is needed to support our study. For C-22A, C-25, L-07 and any other MPU C-, E-, F- or L-Pad wells that have taken drilling kicks, could you please provide us with: 1. detailed well histories, 2. detailed mud weight versus depth information, and 3. any additional information that may provide insight into formation pressure within the HRZ/KalubiklKuparuk interval? We also understand that kicks have occurred while drilling in the Kuparuk River Unit Gas Storage Area. Could you also provide the above information for any wells that may have taken drilling kicks within the same geologic section? We appreciate your cooperation. If you have any questions or require additional information, please contact Mr. Robert Crandall or the undersigned at (907) 270-1433. Sincerely, Pz;tz_-~-~ c ..-' Steve Davies Petroleum Geologist .¡ ) " lQQ/cf1 ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Crandall Senior Petroleum Geologist Blair Wondzell P.I. Supervisor Date: November 22, 1999 File: MP~GeOlogy.dOC From: Steve Davies Petroleum Geologist Subject: MPU C-12A Well Control Situation - Geologic Evaluation On November 6, 1999, Paul Lockwood of BP notified John Crisp of AOGCC that the Milne Point Unit (MPU) C-12A well had taken a kick at a measured depth of 8,933 feet. The well bore was subsequently controlled using 11.6 ppg mud, a liner was run and cemented in place, and operations were suspended. C-12A lies north-northeast of the C-Pad. It is a sidetrack of C-12, a water injection well designed to provide pressure support for the offset Kuparuk production wells. C-12A is surrounded by C-3, C-4, C-7, C-10 and C-12 (see Figure 1). (-3 and C-4 were drilled in 1982, and C-7, C-10 and C-12 were drilled in 1985. The first four of these wells have complete log suites across the zone of interest. This zone was not logged in C-12 due to borehole problems. The MWD log from the lower portion of C-l2A is presented on Figure 2. Dual induction logs from the nearby C-4 and (-7 wells are presented on Figures 3 and 4. They illustrate the local stratigraphy of the northern MPU C-Pad area. The current maximum measured depth of 8,933 feet in the C-l2A borehole apparently lies in interlaminated siltstone and shale located just above the top of the Kuparuk D interval (Figures 3 and 4). The underlying Kuparuk D interval, should consist of firm to hard shale that is interlaminated with minor quantities of siltstone. Close examination of well logs from C- 3, (-4, (-7 and (-10 shows no indication of development of sand at this level. Review of the (-4 mudlog and the drilling histories from these four offset wells indicates that the weight of mud utilized to drill this interval ranged from 9.8 to 10.3 ppg, and was typically in the range of 10.1 to 10.3 ppg (see attached spreadsheets). BP's prognosis for the C-12A well indicates 9.2 to 9.6 ppg mud would be in the borehole while drilling this interval. Reportedly, the calculated mud weight needed to kill the kick in (-12A was 11.4 ppg, and 11.6 ppg mud was actually utilized to provide adequate safety margin for tripping pipe (Tom Maunder, AOG(C, personal communication). According to BP, offset production wells have not shown signs of response to water injection into (-12, and the Kuparuk reservoir within the (-12 fault block has pressured up to the equivalent of 11.6 ppg mud (Katie Nitzberg, BP, personal communication). Other nearby wells show pressure depletion within the Kuparuk reservoir. According to Ms. Nitzberg, BP had stopped to take a pressure measurement at the time of the kick. ) , AOGCC currently has a meeting scheduled with BP exploration representatives at 13:00 on November 22, 1999. The purpose of the meeting is to clarify rig operations at the time of the kick and to help us better understand the geology and pressure regimes present in the C-l2A area. Steve Davies Petroleum Geologist cc: T. Maunder, AOGCC I 149 34 OC 'tV o o o. -0 n o to ~~ ~ . ~A~U' OGA 50,ooe I '1} -~ I 149 3200 W i 149 3C 00 W --'---- - i I '_I ~ ;',_J ~ '_1." I ...~ I Ì""- --J o 0J o o o z MPUC-11 hlPU C-02 Ct~ c-- c=: MPU C-1 ì-¡--' ~ '<:'""i- --, r' -, ~ - --:- 1-'-- ! - I ,_ =- ;-- 560,000 I .- --:- ¡0~tJe£ (, 11/16/99 17:56 FAX 907 564 5193 .. .,.' G 'l . ......n..----... ... . ._._. , _ ._.. ..___ .' ..---'-'-'.. J, A ..- .-'.- .....- ..¡ . --.-.... .-.-' . "-' from: Sperry To: KatieNitzbêiQ- .' .-. r-,'- r- , \ f r f"\ ,:"J ~.. t ;- 1 \1 ;- I J./ r- \.... ....,. . í...~. ,:J\,: -',- "';"" ("~ 'r' , ': ~J~' --------------------......------------- .~:.,..:.<. L';i & Gas Cc;-.~. VV¡lIIíllssl~r! Ancharage MßP EXPb~~ATI~:-L----·:---:-.::. . .. ,~~:~~~, . .'.. ÒÔ/~~) ~ Date: 111"/99 lime: 7~' - . 0.2 141 002 Page 2 of: ohm-m Medium Phase EWR - (SEMP) 0.2 . .-...-....--- .......... .................. ........................... .............. .......... .---.--.... ......... Form Expos Time 2 hours - . 2 .2.õR..... .... ....... 0..0.... o....n ..........._..~~;;~;........ ....... 0 . ....... ...... ......... ....; Deep Phase EWR (SEDP) ROP Avg . (SROP) 1K , 0 .... . ..---..... -.---.. --.--. .......------.... -.----.... ------..-. feet per hr Gamma Ray Combined (SGRC) api ) 150 I-=-- / : ,! 150 Depth 0.2 300 _._-_.-.._--.-._.---._--.-._.~._-_._--.-._..--. I I p"-' .::~,..::_-z'" , -4._~~_ I :~ ~.-~:~ I ~~. .J- ~ ,:;~:. ;{ :..~",~1:r~ .' . ~;:~.. "; 11MZ~ 8700 .::; , ~ 1, I : ~.! 1"f' I- . r I ';""--T c::..........--. I I l I I I I I' o. ."'-:.":.;.:....~ 1 :~ . . ~ j- .~ ~ ·:'::....l 8800 ì .~~t",,- MlCICI ..c ,J-L- ,~.., ~ .. ~:~ ..\: ~ , ~ ..=.. ~ .. ::I I ; i -;-.. I ~ I ! :::wI I I SGRC'-+. I I f I ! I I I I ._.~~~ ~~. J I I I ¡ , " I I SROP -+ Þ.-... ". -----I---l__~ .Z,L I: 1----- 'l;' :;'-3 > ! , 'I ! I ~,::' ~''''''-_:!I ~ <., --- ,=;.~~~ ~~~ -.. <r-' .:..~ ------r~ - - 8900 0,2 , I -~ -' 11'1 ! II " +- SFXE I· ! I i ,I ,\ I ì I III' i I', Ii . j I· I ¡ j ,! ohm-m Shallow Phase ·EWR . (SESP) ohm-m X-Shallow Phase EWR (SEXP) III, Ii ; i r ¡ ì ! i ' t ¡ I j !! " - TI ','j -E- SEXP,SESP,SEMP,SEDP I I r I I ' I I' I I I ¡ I ' I 1+----. . ! : I II· ! - . ! 1 ¡ !! I I I ! 1 :L_.__ ohm-m I I ' \. Il ¡ ~ I , \ I ! ! ¡ rr : I . I . ' I I It - _. .... I'! Ii:; \: , ! ! ~. I I! ~-~~-- ;. +l ì ! I . .1.1 .. . 'I '1' l' :.. ; , , , ¡ . I I I I I . ~ I . r T1 j I I ¡Ii ~ I ; !, I l' I. {, . ¡ r :. :; I I' L~.,, i , !. : , ! '" I 11 II ,(, I I , , r-~. I\..\. I I I ,~'i! II ~¡ , . t' I "-, )- ~,) ,\ ';:=- I I I ~ I I \... I I ( II' ~L_--. I '> I ~ I ?"'-l ~:;-í ~ ¡ I .1 ! ¡ i ~ ; ¡ i I ! !: I I it;il! ~ ~; I I I r i ¡! ¡ - ~!... ~ ! r I . : ! I ¡ ¡ ; i 1,1 I ;! I ¡ :: ¡I I I : ¡ !.I' : ! ; ¡ ! ,- --l .. - -l-- i \ I ì I Ii ¡ Ib- ! I í I '- _ : ¡::'l9UE?E. 2 ~ \ ~ f i~ ~~ i , ~ I ,,-~ ~. '.~ 1< ~ :,.~ s~ I . S ~ -" 61 'tj>lW ~ ", ~ ~ ...- \~ 1. -----J-:- J I .,.- ~ ~ - ~ -- ::! ~ UOISSIWWo::> UOI:¡eAJaSuoJ Se!) 18 no e)!selV \. 0098 00¿8 a dn>l/.l )J!>I 'v'ZI-J JO uoqe:>°l 'xOJdd'v' -1<4 \ 0068 ) í ~ J dn)/.l ,/: , 0006 ( ,. , 0016 \ .,1 '. < NOI.L:>nONI lVnO HJ.d30 0311nSV3W t7-J ~INn ~NIOd 3N11W ( I I pa~ON SV E 3~n9I~ :õIe'JS O:lS :¡\q UM1!JQ 1dd'EaJn6!:!\ ~t -::>\pedJ\ndW \>truedn)\SJOOd\õKIoIS-4JON lVilN30I:lNOJ :~õIt!:I , t , I J ( I . t , I I ... '\ ~ , ì ì i ~ , . I I J J ( I , I ) I ,I t ,~ ¡ I i ~: ..J¡ ~I !'> I .;,ç-- J . I , -f' b l':=> ; ~ ! 'è r +--.. , , i i.s. ¡ f ' ~ ',- -+-·:,/1 .- L . I ~! I~ tr-t ~ : I ' i~! ,~ I ~! . :!it ! , :~i .;- ~ I : - ~ ~ ! ~ 11-' 11 ¡ If ; ..:..a- If j Alaska Oil &. Gas Conservation Commission '\ ;\1 : ¡ ,1-:'-' ~- .2- I: " I : i*MKR19 ~ 1,-, i : I . '" , .1-7- : ( : . ,~ -+-- ...... \- '''l}- 9100 , ...P ¡ ;!~ ~ ; J r. ~ ~ . (~, ' ! \, :~ I .þ ': (" i ,- , 9200 I , ., ; ~ : _ Approx. ~1 ~. Location \--:.- of C-12A I' . i~ Kick IS-i-T/Kup D <1 i {I-:- ~-'- 1 ! . /- 9300 , ~, , \ I, , 1\ : I -r--- iJ-;-::::. y , 9400 , i~ I \---- I \ ~ \' , I; I I' ~ ; J I ' ~_~-¡.. 'f/Kup C "C-. ! -- ~~ 9'00 '- .. ' ~ :~: i i ¡ ) I , I I ! . ; I ,., \ , , , ;!. ~I I \ I ': I I' i , i .... ~,., \' ..' , I, ~' I I I ¡ , I : I ~ " : I ) ¡, ,. ~ J ¡,II ~'f: ì : ~ ! 1 "!ill r:! ¡ii ~. (I r ¡ -& ! ¡ . ¡¡I , , ¡I i! MILNE POINT UNIT C-7 MEASURED DEPTH DUAL INDUCTION \ : " , i \ _ :~; '\, l \ \' ¡:' "I:n-- ,f I :¡¡ .-: 1:,: ¡:¡¡ ! f; I ¡ ,: II f: I ; 111 i I I ";' i ¡;,/iY- ,! I, I, I 1.1'j!~ r I,r I \,~ WL,i !~¡ I :::1L :1: : i ¡;it- \ i ;;:,] ) , , : I! I I:: ¡ (i ';); ! ,I :J ¡ ! :1: ¡ '.. I! ; l' I I : I I I J : I ,: I ¡ , :! ~; ¡ 1 : ) ; in-- ! :7~m_~, . :,--~,-~~:-:,Tl" - , ~, ; ! \, I' fr-._- ~ ¡II ~,':,I! II' i ~, :, :" ',: ... :_, -:--~n- I" ~.¡!, : ¡ ! +-- - , \ ' --rrt= '~¡. ! "I, ¡ ,/ i I' ,..;..+-- I & :," : I l----r_+_ - , !:: :r' ~.¡ ~ I,' '-+-I-- :,.1 f!, 'I~ i: ì I '\ ;,:~ ~) ,: I , ' t .: I ---; ~ : ' :¡r- . I 'I '~ I :n-- - ,CJ' -H- ;:: :4-. t ~ : I I : ~ i!: Ii i , : .' i I i ¡ !¡; ;l' : :+-- :~-;: ¡;I I : i: I I,' ), I '! ' ! ¡ : J : ! ! I i ~ ',': ,I '~ I :::; : ~ I ¡ t 1 ~ ' ~ ;! r '\1: ' !.4- I " ,I} ¡, ,:: ! 'I ~ ' .n--- I ¡: IJ : i ,:++- ; : <: ; , ; :t+-- I! ,< ; : 'It i~ ' ! ' ¡ ~ \.' . Ii ¡ i !lL_ Ji ! : iJL ';, ~ ~-4- :~, , , ) .. no ¡ ! , ! ¡ I ¡ I: I ; i; ¡ I ; ¡ . : I ¡; , , I j I! ¡ ,!:r , ; : \; ,'; ; ¡; ~ 1 I r I , I . CONADENTIAL Drawn by: Scale: As Noted , I, , I I ~ ' I' ii , : ,f--- , i ¡ I -r+- File Path: North_Slope\Pools\Kupal1Jk\ MPU\Cpad\C-l2A \Ftgure4.ppt SFD FIGURE 4 , \ MILNE POINT UNIT C-12A Comparison to Offset Wells Nov. 22, 1999 AOGCC CONFIDENTIAL Interval Thickness Comparison C-3 C-4 C-7 C-10 C-12 C-12A Marker I Sand M 19 - B/HRZ 75 110 100 99 No Log 70 C-12A Kick to M 19 127 T/Kup D to M 19 138 147 149 141 No Log ( 145) T/Kup C to T/Kup 0 129 149 145 146 158 ( 120) Mud Weight Comparison C-3 C-4 C-7 C-10 C-12 C-12A Marker I Sand M 19 - B/HRZ T/Kup D to M 19 10.1 9.8 10.3 T/Kup C to T/Kup 0 10.3 Kup B 10.1 C-12A Prognosis 9.2 to 9.6 Mud Weight Pressure on Formation Comparison C-3 C-4 C-7 C-10 C-12 C-12A Marker I Sand M 19 - B/HRZ T/Kup D to M 19 3666 3437 3832 4089 Est. T/Kup C to T/Kup 0 3650 Kup B 3795 C-12A Prognosis at T/Kup 0 3300 - 3450 C-12a_Comparison.xls Summary 11/22/99 9:15 AM \ \ MILNE POINT UNIT AOGCC C-12A Comparison Calculations CONFIDENTIAL Nov. 22, 1999 C-3 KB = 45 MD TVD TVDss Interv. Th. Calc. Press. Bf H RZ 7494 6576 6531 Mrk 19 7583 6651 6606 75 T f Kup D 7744 6789 6744 138 MW 10.3 7825 6859 6814 3650 T f Kup C 7893 6918 6873 129 Dir Data 7400 6496 6451 7500 6581 6536 7600 6666 6621 7700 6751 6706 7800 6837 6792 7900 6924 6879 C-4 KB = 52 MD TVD TVDss Interv. Th. Calc. Press. Bf H RZ 8540 6806 6754 Mrk 19 8667 6916 6864 110 MW 10.1 8800 7032 6980 3666 T f Kup D 8836 7063 7011 147 T / Kup C 9005 7212 7160 149 Dir Data 8500 6771 6719 8600 6858 6806 8700 6945 6893 8800 7032 6980 8900 7119 7067 9000 7208 7156 9100 7296 7244 C-7 KB = 52 MD TVD TVDss Interv. Th. Calc. Press. BfHRZ 8896 6716 6664 Mrk 19 9042 6816 6764 100 T f Kup D 9260 6966 6914 149 T f Kup C 9470 7111 7059 145 Dir Data 8700 6583 6531 8800 6651 6599 8900 6719 6667 9000 6788 6736 9100 6856 6804 9200 6925 6873 9300 6993 6941 9400 7062 7010 9500 7132 7080 C-12a_Comparison.xls Calculations 11/22/99 9:15 AM C-10 B/HRZ Mrk 19 MW9.8 T I Kup D T I Kup C MW 10.1 Dir Data C-12 MW 10.3 T I Kup D T I Kup C -, \ MILNE POINT UNIT C-12A Comparison Calculations Nov. 22, 1999 AOGCC CONFIDENTIAL KB = 52 TVD TVDss Interv. Th. Calc. Press. 7555 6653 6601 7687 6752 6700 99 7745 6796 6744 3437 7870 6893 6841 141 8052 7039 6987 146 8345 7278 7226 3795 MD 7500 7600 7700 7800 7900 8000 8100 6612 6686 6761 6838 6916.5 6996.7 7078.1 6560 6634 6709 6786 6865 6945 7026 KB = 52 MD TVD TVDss Interv. Th. Calc. Press. 10269 7206 7154 3832 10415 7289 7237 10710 7446 7394 158 10200 10300 10400 10500 10600 10700 10800 C-12A Prognosis MD B/HRZ Mrk 19 T I Kup D T I Kup C C-12A B/HRZ Mrk 19 Kick Dir. Data 7167 7224 7281 7335.7 7389.5 7441.3 7491.5 TVD 8689 6731 8759 6796 8915 6941 9044 7061 KB = 46 TVD TVDss 8730 6747 6701 8802 6816 6771 8933 6943 6897 MD 8700 8800 8900 9000 6718 6815 6911 7008 7115 7172 7229 7284 7338 7389 7440 TVDss Interv. Th. Calc. Press. 6685 6750 65 6895 145 3442 7015 120 Interv. Th. Calc. Press. 70 127 4089 6672 6769 6866 6962 C-12a_Comparison.xls Calculations 11/22/99 9:15 AM ì ) STATE OF ALASKA ) ALASKA úlL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~h\lr:r -<; C;õ 1. Type of Request: 0 Abandon i:8J Suspend 0 Plugging 0 Time Extension 0 Perforate o Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other 00 Change Approved Program 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration -(Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 289' NSL, 2348' WEL, SEC. 03, T13N, R10E, UM At effective depth 5. Type of well: D Development D Exploratory D Stratigraphic IZI Service 6. Datum Elevation (DF or KB) Plan KBE = 45.601 7. Unit or Property Name Milne Point Unit At total depth 461' NSL, 2350' WEL, SEC. 03, T13N, R10E, UM 12. Present well condition summary (Planned) 8. Well Number MPC-12Ai 9. Permit Number 199-091 10. API Number 50- 029-21373-01 11. Field and Pool Milne Point Unit I Kuparuk River Sands (Planned) Total depth: measured 8933 feet Plugs (measured) Abandon Perfs, Cement Top Tagged at 9551' (8/99) true vertical 6943 feet KlO Plug Cement Top at 70761 (11/99) Effective depth: measured 8838 feet Junk (measured) true vertical 7603 feet Casing Length Size Cemented MD TVD Structural Conductor 801 13-3/8" To Surface 108' 108' Surface 6034' 9-5/8" 1625 sx PF 'E', 250 sx Class 'G' 6070' 4703' Intermediate Production 10922' 7" 300 sx Class 'G' (Top of SIT Window) 7060' 5291' Liner 2173' 4-1/2" 113 sx Class 'G' 6751' - 8924' 5143' - 6926' true vertical None RECEIVED 0 'R/G;/4/.. A!aska~Oil & Gas Cons. Commission l~~nr~10rane NOV 12 1999 Perforation depth: measured None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments IZI Description summary of proposal D Detailed operations program D BOP sketch 14. Estimated date for commencing operation November 9, 1999 16. If proposal was verbally approved \ . _.\ ~ Tom Maunde~~~l.J.J'ò>'--r 1117/99 Name of approver Date approved Contact Engineer NameINumber: Mik Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I ~ereby cert~'f trfiÍ the ~regtj1' rue éY'fPf¢~ect to the best of my knowledge Signed í.LtÆ-iV~ .U~ .. . . Charles M lIary er Title Semor Dnlllng Engineer ( )Commission Use Only Conditions 8} ~proval: Notify Commission so repreSe"ntative may witness \,o\ed 0 Plug integrity _ BOP Test _ Location clearance ~?'P eò ~e\: \'t\ Mechanical Integrity Test _ Subsequent form required 10- ... ~ -~QS\~",\ o~ ~~<è.~«, \ \ ~ 'Q~ CIt.?Ç>\\~ -Çc, "''''l \"\C)::' T'\~~\ c..~ . - pproved by order of the Commission JRIGINAL 51GNFn RY Commissioner Form 10-403 Rev. 06/15/88 Robert N. Christenson 15. Status of well classifications as: DOil DGas IZI Suspended Service Date 1(- 1\ / q 9 I Approval No. ,!iff - ;J.~3 51 Date \ l-l'1-1J Submit In Triplicate of ) ) ~ hared ervices t. rilling Alaska ...' BP Exploration I ARGO Alaska Inc. MPC-12Ai Suspension Report Nordic 3 Gentlemen: This letter is in regards to the condition and forward plan for well MPC-12Ai. Current wellbore condition: A 6-1/8" hole was drilled to 8,9331 MD, approximately at the top of the Kuparuk '0' shale. At this point the well kicked while a connection was being made. After circulating out the influx and killing the well, a 4-1/2" liner was run to bottom and cemented. After the cement job, the liner, liner top packer and 7" casing was pressure tested to 3500 psi. The well currently stands suspended with 11.6 ppg mud in the 4-1/2" liner, corrosion inhibited seawater from the liner top back to freeze depth, and freeze protection from there back to surface. These suspensions activities were verbally approved by Mr T. Maunder of the AOGCC in telephone conversation with Mr. F. Johnson on 7 November 1999. Plan forward: The drilling rig has moved off the well. Planning activities will commence shortly to determine the best way to finish drilling this well to the permitted depth. ~Ctl~ M~ Operations Drilling Engineer Shared Services Drilling RECEIVED NOV 12 1999 Alaska,Oil & Gas Cons. Commission Anchorage Wellhead: 11" 5M Milne pt. phase 1 w/10" x 3.5" BTC pin x EUE lift threads Tbg. Hng. 3" CIW "H" BPV profile MPC-12Ai ÞCTIJAI... SUSPENSION Cellar Box Elevation: 1 7. 1 ' Rig RKB Elevation: 30.00' . 13 3!PJ', 48#, H40, BTC 1 108' 1 å 95/8", 36#Ift, K-55, BTC. I 6,070' I / 7',26#, L-80, BTC ~ Note: The completion tubing will be used for IWAG service. T X 4 112" Baker Liner Hanger Pkr Cement KO Plug Halliburton EZSV WindcNlSection,7,067TO 7,117 DIRECTIONAL PLAN (PROPOSED PLAN Wp7) KOP @ 7,100' Max. hole angle = 55° at KO Window Hole angle thru' perfs = 8° - 6° 110,228'1 BakerPBRSealAssy. 10,242'1 BOT 7', 'HB' Packer 41/2 ", 12.6#Ift, L-80 IBT-Mod BaTT, '2-8' Packer RECEIVED Tubing Tail .... -, Estimated TOC ?? - 10,876'1 PBlD (wireline tag) NOV 12 1999 Pumped 23.6 bbls (113 sx) cement Alaska-OU & Gas Cons. 0Jrnm1ølon -.. Ancboraga HOLE ANGLE at TO: 2 ° FmD 1 8,838' I Linerdepth I 8,924' I 10 I 8,933' I DATE 11/9199 REV. BY MTT COMMENTS Actual Suspension MILNE POINT UNIT Well C-12Ai API No: 50-029-21373-01 BP EXPLORATION AK ) ~. TONY KNOWLES, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 14_ 1999 Charles MallaI)' Senior Drilling Engineer SP Exploration (Alaska) Inc. P 0 Sox I 966 12 Anchorage, AK 995 19-66 12 Re: Milne Point Unit MPC-12Ai SP Exploration (Alaska) Inc. Permit No: 99-091 Sur Loc: 496'NSL. 2027'WEL, Sec. 10, T13N, RIOE, UM Stmhole Loc. 461 'NSL. 2350'WEL. Sec. 03, T 13N, RIOE, UM Dear Mr. Mallaf\': Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies. and does not authorize conducting drilling operations until all other required permitting determinations are made. The blo\vout prevention equipment (SOPE) must be tested in accordance with 20 AAC 25.035~ and the mechanical integrity (r..1I) of the injection \vells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the SOPE test prior to drilling ne\\' hole must be given so that a representative of the Commission may \vitness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chainnan BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game. Habitat Section \\'/0 encl. Department of Environmental Conservation w/o encl. 'ii. Ii STATE OF ALASKA ALASKA .L AND GAS CONSERVATION CO~ )ISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill ORe-Entry 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 289' NSL, 2348' WEL, SEC. 03, T13N, R10E, UM At total depth 461' NSL, 2350' WEL, SEC. 03, T13N, R10E, UM 12. Distance to nearest property Iine113. Distance to nearest well ADL 025509,2928' . No Close Approach 16. To be completed for deviated wells Kick Off Depth 7100' MD Maximum Hole Anç¡le 18. Casing Program Size Hole Casing Weight Grade Coupling Length 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2559' ~ Redrill 11 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil o Deepen ~ Service 0 Development Ga~ 0 Sin91e Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 45.60' Milne Point Unit / Kuparuk River 6. Property Designa~.n Sands ADL 047434 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-12Ai 9. Approximate spud date 10/18/99 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9509' MD / 7491' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Maximum surface 2100 psig, At total depth (TVD) 7000' /2900 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 6950' 5258' 9509' 7491' 288 sx Class 'G' 11 . Type Bond (See 20 MC 25.025) Number 2S100302630-277 Amount $200,000.00 55° Specifications 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10975 7578 1 0801 7492 Length Plugs (measured) o~% . (Planned TOC f/Kick Off Plug: 6860') G //11 )(-' . TOe f/Abandon Perfs: 10250' I V ~ , Casing feet feet feet feet Size Junk (measured) Structural Conductor Surface Intermediate Production Liner 80' 6034' 13-3/8" 9-5/8" Cemented MD TVD To Surface 108' 108' 1625 sx PF 'E', 250 sx Class 'G' 6070' 4703' 300 sx Class 'G' 1 0956' 7569' (Planned Section Mill 7060' - 7110') 10922' 7" Perforation depth: measured Sqzd: 10416' - 10438', 10708' - 10732', 10750' -10796' true vertical Sqzd: 7290' - 7302', 7445' - 7458', 7467' - 7490' '1 ,: ;~... '" ':. .. '. ~:,..: ~: .:.~ ::~-.": ;:~ ,;;;.,\.':::=,iil' 20. Attachments g Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch g Drilling pn5~~kHt g Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 MC 25.050 Requirements Contact Engineer Name/Number: Bob Kaluza, 564-5344 Prepared By Name/Number: Terrie Hubble, 564-4628 21 . I ~ereby certify t'ffhe "rpg,oing iH~nd correct to the best of my knowledge Signed charlesMa~·CJl..-. ~%- Title Senior Drilling Engineer V Commission Use Only Permit Number API Number Approval Date See cover letter q q - Oct l 50-029-21373-01 / () -I/f - 77' for other requirements Conditions of Approval: Samples Required 0 Yes ~o Mud Log Required 0 Yes œtNo Hydrogen Sulfide Measures 0 Yes ~o Directional Survey Required J8jYes (J No Required Working Pressure for BOPE D2K; Çi3K; D4K; D5K; 01 OK; D 15K Other: Date <7-13 - r¡ ~ Approved By Form 10-401 Rev. 12-01-85 ORIGINAL SIGNED BY nobort N. Chrisb:mson Commissioner by order of the commission Date / () - /..¡; - f t Submit In Triplicate · ) ) IWell Name: I MPC-12Ai I Well Plan Summary I 1 ype of Well (producer or injector): IIWAG Injector I Surface Location: ·1 arget Start: Intermediate 1 arget I=nd: I AI-I= Number: 496' NSL, 202(' WI::L, ~ec. 10, 113N, 1-<101::, UM X = bb8,438.0b Y = 6,028,f81.5b 289' Nt>L, 2348' WI::L, Sec. 3, 113N, 1-<101::, UM X = 558,069.11 Y = 6,033,850.38 Z = 7,015' TVDss 461' NSL, 23bO' WI::L, Sec. 3, 113N, 1-<101::, UM X = 558,065.20 Y = 6,034,022.79 Z = 7,445.77' TVDss 133(160 I kig: I Nordic 3 Il::.stimated ~tart uate: I uct. 18, 1999 1 I uperating days to complete: 112 I Mu I 9,b09' 1.1 Vurkb: 1 (,491' 1 Ktsl=: 14b.60' I Well uesign (conventional, slim hole, etc.): Objective: I Conventional t>idetrack Injector Sidetrack out of existing (" csg into the Seabee -ormation, directionally drill 6 1/8" hole thru HRZ, Kalubik, Upper Kuparuk formations to Kuparuk 'c' & 'A' sands target, TD well 180' into the Miluveach Shale Formation. Run, cmt and test 4 1/2" solid liner, complete with 3 }2", L-80, premium thread tubing. Well Name: API Number: Well Type: Current Status: Last H2S Sample: Cement: TD / PBTD: BHP: BHT: Is this well frac'd? Mechanical Condition: MPL-16 Wellhead: Nordic 3: Tubing: Liner: Casing: Casing Head: Casing Hanger: 7" Packoff: Tubing Head Adapter: Tbg. Hanger: Tree: Open Perfs: Tubing Fluids: Annulus Fluids: Current Well Information MP C-12 50-029-21373 IWAG Injector All open perf's P & A'd o ppm Estimated TOC behind the 7" production casing 9,650' 10,975' / 10,899' 2,900 psi Kuparuk 'c' Estimated from offset wells 170°F@ 7,500' ss Estimated No Cellar Box MSL = 17.1' KB / MSL = 47.1' 3-1/2",9.3# L-80 BTC Tubing None Surface: 108' 13 3/8", 48#, H-40, BTC Intermediate: 6,070', 9-5/8", 36# , L-80 BTC Production: 10,956',7",26#, L-80, BTC FMC 11" 5M FMC 10 %" BTC thread Mandrel type FMC 11", 5M x 3 1/8" FMC 10" x 3 }2" BTC Pin x EUE lift threads C.I.W. 3", 'H' type BPV profile FMC 5M,3 1/8",3 1/8" 8rd Treetop connection P&A'd on pre-rig Seawater with diesel cap down to -2000' Seawater with diesel cap down to -2000' Target Estimates: Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Materials Needed: L-80 Intermediate: ) ) Injector to sweep 1,210 MSTBO Injection rate 'most likely': 1,000 bId L-80 Production: 2,560' 7" x 4-1/2" 4-1/2" 4-1/2" 30 - 4-5/8" x 5 7/8" x 8" 6,950' 7" x 3-1/2" Will run 'X' nipple 1 - 3~" 2 - 3-1/2" 3-1/2" 2 Each - 3-1/2" L-80 Completion: 4.5", 12.6#, L-80, IBT-Mod liner Baker liner top hanger / packer Halliburton float collar Halliburton HPDJ float shoe Rigid Centralizers 3.5", 9.3# , L-80 NSCT tubing Baker 'S-3' production packer SSSV 'XN' nipple 'X' Nipple WLEG 10', 8', 6', 4', 2' NSCT space out pups Drilling Hazards and Continaencies 1) Well Control MANDITORY WELL CONTROL DRILLS: · D1 and D2 drills should be held at least once per week per crew as appropriate. · D1, Should only be conducted inside the casing string. · D2, May be conducted either in cased or open hole - if done in open hole THE WELL WILL NOT BE SHUT IN! · D3, Should be completed before spudding the well and with each crew during the tophole section of the well · D4 , Should be conducted prior to every well spud or workover, and at least every 30 days in the event of rig stacking or delays to the program. It should also be implemented if intrusive work has been carried out on the accumulator or its associated system. · D5, Should be carried out prior to drilling out or working in the intermediate or production casing strings, IT SHOULD NEVER BE IMPLEMENTED WHEN FORMATIONS ARE OPEN TO THE CASING (i.e. perfs damaged casing or open hole.) · IN ALL CASES, ENSURE THAT THE DRILLS ARE CAREFULLY CARRIED OUT AND DO NOT EXPOSE EQUIPMENT, CASING OR FORMATION TO EXCESSIVE PRESSURES AND LOADS. 2) Hydrogen Sulfide · MP C Pad is not designated as an H2S Pad. 3) Kick tolerance · The kick tolerance for the 6 1/8" open hole section would be 34.4 bbls assuming an influx at the 8,910' Top of the Kuparuk formation. This is a worst case scenario based on a 9.0 ppg pore pressure gradient in the top of the production section and a fracture gradient of 12.0 ppg at the 9 5/8" surface casing shoe with a 9.2 ppg mud in the hole. 4) Breathing · There have been several instances of 'breathing' under C pad. On Well C-39 'breathing' started while drilling the Kuparuk production zones. 'Breathing' occurred after cementing the 7" production casing on the same well. 'Breathing' occurs often in the Seabee Formatuion at Milne Point. Read and follow the 'breathing' RP to handle any 'breathing' problems. 5) Lost Circulation · There is a possibility for lost circulation in the C-pad area while drilling and a high probability for lost circulation while cementing the 4 %" liner. The Seabee formation and some Kuparuk zones are very likely to 'breath' during cementing and after cementing. · Follow the LOST CIRCULATION DECISION MATRIX if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 6) Faults . No faults predicted along directional well path. ) ) 7) Hydrocarbons · Will be kicking off in the Seabee interval, therefore the first hydrocarbon zone will be the Kuparuk 'C' sands at @ 9,030' MD, 7,000' TVDss. 8) Unexpected High Pressures · It in unlikely there will be unexpected overpressure when drilling into the Kuparuk formation on this well but there is a possibility of encountering unexpected higher pressures due to injection well communication under C pad when drilling into the Kuparuk Zone. Hold a D2 kick drill prior to drilling into the Kuparuk Formation. 9) Shale Sticking and Bit Balling · Possible bit balling problems in the lower Seabee due to high clay content. One technique to get the balling off the bit, is to PU off bottom about one foot and rotate the bit at over 100 RPM's. Possible shale sticking problems drilling the rat hole in the Miluveach Shale. If shale sticking does occur use whatever time necessary to circulate the hole clean, wiper trip through the shale if needed and condition the mud as needed. 10) Pad Data Sheet . Please Read the Pad Data Sheets Thoroughly. Drillina Proaram Overview Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPC-12Ai. Close Approach Wells: NONE - All wells may flow. There are no risky close approach issues. I Well Name None I current ~tatus \l-'rOduction I-'riority I I-'recautions Well Control: Expected Formation Pressures & BOPE Test Pressures I::xpected tsHI-' 2,900 psi, 1,000' I VUss (estimated) Max I::XP ~urface I-'ressure 2,100 psi (.115 psi/ft gas gradient) tsU1-'1:: kating b,OOO psi WiJ (entire stack & valves) I-'Ianned I:5UI-'I:: .. est I-'res. 3,bOO/2bO psi kams and Valves 2,500/250 psi Annular Mud Program I-'roduction Mud I-'roperties: LSNU uensity (ppg) II-unnel vis I 9.2 - 9.6 3b - 4b YI-' 10 - 20 I 6 1/B" hole section I HI HI-' 10-12 pH B.b-9.0 I AI-'l Hltrale 4-6 I ~olids <6% NOTE: See attached Baroid mud recommendation LCM Restrictions: None Waste Disposal: Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. ) ~ ) Formation Markers I-ormation ·1 ops Mu I Vuss I-'ore I-'si i::MW (ppg) liomments I HkL 8,bfO 6,b/0 I::SHkL 8,6/0 6,66b MK-19 8,(38 6,/30 IKUU 8,89b 6,8/b ~ossibility of encountering unexpected high IKUC 9,030 fOOO 2,900 f.9/ IKUI::S 9,0/3 f,040 2,916 /.96 pressure entering the Kuparuk ~and IKUA 9,212 /1fO 2,966 f.96 IKA3 9,222 /,180 2,9/0 f.96 1KA2 9,244 /,200 2,9/8 f.95 IKA1 9,298 /,2bO 2,998 f.95 Miluveach 9,341 f,290 CasinglTubing Program Hole Size lisgl Wt/l-t lirade Conn Length lOp tstm Tbg O.D. MDITVD MDITVD 6 1/8" 4 1/2" 12.6# L-80 IHI-Mod 2,b59' 6,950'/b,2b8' 9,b09'lf ,491' I ubing 3 1/2" 9.3# L-80 N~GI 6,920' 30'/30' 6,9bO'/5,2b8' Cement Calculations I Liner Size 14 Y2" IHI-Mod 1 tsasis680' shoe jts, 30% excess in open hole (6 1/8" hole), 1 bO' liner lap (l" casing) & 200' above liner top (3 Y2" dp) ILJ 9,b09' MU (l,491 I VLJrkb), Window at f, 100' (5,343'), Liner top at 6,950' (b,258') 1.1 otal ~ement ~pacer 30 bbls of 1::S4b Viscosified Spacer Weighted to .b ppg above mud weight. Volume: I ail 288 sxs, Class 'G' + .3/%LJ65 + 3%U53 +.1 gps LJ13b + 2.0 gps LJ600 + 0.14% 0800 + 0.2 gps 047 I emp I::SHS I -1/00 r from ~Ok, I::SHG I 1300 r estimated by LJowell Centralizer Placement: 1. Run (1) rigid straight centralizer per joint first 1,000'. 2. Run each centralizer in the middle of each joint of casing. Other Cement Considerations: 1. Mix all slurries 'on the fly'. Survey and Logging Program 6 1/8" ~ection: Open Hole: MWu 1 lit< 1 t<es II-'Wu - Over entire interval. :sample liatchers - None! Cased Hole: lil;L 1 lit< llits 1 - static pressure Perforating: Will be perforated Post-Rig via CT conveyed 2 V;" guns. AFE'd for 250'. Locations I-'erf Interval: liun ~ize 1 1 ype: uelivery: Under tsalance: ts HI-': tsH 1 : ) ", ÌI " Bit Recommendations i::SHA Hole :size uepths (MU) i:Sit 'I ype Nozzle 1 How Kate K-Kev's Hours Number and Section 1 61/8" 1 0,200' - 12,000' S I K-03LJ 13-13-13: 2t>0+ gpm 300-3t>0 30 2 61/8" 12,000'- 13,36b' S I K-09LJ 12-12-12: 2t>0+ gpm 300-3t>0 3b-40 PDC Bits: May run POC bit as the second bit rather than the STR - 090. Motors and Required Doglegs isHA Number 1 2 (insert) 3 (POC) Motor :size and Motor Required 4 %" :sperrydrill {18, 2.2 stg :Slow Speed, 1.15° adj w/5.8" pad 4 %" :sperrydrill {18, 2.2 stg :Slow Speed, 1.15° adj w/5.9" sleeve 4 %" :sperrydrill 41b, 6.3 stg :Slow Speed, 1.15° adj w/5.9" sleeve "low Kate Kt-'M's Kequired uoglegs 6° drop out of the window 2bO - 300 gpm 2bO - 300 gpm 2t>0 - 300 gpm I b mtr, t>0 rotate 15 mtr, 60 rotate Hold 29° tangent to ILJ Hold 29° tangent to ILJ It> mtr, 60 rotate MPC-12Ai Operations Summary Pre-Ria Operations 1 . WSA P & A'd all open perfs prior to 4ES rig move. 2. MIRU Nabors 4ES 3. NO Tree, NU Stack and Test. 4. POOH wi 3 ~" tbg. Tbg cut at 9,400'. 5. Cont. POOH, laid down old tbg. NORM inspected. Saved 80 jts to be left in hole for circulating string. 6. RIH set EZSV on OP @ 7,310' and test to 2,000 psi. (AOGCC will be notified 24 hrs prior to all casing testing). 7. Displaced well bore to milling fluid, spot 18 ppg mud pill top of EZSV to 7,100'. 8. RIH with BOT 7" milling assy. Mill 50' section from ± 7,060' to 7,110'. 9. Spot cement plug from EZSV to 100' above section. Hesitation squeeze. 10. POOH 11. WOC. RIH tag cmt top. POOH 1000'. Test casing to 3,500 psi. 12. RIH wi 2,000', 3 ~"circulating string. Freeze protect. Land hanger. 13. NO BOPE, NU Tree & Test. Move off. Snapshot of Well Proaram 1. MIRU Nordic 3 2. Circulate out freeze protect, pull and lay down the 3 ~", 2,000' circulating string. 3. MU 6 1/8" BHA #1, RIH tag cement, dress cmt to KO point, KO drill to bit exhaustion. 4. MU BHA #2, drill to planned TO. Need 180' rat hole in Miluveach. 5. Run, cement and test 4 ~" liner. 6. Run E-line CBL. 7. Run and test 3 ~" NSCT completion assy. 8. NO BOPE, NU tree, Move to MPJ-15i. 9. Perforate Post Rig Release ) MPC -12 ) KOP = 500' Max hole angle = 60.2 @ 10,876' FMC Tubing hanger w/3-1/2" 'H' BPV profile Orig. KB - SL = 52' (Alaska United #3) Orig. KB - GL = 35' (Alaska United #3) Tree: FMC 3-1/8" 5M with 3-1/2" 8rd treetop connection ~ ~ 9-5/8".40# L-80 Btrs @ 6.070' Top of cmt, 200' above window (6,860') Mill 7" casing from 7,060' - 7,110' L~·¡¡'.!.L~" ;~..:.J - Bridge plug @ 7,310' 10.4 ppg mud from top PBR to BP. Top of cmt, 100' above top GLM (10,250') lii!!I!!llu!]!!!!!!! BOT PBR seal assembly 110,228' I tiïiiïI BOT 'HB' retreivable packer (2.89"10) 110,242' 1 X Cameo 'W-1' selective nipple (2.812"10)110,280' I Or, " " '"", Cameo 'MMG-2' GLM (?r~?"ln), 1.5" valves U.J ~ 10.345'1 10,396' I ill . Blast jì'nt (39.'34¡' length), 4.25"/3.00" 00/10 . 10,404' I BOT C.L. Seal ass. 110,475' 1 BOT '2-B' Perm. packer (5.875"00, 4.25"10) w/millout extension (5"00,4.43"10) 110,476' I Perforation Summary ** All shot on 4-27-85** Cameo '0' nipple (2.75"10) 110,501' 1 Tubing tail \10,510' I Tag fill S/L 8/99 110,755' 1 PBTO Wireline tag I 10,878' I ~ ~"26# L-80 Btrs (6.276"ID. 6. 151 "driftj 10.956' I Date Revised by Mik Triolo Mik Triolo Comments Milne Point Unit WELL: C-12i API #: 50-029-21373-00 Proposed Decompletion 8/2/99 8/9/99 Proposed decompletion by 4ES Revision:Proposed decompletion by 4ES Wellhead: 11" 5M Milne pt. phase 1 wI 10" x 3.5" BTC pin x EUE lift threads Tbg. Hng. 3" CIW "H" BPV profile MPC-12Ai PROPOSED COfv1PlETlŒJ Cellar Box Elevation: 17. 1 ' Rig RKB Elevation: 30.00' . 133/8",48#, H-40, BTC I 108' I .. 12,000' I 3112" 'X' nipple, 102.750" ~ \: KUPARUK 'C' SANDS \. 4- ÆRFŒA1lON ZQIJES: < KUPARUK 'A' SANDS 3112" 'X nipple, 2.750" 10 T x 3 112" Baker Production Pkr Note: 3 1/2" WLEG will be stabbed into the 4 1/2" liner top. Note: The completion tubing will be used for IWAG service. 31/2",9.3#, L-80, NSCT 95/8",36#Ift, K-55, BTC. I 6,070' I /' 7',26#, L-80, BTC T x 4 112" Baker Liner Hanger Pkr Cement KO Plug 6"Window I 7,100' I Halliburton EZSV DIRECTIONAL PLAN (PROPOSED PLAN 5A) KOP @ 7,100' Max. hole angle = 55° at KO Window Hole angle thru' perfs = 22° 110,228'1 BakerPBRSeal Þssy. 10,242'1 BOTT, 'HB' Packer 41/2 ", 12.6#Ift:, L-80 IBT-Mod BOT 7", '2-B' Packer Tubing Tail F81D 9,425' ID 9,509' 10,876'1 PBm (wireline tag) HOLE ANGLE at TD: 22 ° DATE 9/01/99 REV. BY RMK COMMENTS Proposed Completion MILNE POINT UNIT Well C-12Ai API No: 50-029-21373-01 BP EXPLORATION AK ~?l::~ r"'""" ) ..-.' . t..\ ) WELL No. -C-12 COMPLETIQN SKETCH MILNE POINT UNIT (I) API No.: 50-029- 21373 PERMIT No.: 85-120 COMPLETED: 7/31/85 LAST WORKOVER: 10/21/89 I FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE 3 1/2", 9.2# L -80 BUTTRESS TU~I~9 (2.992· 1.0., 2.867" DRIFT) '00 'fi 7 !J.ð9'r NOTES: 1. ALL MEASUREMENTS ARE FROM KOB OF ALASKA UNITED #3 KDB-SL = 52' KDB-GL = 35' 2. MAX. L = 60.2" @ 10,876' MD 3. K.O.P. = 500' 4. SLANT HOLE: YES 5. MIN. L = N/A 6. TREE TYPE: FMC 3 1/8", API 5000# WITH 3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS CAMCO '0' NIPPLE @ 10,501' (2.750" 10) 8, COMPLETION FLUID: 10.2 PPG NaCI-NaBr 9. FRACTURE STIMULATION: 7-19-85 MIDDLE KUP 75,000 LBS 16-20 ISP 9-5-85 LK-2 40.000 LBS 16-20 ISP (SCREENED OUT) PERFORATION DATA 12 SPF, \20· PHASING, 5" GUNS (ALL DEPTHS FROM OIL LOG 4-27-85) MIDDLE KUP 10,416'-10,438' MD 7289'-7301' TVD LK-2 J",C1L50'-10,796' MD 7466'-7489' Iv!> A 4 SPF, O· PHASING, 2 1/8" GUNS (ALL DEPTHS FROM OIL LOG 4-27-85) LK-1 10,708'-10,732' MD 7445'-7457' TVO CONOCD INC. ANCHORAGE DIVISION ( sssv ) 687' CAMCO TRDP-fA SSA SSSV (2.812· 10) 10,173' 3 1/2" CAMCO KBUG GLM 10.228' BOT PBR. SEAL ASSEMBLY 10.242' BOT 'HB' RETRIEVABLE PACKER (2.89" 10) ~ 10,280' CAMCO 'w-¡' SELECTIVE NIPPLE (2.812" ID) g:= 10,345' CAMCO 'MMG-2' GAS LIFT MANDREL 2.920" 10, 1.5" VALVES . 10.396' CAMCO 'MMG-2' GAS LIFT MANDREL 2.920" 10, 1.5" VALVES 10.404' BLAST JOINT (39.34' TOTAL LENGTH, 4.250· 00, 3.00" 10) 3 1/2· 9.2#, L-80, BTRC TBG - mr·- - - - --'\ ~ 10,475' BOT C.L. SEAL ASSEMBLY ~~~'lJ ) 10,476' BOT '2-B' PERMANENT PACKER (5.875· 00, 4.25· 10) WITH MILLOUT EXTENSION, (5.0· 00, 4.430" 10) ò "'" -10,501' CAMCO '0' NIPPLE (2.750" 10) _ ~ 10,510' TUBING TAIL -=- ~ 10,865' TAG FILL S/L 3-18-89 ...,....< 10,876' PBm (WlREUNE TAG) ~ ~ 10,956' T 26# L-80 BTRS (6.276" 10, 6.151· DRIFT) APPROVED BY: HDS DATE: 03/17/92 DRAF1ED BY: SJN CAD FILE: WCOC12 ) ) c:;rar-'ll""'Y-5un pr:,'....L'''' Gi~EAVICG$ A iliüJlI<'Ir!'" <_A.... Shared Services Drilling Well MPC-12A Wp5 DrillQuest.. Well: Current Well Properties MPC-I2A Eastings Horizontal Coordinates: Ref. Global Coadlnates : Ref. SlruCture Reference : Ref. Geographical Coordinates : RKB Elevation : 6028781.55 N, 558438.05 E 1430.81 N, 391.27 E 70' 29' 21.2733" N, 149' 31' 20.3098' W 45.6Oft above Mean Sea Level 45.6Oft above Structure Reference -500 o I North Reference : UnIts : True North Feet 7" Liner" 9508.60 'v1D, 7491.37 ìVD Total Depth: 9508 60ft MD, 7491.37ft ìVD ~=~¡n: Measurement IJnIIs : North Ref-.ce : Proposal Data for MPC-12A Wp5 MPC-I2A MPC-I2A II True North 5000 5000 Dogleg HVerity : Degrees per 100ft Vertical SectiOl1 AzImuth: 356.381' Ver1JcaI SectiOl1 Description: MPC-I2A Vertical SectiOl1 Origin: 0.00 N,O.oo E Me.aured Incl. Nlm. Vertical Northlnga e.atlngs Vertical Dogleg Depth Depth Section Rate 7100.00 55.186 351.000 5343.10 4215.68 N 282.77 W 4225.12 7661.45 21.819 359.152 5776.54 4557.56 N 321.49 W 4S61!.76 6.000 9044.59 21.819 359.152 7060.60 5071.57 N 329.10 W S082.23 0.000 9346.20 21.819 359.152 7340.60 5183.66 N 330.75 W 5194.20 0.000 9508.60 21.819 359.152 7491.37 5244.01 N 331.65 W 5254.49 0.000 U) C) .E .r::. 1:: o Z 4500 - U) C) c: :.c: 1:: o Z ~nd Dir : 7661.45ft MD, 5776.54ft ìVD - 4500 . 5400.00 4500 I -500 Scale: 1 inch = 500ft astihgs n, Start Dir t!! 6.000o'100ft: 71 OO.OOft MD, 5343.10ft TVD .. ...... .... -BSF-4430.60TVD I o Reference is True North 5000 - Single Well Target Data for MPC·12A Measurement Units: ./" II Target Nama ~U'C.I2Af¡;¡¡¡;:l oordlnate Int TVO TVO Northlngs eastlnga Northlngs Eastlngs Target pe Shape \.:~;\~ . . EÐtry Puinl 7015.00 7060.60 5071.57 N 329.10 Yo' 6033850.38 N 5511069.11 E Cin:1c Tie-on, Start Dlr @ 6.000o'100ft: 7100.00ft MD, 5343,10ft ìVD 5500 - .r::. .. a. Q) o m 6000 o 1:: Q) > 6500 - · . ... . .. . . ... . . .... . ... . . ... . ... . .... .. ................................................... Ba3t! HRZ - 6730.60 TVD · . h.... .... . . ..... . .... . . - . - -.. . ....... ........ ..... .. ............ ... -. . . .......... .. ... MK-19. 6795.60 TVD · . . . . . . . ... . . . . . . . - . . . . . . . . . . - . . . . .. . . . . . . ~ . . . - -. . . . - . . . . . . . . . . . -. -. . . -. . . . . . . .. . . .. .. . . ... TKUL> - 6940.60 TVD 7000 - ¢::: o o 10 II .s:::. o oS .. .... . . .... . . ... ... . . ... . . .... . ... . ...... .. --. . .... . ... . .. .. .... . . .. . KUPARUK C - 7Q60.60 TVD .. ...... ...... ..-... . M.,,<-.:n1"r;Û·gH;r.i"ril..: ... ......... ......... .......... ...... ........ -KUPARUKB-7IOO.6IJ TVD 7/J(j11.60 TV/) ~.'·/~·' 1;"1·'11 ~I~·.:·i ~:(~·.~·.:iì';160 1VD '''.1,', ".':' ,',.1 Ii (" · . . . . . . . . .. . . . .. . .. . ... . . . . . . . . . . .. .. . . . .. . . . .. .. .. ............ -- .. . . .. . . . . .. .. . . .. . . . . . -. 'f1G.I.l - 7305.60 1VD · . . -. . .... ... . ..... . .... . . . .... . . . --. . .... ..... '\. .. . . .... .. ...... . . --. . . .... .. .. .. . . .. - MlLUVE..CH - 7340.60 1VD ~ ~~J ~ Total Depth: 9508.60ft MD, 7491.37ft TVD 7" liner - 9508.60 MD, 7491.37 ìVD "* 7500 - o en I 4500 Scale: 1 inch = 500ft I 5000 5500 Section Azimuth: 356.3810 (True North) Vertical Section spal"'"'l""'y-sun DAU."'-'NG$~AVIC::$S . fWlJ~'oIf<)l ('OW.iIY Well: Current Well Properties MPC-12A Horizontal Coordinates: Ref, Global Coordinates: Ref. Structure Reference : Ref. Geographical Coordinates: RKB Elevation; North Reference: Units : ) ) Shared Services Drilling Well: MPC-12A Wp5 6028181.55 N, 558438.05 E 1430,81 N, 391.21 E 10' '21.2133" N, 149' 31' 20.3098" W DrillQuest~ 45.601t a ove Mean Sea Level 45.6 ,above Structure Reference *1,1 True North Feet Single Well Target Data for MPC·12A Measurement Units : It Coordinate Targat Point TVD TVD Northlnga Eatlngo Northlngo eootlngo Targot Nama Typo Shape MPC-12A Target EnIlyPoinl 70 IS.(() 7060,60 S071.S7 N 329,10 W 60338SO.38 N SS8069, II E Circle 5400 - 5200 - 5000 - en C) .£: 4800 .L:. t o Z 4600 - 4400 - 4200 - Scale: 1 inch = 200ft -600 I Eastings -200 I o I -400 I jI!' . er· 9508.60 MD, 7491.37 lVD ,.,--Total th : 9508.60ft MD, 7491.37ft lVD 5: 'U ~ ~ ::¡: . 7200,00 "C UI Ml'C-12, Target- C¡"(;We D 7060.611 rVlI 5IJ71.S71V, 329.10 If . . 6000,00 .819° Inclination 2° Azimuth '~~End Dir: 7661.45ft MD, 5776.54ft lVO ~.oo - 5400 - 5200 - 5000 en C) 4800 .5 .r:::. t o Z - 4600 - 4400 I -600 Scale: 1 inch = 200ft I -400 -Tie-on, Start Dir @ 6.0000/100ft: 7100.00ft MD, 5343.1 Oft lVD \ - 4200 I I -200 0 Eastings Reference is True North Sperry-Sun Drilling Services Proposal Report for MPC-12A Wp5 Revised: 2 September, 1999 Alaska State Plane Zone 4 Prudhoe Bay Unit MILNEPT MPC Measured Sub-Sea Vertical Local Coordinates Global q~o~S,!ñ'ites Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings"" u"HEª§lings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) .};;, .,lft) (°/1 o Oft) (ft) - 7100.00 55.186 351.000 5297.50 5343.10 4215.68 N 282.77 W 558122.16 E 4225.12 TiEHm Start Dir ßß 6.0000hOOft: 71 .000 MD, 5343.1 Oft TVD 7200.00 49.215 351.752 5358.76 5404.36 4293.77 N 558109.68 E 6.000 4303.80 7300.00 43.251 352.652 5427.90 5473.50 4365.28 N 558099.30 E 6.000 4375.79 7400.00 37.295 353.778 5504.16 5549.76 4429.43 N 558091.13 E 6.000 4440.30 7500.00 31.353 355.260 5586.72 5632.32 4485.53 N 558085.25 E 6.000 4496.63 7600.00 25.435 357.351 5674.65 5720.25 4532.95 N N 558081.73 E 6.000 4544.15 7661.45 21.819 359.152 5730.94 5776.54 4557.56 N N 558080.76 E 6.000 4568.76 End Dir : 7661.45ft MD, 5776.54ft TVD 7700.00 21.819 359.152 5766.73 5812.33 4571.88 6033350.76 N 558080.43 E 0.000 4583.07 7800.00 21.819 359.152 5859.56 5905.16 4609.04 6033387.92 N 558079.59 E 0.000 4620.19 7900.00 21.819 359.152 5952.40 5998.00 4646.21 6033425.08 N 558078.75 E 0.000 4657.32 8000.00 21.819 359.152 6045.24 323.35 W 6033462.23 N 558077.91 E 0.000 4694.44 8100.00 21.819 359.152 6138.07 323.90 W 6033499.39 N 558077.06 E 0.000 4731.56 8200.00 21.819 359.152 6230.91 324.45 W 6033536.55 N 558076.22 E 0.000 4768.69 8300.00 21.819 359.152 6323.75 325.00 W 6033573.71 N 558075.38 E 0.000 4805.81 8353.02 21.819 359.152 6372.97 325.29 W 6033593.41 N 558074.93 E 0.000 4825.50 Sail ~21.819° Inclination on 359. 2° Azimuth 8400.00 21.819 359.152 6416.58 4832.02 N 325.55 W 6033610.86 N 558074.54 E 0.000 4842.94 ,-,' 8500.00 21.819 359.152 6509.42 4869.19 N 326.10 W 6033648.02 N 558073.70 E 0.000 4880.06 8600.00 21.819 359.152 6602.26 4906.35 N 326.65 W 6033685.18 N 558072.85 E 0.000 4917.18 8689.13 21.819 359.152 6685.00 6730.60 4939.47 N 327.14 W 6033718.30 N 558072.10 E 0.000 4950.27 Base HRZ 8700.00 21.819 359.152 6695.09 6740.69 4943.51 N 327.20 W 6033722.34 N 558072.01 E 0.000 4954.31 8759.15 21.819 359.152 6750.00 6795.60 4965.49 N 327.53 W 6033744.31 N 558071.51 E 0.000 4976.26 MK-19 8800.00 21.819 359.152 6787.93 6833.53 4980.67 N 327.75 W 6033759.50 N 558071.17 E 0.000 4991.43 8900.00 21.819 359.152 6880.76 6926.36 5017.84 N 328.30 W 6033796.65 N 558070.33 E 0.000 5028.55 8915.33 21.819 359.152 6895.00 6940.60 5023.54 N 328.38 W 6033802.35 N 558070.20 E 0.000 5034.25 TKUD 9000.00 21.819 359.152 6973.60 7019.20 5055.00 N 328.85 W 6033833.81 N 558069.49 E 0.000 5065.68 Continued... 4 September, 1999 - 1:57 -1- Dril/Quest . . Sperry-Sun Drilling Services Proposal Report for MPC-12A Wp5 Revised: 2 September, 1999 Alaska State Plane Zone 4 Prudhoe Bay Unit MILNEPT MPC Measured Sub-Sea Vertical Local Coordinates Global Coo.~,~tri'!es Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings ""~ltJngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) .eft) e/100ft) (ft) ~ 9044.59 21.819 359.152 7015.00 7060.60 5071.57 N 329.10 W 0.000 5082.23 KUPARUK C MPC-12A Target. 200.00 Radius., Geological 1.l-~' 9087.68 21.819 359.152 7055.00 7100.60 5087.59 N 558068.75 E 0.000 5098.23 KUPARUK B Ii/I 9100.00 21.819 359.152 7066.44 7112.04 5092.16 N 558068.64 E 0.000 5102.80 9200.00 21.819 359.152 7159.27 7204.87 5129.33 N 558067.80 E 0.000 5139.92 0 9222.33 21.819 359.152 7180.00 7225.60 5137.62 N 558067.61 E 0.000 5148.21 KUPARUK A ",.,- S~~ 9233.10 21.819 359.152 7190.00 7235.60 5141.63N 33920.42 N 558067.52 E 0.000 5152.21 TKA2 9254.64 21.819 359.152 7210.00 7255.60 5149.63 N 6033928.43 N 558067.34 E 0.000 5160.21 TKA2 9300.00 21.819 359.152 7252.11 7297.71 5166.49 N 6033945.28 N 558066.96 E 0.000 5177.05 9308.50 21.819 359.152 7260.00 7305.60 5169.65 6033948.44 N 558066.89 E 0.000 5180.20 TKA1 9346.20 21.819 359.152 7295.00 7340.60 5183.66 6033962.45 N 558066.57 E 0.000 5194.20 MILUVEACH 9400.00 21.819 359.152 7344.95 7390.55 52º~;f35 N 331.05 W 6033982.44 N 558066.12 E 0.000 5214.17 9500.00 21.819 359.152 7437.78 7483.38 524G1B2 N 331.60 W 6034019.60 N 558065.28 E 0.000 5251.30 9508.60 21.819 359.152 7445.77 7491.37 ...n...... 331.65 W 6034022.79 N 558065.20 E 0.000 5254.49 ¡'UN Total DeRth : 9508.6Oft MD, 7491.37 TVD 7" Liner All data is in feet unless otherwise stated. Direction$.,an ates are relative to True North. Vertical depths are relative to MPC-12A. Northings and Eastings are relative to MPC-12A. "-' Magnetic Declination at Surface is 27.219° (02-Sep-99), The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPC-12A and calculated along an Azimuth of 356.381 ° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9508.60ft., The Bottom Hole Displacement is 5254.49ft., in the Direction of 356.381° (True). Continued... 4 September, 1999 -1:57 -2- DrillQuest Sperry-Sun Drilling Services Proposal Report for MPC-12A Wp5 Revised: 2 September, 1999 Prudhoe Bay Unit Comments Measured Depth (ft) 7100.00 7661.45 8353.02 9508.60 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5343.10 5776.54 6418.57 7491.37 4215.68 N 4557.56 N 4814.56 N 5244.01 N 282.77 W 321.49 W 325.29 W 331.65 W Tie-on, Start Dir @ 6.0000/100~.~ 710 . End Dir : 7661.45ft MD, 577~. 'u TVD Sail @ 21.819° Inclination on¡~. 52° Azimuth Total Depth: 9508.6Oft . ,eft TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings (ft) (ft) (ft) (ft) 8689.13 6730.60 6685.00 4939.47 N Base HRZ 8759.15 6795.60 6750.00 4965.49 N MK-19 8915.33 6940.60 6895.00 5023.54 N TKUD 9044.59 7060.60 7015.00 5071.57 N KUPARUK C 9087.68 7100.60 7055.00 5087.591N KUPARUK B 9222.33 7225.60 7180.00 513i¡62.N 330.07 W KUPARUK A 9233.10 7235.60 7190.00 5141.63' 330.13 W TKA2 9254.64 7255.60 7210.00 5149.63 330.25 W TKA2 9308.50 7305.60 7260.00 5169.65 N 330.55 W TKA1 9346.20 7340.60 7295.00 5183.66 N 330.75 W MILUVEACH 4 September, 1999 - 1:57 -3- Alaska State Plane Zone 4 MILNEPT MPC --' '_/ Continued... DrillQuest H 155823 DATE INVOICE I CREDIT MEMO DESCRIPTION 082799 CK082799 HANDL=NG INST: S/H TERRI HUBBLE X4628 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ .ßP§!<PLqRATIO~ (ALASKA)¡INC. '.. p.O..aO~196612 :Uu).:: . . ANCHORAGË~ALASKA 99519-6612 f""---~ GROSS 100.00 '1\ ~C- ~ ~A1 100.00 VENDOR DISCOUNT f:'iaST ijÄTIQNALBANK ,OF ASHLAND .. . . AWÀFF1lIATEOF NÀ'tIONAl CITY BANK -CleVELAND. OHIO . . ·56-389 412 DATE U8/~O/Y'" CHECK NO. OU 1 ~~1::f~3' ALASKAST14 NET 00 100.00 H 100.00 No. H 1.55823 CONSOllDA rED COMMERCIAL ACCOUNT 00155823 . u, P_ .__ _ 0_.· .-. . .-. PAY ONE -_HUNDfJEi)::' &:Øò/l OO*****#***:ii**it-;'**,************iÍ-******** US DOLLAR TÓThè O~DER- 'Of .".,' _AL~S~ft STATE.::P~~T OF REVEN\JE aoo 1 <PORCUP I NE:{:DR ANCHORAGE AK 99501-3120 III ~ 5 5 8 2 j III I: 0 ~ ~ 2 0 ~ B g 5 I: 0 0 B ~ ~ ~ gill DATE 08/30/99 AMOUNT $100.00 NQTVALlD AFTER 120 DAYS l·<'~-""i.. ..'.: .., ...... ':., '. ~.... '\ !'i . . - "\ / t)·· I, '>.. ,;.,.-...> {J(Vll, ) , hared ervice rilling ) WELL NAME MPC-12Ai DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one catefory per cover sheet) ŒJ DRILLING PERMIT 0~=i~~áte:~~ o Pennit APßli,Eàti Re;(ew",¡\ 't )'3k'1 SDE/ES: ¡j í'. UVVVrlate: }l/th, IZI Penn~p~li -:i?n ~uþ~itted: (]ï TA:/10MeiJ, \~ Date: ì J3/9r D PRE-RIG WORK o Pre-Rig Memo Reviewed: SDE/ES: Date: D Pre-Rig Memo Sent to Slope: ODE: Date: D Pre-Rig Sundry Documentation Prepared: ODE: Date: o Pre-Rig Sundry Application Re~iewed: SDE/ES: Date: D Pre-Rig Sundry Application Submitted: TA: Date: D SUNDRY NOTICE o Sundry Documentation Prepared: ODE: Date: o Sundry Application Reviewed: SDE/ES: Date: o Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Alter Casing -- Suspend - Repair Well - Plugging Pull Tubing Variance Change Approved Program Operation Shutdown Re-enter Suspended Well - Time Extension - - - Perforate Stimulate - - Other(Explain): APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received - T A: Approval to Commence Operations SDE/ES: - Date: Date: WELL PERMIT CHECKLIST COMPANY" r~ 'P }.. WELL NAME M r-' u M ~c. ...\ ¡~ PROGRAM: exp _ dev -Â- redrll A- serv _ wellbore seg _ann. disposal para req _ FIELD & POOL S ¿ 5""( ~ 0 INIT CLASS S ¿ (l.. - WAG I rv. GEOL AREA '8 ct Ù UNIT# \ \ '3 À ? ON/OFF SHORE C) V\. ADMINISTRATION 1. Permit fee attached. . . . . . .. .............. 2. Lease number appropriate. . .. .............. 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . ÞflPR pATE 12. Permit ca~ be issued without administrativ~ approval.. . . . . ~ } y ~q~ 13. Can permit be approved before 15-day walt.. . . . . . . . . . ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations . . . . . . . . . . ~ t~N>J fJPr 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to 3ð~a psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . G N 28. Work will occur without operation shutdown. . . . . . . . . . . ® .Þl. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y Q:!) 30. Permit can be issued wlo hydrogen sulfide measures. . . .... Y N 31. Data presented on potential overpressure zones - , . . . . . Y N 32. Seismic analysis of shallow gas zonA<;, . . . . . . . . . . . . Y N A~rR DATE 33. Seabed condition surway (ií eM-shore). . . . . . . . . . . . . Y N ~ 1'fJyt1q q'l 34. Sontact 'lnrr.efJ5hone for weekly progress reports [exploratory only] Y N ANNULAR DISPOSAL 35. With proper cementing records, th's plan Jv8 AI'\I'\c..tfo, c~p-ø-( (A) will contain waste in '8 suo e receiving zone; . . . . . . . Y N (B) will not contamina eshwater; or cau . ling waste. ., Y N to surface; (C) will not imp mech~!1Î"dllnt Ity of the (D) will not damage producing rm . pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEO-Opt ENGINEERING: UIC/Annylar COMMISSION: RPè~ BE~Qo; CJ(fJ- WM ( DWJ ~ JDH~ __ RNC . CO CD .:J/rtl't" AppR. D~ TE ta.Jlt.w-. CJ{ r 7(o/j GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist ~ ~~ ~~ ~N Y N ~ ~N Œ* E'~rrf,'1" ~~Y ~N ~ ...þ "I c) - /'iO¡ ,A-(J¡J1d'¡'¿ ~ 0 0 Z 0 -I :E ;:;u ...... -I m ...... z -I :J: ...... (J) » ( ;:;u m » N)f+ Y N Y N Y N Comments/Instructions: ) ) Welll-listory 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 sim.plify fìnding infonnation. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) I qCj;oc¡¡ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 04 15:09:16 2001 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .01/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .01/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPC-12A PB1 500292137370 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 07-NOV-01 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-90177 E. CRIBBS WESTER/LOCKW # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 10 13N 10E RECE\VED 496 2027 DEC 2 8 2001 .00 47.95 17.10 Alaska Oil & Gas Cons. Commission Anch.arage # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 7067.0 ') ) 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) UNLESS OTHERWISE NOTED. 3. MWD RUN 1 COMPRISES DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER- MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 ( EWR4) . 4. DIGITAL AND LOG DATA ONLY ARE SHIFTED TO THE CASED-HOLE WIRELINE GAMMA RAY LOG (CCL) RUN ON 25 JANUARY 2000. THE PDC LOG WAS RECEIVED FROM DEWAYNE SCHNOOR (BP) ON 10/30/01. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUN 1 REPRESENTS WELL MPC-12APB1 WITH API# 50-029-21373-70. THIS WELL REACHED A TOTAL DEPTH OF 8934'MD/6943.90'TVD. THIS WELL WAS TD'D PREMATURELY DUE TO A GAS KICK. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC SMOOTHED GAMMA RAY COMBINED SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7033.5 7040.5 7040.5 7040.5 STOP DEPTH 8894.0 8901.0 8901.0 8901.0 ') ) RPD 7040.5 8901.0 FET 7040.5 8901.0 ROP 7079.0 8938.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE DEPTH GR 7033.5 7032.5 7043.0 7042.0 7070.5 7069.0 7207.5 7205.0 7277.5 7275.5 7343.0 7340.5 7474.5 7471.5 7567.0 7563.5 7617.0 7617.5 7666.5 7669.5 7688.0 7688.5 7712.5 7711.5 7759.0 7755.0 7784.5 7781.0 7948.0 7945.0 8015.5 8010.5 8053.5 8049.5 8078.0 8075.5 8177.0 8172.0 8300.0 8298.5 8317.0 8311.5 8359.5 8356.0 8466.5 8463.5 8516.5 8513.0 8520.0 8516.0 8541.0 8537.5 8554.0 8550.0 8566.0 8562.5 8581.5 8577.5 8589.0 8585.5 8606.5 8602.0 8638.0 8633.0 8646.5 8642.5 8654.5 8650.0 8671.5 8667.0 8675.0 8670.5 8676.5 8672.0 8682.5 8678.5 8687.0 8682.5 8691.5 8687.0 8714.0 8710.0 8722.0 8717.5 8730.0 8725.5 8732.5 8727.5 8769.5 8764.5 8781.5 8777.0 8798.0 8794.5 8938.0 8934.5 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7032.5 8934.5 $ # REMARKS: MERGED MAIN PASS. ') ) $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7033.5 8938 7985.75 3810 7033.5 8938 ROP MWD FT/H 18.61 357.49 142.368 3719 7079 8938 GR MWD API 43.89 308.83 122.513 3722 7033.5 8894 RPX MWD OHMM 0.61 1217.42 3.22453 3722 7040.5 8901 RPS MWD OHMM 0.58 1630.92 7.77704 3722 7040.5 8901 RPM MWD OHMM 0.54 2000 25.4922 3722 7040.5 8901 RPD MWD OHMM 0.56 2000 24.5456 3722 7040.5 8901 FET MWD HOUR 0.18 4.04 0.569675 3722 7040.5 8901 First Reading For Entire File......... .7033.5 Last Reading For Entire File.......... .8938 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 F i 1 e Type...... . . . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record ) FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 7032.5 7039.5 7039.5 7039.5 7039.5 7039.5 7077.5 STOP DEPTH 8890.5 8897.5 8897.5 8897.5 8897.5 8897.5 8934.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 04-NOV-99 Insite 4.15 Memory 8934.0 7072.0 8934.0 17.2 50.8 TOOL NUMBER P1376GRV4 P1376GRV4 6.125 Water 9.60 44.0 9.6 500 4.5 Based 2.600 .970 2.400 2.600 63.0 107.0 63.0 63.0 ) ) # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7032.5 8934.5 7983.5 3805 7032.5 8934.5 ROP MWD010 FT/H 18.61 357.49 142.379 3715 7077.5 8934.5 GR MWD010 API 43.89 308.83 122.591 3717 7032.5 8890.5 RPX MWD010 OHMM 0.61 1217.42 3.22606 3717 7039.5 8897.5 RPS MWD010 OHMM 0.58 1630.92 7.78423 3717 7039.5 8897.5 RPM MWD010 OHMM 0.54 2000 25.4142 3717 7039.5 8897.5 RPD MWD010 OHMM 0.56 2000 24.0389 3717 7039.5 8897.5 FET MWD010 HOUR 0.18 4.04 0.569126 3717 7039.5 8897.5 First Reading For Entire File......... .7032.5 Last Reading For Entire File.......... .8934.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .01/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE ) ) Date... ............. .....01/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) ) '. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 07 14:23:58 2001 Reel Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0 1 / 11 / 07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 01 / 11 / 07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPC-12Ai 500292137301 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 07-NOV-Ol JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-90177 E. CRIBBS WESTER/LOCKW # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 10 13N 10E 496 2027 REC·E"Jt::D .00 47.95 17.10 DEC 2 8 Z001 # WELL CASING RECORD ·"\a"'t.~ Oil &. Gas Con$ Comn\l~siO!l r~~ ~ña \., And~;)mge 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 7067.0 ) ) 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) UNLESS OTHERWISE NOTED. 3. MWD RUN 1 COMPRISES DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER- MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 ( EWR4) . 4. DIGITAL AND LOG DATA ONLY ARE SHIFTED TO THE CASED-HOLE WIRELINE GAMMA RAY LOG (CCL) RUN ON 25 JANUARY 2000. THE PDC LOG WAS RECEIVED FROM DEWAYNE SCHNOOR (BP) ON 10/30/01. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUN 1 REPRESENTS WELL MPC-12Ai WITH API# 50-029-21373-01. THIS WELL REACHED A TOTAL DEPTH OF 8934'MD/6943.90'TVD. THIS WELL WAS TD'D PREMATURELY DUE TO A GAS KICK. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC SMOOTHED GAMMA RAY COMBINED SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .01/11/07 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7033.5 7040.5 7040.5 7040.5 STOP DEPTH 8894.0 8901.0 8901.0 8901.0 RPD FET ROP $ ) ) 7040.5 7040.5 7079.0 8901.0 8901.0 8938.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 7033.5 7043.0 7070.5 7207.5 7277.5 7343.0 7474.5 7567.0 7617.0 7666.5 7688.0 7712.5 7759.0 7784.5 7948.0 8015.5 8053.5 8078.0 8177.0 8300.0 8317.0 8359.5 8466.5 8516.5 8520.0 8541.0 8554.0 8566.0 8581.5 8589.0 8606.5 8638.0 8646.5 8654.5 8671.5 8675.0 8676.5 8682.5 8687.0 8691.5 8714.0 8722.0 8730.0 8732.5 8769.5 8781.5 8798.0 8938.0 $ GR 7032.5 7042.0 7069.0 7205.0 7275.5 7340.5 7471.5 7563.5 7617.5 7669.5 7688.5 7711.5 7755.0 7781.0 7945.0 8010.5 8049.5 8075.5 8172.0 8298.5 8311.5 8356.0 8463.5 8513.0 8516.0 8537.5 8550.0 8562.5 8577.5 8585.5 8602.0 8633.0 8642.5 8650.0 8667.0 8670.5 8672.0 8678.5 8682.5 8687.0 8710.0 8717.5 8725.5 8727.5 8764.5 8777.0 8794.5 8934.5 # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7032.5 8934.5 $ # REMARKS: MERGED MAIN PASS. ) ) $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4. 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7033.5 8938 7985.75 3810 7033.5 8938 ROP MWD FT/H 18.61 357.49 142.368 3719 7079 8938 GR MWD API 43.89 308.83 122.513 3722 7033.5 8894 RPX MWD OHMM 0.61 1217.42 3.22453 3722 7040.5 8901 RPS MWD OHMM 0.58 1630.92 7.77704 3722 7040.5 8901 RPM MWD OHMM 0.54 2000 25.4922 3722 7040.5 8901 RPD MWD OHMM 0.56 2000 24.5456 3722 7040.5 8901 FET MWD HOUR 0.18 4.04 0.569675 3722 7040.5 8901 First Reading For Entire File......... .7033.5 Last Reading For Entire File.......... .8938 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/07 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Corrnnent Record ) FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 7032.5 7039.5 7039.5 7039.5 7039.5 7039.5 7077.5 STOP DEPTH 8890.5 8897.5 8897.5 8897.5 8897.5 8897.5 8934.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 04-NOV-99 Insite 4.15 Memory 8934.0 7072.0 8934.0 17.2 50.8 TOOL NUMBER P1376GRV4 P1376GRV4 6.125 Water 9.60 44.0 9.6 500 4.5 Based 2.600 .970 2.400 2.600 63.0 107.0 63.0 63.0 ) ) # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7032.5 8934.5 7983.5 3805 7032.5 8934.5 ROP MWD010 FT/H 18.61 357.49 142.379 3715 7077.5 8934.5 GR MWD010 API 43.89 308.83 122.591 3717 7032.5 8890.5 RPX MWD010 OHMM 0.61 1217.42 3.22606 3717 7039.5 8897.5 RPS MWD010 OHMM 0.58 1630.92 7.78423 3717 7039.5 8897.5 RPM MWD010 OHMM 0.54 2000 25.4142 3717 7039.5 8897.5 RPD MWD010 OHMM 0.56 2000 24.0389 3717 7039.5 8897.5 FET MWD010 HOUR 0.18 4.04 0.569126 3717 7039.5 8897.5 First Reading For Entire File......... .7032.5 Last Reading For Entire File.......... .8934.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/07 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .01/11/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE ) ) Da t e. . . . . . . . . . . . . . . . . . . . . 01/11/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) ') mpc-12a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 04 11:01:01 2001 Reel Header Service name.. . .. . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .01/12/04 Origin.................. .STS Reel Name. .. .. . .. . . ... . . .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.. . .. . . . . . . .. . . . . . . ..01/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. .. . . . .. . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name. ..... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MII'lD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPC-12A 500292137301 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 28-NOV-01 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MII'lDRUN 1 AK-MM-90177 E. CRIBBS WESTER/LOCKW MWD RUN 2 AK-MII'l-10091 B. JAHN JOHN MCMULLE MWD RUN 3 AK-MII'l-10091 B. JAHN JOHN MCMULLE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 10 UN 10E 496 2027 47.95 17.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 7067.0 4.250 4.500 8784.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. RECEIVED Or-,,,,, 2 c\.., 8 2001 # REMARKS: 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS) . Page 1 ~laSi\é1 i,}i¡ ~ ,..,' ,. VO.;3 ~..J'...IU.:.:: ~,:v~,.. t' ~ ;1'af¡t ""'i, \ 11 JJ:~I¡j, ') ) mpc-12a.tapx 3. MPC-12A KICKED OFF FROM THE MPC-12A PB1 WELLBORE AT 8784 'MD/ 6752.69'TVDSS. 4. MWD RUN 1 (MPC-12A PB1) COMPRISED DIRECTIONAL, DUAL GAMr:1A RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4). RUN 1 WAS DRILLED WITH NORDIC 3, A ROTARY RIG. THE DRILL FLOOR ELEVATION (DFE) WAS 47.95' AMSL. 5. MWD RUNS 2 AND 3 WERE DIRECTIONAL WITH NATURAL GAMr:1A PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. RUNS 2 AND 3 WERE DRILLED WITH NABORS 3S, A COILED TUBING DRILLING RIG. ITS DFE WAS 35'AMSL, BUT DEPTHS WERE REFERENCED TO A GAMMA RAY TIE-IN POINT. 6. DIGITAL DATA ONLY WERE SHIFTED TO THE CASED HOLE GAMr:1A RAY LOG RUN ON 1/25/2000. ALL LOG HEADER AND LOG DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-3 REPRESENT WELL MPC-12A WITH API#: 50-029-21373-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9106'MD/7039.62'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (BASED ON SEDP) . $ File Header Service name............ .STSLIB.001 Service Sub Level Name. .. Version Number..... _.... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type.......... ..... .LO Previous File Name...... .STSLIB.OOO Conunent Record FI LE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7033.5 7040.5 7040.5 7040.5 7040.5 7040.5 STOP DEPTH 9079.5 8788.0 8788.0 8788.0 8788.0 8788.0 Page 2 ') ) mpc-12a.tapx ROP $ 7079.0 9111.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 7033.5 7032.5 7043.0 7042.0 7070.5 7069.0 7207.5 7205.0 7277.0 7275.5 7343.0 7340.5 7474.0 7471.5 7566.5 7563.5 7617.0 7617.5 7666.0 7669.5 7688.0 7688.5 7712.5 7711.5 7759.0 7755.0 7784.0 7781.0 7948.0 7945.0 8015.5 8010.5 8053.5 8049.5 8078.0 8075.5 8177.0 8172 . 0 8300.0 8298.5 8317.0 8311.5 8360.0 8356.0 8466.5 8463.5 8516.5 8513 . 0 8520.0 8516.0 8541.0 8537.5 8554.0 8550.0 8566.0 8562.5 8581.5 8577.5 8589.0 8585.5 8606.5 8602.0 8638.0 8633.0 8646.5 8642.5 8654.5 8650.0 8671.5 8667.0 8675.0 8670.5 8676.5 8672.0 8682.5 8678.5 8687.0 8682.5 8691.5 8687.0 8714.0 8710.0 8722.0 8717.5 8730.0 8725.5 8732.0 8727.5 8737.0 8732.0 8769.5 8764.5 8770.0 8765.0 8772.0 8768.0 8773.5 8769.5 8777.5 8773.0 8781. 5 8777.0 9111. 0 9106.5 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7032.5 8784.0 MWD 2 8784.5 9008.0 MWD 3 9008.0 9106.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Page 3 ') ') mpc-12a.tapx Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. . .. .. ... . .. ..... .. . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7033.5 9111 8072.25 4156 7033.5 9111 ROP MWD FT/H 0.08 357.49 123.721 4042 7079 9111 GR MWD API 43.89 308.83 125.354 4093 7033.5 9079.5 RPX MWD OHMM 0.61 1217.42 3.34366 3496 7040.5 8788 RPS MWD OHMM 0.58 1630.92 8.1922 3496 7040.5 8788 RPM MWD OHMM 0.54 2000 27.053 3496 7040.5 8788 RPD MWD OHMM 0.56 2000 26.0443 3496 7040.5 8788 FET MWD HOUR 0.18 4.04 0.573132 3496 7040.5 8788 First Reading For Entire File......... .7033.5 Last Reading For Entire File....... ... .9111 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type. .. . . . .. .. '" . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. .. Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type.. . .. . .. . . . .. .. .LO Previous File Name...... .STSLIB.001 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS 2 header data for each bit run in separate files. 1 .5000 START DEPTH 7032.5 7039.5 7039.5 7039.5 7039.5 STOP DEPTH 8784.0 8783.5 8783.5 8783.5 8783.5 Page 4 ) RPX ROP $ 7039.5 7077.5 8783.5 8784.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point.. ........... .Undefined Frame Spacing.................... .60 .1IN Max frames per record. . .. . . . . . .. . .Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') mpc-12a.tapx 04-NOV-99 Insite 4.15 Memory 8784.0 7072 . 0 8784.0 17.2 50.8 TOOL NUMBER P13 7 6GRV4 P13 7 6GRV4 6.125 Water 9.60 44.0 9.6 500 4.5 Based 2.600 .970 2.400 2.600 63.0 107.0 63.0 63.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Page 5 ) ) mpc-12a.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7032.5 8784 7908.25 3504 7032.5 8784 ROP MWD010 FT/H 18.61 357.49 144.3 3414 7077.5 8784 GR MWD010 API 43.89 308.83 121.397 3504 7032.5 8784 RPX MWD010 OHMM 0.61 1217.42 3.34543 3489 7039.5 8783.5 RPS MWD010 OHMM 0.58 1630.92 8.20324 3489 7039.5 8783.5 RPM MWD010 OHMM 0.54 2000 26.9858 3489 7039.5 8783.5 RPD MWD010 OHMM 0.56 2000 25.5196 3489 7039.5 8783.5 FET MWD010 HOUR 0.18 4.04 0.572872 3489 7039.5 8783.5 First Reading For Entire File......... .7032.5 Last Reading For Entire File.......... .8784 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. .. Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type. .. . . . .... . .. . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 Fi le Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 8784.5 8796.0 STOP DEPTH 8976.5 9008.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: ~ 17-MAR-01 Insite N/A Memory 9006.0 8784.0 9006.0 17.2 29.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER 62181 # BOREHOLE AND CASING DATA Page 6 ) ) OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): mpc-12a.tapx 4.250 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Based Water 11.60 54.0 9.6 180000 4.2 .000 .000 .000 .000 .0 107.9 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8784.5 9008 8896.25 448 8784.5 9008 ROP MWD020 FT/H 0.19 30.65 9.80308 425 8796 9008 GR MWD020 API 77.81 217.17 147.764 385 8784.5 8976.5 First Reading For Entire File......... .8784.5 Last Reading For Entire File.. ........ .9008 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. .. Version Number.......... .1.0.0 Page 7 ) Date of Generation...... .01/12/04 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 ) mpc-12a.tapx header data for each bit run in separate files. 3 .5000 START DEPTH 8977.0 9008.5 STOP DEPTH 9075.0 9106.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record. . .. ... .. .. . .Undefined 18-MAR-01 Insite N/A Memory 9106.0 9006.0 9106.5 30.9 32.3 TOOL NUMBER 62181 4.250 Water 11.60 54.0 9.6 180000 4.2 Based .000 .000 .000 .000 .0 120.6 .0 .0 Page 8 ) ) mpc-12a. tapx Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8977 9106.5 9041.75 260 8977 9106.5 ROP MWD030 FT/H 0.08 57.93 12.3276 197 9008.5 9106.5 GR MWD030 API 107.12 165.77 153.667 197 8977 9075 First Reading For Entire File......... .8977 Last Reading For Entire File.......... .9106.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. .. Version Number.......... .1.0.0 Date of Generation...... .01/12/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name........ .... .LISTPE Date.................... .01/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name..... .......... . UNKNOWN Continuation Number..... .01 Next Tape Name. ......... . UNKNOWN Comments.... ....... ..... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . .. . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .01/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name. . . . . . .. . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 9