Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
197-142
• • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5 D FEB 2 4 2.012- Mr. Tom Maunder 42 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ....- venue r�/� Anchorage, Alaska 99501 1' Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPG -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPG-01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG-02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG-05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG-07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG -08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG -09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG -10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG -11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 ---- MPG -12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG -13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG -15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG -16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG -17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG -18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG -19 2041920 50029232280000 1.6 NA 1.6 NA 13.6 8/15/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-142 397-145 i3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612- ,-"i'-'. :'~'¢' '.~ ~ .... ~ ...... 50-029-22792 ....... ~~~'~"~ 9. Unit or Lease Name 4. Location of well at surface ~ ~"': " ~~i 1784' Neb, 3365' WEb, SEC. 27, T13N, R10E, UM ? ._!./~'./~.. ~,~_ Milne Point Unit At top of productive interval~ --[ ~----'~.~r~ ~__ __ I~! 10' Well Number 2375' NSL, 3843' WEb, SEC. 27, T13N, R10E, UM~' MPG-12 At total depth .3 .~- ....... ~.,~ ............. 11. Field and Pool 2958' NSL, 4021' WEb, SEC. 27, T13N, R10E, UM Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 58.05'I ADb 025906 12. Date Spudded8/5/97 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °ffsh°re 116' N°' °f C°mpleti°ns8/11/97 1/21/98 N/A MSL One ,17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121 · Thickness of Permafrost 7452 7302 FTI 4394 4293 FTI ~]Yes [] No N/A MD 1800' (Approx.) 122. Type Electric or Other Logs Run MWD, EMMS, GR/CCL 23. CASING~ LINER AND CEMENTING RECORD CASING I SETTING DEPTH HOLE SIZEI WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 120' 24" _~50 sx Arcticset I (Approx.) 9-5/8" 40# L-80 29' 4532' 12-1/4" 1730 sx PF 'E', 455 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and i25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 3927' MD TVD MD TVD ~,-1/2" disc assy w/3" glass disc 4145'-4148' 4140' 4086'-4106' 3993'-4012' 4215'-4240' 4119'-4143' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 4284'-4304' 4186'-4205' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Attachment 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Februar/8, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED !OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~chora¢~l Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSB1 4076' 3983' TSBE 4103' 4009' TSBD 4211' 4115' TSBC 4246' 4149' TSBB 4280' 4182' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig ~1. 'T';,,.. ~' ~' '~' Date ~ ~ MPG-12 97-142 397-145 ~repared DF Name/NumDer; ~a~F Campoamor, 5~4-5722 Well Number Permit No. / Approval No. ,, INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL NAME: MPG-12 26. (10-407) Attachment- Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) 6735'-7452' EZSV at 4482' 4394'-4479' Amount & Kind of Material Used Freeze protect with 70 bbls diesel P&A Kuparuk with 66-1/2 bbls 'G' Cement Kuparuk P&A #2 with 18 bbls 'G' cement below EZSV, sqzd to 700 psi Cement above EZSV, 4 bbls 'G' Cement Frac w/Proplock 4284'-4304 Frac w/Proplock 4215'-4240 Frac w/Proplock 4086'-4106 18,347# 16/20 Carbolite behind pipe 31,000# 16/20 Carbolite behind pipe 47,500# 16/20 Carbolite behind pipe Performance Enquiry Report Operator BP Exploration Date 00:30, 26 Mar 98 Page 1 The analysis is from - 00:00, 10 Aug 97 - to - 00:00, 10 Aug 97 Programs in Result Table: MPG-12 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPG-12 Event 00:00, 10 Aug 97 00:00, 10 Aug 97 0 hr 0 min Obtained leak off 12.7 Hole Size MDR 8-1/2 Facility Date/Time 04 Aug 97 05 Aug 97 06 Aug 97 07 Aug 97 08 Aug 97 09 Aug 97 10 Aug 97 M Pt G Pad Progress Report Well MPG- 12 Rig Nabors~F~.~ Page Date Duration Activity 03:01-04:00 04:00-04:15 04:15-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-15:00 15:00-20:00 20:00-21:30 21:30-02:00 02:00-06:00 06:00-01:00 01:00-02:00 02:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-12:30 12:30-13:30 13:30-14:30 14:30-15:00 15:00-06:00 06:00-08:00 08:00-11:30 11:30-12:00 12:00-13:00 13:00-15:30 15:30-18:00 18:00-19:00 19:00-20:30 20:30-22:30 22:30-00:00 00:00-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-11:00 11:00-12:30 12:30-13:00 13:00-17:00 17:00-18:00 18:00-01:30 01:30-06:00 06:00-09:00 09:00-12:30 12:30-13:30 13:30-17:00 17:00-17:30 17:30-18:00 18:00-19:30 19:30-20!30 20:30-22:30 22:30-00:00 00:00-06:00 3/4 hr 1/4 hr 1-3/4 hr 1/2 hr 2hr 3-1/2 hr 3hr 5hr 1-1/2 hr 4-1/2 hr 4hr 19 hr lhr lhr lhr 1/2 hr 1-1/2 hr 6-1/2 hr lhr lhr 1/2 hr 15hr 2hr 3-1/2 hr 1/2 hr lhr 2-1/2 hr 2-1/2 hr lhr 1-1/2 hr 2hr 1-1/2 hr 6hr 1-1/2 hr lhr 1/2 hr 2hr 1-1/2 hr 1/2 hr 4hr lhr 7-1/2 hr 4-1/2 hr 3hr 3-1/2 hr lhr 3-1/2 hr 1/2hr 1/2 hr 1-1/2 hr lhr 2hr 1-1/2 hr 6hr Rigged down Drillfloor / Derrick Held safety meeting Rig moved 15.00 % Held safety meeting Rig moved 50.00 % Rig moved 100.00 % Installed Drillfloor / Derrick Rigged up B ell nipple Held safety meeting Made up BHA no. 1 Drilled to 466.0 ft Drilled to 2290.0 ft Circulated at 2290.0 ft Pulled out of hole to 187.0 ft Serviced Top drive R.I.H. to 2290.0 ft Drilled to 2475.0 ft Drilled to 3309.0 ft Circulated at 3309.0 ft Pulled out of hole to 1924.0 ft R.I.H. to 3309.0 ft Drilled to 4550.0 ft Circulated at 4550.0 ft Pulled out of hole to 4550.0 ft Downloaded MWD tool Serviced Top drive R.I.H. to 4550.0 ft Circulated at 4550.0 ft Dropped EMMS survey barrel Pulled out of hole to 950.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 4531.6 ft (9-5/8in OD) Circulated at 4531.6 ft Mixed and pumped slurry - 182.000 bbl Displaced slurry - 337.000 bbl Circulated at 2113.0 ft Mixed and pumped slurry - 580.000 bbl Displaced slurry - 160.000 bbl Rigged down Casing handling equipment Installed Casing head Rigged up BOP stack Rigged up All rams Rigged up All functions Tested All functions Installed Wear bushing Made up BHA no. 2 R.I.H. to 2113.0 ft Drilled installed equipment - DV collar R.I.H. to 4445.0 ft Performed cement integrity test Drilled cement to 4570.0 ft Performed formation integrity test Drilled to 5369.0 ft 1 25 March 98 Facility M Pt G Pad Progress Report Well MPG- 12 Rig Nabors 4~S ~9-~ ~ Page Date 2 25 March 98 Date/Time 11 Aug 97 12 Aug 97 06:00-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-06:00 06:00-07:30 07:30-09:30 09:30-13:00 13:00-14:00 14:00-17:00 17:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-01:00 01:00-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-11:00 11:00-12:00 12:00-14:00 14:00-15:00 15:00-17:00 17:00-22:00 22:00-00:00 Duration 4-1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr 16hr 1-1/2 hr 2hr 3-1/2 hr lhr 3hr 1-1/2 hr lhr lhr lhr 3-1/2 hr 3-1/2 hr 1-1/2 hr 1/2hr 1/2 hr 1-1/2 hr 2-1/2 hr lhr 2hr lhr 2hr 5hr 2hr Activity Drilled to 6028.0 ft Circulated at 6028.0 ft Pulled out of hole to 6028.0 ft Serviced Top drive R.I.H. to 6028.0 fl Drilled to 7300.0 ft Circulated at 7452.0 ft Pulled out of hole to 945.0 ft Pulled BHA Rigged down Rig services R.I.H. to 7452.0 fl Circulated at 7452.0 ft Mixed and pumped slurry - 66.500 bbl Pulled out of hole to 6013.0 fl Circulated at 6013.0 ft Pulled out of hole to 0.0 ft R.I.H. to 4482.0 fl Functioned Setting tools Mixed and pumped slurry - 22.000 bbl Circulated at 4193.0 ft Circulated at 4193.0 ft Pulled out of hole to 2490.0 ft Circulated at 2490.0 ft Pulled out of hole to 0.0 ft Rigged down Drillstring handling equipment Rigged down BOP stack Rigged up Production master - surface tree Serviced Block line Facility Date/Time 07 Jan 98 08 Jan 98 09 Jan 98 10 Jan 98 11 Jan 98 12 Jan 98 Progress Report M Pt G Pad Well MPG-12 Page 1 Rig Nabors 4ES Date 25 March 98 20:00-06:00 06:00-07:00 07:00-07:30 07:30-08:30 08:30-10:00 10:00-12:30 12:30-14:30 14:30-15:30 15:30-16:30 16:30-17:30 17:30-18:30 18:30-20:00 20:00-21:30 21:30-00:00 00:00-02:30 02:30-04:00 04:00-06:00 06:00-09:00 09:00-10:00 10:00-12:30 12:30-14:00 14:00-15:30 15:30-16:30 16:30-19:30 19:30-21:30 21:30-22:30 22:30-03:30 03:30-05:30 05:30-06:00 06:00-07:00 07:00-09:00 09:00-12:00 12:00-16:00 16:00-17:00 17:00-18:00 18:00-22:45 22:45-00:30 00:30-00:45 00:45-01:00 01:00-03:00 03:00-06:00 06:00-09:00 09:00-10:00 10:00-14:30 14:30-19:00 19:00-20:00 20:00-20:30 20:30-23:30 23:30-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-14:30 14:30-15:00 Duration 10hr lhr 1/2 hr lhr 1-1/2 hr 2-1/2 hr 2hr lhr lhr lhr lhr 1-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 2hr 3hr lhr 2-1/2 hr 1-1/2 hr 1-1/2 hr lhr 3hr 2hr lhr 5hr 2hr 1/2 hr lhr 2hr 3hr 4hr lhr lhr 4-3/4 hr 1-3/4 hr 1/4 hr 1/4 hr 2hr 3hr 3hr lhr 4-1/2 hr 4-1/2 hr lhr 1/2 hr 3hr 6-1/2 hr lhr 1/2 hr 1/2 hr 6-1/2 hr 1/2 hr Activity Rig moved 100.00 % Rigged up Additional services Installed Hanger plug Removed Xmas tree Installed BOP stack Tested BOP stack Serviced HCR valve Tested HCR valve Removed Hanger plug Made up BHA no. 1 Pulled BHA Removed BOP stack Removed Tubing head spool Installed Tubing head spool Installed BOP stack Tested Tubing head spool Ran Drillpipe to 120.0 ft (3-1/2in OD) Ran Drillpipe to 120.0 ft (3-1/2in OD) (cont...) Circulated at 1875.0 ft Ran Drillpipe to 4394.0 ft (3-1/2in OD) Reverse circulated at 4394.0 ft Pulled Drillpipe in stands to 1544.0 ft Ran Drillpipe in stands to 4394.0 ft Circulated at 4394.0 ft Pulled Drillpipe in stands to 4394.0 ft Removed BOP stack Removed Tubing head spool Installed BOP stack Tested BOP stack Tested BOP stack (cont...) Held safety meeting Conducted electric cable operations Perforated from 4284.0 ft to 4304.0 ft Conducted electric cable operations Flow check Bullhead well Monitor wellbore pressures Bleed down well Bullhead well Monitor wellbore pressures Bleed down well Bleed down well (cont...) Tested Variable ram Ran Tubing to 4000.0 ft (3-1/2in OD) Circulated at 4000.0 ft Rigged up High pressure lines Held safety meeting Tested Testing equipment Injectivity test - 150.000 bbl injected at 837.0 psi Injectivity test - 150.000 bbl injected at 837.0 psi (cont...) Mixed and pumped 64.000 bbl of treatment Reverse circulated at 4000.0 ft Monitor wellbore pressures Monitor wellbore pressures Facility Date/Time 13 Jan 98 14 Jan 98 15 Jan 98 16 Jan 98 M Pt G Pad Progress Report Well MPG-12 Page 2 Rig Nabors 4ES Date 25 March 98 15:00-16:00 16:00-16:15 16:15-16:30 16:30-17:00 17:00-19:00 19:00-20:30 20:30-00:45 00:45-02:45 02:45-06:00 06:00-07:00 07:00-07:30 07:30-10:00 10:00-11:00 11:00-12:00 12:00-13:00 13:00-14:00 14:00-16:00 16:00-16:15 16:15-17:45 17:45-18:00 18:00-20:00 20:00-20:30 20:30-22:00 22:00-02:00 02:00-05:30 05:30-06:00 06:00-07:30 07:30-08:15 08:15-08:30 08:30-09:30 09:30-11:00 11:00-12:30 12:30-14:00 14:00-15:00 15:00-15:15 15:15-22:00 22:00-22:45 22:45-23:00 23:00-01:00 01:00-01:30 01:30-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-13:00 13:00-16:00 16:00-18:00 18:00-19:00 19:00-19:15 19:15-22:00 22:00-00:30 00:30-01:30 01:30-02:45 Duration lhr 1/4 hr 1/4 hr 1/2 hr 2hr 1-1/2 hr 4-1/4 hr 2hr 3-1/4 hr lhr 1/2 hr 2-1/2 hr lhr lhr lhr lhr 2hr 1/4 hr 1-1/2 hr 1/4 hr 2hr 1/2 hr 1-1/2 hr 4hr 3-1/2 hr 1/2hr 1-1/2 hr 3/4 hr 1/4hr lhr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 1/4hr 6-3/4 hr 3/4 hr 1/4 hr 2hr 1/2hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 4hr 3hr 2hr lhr 1/4 hr 2-3/4 hr 2-1/2 hr lhr 1-1/4 hr Activity Reverse circulated at 4000.0 ft Removed High pressure lines Ran Tubing to 4095.0 ft (3-1/2in OD) Flow check Circulated at 4095.0 ft Ran Tubing to 4275.0 ~t (3-1/2in OD) Circulated at 4230.0 ft Pulled Tubing in stands to 0.0 ft Conducted electric cable operations Conducted electric cable operations (cont...) Rigged down sub-surface equipment - Production logging tools Ran Tubing in stands to 4235.0 ft Reverse circulated at 4235.0 ft Flow check Reverse circulated at 4260.0 ft Flow check Reverse circulated at 4260.0 ft Flow check Circulated at 4260.0 ft Flow check Circulated at 4260.0 ft Flow check Pulled Tubing in stands to 0.0 ft Perforated from 4214.0 ft to 4239.0 ft Conducted electric cable operations Ran Tubing in stands to 350.0 ft Ran Tubing in stands to 350.0 ft (cont...) Circulated at 3916.0 ft Held safety meeting Injectivity test - 20.000 bbl injected at 1835.0 psi Monitor pressures Injectivity test - 145.000 bbl injected at 1695.0 psi Monitor pressures Mixed and pumped 368.400 bbl of treatment Reverse circulated at 3916.0 ft Monitor wellbore pressures Reverse circulated at 3916.0 ft Flow check Circulated at 3916.0 ft Flow check Pulled Tubing in stands to 0.0 ft Made up BHA no. 1 R.I.H. to 4008.0 ft Serviced Draw works Serviced SCR Washed to 4180.0 ft Reverse circulated at 4180.0 ft Circulated at 4180.0 ft Pulled out of hole to 7.0 ft Pulled BHA Conducted slickline operations on Slickline equipment - Tool run Installed Bridge plug Tested Bridge plug - Via annulus and string Circulated at 4160.0 ft Facility Date/Time 17 Jan 98 18 Jan 98 19 Jan 98 20 Jan 98 M Pt G Pad Progress Report Well MPG-12 Page 3 Rig Nabors 4ES Date 25 March 98 02:45-04:15 04:15-06:00 06:00-07:30 07:30-07:45 07:45-10:30 10:30-10:45 10:45-13:00 13:00-14:30 14:30-15:30 15:30-17:30 17:30-18:00 18:00-06:00 06:00-13:00 13:00-13:30 13:30-14:00 14:00-15:00 15:00-15:15 15:15-16:15 16:15-16:45 16:45-17:15 17:15-18:30 18:30-22:00 22:00-23:00 23:00-06:00 06:00-07:30 07:30-08:15 08:15-08:30 08:30-11:30 11:30-12:30 12:30-14:00 14:00-16:15 16:15-16:30 16:30-17:30 17:30-18:45 18:45-19:30 19:30-21:30 21:30-22:30 22:30-00:00 00:00-00:45 00:45-03:00 03:00-06:00 06:00-12:00 12:00-12:30 12:30-17:00 17:00-20:00 20:00-21:00 21:00-21:30 21:30-21:45 21:45-00:00 00:00-01:30 01:30-02:00 02:00-04:00 04:00-06:00 06:00-06:15 Duration 1-1/2 hr 1-3/4 hr 1-1/2 hr 1/4 hr 2-3/4 hr 1/4 hr 2-1/4 hr 1-1/2 hr lhr 2hr 1/2 hr 12hr 7hr 1/2hr 1/2 hr lhr 1/4 hr lhr 1/2hr 1/2 hr 1-1/4 hr 3-1/2 hr lhr 7hr 1-1/2 hr 3/4 hr 1/4 hr 3hr lhr 1-1/2 hr 2-1/4 hr 1/4 hr lhr 1-1/4 hr 3/4 hr 2hr lhr 1-1/2 hr 3/4 hr 2-1/4 hr 3hr 6hr 1/2 hr 4-1/2 hr 3hr lhr 1/2 hr 1/4 hr 2-1/4 hr 1-1/2 hr 1/2 hr 2hr 2hr 1/4 hr Activity Pulled Drillpipe in stands to 0.0 ft Tested All functions Tested All functions (cont...) Retrieved Hanger plug Installed Logging/braided cable equipment Held safety meeting Conducted electric cable operations Perforated from 4086.0 ft to 4106.0 ft Perforated Ran Tubing in stands to 3792.0 ft Circulated at 3792.0 ft Circulated at 3792.0 ft Circulated at 3792.0 ft (cont...) Held safety meeting Installed High pressure lines Tested Completion equipment Injectivity test - 20.000 bbl injected at 1760.0 psi Monitor pressures Injectivity test - 31.600 bbl injected at 840.0 psi Monitor pressures Injectivity test - 205.000 bbl injected at 2486.0 psi Monitor pressures Mixed and pumped 482.000 bbl of treatment Monitor wellbore pressures Monitor wellbore pressures (cont...) Reverse circulated at 3792.0 ft Flow check Laid down 3792.0 ft of Tubing Made up BHA no. 2 R.I.H. to 4105.0 ft Washed to 4170.0 ft Flow check Serviced Block line Pulled out of hole to 132.0 ft Pulled BHA Ran Drillpipe in stands to 4179.0 ft Retrieved Bridge plug Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 3 R.I.H. to 4177.0 ft Washed to 4204.0 ft Washed to 4204.0 ft (cont...) Pulled out of hole to 3955.0 ft Reverse circulated at 3955.0 ft Laid down 3637.0 ft of 3-1/2in OD drill pipe Pulled BHA Rigged up Rigging equipment Held safety meeting Conducted electric cable operations Installed Production packer Rigged down Logging/braided cable equipment Ran Tubing to 2350.0 ft (2-7/8in OD) Pulled Tubing in stands to 0.0 ft Held safety meeting Facility Date/Time 21 Jan 98 Progress Report M Pt G Pad Well MPG-12 Page 4 Rig Nabors 4ES Date 25 March 98 06:15-12:00 12:00-14:30 14:30-16:15 16:15-16:30 16:30-05:00 05:00-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-14:00 14:00-18:00 Duration 5-3/4 hr 2-1/2 hr 1-3/4 hr 1/4 hr 12-1/2 hr lhr 1/2hr 3hr 2hr 2-1/2 hr 4hr Activity Installed Electrical submersible pumps Ran Tubing to 1640.0 ft (2-7/8in OD) Rigged up sub-surface equipment - Other sub-surface equipment Held safety meeting Ran Tubing in stands to 3905.0 ft Space out tubulars Held safety meeting Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Circulated at 3905.0 ft Milne Point Unit, Alaska TO: Bill Hill FROM: Kirby Walker Well Name: [MPU G-12 Main Category:/PERF Sub Category: Wireline Operation Date: ~01-10-98 Date: I January 10, 1998 Objective: To perforate the OB sands from 4,284'-4,304' (4,186-4,204' TVD) and to measure SBHP and temperature. Sequence of Events: 08:50 09:05 09:58 10:03 11:45 12:58 14:05 14:40 15:30 16:09 16:19 16:29 16:39 17:00 Safety meeting with SWS, BP, rig crew, and company man Start RIH w/GR/CCL set down at 4,348' Log up to 4,116' - S/D examine logs - reset counter (50' shallow) RIH w/GR/CCL to 4,391' POOH logging to 3 100' to get a,l[;af. Ungu Sand. POOH ' ~ -' RD lubricator. RU 7" HSD gun with 4 spf, 58C-UP RDX, (0-1.8~0~) RIH w/7" perforating string Gun correlated to depth. Recheck depths. Fire Gun. *"P-©©I~i! RD lubricator. RU Production Log w/GR/CCL/Temp/Press RIH w/PL string to 4,294' (mid perf) First pressure/temperature reading BHP - 1918 psi BHT - 83° BHP - 1917 psi BHT - 83° BHP - 1917 psi BHT - 83° BHP - 1917 psi BHT - 83° - POOH RD SWS. Results: G-12 was successfully perforated in the OB Sand from 4,284' - 4,304'. SBHP and SBHT readings were also taken (1,917 psi and 83°)` at midperf 4,294' (4,195' TVD). Interval Measured Depth ......... Top Ft. Base Ft. Gun Dia. Shot Den. Tie in log/date - 1-10-98 Phasing 4,284 It 4,304 J[ 7" II 4 spf il 0-180° J BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Bill Hill FROM: Jim Fox/Kirby Walker DATE: 01/12/98 RE: G-12 (OB Sand) DATA FRAC AND PROPLOK FRAC TREATMENT SERVICE CO'S.: Dowell, Halliburton, Nabors, Peak JOB SUMMARY Of the 80,000# of proppant (16/20 Carbo-Lite) originally designed to be injected in the OB, only 18,347# were actually placed behind pipe. A total of 308 bbl of 60# HEC gel were used to pump 30,296# of proppant (11,949# was left in the tubing/casing and had to be reversed out). All of which was coated with Halliburton's PropLok resin for formation consolidation purposes. The job got off on a slow start as a result of Dowell's blender running out of fuel. It had to be rigged down and taken to Kuparuk to have the fuel system flushed and refilled. The rig circulated the hole during this time. Being one of the "Sweet Sixteen" wells, an extensive DataFRAC was designed for the G-12 prior to the actual Fracture treatment. Due to a frozen manifold KCI tank, the job went a bit different than designed. An empty/clean vac truck was ordered to pull the fluid off the frozen frac tank and send it to the frac equipment via the vac truck. Rather than waiting on the truck, it was decided to pump the Injection Test and Matrix Test with diesel that was on location for freeze protecting. The delay in availability of the vac trucks allowed for more time to collect the falloff data of the pump-in tests. The vac truck arrived so the DataFRAC was able to be pumped using the 2% KCI as planned. 125 BBL were pumped at the designed rate of 12 BPM when pumps were shut down and pressure falloff was analysed. The Leakoff coefficient found was a bit higher than expected and the job was redesigned as such. Treating pressure was fairly constant throughout the job at 1,780 psi until the 6 PPA stage hit the perfs. From here both the treating pressure and annular pressure began rising sharply until screenout occurred. Notes: · I spoke with the Dowell supervisor, Steve Doughtan, about how to prevent equipment from running out of fuel as it did on this job. He mentioned that the POD (blender) has a smaller fuel tank than the other equipment and needs to be filled more often than the other equipment. He is looking into getting a larger tank installed on the unit while until then we (both Dowell and BP) must remind the fuelers that they need to refuel the POD about every 3 hours. · It was found that the frozen water tank was the one left on G-Pad from the G-1 1 frac where it had reported problems of fluid transfer through the manifold. Hot water (150°F) was put into the tank after the job and HB&R is going to further heat the fluid if necessary to melt the ice. This tank will be used for the next stage. · The treating string was 3.5" 9.3 ppf 8-round tubing. The string of NSCT that is normally used is still in the hole on 5S. · HEC gel was utilized while pumping the PropLok due to an incompatibility between the guar gel and the PropLok additive. I NJECTIVITY TEST Design Rate, Bbls Max Rate, ISIP, psi NWB friction, Treat grad, BPM Pumped BPM psi psi/ft 12 20.5* 10.4 992 230 0.64 * pumped with diesel DATA FRAC Bbls Bbls XL gel Time XL gel on Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped to Perfs perfs psi psi/ft 125 125* N/A 1,659 703 164 0.63 *2% KCI was used as DF fluid FRAC Sand Lead prop Coated Design total pumped, behind pipe, prop behind pipe, Sand left in Job was M# M# behind M# Casing, M# /size pipe, M# /size Screened Out - 30,296 18,347 18,347 80,000 11,949 end of 7 PPA 16/20 16/20 Ft of sand Estimated Final ISIP, psi ISIP Incr Actual Pad TSO, design, TSO, in Pipe sand top STP, overdatafrac Percentage min Nolte psi Plot 9' 4,275' 5,140 N/A N/A 27.2% 7.4 421 DATE/TIME OPERATIONS SUMMARY 01110/98 M IRU Dowell. 21:00 Pre-job safety meeting. 23:10 Pressure test surface treating lines. - 6,618 psi 23:29 Start pumping 2% KCI for Matrix Test at 0.50 BPM. 23:37 Start pumping Injectivity Test with Diesel at 10 BPM. 04:55 Start DataFRAC 06:41 Start pumping redesigned job. 07:06 Screenout job at beginning of 7 PPA stage. 07:36 Reverse out 10,534~ of 16/20 proppant coated with PropLOK TIMEI PUMPING SUMMARY RATE IANNPi WHP STAGE CUM BPM PSlG I PSIGI BBL aBE COMMENTS 01/12/98 DATA FRAC 23:29 0.5 584 720 7.2 0 Start Matrix Test (2% KCI) 23:37 0 0 0 0 7.2 S/D could not get KCI rate - frozen tank 00:10 10 859 1757 20 0 Start Injectivity Test (diesel) 00:14 0 870 1748 0 27 Shutdown - monitor pressure falloff 01:59 0.5 150 380 35 34.1 Start Matrix Test (diesel) 02:07 0.5 721 1125 0 0 Matrix Test (pressure update) 02:33 0.5 854 1349 0 0 Matrix Test (pressure update) 03:07 0 996 1482 0 69.1 S/D ISlP - 964 psi .0..4:51 0 308 749 125 0 Start DataFRAC (2% KCl) 04:55 12 854 1720 0 0 DataFRAC (pressure update) 05:02 0 872 1652 0 196.4 S/D ISIP - 703 psi 06:41 12 959 1734 54 0 Start PAD (60# HEC) 06:45 12 904 1766 93 54 1 PPA (60# HEC) 06:54 12 1005 1711 12 147 2 PPA (60# HEC) 06:55 12 1019 1871 18 159 3 PPA (60# HEC) 06:56 12 1010 1871 25 177 4 PPA (60# HEC) 06:57 12 1038 1775 30 202 5 PPA (60# HEC) 07:00 12 1069 1812 35 232 6 PPA (60# HEC) 07:03 12 1119 1601 39 267 7 PPA (60# HEC) 07:06 12 3179 3464 2 306 8 PPA (60# HEC) 07:06 0 5166 4687 0 308 Screenout - S/D pumps 07:36 ..... Rig starts to reverse out proppant Page 4 FLUIDS PUMPED DOWNHOLE MATRIX TEST: INJ TEST: DATA FRAC: FRAC: 1st Attempt - 7.2 BBL of 2% KCI were pumped. 2® Attempt - 35 BBL of Diesel 20 BBL of Diesel 125 BBL of 60# HEC gel 308 BBL 60# HEC gel 703 BBLs TOTAL FLUIDS PUMPED DOWN HOLE Milne Point Unit, Alaska TO: Bill Hill FROM: K. WalkedH.Thackeray Well Name: I!MPU G-12 Main Category: PERF Sub Category: Wireline Operation Date: 01-13,14-98 Date: I January 14, 1998 I Objective: To perforate the OA sands from 4,215'-4,240' (4,118-4,142' TVD) and to measure SBHP and temperature. Sequence of Events: RU SWS. Call for radio silence. RIH w/GR/CCL & 25' of perforating guns. Set down at 4,256'. Correlate to GR/CCL log 1/10/98. Perforate "OA" sand from 4215-4240' with 4 spf, 58C-UP RDX, (0-180°). POOH. RIH with Production Log w/GR/CCLITemp/Press. Set sensor at 4228'. Initial BHP = 2087.6 psi, T = 78.5 F 20 min BHP = 2084.2 psi, T = 78.2 F 30 min BHP = 2084.0 psi, T = 78.2 F 40 min BHP = 2083.6 psi, T= 78.0 F 50 min BHP = 2083.4 psi, T = 78.0 F 60 min BHP = 2083.5 psi, T = 77.9 F POOH. RD SWS. Results: G-12 was successfully perforated in the OA Sand from 4,215' - 4,240'. SBHP and SBHT readings were also taken (2083 psi and 78°) at midperf 4,228' (4,130' TVD). Interval Measured Depth ......... Top Ft. Base Ft. Gun Dia. Shot Den. Tie in log/date - 1-10-98 Phasing 4,215 J[ 4,240 II 7" I! 4spf 1l 0'180° J Page I BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: J. Spearman / B. Hill FROM' M. O'Malley DATE: 01/14/98 RE: G-12AO. DATA FRAC AND PROP-LOK FRAC SERVICE CO'S.: Dowell, Nabors, and Peak JOB SUMMARY Frac treatment for the AO sand was designed on location by Jim Spearman, Of the 80,000# of proppet ( 16/20 Carba-Lite ) proplok frac treatment, 47M# of the slurry was pumped, a total of 31 M# was placed behind pipe, approx. 16.2M# was left in pipe and was reversed out to surface. All of the treatment was coated with Halliburton's Proplok resin for formation consolidation purposes. Arrived location rigged up DS frac fleet and the Halliburton's proplok treatment van. Held pre-job safety meeting, During the first stage of the data frac a hour matrix was performed with a lengthy fall off period, also a short second data frac was performed while displacing for pad. Tested all equipment to 5620 psi. Tested the annular pop off's, The results were not consistent, so a max. screen out pressure was set at 3400 psi. The data frac and the fracturing treatment pumping was steady 1620 psi. but pressure started to take a dip down as the 8ppg was on perfs, slight increase as the 9ppg entered the perfs approx. 42 Bbls into the 71 Bbls stage of 10 pound slurry tubing pressure increased cut sand and attempted to flush surface lines screened out. Shut down pumping just as the 10ppg was on perfs. Reversed the tbg. Clean. RD DS. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP, psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft 12 20 13.6 585 525 MATRIX TEST Design Rate, Bbls Max Rate, Final STP, ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft .5 45 .8 560 510 Page 2 DATA FRAC Bbls Bbls HEC to Time HEC gel Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped perfs on perfs psi psi/ft 158 100 8.5 1,555 640 124 .65 With HEC. DATA FRAC Bbls Bbls KCLto Time KCL on Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped perfs perfs psi psi/ft 50 50 4 min. 1,496 630 124 .65 With KCL FRAC Sand Lead prop Tail prop Design total pumped, behind pipe, behind behind pipe, Sand left in Job was M# M# pipe, M# M# casing, tbg M# /size /size Screen out 47 M 31.M 31 M 80,000 16.2 start of 10 ppg 16/20 16/20 Operational problems The mixing of surface diesel and the HEC gel has created a fluid disposal problem. The issue is being work at this time. The next frac job we will be using glycol for warm up fluid and freeze protection. DATE/TIME OPERATIONS SUMMARY f, 01/14/98 00:01 3.5", 9.2 ppf tbg. In place w/tubing tail at 3900' MD and Petredat gauge at 3870". MIRU Dowell. Complete filling tanks. 00:01 Petredat gauges start on 15 sec. Interval. 08:00 Hold pre-job safety meeting. 08:35 Pumps primed. Start pressure test to 6500 psi 08:55 Pressure test to 5600 psig - ok. 09:25 Start injectivity test with 2% KCL water watch for 1 hour 09:30 freeze protect lines. 11:00 Start matrix test. Pump at .5 bpm for 1hr. 12:00 S/D pumps - monitor pressure fall off. With well shut it at rig floor freeze protect treating lines w/diesel. Continue monitoring falloff pressures for one hour. 12:05 Start 100 Bbl HEC Data Frac 12 bpm. 12:14 Start flush with 2% KCL 12:20 I Shut down 640 ISIP monitor well for 30 min. P~q~ R 12.'~6 Start a second data with HEC 50 Bbls while displacing flush fluid away. 13:00 Shut down pumping 630 ISIP monitor well for a hour. 14:17 Start Frac HEC pad 14:25 Pad on perfs 14:27 Start 1 ppg. Continue with pump schedule 1 ppg. Thru. 10 ppg, 14:46 Start 10 ppg. Approx 42 Bbls in the annulus started to climb. Went to flush fluid. 14:49 Screened out psi climbed to 3400 psi. shut down. Flush lines out. Rd DS PUMPING SUMMARY BPM I PSIG PSIG BBL BBL COMMENTS INJECTIVITY TEST DISPLACEMENT = 58 BBLS 09:25 12.5 735 1600 0/20 20 Start injectivity test w/2% KC 585 Sd. Monitor WHP. ISIP = 210 psi. End monitor WHP. MATRIX TEST 11:00 .5 210 .5 49 Start pumping no gain in tubing pressure 11'10 .5 631 8 57 Start matrix. Tbg. psi responding. 11'15 .8 620 838 11 60 Bumped the rate to .8 bpm 11:28 .8 672 990 20 69 12:00 0 680 935 45 94 Shut down matrix 12:04 0 342 645 DATA FRAC 12:08 0112 809 1650 0/6 110 Est rate w/HEC 60 # 100 Bbls 12:12 12 772 1734 58 168 Gel on perfs 12:17 12 777 1739 100 210 Gel flush .Switch to 2% KCL 12:21 12 764 1550 0/58 Stop pumping 12:22 0 640 814 0 254 Monitor WHP 12:58 0/12 440 654 0/1 Start a 50 Bbl 2% KCL data frac 13:00 12 708 1470 50 304 Stop pumping 13:05 0 621 830 0 Monitor WHP ISIP = 621 FRAC i~,'~"'~"~ ' 0/12 731 1542 0 0/ Establish rate with 60# gel 114:23 12 713 1580 61 61 Stage pad 12 740 1590 100 161 Stage 1 ppg 16/20 with risen 14:35 12 780 1640 10 171 Stage 2 ppg 14:37 12 772 1645 15 186 3 ppg. 14:39 12 780 1615 18 204 4 ppg 14:40 12 772 1640 21 225 5 ppg 14:42 12 770 1650 23 248 6 ppg 14:44 12 763 1620 25 273 7 ppg 14:46 12 763 1500 26 299 8 ppg 14:48 12 763 1372 27 325 9 ppg 14:50 12 804 1352 71 396 10 ppg 14:53 12 2420 3400 41 Bbls into the 10 pound screaned out. Reverse out. 47M pumped. 31M behind pipeStage flush 15:00 Reverse tbg. clear. Monitor pressure, 12 hours clean out and continue as per program. FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 241 Bbls FRAC: 378 Bbls 619 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 80 Bbls Diesel to IA, tubing, or GC 40 Bbls Diesel Recovered (not downhole) 120 Bbls Total Diesel PETREDAT WINDOW 60 hours reading time at 15 sec. From 12:00 01/16 to 24:00 01/19 GEL QUALITY CONTROL CHECK Fresh H20 Fresh H20 60# GEL 60# GEL PIPE. XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 100 deg. 70 FLUID ADDITIVES Milne Point Unit, Alaska TO: Bill Hill FROM: H.Thackeray Well Name: I MPU G-12 Main Category: IPERF Sub Category: lWireline Operation Date: ~01-16-98 Date: I January 17, 1998 Objective: To perforate the N sands from 4,086'-4,106' (3,993-4,012' TVD). Sequence of Events: RU SWS. PJSM. RIH w/GR/CCL. Top of sand on RBP @ 4165'. Correlate depth to Sperry-Sun MWD 8/11/97. POOH. Call for radio silence. RIH w/CCL & 20' of perforating guns. Correlate to GR/CCL just ran. Perforate "N" sand from 4086-4106' with 4 spf, 58C-UP RDX, (0-180°). POOH. All shots fired. Lift radio silence. RD SWS. Results: G-12 was successfully perforated in the N Sand from 4,086' - 4,106'. Interval Measured Depth Tie in log/date - 8-11-97 Top Ft. Base Ft. Gun Dia. Shot Den. Phasing [ 4,086 J[ 4,106 Jl 7" It 4spf !1 0'180° J BP EXPLORATION (ALASKA) INC. Milne Point Unit TO: Bill Hill/Jim Spearman ~!. ~ ~ .,,-~._~ i~':',; · "" , .') ::/C FROM: Dan Robertson '~'~.~. ',,.~. , ,. DATE: 1/17/98 ' ~0~rS~'~ RE: MP G-12 N SAND DATA FRAC AND FRAC w/Halco Proplock SERVICE CO'S.: DS, Halco, Peak, Nabors JOB SUMMARY Injection test: Pumped 20 bbls 2% KCI at 15 bpm, 2000 psi STP. 9.6 ppg brine entering perfs during this stage. SD 1.5 hrs. Matrix Injection test: Pumped 85 bbls 2% KCI at 0.7 bpm, 800 psi STP. 9.6 ppg brine entering perfs initially, followed by 2% KCI. SD 20 min. HEC data frac: Pumped 100 bbls of 60# HEC gel through perfs at 20 bpm. SD and monitor pressure 30 min. 2% KCI Data Frac: Pumped 50 BBLS of 2% KCL through perfs at 20 bpm. SD and monitor pressure 30 min. Perform data frac analysis. Frac: Placed 47.5 M# 16/20 carbolite behind pipe at 20 BPM. Net pressure began increasing rapidly with 10 ppg entering perfs. Gained 350-400 psi net pressure, went to flush, then pressure began dropping. Possibly broke out of zone. Gradually reduced rate from 20 bpm down to 5 bpm at end of job in attempt to induce screenout. Still no screenout. Annulus ISIP following frac was 780 psi, approximately 100 psi increase over data frac. N sand carbolite is dyed purple, OA Sand carbolite is dyed red, OB sand carbo'lite is dyed blue for identification should any proppant production related problems occur. Note that 60/40 glycol premixed at the CFP was heated and used for pressure testing and freeze protection. Seemed to work well and made disposal simpler/cheaper than diesel since the former is non hazardous as a class 1 material. INJECTIVITY TEST Design Rate, BPM Bbls Pumped Max Rate, lAP psi bpm IFinal ISIP' I NWBfricti°n' I Treatgrad'PsI psi psi/ft 01/21/98 10:42 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL TIMEI RATE I ANNPI WHP I STAGE BPM I PSIGIPSIGI BBL PUMPING SUMMARY CUM COMMENTS BBL 15 I 20 I 20 I n/a I ~50 I I 0.~3 HEC DATA FRAC Bbls Bbls gel thru Time XL gel on Final Ann Annulus NWB friction, Treat grad, Pumped Perfs perfs press, psi ISIP, psi psi psi/ft 100 100 5 min 795 695 100 0.67 2% KCL DATA FRAC Bbls Bbls 2% KCI Time XL gel on Final Ann Annulus NWB friction, Treat grad, Pumped Thru Perfs perfs STP, psi ISIP, psi psi psi/ft 50 50 2.5 min 740 650 90 0.66 FRAC Sand Actual prop Tail prop Design total pumped, behind pipe, behind behind pipe, Liner Sand, Job was M# M# pipe, M# M# M# /size /size Flush 51.9 47.5 N/A 61 4.4 16/20 Ft of sand Estimated Final ISIP, psi ISIP Incr Pad Time to start in Pipe sand top STP, over datafrac fraction, of TSO, min psi pad/slurry vol, % 100 3980 1300 780 100 27 10 DATE/TIME OPERATIONS SUMMARY , !1/17/98, 10:00 DATA FRAC MIRU frac, vac, pump. AMBIENT=(-30), WIND=17 MPH, Wind chill= -65 F. 3.5" tubing to 3800'. 9.6 ppg NaCI brine in hole. Pre job operational and safety meeting. PT at 6000 psi with 60/40 glycol. Flush glycol to open top tank. Start injection test. 1/17/98 FRAC 2200 PUMP FRAC AS PER REVISED TSO 23OO RD DS PUMPING SUMMARY TIME J RATE ANNP WHP STAGE CUM COMMENTS I BPM PSIG PSIG BBL BBL 1/17/98 INJECTIVITY TEST DISPLACEMENT = 54 BBLS to top perf 1515 0/15 8 100 0 0 Start injectivity test. 9.6 ppg brine going into perfs. SlWHP should be zero prior to pumping 1516 15.2 8 2370 10 1517 15.2 8 1860 20/0 20/0 SD 1.5 hrs. Close ground valve to isolate well. Circulate glycol to tank to freeze protect surface lines. Annulus pressure does not seem to be reading correctly. ISlP= 650 psi. MATRIX INJECTION DISPLACEMENT = 54 BBLS 1612 0/0.7 0 110 0 53 Start injectivity test. 9.6 ppg brine going into perfs. 1618 0.7 500 650 5 58 . 1655 0.7 630 840 85 SD 1.5 hrs. ISIP= 590 psi HEC DATA FRAC DISPLACEMENT = 54 BBLS 1720 0/ 230 440 0 0 Start 60# HEC gel 1724 20 750 2100 54 gel at perfs 1726 20 820 2140 100/0 185 Switch to 2% KCl 1728 20 790 2750 55/0 240 ISIP=695b annulus, 850 psi on tubing. SD monitor pressure 30 min. NWBF= 100 psi. Frac grad =0.67 psi/ft 2% KCI DATA FRAC 1800 0/20 370 580 0 242 Start 2 % KCL 1803 20 740 2500 50 292 SD. ISIP=830 psi on tubing, 650 psi on annulus. FG= 0.66 psi/ff. NWBF=90 psi. 1838 0 255 467 294 Move fluid to prevent freeze up. 1844 Shut down PUMPING SUMMARY BPM PSlG I PSlGI BBL BBL FRAC 2213 0/20 240 450 0 Start 60# HEC Pad 2216 20 820 2250 30 !2217 20 800 2170 54 Pad at perfs 2219 20 850 2220 94/0 Stage 1 ppg 16/20 Carbolite 2221 20 830 2200 54 148 I ppg at perfs 2224 20 820 2180 103/0 197 Stage 2 ppg 5 202 13/0 210 3 ppg 215 2226 19.9 800 2220 17/0 227 4 ppg 239 2 ppg at perfs 21/0 249 5 ppg 253 2227 20 800 2261 23/0 272 6 ppg 273 3 ppg at perfs 25/O 297 7 ppg 304 4 ppg at perfs 2229 20 814 2330 26/0 323 8 ppg 329 5 ppg at perfs 358 6 ppg at perfs 2231 20 850 2400 28/0 352 9 ppg 378 ppg at perfs 2234 20 920 2260 29/0 381 10 ppg 402 8 ppg at perfs 422 9 ppg at perfs 428 2236 20 1150 2500 39 440 Stage flush w/HEC. Net pressure increase of 350 psi, pressure increasing rapidly. 20/0 Stage 2% KCL. Net pressure dropping rapidly, reduce rate gradually to induce screenout 2240 5 780 19 482 SD. ISIP- 780 psi. 15 bbls underdisplacement Page 5 FLUIDS PUMPED DOWNHOLE 2% Kcl 300 bbls 60#HEC 562 bbls 60/40 Glycol 80 bbls (used on surface, not pumped downhole) 862 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WIN DOW 12:00 1/16/98 to 00:00 hrs 1/20/98, Petradat in GLM at 3750' MD GEL QUALITY CONTROL CHECK SEA H20 60#geltemp 60#GEL 60#GEL pH TEMP pH VISCOSITY DF/FRAC 7 80 7 60 cp FLUID ADDITIVES DS 60#/Mgal HEC system w/2.5 gpt J-134, 2 gpt F-75N. All 16/20 carbolite coated with Halliburton proplock at 0.375 gal/100# proppant, ES-5 surfactant at 2 gal/ 100#. SPt SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 Y-SUN DRILLING SERVICES ANCHORAGE ALASKA ufV~Y'~ /~7/~ DATE OF S : 081197 MWD SURVEY JOB NUMBER: AK-MM-70230 PAGE KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -58.05 112.00 112.00 53.95 212.03 212.03 153.98 304.69 304.69 246.64 394.94 394.94 336.89 0 0 N .00 E .00 .00N .00E .00 0 0 N .00 E .00 .00N .00E .00 0 2 S 28.79 W .04 .03S .02W -.02 0 15 N 72.58 W .26 .00N .23W .07 0 27 N 79.11 W .23 .13N .76W .34 486.26 486.25 428.20 571.41 571.36 513.31 660.26 660.09 602.04 750.66 750.25 692.20 839.02 838.22 780.17 0 56 N 62.46 W .57 .54N 1.78W 2 24 N 56.96 W 1.72 1.84N 3.89W 3 27 N 49.38 W 1.27 4.60N 7.49W 4 40 N 48.33 W 1.35 8.82N 12.31W 6 4 N 44.25 W 1.63 14.57N 18.26W 1 03 2.88 6 57 12.01 19 23 933.60 932.18 874.13 1023.05 1020.79 962.74 1115.15 1111.61 1053.56 1205.32 1199.96 1141.91 1296.82 1289.12 1231.07 7 2 N 50.03 W 1.24 21.87N 26.20W 8 33 N 54.13 W 1.81 29.29N 35.79W 10 30 N 55.34 W 2.13 38.09N 48.25W 12 25 N 55.80 W 2.13 48.22N 63.05W 13 31 N 54.92 W 1.22 59.91N 79.95W 28 52 38.40 50 43 64.41 80 49 1389.36 1379.04 1320.99 1482.07 1469.10 1411.05 1574.12 1558.57 1500.52 1663.40 1645.43 1587.38 1755.77 1735.36 1677.31 13 48 N 56.46 W .49 72.23N 98.01W 13 41 N 55.92 W .18 84.48N 116.31W 13 28 N 55.48 W .26 96.66N 134.16W 13 15 N 55.53 W .23 108.35N 151.17W 13 10 N 55.57 W .10 120.29N 168.59W 97 51 114.54 131 37 147.48 163 . 95 1847.06 1824.25 1766.20 1940.01 1914.87 1856.82 2031.94 2004.49 1946.44 2122.70 2092.86 2034.81 2212.58 2179.95 2121.90 13 8 N 55.47 W .04 132.06N 185.71W 12 34 N 53.39 W .79 144.08N 202.54W 13 1t N 50.96 W .90 156.65N 218.72W 13 8 N 50.87 W .07 169.69N 234.77W 15 30 N 44.80 W 3.11 184.66N 251.16W 180.17 196.55 213.27 230.40 249.47 2308.36 2272.21 2214.16 2399.99 2360.42 2302.37 2492.77 2449.66 2391.61 2585.60 2538.92 2480.87 2677.90 2627.77 2569.72 15 39 N 43.27 W .46 203.16N 269.04W 15 43 N 37.83 W 1.61 221.97N 285.13W 16 1 N 34.26 W 1.10 242.48N 300.05W 15 51 N 33.82 W .23 263.61N 314.32W 15 36 N 33.97 W .26 284.38N 328.27W 272.35 295.01 318.97 343.32 367.24 2769.66 2716.17 2658.12 2865.14 2808.26 2750.21 2956.88 2896.87 2838.82 3049.47 2986.36 2928.31 3142.46 3076.21 3018.16 15 30 N 30.79 W .94 305.15N 341.45W 15 7 N 29.77 W .49 326.92N 354.16W 14 52 N 29.43 W .28 347.56N 365.89W 14 52 N 30.00 W .16 368.21N 377.68W 14 57 N 29.89 W .09 388~96N ~389.63W 390.94 415.46 438.61 461.79 485.11 ORIGINAL SP~--%Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 081197 MWD SURVEY JOB NUMBER: AK-MM-70230 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3234.28 3164.98 3106.93 3326.98 3254.67 3196.62 3418.24 3343.01 3284.96 3511.53 3433.37 3375.32 3604.56 3523.62 3465.57 14 38 14 39 14 23 14 23 13 41 N 29.35 W .37 409.35N 401.22W N 29.16 W .06 429.81N 412.69W N 29.21 W .30 449.80N 423.85W N 23.46 W 1.53 470.56N 434.12W N 21.75 W .87 491.40N 442.81W 507.99 530.89 553.25 576.09 598.56 3694.84 3611.43 3553.38 3788.17 3702.35 3644.30 3878.40 3790.30 3732.25 3969.42 3879.04 3820.99 4063.79 3971.09 3913.04 13 7 12 59 12 50 12 51 12 37 N 20.60 W .71 510.92N 450.38W N 20.71 W .14 530.65N 457.81W N 20.95 W .18 549.50N 464.98W N 16.68 W 1.04 568.64N 471.51W N 16.60 W .23 588.58N 477.46W 619.44 640.47 660.59 680.80 701.61 4153.52 4058.62 4000.57 4248.00 4150.78 4092.73 4339.93 4240.45 4182.40 4432.80 4331.00 4272.95 4474.81 4371.96 4313.91 12 45 12 44 12 43 12 55 12 43 N 16.98 W .16 607.45N 483.16W N 17.12 W .03 627.38N 489.27W N 17.22 W .03 646.73N 495.25W N 17.48 W .23 666.41N 501.40W N 17.57 W .48 675.30N 504.21W 721.32 742.16 762.42 783.03 792.36 4568.40 4463.21 4405.16 4659.53 4552.20 4494.15 4751.99 4642.75 4584.70 4844.00 4732.93 4674.88 4936.61 4823.66 4765.61 12 58 11 52 11 23 11 30 11 35 N 16.77 W .33 695.20N 510.35W N 14.83 W 1.29 714.06N 515.71W N 13.32 W .61 732.15N 520.25W N 14.06 W .20 749.91N 524.57W N 14.40 W .12 767.88N 529.13W 813.18 832.79 851.42 869.67 888.19 5029.32 4914.56 4856.51 5121.47 5005.00 4946.95 5214.15 5096.03 5037.98 5307.59 5187.82- 5129.77 5399.61 5278.23 5220.18 11 8 10 56 10 45 10 46 10 41 N 14.55 W .49 785.57N 533.70W N 15.01 W .24 802.63N 538.20W N 13.97 W .29 819.52N 542.56W N 16.55 W .52 836.34N 547.15W N 15.22 W .28 852.82N 551.84W 906.45 924.08 941.50 958.94 976.07 5490.91 5367.96 5309.91 5586.02 5461.44 5403.39 5680.53 5554.32 5496.27 5774.94 5647.05 5589.00 5870.33 5740.72 5682.67 10 10 10 10 10 38 35 43 55 53 N 16.28 W .22 869.08N 556.43W N 17.71 W .28 885.83N 561.55W N 16.87 W .21 902.52N 566.74W N 19.70 W .61 919.35N 572.31W N 19.17 W .11 936.37N 578.31W 992.96 1010.48 1027.95 1045.67 1063.71 5965.43 5834.13 5776.08 6061.88 5928.96 5870.91 6155.18 6020.78 5962.73 6250.58 6114.71 6056.66 6344.94 6207.64 6149.59 10 10 10 10 9 43 19 4 4 55 N 19.67 W .20 953.19N 584.24W N 18.83 W .43 969.82N 590.05W N 19.93 W .34 985.41N 595.53W N 16.65 W .60 1001.25N 600.77W N 16.60 W .16 1016.94N 605.46W 1081.52 1099.12 1115.63 1132.31 1148.69 SPi~-~2Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 081197 MWD SURVEY JOB NUMBER: AK-MM-70230 KELLY BUSHING ELEV. = 58.05 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 6437.86 6299.19 6241.14 9 46 N 17.10 W .19 6531.34 6391.32 6333.27 9 40 N 16.11 W .20 6627.97 6486.59 6428.54 9 36 N 16.36 W .08 6723.59 6580.90 6522.85 9 21 N 14.82 W .38 6818.66 6674.78 6616.73 8 50 N 16.21 W .58 1032.15N 610.06W 1164.57 1047.28N 614.57W 1180.36 1062.82N 619.10W 1196.55 1077.99N 623.33W 1212.30 1092.47N 627.35W 1227.32 6914.01 6769.06 6711.01 8 19 N 17.66 W .58 7011.05 6865.11 6807.06 8 1 N 20.46 W .51 7106.62 6959.79 6901.74 7 39 N 19.51 W .42 7202.20 7054.52 6996.48 7 33 N 20.79 W .20 7297.45 7148.95 7090.90 7 33 N 20.07 W .10 1106.09N 631.49W 1241.55 1119.14N 635.99W 1255.34 1131.39N 640.45W 1268.36 1143.26N 644.81W 1280.99 1155.00N 649.18W 1293.49 7392.84 7243.52 7185.47 7 24 N 19.49 W .19 1166.69N 7452.00 7302.19 7244.14 7 24 N 19.49 W .03 1173.87N 653.38W 1305.89 655.93W 1313.51 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1344.70 FEET AT NORTH 29 DEG. 11 MIN. WEST AT MD = 7452 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 343.17 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 7,452.00' MD SPF .....Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 081197 JOB NUMBER: AK-MM-70230 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.05 .00 N .00 E 1000.00 998.00 939.95 27.28 N 33.01 W 2000.00 1973.39 1915.34 152.06 N 213.05 W 3000.00 2938.54 2880.49 357.20 N 371.33 W 4000.00 3908.85 3850.80 575.15 N 473.46 W .00 2.00 2.00 26.61 24.61 61.46 34.85 91.15 29.69 5000.00 4885.79 4827.74 780.09 N 532.27 W 6000.00 5868.10 5810.05 959.24 N 586.41 W 7000.00 6854.17 6796.12 1117.69 N 635.45 W 7452.00 7302.19 7244.14 1173.87 N 655.93 W 114.21 23.07 131.90 17.69 145.83 13.93 149.81 3.98 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP~-~qY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 081197 JOB NUMBER: AK-MM-70230 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.05 58.05 58.05 .00 158.05 158.05 100.00 258.05 258.05 200.00 358.05 358.05 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .06 S .04 W .00 .00 .07 N .48 W .00 .00 458.06 458.05 400.00 558.09 558.05 500.00 658.22 658.05 600.00 758.48 758.05 700.00 858.96 858.05 800.00 .33 N 1.37 W 1.53 N 3.42 W 4.52 N 7.39 W 9.25 N 12.79 W 16.08 N 19.74 W .01 .00 .04 .04 .17 .13 .43 .26 .91 .48 959.67 958.05 900.00 1060.73 1058.05 1000.00 1162.40 1158.05 1100.00 1264.86 1258.05 1200.00 1367.74 1358.05 1300.00 23.92 N 28.64 W 32.59 N 40.35 W 43.03 N 55.41 W 55.61 N 73.83 W 69.38 N 93.71 W 1.62 .71 2.68 1.06 4.35 1.67 6.81 2.46 9.69 2.88 1470.70 1458.05 1400.00 1573.58 1558.05 1500.00 1676.36 1658.05 1600.00 1779.07 1758.05 1700.00 1881.76 1858.05 1800.00 82.97 N 114.08 W 96.59 N 134.06 W 110.03 N 153.62 W 123.30 N 172.97 W 136.53 N 192.21 W 12.65 2.96 15.53 2.88 18.31 2.78 21.02 2.71 23.71 2.69 1984.26 1958.05 1900.00 2086.96 2058.05 2000.00 2189.90 2158.05 2100.00 2293.66 2258.05 2200.00 2397.53 2358.05 2300.00 149.86 N 210.27 W 164.56 N 228.47 W 180.52 N 246.93 W 200.27 N 266.32 W 221.44 N 284.72 W 26.21 2.49 28.91 2.70 31.85 2.94 35.61 3.76 39.48 3.87 2501.50 2458.05 2400.00 2605.48 2558.05 2500.00 2709.34 2658.05 2600.00 2813.12 2758.05 2700.00 2916.71 2858.05 2800.00 244.47 N 301.41 W 268.12 N 317.34 W 291.39 N 333.00 W 315.12 N 347.38 W 338.57 N 360.82 W 43.45 3.97 47.43 3.99 51.29 3.86 55.07 3.78 58.66 3.59 3020.18 2958.05 2900.00 3123.66 3058.05 3000.00 3227.12 3158.05 3100.00 3330.48 3258.05 3200.00 3433.77 3358.05 3300.00 361.70 N 373.92 W 384.75 N 387.21 W 407.77 N 400.34 W 430.59 N 413.12 W 453.17 N 425.73 W 62.13 3.47 65.61 3.48 69.07 3.45 72.43 3.36 75.72 3.29 SP~-~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 081197 JOB NUMBER: AK-MM-70230 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3537.01 3458.05 3400.00 3640.00 3558.05 3500.00 3742.71 3658.05 3600.00 3845.33 3758.05 3700.00 3947.89 3858.05 3800.00 4050.43 3958.05 3900.00 4152.93 4058.05 4000.00 4255.46 4158.05 4100.00 4357.98 4258.05 4200.00 4460.55 4358.05 4300.00 476.37 N 436.65 499.20 N 445.92 521.09 N 454.20 542.63 N 462.36 564.05 N 470.13 585.78 N 476.63 607.32 N 483.12 628.95 N 489.75 650.53 N 496.43 672.31 N 503.26 W 78.96 3.24 W 81.95 2.99 W 84.66 2.70 W 87.28 2.62 W 89.84 2.57 W 92.38 2.54 W 94.88 2.50 W 97.41 2.53 W 99.93 2.52 W 102.50 2.57 4563.11 4458.05 4400.00 4665.51 4558.05 4500.00 4767.59 4658.05 4600.00 4869.64 4758.05 4700.00 4971.71 4858.05 4800.00 694.06 N 510.01 715.25 N 516.02 735.16 N 520.96 754.87 N 525.82 774.71 N 530.88 105.06 2.56 107.46 2.40 109.54 2.08 111.59 2.04 113.66 2.08 5073.65 4958.05 4900.00 5175.50 5058.05 5000.00 5277.28 5158.05 5100.00 5379.07 5258.05 5200.00 5480.83 5358.05 5300.00 793.85 N 535.85 812.51 N 540.81 830.91 N 545.54 849.14 N 550.84 867.29 N 555.91 W 115.60 1.94 W 117.44 1.85 W 119.23 1.79 W 121.02 1.79 W 122.78 1.76 5582.57 5458.05 5400.00 5684.33 5558.05 5500.00 5786.14 5658.05 5600.00 5887.98 5758.05 5700.00 5989.78 5858.05 5800.00 885.23 N 561.36 903.19 N 566.95 921.35 N 573.02 939.52 N 579.41 957.45 N 585.77 W 124.52 1.74 W 126.28 1.75 W 128.09 1.82 W 129.93 1.84 W 131.73 1.79 6091.45 5958.05 5900.00 6193.03 6058.05 6000.00 6294.60 6158.05 6100.00 6396.11 6258.05 6200.00 6497.58 6358.05 6300.00 974.84 N 591.76 991.64 N 597.79 1008.62 N 602.97 1025.37 N 607.98 1041.83 N 613.00 W W W W W 133.40 1.68 134.98 1.58 136.55 1.56 138.07 1.52 139.53 1.47 6599.03 6458.05 6400.00 6700.43 6558.05 6500.00 6801.73 6658.05 6600.00 6902.89 6758.05 6700.00 7003.92 6858.05 6800.00 1058.19 N 617.74 1074.35 N 622.37 1089.97 N 626.62 1104.55 N 631.00 1118.20 N 635.64 W W W W W 140. 98 1.44 142.38 1.40 143. 68 1.30 144. 84 1.15 145. 87 1. 04 SP?-L~IY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 081197 JOB NUMBER: AK-MM-70230 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7104.87 6958.05 6900.00 1131.17 N 640.37 W 146.82 .95 7205.76 7058.05 7000.00 1143.70 N 644.97 W 147.71 .89 7306.63 7158.05 7100.00 1156.14 N 649.59 W 148.58 .88 7407.49 7258.05 7200.00 1168.47 N 654.01 W 149.44 .85 7452.00 7302.19 7244.14 1173.87 N 655.92 W 149.81 .37 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPF~EY-SUN DRILLING SERVICES SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 ANCHOP~AGE ALASKA DATE OF : 97 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70236 PAGE KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT SECT 660.26 660.09 602.04 3 27 715.51 715.22 657.17 3 59 805.44 804.86 746.81 5 10 896.60 895.54 837.49 6 34 988.28 986.51 928.46 7 36 N 49.38 W .00 4.59N 7.48W N 49.70 W .97 6.92N 10.21W N 46.62 W 1.33 11.73N 15.55W N 49.00 W 1.56 17.97N 22.47W N 53.57 W 1.29 25.02N 31.31W 6 9 15 23 33 .56 .58 .73 .71 .01 1078.56 1075.78 1017.73 9 28 1170.32 1166.02 1107.97 11 20 1260.69 1254.34 1196.29 13 0 1352.19 1343.36 1285.31 13 45 1444.50 1432.95 1374.90 14 8 N 55.09 W 2.08 32.82N 42.22W N 56.74 W 2.06 42.09N 55.95W N 56.28 W 1.85 52.61N 71.84W N 57.57 W .88 64.16N 89.59W N 57.38 W .41 76.12N 108.35W 43 56 71 87 104 .64 .49 .16 .35 .23 1536.74 1522.53 1464.48 13 24 1627.44 1610.74 1552.69 13 30 1718,59 1699.38 1641.33 13 28 1809.47 1787.78 1729.73 13 20 1900.78 1876.70 1818.65 12 55 N 57.19 W .79 87.99N 126.82W N 56.78 W .15 99.49N 144.53W N 57.85 W .28 110.98N 162.42W N 58.27 W .17 122.12N 180.30W N 55.59 W .81 133.44N 197.69W 120 137 153 169 184 .94 .08 .25 .10 .96 1992.93 1966.58 1908.53 2084.98 2056.26 1998.21 2177.25 2145.77 2087.72 2270.72 2235.92 2177.87 2364.05 2325.67 2267.62 12 32 13 29 14 36 15 58 15 52 N 55.38 W .42 144.95N 214.44W N 52.64 W 1.22 157.15N 231.20W N 49.63 W 1.45 171.22N 248.62W N 44.67 W 2.01 188.00N 266.65W N 44.12 W .19 206.30N 284.56W 200 217 235 257 279 .83 .36 .87 .15 .85 2455.80 2413.88 2355.83 16 3 2548.50 2502.94 2444.89 16 10 2641.18 2592.02 2533.97 15 50 2733.48 2680.82 2622.77 15 49 2825.95 2769.86 2711.81 15 28 N 39.45 W 1.41 225.10N 301.36W N 36.85 W .79 245.34N 317.24W N 36.26 W .41 265.86N 332.46W N 35.92 W .10 286.21N 347.30W N 32.77 W 1.00 306.79N 361.37W 302 326 35O 374 398 .72 .68 .73 .50 .28 2919.65 2860.20 2802.15 15 20 3011.48 2948.79 2890.74 15 11 3104.08 3038.15 2980.10 15 12 3197.37 3128.20 3070.15 15 2 3289.68 3217.38 3159.33 14 53 N 32.59 W .15 327.74N 374.81W N 32.85 W .17 348.08N 387.88W N 33.21 W .11 368.45N 401.12W N 33.01 W .19 388.84N 414.42W N 32.66 W .19 408.87N 427.35W 422 445 468 492 515 .22 .48 .80 .17 .09 3382.20 3306.81 3248.76 14 48 3472.93 3394.55 3336.50 14 40 3566.15 3484.75 3426.70 14 34 3657.49 3573.29 3515.24 13 52 3749.47 3662.68 3604.63 13 22 N 31.89 W .23 428.93N 440.01W N 31.05 W .28 448.63N 452.07W N 26.41 W 1.26 469.25N 463.38W N 25.00 W .85 489.46N 473.12W N 24.31 W .58 509.15N 482.16W 537.95 560.30 583 .31 605.48 626. 94 ORIGINAL SP~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 80897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70236 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3840.82 3751.57 3693.52 13 18 N 23.86 W .13 528.39N 490.76W 3932.85 3841.15 3783.10 13 10 N 23.46 W .17 547.69N 499.21W 4024.41 3930.35 3872.30 12 52 N 20.43 W .81 566.82N 506.93W 4116.34 4019.97 3961.92 12 54 N 20.36 W .03 586.05N 514.08W 4208.12 4109.41 4051.36 13 0 N 20.53 W .12 605.33N 521.26W 647.84 668.77 689.32 709.79 730.32 4301.06 4199.98 4141.93 12 54 N 20.51 W .11 624.84N 528.57W 4438.40 4333.78 4275.73 13 9 N 20.31 W .19 653.88N 539.37W 751.12 782.03 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 847.63 FEET AT NORTH 39 DEG. 31 MIN. WEST AT MD = 4438 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 343.17 DEG. TIE-IN SURVEY AT 660.26' MD LAST SURVEY STATION AT 4,438.40' MD SP~-'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 80897 JOB NUMBER: AK-EI-70236 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 660.26 660.09 602.04 4.59 N 7.48 W 1660.26 1642.65 1584.60 103.69 N 150.94 W 2660.26 2610.38 2552.33 270.06 N 335.54 W 3660.26 3575.98 3517.93 490.06 N 473.40 W 4438.40 4333.78 4275.73 653.88 N 539.37 W .17 17.61 17.44 49.88 32.27 84.28 34.40 104.62 20.33 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPerRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 80897 JOB NUMBER: AK-EI-70236 KELLY BUSHING ELEV. = 58.05 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 660.26 660.09 602.04 758.44 758.05 700.00 858.87 858.05 800.00 959.57 958.05 900.00 4.59 N 7.48 W 8.86 N 12.50 W 15.15 N 19.23 W 22.76 N 28.25 W .17 .39 .22 . 82 .43 1.52 .70 1060.59 1058.05 1000.00 1162.20 1158.05 1100.00 1264.49 1258.05 1200.00 1367.32 1358.05 1300.00 1470.39 1458.05 1400.00 31.13 N 39.79 W 41.22 N 54.62 W 53.09 N 72.56 W 66.09 N 92.63 W 79.53 N 113.67 W 2.54 1.02 4.15 1.61 6.44 2.30 9.27 2.82 12.34 3.07 1573.25 1558.05 1500.00 1676.09 1658.05 1600.00 1778.91 1758.05 1700.00 1881.65 1858.05 1800.00 1984.19 1958.05 1900.00 92.58 N 133.94 W 105.70 N 154.05 W 118.41 N 174.30 W 131.02 N 194.16 W 143.88 N 212.87 W 15.20 2.87 18.04 2.84 20.86 2.82 23.60 2.73 26.14 2.55 2086.82 2058.05 2000.00 2189.95 2158.05 2100.00 2293.74 2258.05 2200.00 2397.71 2358.05 2300.00 2501.76 2458.05 2400.00 157.41 N 231.54 W 173.30 N 251.06 W 192.51 N 271.10 W 212.91 N 290.97 W 234.93 N 309.42 W 28.77 2.63 31.90 3.13 35.69 3.79 39.66 3.98 43.71 4.05 2605.87 2558.05 2500.00 2709.81 2658.05 2600.00 2813.69 2758.05 2700.00 2917.42 2858.05 2800.00 3021.08 2958.05 2900.00 258.09 N 326.76 W 280.98 N 343.51 W 304.04 N 359.60 W 327.24 N 374.49 W 350.20 N 389.24 W 47.82 4.10 51.76 3.94 55.64 3.88 59.37 3.73 63.03 3.66 3124.71 3058.05 3000.00 3228.28 3158.05 3100.00 3331.76 3258.05 3200.00 3435.20 3358.05 3300.00 3538.56 3458.05 3400.00 372.97 N 404.08 W 395.57 N 418.79 W 417.98 N 433.17 W 440.43 N 447.13 W 463.03 N 460.29 W 66.66 3.63 70.23 3.57 73.71 3.49 77.15 3.43 80.51 3.37 3641.79 3558.05 3500.00 3744.71 3658.05 3600.00 3847.48 3758.05 3700.00 3950.21 3858.05 3800.00 4052.82 3958.05 3900.00 486.05 N 471.53 W 508.14 N 481.70 W 529.79 N 491.38 W 551.32 N 500.79 W 572.76 N 509.14 W 83.74 3.23 86.66 2.92 89.43 2.77 92.16 2.72 94.77 2.61 4155.41 4058.05 4000.00 594.23 N 517.11 W 97.36 2.59 SP'--~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING MILNE POINT / MPG-12 500292279200 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 80897 JOB AKIMBER: AK-EI-70236 KELLY BUSHING ELEV. = 58.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4258.04 4158.05 4100.00 4360.63 4258.05 4200.00 4438.40 4333.79 4275.73 615.84 N 525.20 W 99.99 2.63 637.31 N 533.23 W 102.58 2.59 653.88 N 539.37 W 104.61 2.03 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASKA ..,IL AND GAS CONSERVATION CO~,.ivllSSlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to SB Producer 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [~ Development Plan RTE = 58.5' I--J Exploratory 7. Unit or Property Name 3. Address []Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number MPG-12 1784' NSL, 3365' WEL, SEC. 27, T13N, R10E, UM 9. Permit Number At top of productive interval 97-142 N/A 10. APl Number At effective depth 50-029-22792 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 2958' NSL, 4021' WEL, SEC. 27, T13N, R10E, UM 12. Present well condition summary Total depth: measured 7452 feet Plugs (measured) true vertical 7302 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor 88' 20" 250 sx Arcticset I (Approx.) 120' 120' Surface 4501' 9-5/8" 1730 sx PF 'E', 455 sx 'G', 4532' 4428' Intermediate Production Liner ~.ppro~e~ O0P¥ Perforation depth: measured N/A ~ , ~' true vertical Tubing(size, grade, and measured depth) N/A r~t~'l~At LIlI~ ~.o ,,,7 Packers and SSSV (type and measured depth) ,~_ Anchorage 13. Attachments ~ Description summaw of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: August 11, 1997 16. If proposal was verbally approved ~ Oil ~ Gas ~ Suspended Blair Wondzell 8/11/97 Me,ice Name of approver Date approved Contact Engin~r Name/Number: James RobeRson, 564-5159 Prepared By Name/Number: Kathy Campoamo6 564-5122 17. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge Signed Chip~vord .,~ ~ ~''¢~ Title Senior Drilling Engineer Date Commission Use Only Conditions of Approval: Noti~ Commission so representative may witness I Approva~ 5 Plug integrity. ~ BOP Test __ Location clearance Mechanical Integrity Test ,,-~9~r~~~rm required 10- .)avid W. Johnston Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submi~ In T~iplicaCe~ MP G-12 ADDENDUM I Milne Pt. Well# MP G-12 was drilled by NABORS RIG# 22E to a depth of 7,452' md. LWD logs revealed the well was "WET". Therefore the KUPARUK SANDS are to be abandoned by placing a cement plug from TD to 300 md feet above the top hydrocarbon bearing sand at 7,035' md. This will place the calculated Top of Cement at 6,735' md. A hole washout of 30% will be utilized in determining volume. l/ A 9-5/8" 40# EZSV will then be placed 50 feet above the 9-5/8" casing shoe. The 9-5/8" cased wellbore will then be used as a Schrader Bluff production well. 9-5/8", 40#, L-80, BTC casing was set at 4,532' md during the drilling of MP G-12. Verbal approval was obtained from B. Wondzell with AOGCC in a phone conversation with J. E. Robertson on BPXA Shared Services Drilling on or about 11AUG97 at ±0900 hrs to abandon the KUPARUK SANDS and set the EZSV as outlined below. . PU 5" muleshoe. RIH to TD at 7,452' md. Circulate and condition wellbore. Spot a 65 bbl balanced cement plug. Slowly pull 20 stands above the calculated top of the cement plug. CBU. POOH. NOTE: Calculated Top Of Cement is 6,735' md which is 300 feet above highest hydrocarbon bearing sand at 7,035' md. NOTE: Volume based on 8-1/2" hole from TD to 300' above KUPARUK 'A' SAND + 30%. PREMIUM G + .2% CFR-3 + HR-5 retarder as required WT: 15.8 PPG YIELD: 1.15 FT3/SK . PU 9-5/8", 40# EZSV. RIH and set same at 4,482' md. Pump 15 bbl cement down through the EZSV. Unsting and leave 4 bbl on top of EZSV. Calculated TOC inside casing will be 4,432' md. Deepest possible perf will be 4,310' md. POOH to 4430' md. CBU. NOTE: 9-5/8" shoe is at 4,532' md. Volume below EZSV based on 50' of 9-5/8" casing below the EZSV, 18' of 12-1/4" open hole + 30% + 82' of 8-1/2" open hole 30%. Volume above EZSV is based on 50 ft inside 9-5/8", 40# casing. PREMIUM G + .2% CFR-3 + HR-5 retarder as required , WT: 15.8 PPG YIELD: 1.15 FT3/SK Displace well with seawater. POOH LDDP. Stop at base of permafrost and displa~ ~ ~ ~ ! V ~ ~ well with diesel. Finish POOH LDDP. £ 0 1997 4. Test casing to 3500 psig. ' ' I~,N ' ~,/aska 0il .& Gas Cons, 5.~~~/P U and Test Tree. RDMO Nabors 22E drilling rig to drill next well. J~~~ Randy Thomas Drlg Op's Engineer Senior Drilling Engineer Drilling Superintendent AUG / - Milne Pt. Well# MP G-12 was drilled by NABORS RIG# 22E to a depth of 7,452 m~. LWD logs revealed the well was "WET". Therefore the KUPARUK SANDS are to be abandoned by placing a cement plug from TD to 300 md feet above the top hydrocarbon bearing sand at 7,035' md. This will place the calculated Top of Cement at 6,735' md, A hole washout of 30% will be utilized in determining voJume. A 9-5/8" 40# EZSV will then be placed 50 feet abeve the 9-5/8" casing shoe. The 9-5/8" cased wellbore will then be used as a Schrader Bluff production well. 9-5/8", 40#, L-80, BTC casing was set at ' md/=~4,532' md during the ddlling of MP G-12. verbal approval was obtained from B, Wondzell with AOGCC in a phone conversation with J. E. Roberteon on BPXA Shared Services Drilling on or about 11AUG97 at =~0900 hrs to abandon the KUPARUK SANDS and set the EZSV as outlined below. , PU 5" muleahoe. RIH to TD at 7,452' md, Circulate and condition wellbore, Spot a 65 bbl balanced cement plug. Slowly pull 20 stands above the calculated top of the cement plug. CBU. POOH. NOTE; Calculated Top Of Cement is 6,735' md which is 300 feet above highest hydrocarbon bearing sand at 7,035' md. NOTE: Volume based on 8-1/2" hole from TD to 300' above KUPARUK 'A' SAND ~. $0%. PREMIUM G + ,2% CFR-3 ~. HR-$ retarder es required WT: 15.8 PPG YIELD: 1.15 FT3/SK PU 9-5/8", 40# EZSV. RIH and set same at 4,482' md. Pump 15 bbl cement down through the EZSV. Unsting and leave 4 bbl on top of EZSV. Calculated TOC inside casing will be 4,432' md. Deepest possible perf will be 4,310' md, NOTE; 9-5/8" shoe is at 4,532' md. Volume below EZSV based on 50' of g-5/8" easing below the EZSV, 18' of 12.1/4" open hole + 30% + 82' of 8-1/2" open hole 30%. Volume above EZSV is based on 50 ft inside g-5/8", 40# casing, PREMIUM G + .2% CFR-3 + HR-5 retarder aS required WT: 15.8 PPG YIELD; 1.15 FT3/$K Displace well with seawater and enough diesel to cover from the base of permafrost to surface. 4, Test casing to 3500 psig. 5, ND BOPE, NU and Test Tree, RDMO Nabors 22E clrilling rig to drill next well, Drlg Op's Engineer Senior Drilling Engineer B~L"tdy_T_13_o. mas Drilling Superintendent Well Report ~~p. '01 /21 /1998 MILNE POINT UNIT SB G-12 Completion Status: 1-O1L Current Status 029-22792-00 197-142-0 BP EXPLORATION MD 0745gTVD 07302 Name Interval Sent Received BO 7825 ~OT~ 1,2 SPERRY MPT/GRC/EWR/CNP 9/26/97 9/26/97 DGR/CNP/SLD-MD ~../'FINAL 114-7452 9/26/97 9/26/97 DGR/CNP/SLD-TVD ~tL'/FINAL 112-7302 9/26/97 9/26/97 DGR/EWR4-MD / I_~: FINAL 114-7452 9/26/97 9/26/97 DGR/EWR4-TVD ~FINAL 112-7302 9/26/97 9/26/97 MWD SRVY ~ SPERRY 0-7452. P~ od ~ 4/4/98 4/6/98 MWD SRVY c..J3/' SPERRY 660.26-4438. ~ ~t t ~ ~ ~ I,~..~. 4/4/98 4/6/98 ! PACKER RED 37004140 l[/iCq/~'~, 2/25/98 2/26/98 PERF '-L~FINAL 40004166 1/16/98 1/21/98 1/29/98 PERF-TEM/PRES t.~INAL 41004356 1/13/98 1/21/98 1/29/98 PERF-TEM/PRES O,F~FINAL 2004396 1/10/98 1/21/98 1/29/98 Daily Well Ops 2~/~/~ 3~_ the well cored? yes Was Comments: Are Dry Ditch Samples Required? yes ~ And Received? Analysis Description Received? ~s--ao---~'~Sample Set'# Monday, January 10, 2 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11867 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape M PC-18 BRIDGE PLUG SET RECORD 9 8 0 21 2 I 1 M PU C-36 PERFORATING RECORD 9 8 0 2 0 5 I 1 G-12 PACKER SETTING RECORD 9 8 01 1 9 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 2/25/98 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11734 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 · , Field: Milne Point (Cased Hole) 1/21/98 _ Well Job # Log Description Date BL RF Sepia LIS Tape MPB-25 PERFORATION RECORD 9 8 0101 1 1 MPU C-15 INJECTION PROFILE 971 124 I 1 MPG-11 STATIC PRESSURE SURVEY 9 71 2 2 3 I 1 MPG-11 PERFORATION RECORD 9 71 2 2 3 I 1 ., MPG-11 PERFORATION RECORD 9 71 2 2 9 1 1 MPG-12 PERFORATING RECORD 9 8 01 10 I I ,,. MPG-12 PERFORATING RECORD 9 8 01 13 I 1 MPG-12 PERFORATING RECORD 9 8 01 1 6 I 1 MPJ-17 RFT 971 1 16 1 1 MPJ-17 PERF RECORD 971 1 19 I 1 MPJ-17 CHEMICAL CUT RECORD 971 1 19 I 1 MPK-34 PERFORATION RECORD 971 1 17 I 1 M P K-34 SUMP PACKER SET RECORD 9 71 1 17 I 1 MPL-35 TCP GR TIE IN W/PRESS-TEMP 971207 I I . ,,, ,. ,, [47.- 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 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 OFt I I_1--1 RI G SEFIL/ICE S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. ~,,~, Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPG-12, September 26, 1997 AK-MM-70230 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22792-00 SEP 2 S 1997 .Al~,,,sa ;.,-,i & Gas, O:-ns. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company O I::t I I--L- I ~ (3 S E I::! ~./I C E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ~l RE: MW Formation Evaluation Logs - MPG-12, AK-MM-70230 September 26, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPG-12: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22792-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22792-00 2" x 5" MD Neutron and Density Logs: 50-029-22792-00 2" x 5" TVD Neutron and Density Logs: 50-029-22792-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company MEMORANDUM TO: David Joh~~, Chairn~-~" State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 9 1997 THRU: Blair Wondzeil, P. i. Supervisor FILE NO: awokhiee.doc FROM: Chuck Scheve, ~,.~ Petroleum Inspector SUBJECT: BOPE Test Nabors 22E PTD # 97-142 Saturday, Auqust 9, 1997: I traveled to BPX's MPU G-12 Well being drilled by Nabors Rig 22E and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows the test lasted 2.5 hours with no failures. The test went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary.: ! witnessed the initial BOPE test on Nabors Rig 22E drilling BPXs MPU G-12 well. Nabors 22E, 819197, test time 2.5 hours, no failures Attachment: awokhiee.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: Ddg Contractor: Nabors Rig No. Operator: BPX Well Name: MP-G12 Casing Size: 9 5/8 Set @ Test: Initial X Weekly Other DATE: 8/9/97 22E PTD # 97-142 Rig Ph.# 659-4446 Rep.: Paul Woodard Rig Rep.' Rod Kle,p,z!~ Location: Sec. 27 T. 13N R. fOE Meridian UM , , Test MISC. INSPECTIONS: Location Gen.: .. ,OK Well Sign OK Housekeeping: OK (Gen) Drl. Rig OK , ,,. ,, PTD On Location Yes Hazard Sec. Yes ~, Standing Order Posted Yes - · FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure 250/5,000 250/5, 000 250/5,000 250/5,000 P/F P , , p' BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 250/35O0 250/5, 000 250/5, OOO 1 1 2 250/5, OO0 250/5,000 250/5,000 250/5, OOO N/A P/F P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK , ,,, Meth Gas Detector OK OK , , H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves 18 No. Flanges 36 i , Manual Chokes 2 Hydraulic Chokes 1 Test Pressure 250/5,000 250/5, OOO Functioned Functioned P/F P P P P ACCUMULATOR SYSTEM: System Pressure 3000 ! Pressure After Closure 1400 I 200 psi Attained After Closure minutes 25 System Pressure Attained 2 minutes 52 s~,. Blind Switch Covers: Master: Yes Remote: YES . Nitgn. Btl's: 8 Bott/es 1900 Psig. Number of Failures: ,0 , ,Test Time:,,, 2,.5. Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 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 II I I . . II I I I I II I II I I I I I I REMARKS: Good Test Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector F!~021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO [ II Waived By: Witnessed By: AWOKHIEE.XL$ Chuck Scheve . 2, 3, 4, 5. 11. 12, 13. 14, 1~, MP G-12 Proposed Summary of Operations Drill and Set 20' Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. MPG-12 has been permitted to drill surface hole without a diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR/Res from surface to TD. Run and cement 9-5/8' casing. ND 20" diverter. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent_ Drift 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig for 30 min. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion rig. NU & Test BOPE to ,5000 psig. ComPlete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and turn well over to production. OD:~M SH~RED SER¥ICES DRILLIM~ P,~/4 Bi' ~RAi'iON Memorandum To: From: Subject: Mr. Wonzell - Blair Wonzell, AOGCC Mark Brofka, SSD Operations Drilling Engineer MPG-10 and MPG-12, corrected operations summaries Date: 28 July 97 As a result of your phone call this morning pointing out lhe error in the MPG-12 "Proposed Summary of Operations," I noted that the same error existed in the MPG-10 summary. I apologize for the errors and have attached new "Proposed Summary of Operations" sheets with the corrections made on step 4 for each respective well. Please place the corrected sheets in with the respective well permits, Thanks for the phone call. If there is anything else I can do for you, please do not hesitate 1o call. Regards - Mark Brofka 564-4809 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Julv 31.1997 Chip Alvord Senior Drilling Engineer BP Exploration (.Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPG-12 BPX Exploration/Alaska) Inc. Permit No. 97-142 · '~ Sur Loc. 1784'NSL. 3365'WEL. Sec. 27. TloN. R10E. UM Btmhole Loc.: 2944'NSL. 4009'WEL. Sec. 27. T13N. R10E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed betbre drilling below the surface casing shoe must be given so that a representative of the Commission may wimess the test. Notice may be given bx.' contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlt;;enclosures Department of Fish & Game. Habitat Section w/o encl. Department of Envinomment Conservation w/o encl. ...... STATE OF ALASKA ALASK,-, ,_)IL AND GAS CONSERVATION CC,,,MISSION PERMIT TO DRILL 20/~J~C 25.005 REVISED: 07/28/97 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 58.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025906 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1784' NSL, 3365' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2944' NSL, 4009' WEL, SEC. 27, T13N, R10E, UM MPG-12 At total depth 9. Approximate spud date Amount $200,000.00 2944' NSL, 4009' WEL, SEC. 27, T13N, R10E, UM 07/31/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025516, 2336'I No Close Approach 2560 7577' MD / 7417' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 2o AAC 25.035 (e) (2)} Kick Off Depth 500' MD Maximum Hole Angle 45-36° Maximum surface 2848 psig, At total depth ri-VD) 7025' / 3550 psig :18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 4491' 31' 31' 4522' 4424' 1396 sx PF 'E', 540 sx Class 'G' 8-1/2" 7" 26# L-80 Btrc-Mod 7547' 30' 30' 7577' 7417' 241 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate I~ECE! V~D Production Liner ,)UL. 2.9 1997 4..~_n~lao,._ .Oil.& 6as cons. C0mrniss~,.~ Perforation depth: measured '_tlnchorago true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Brofka, 564-4809 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~.y~ ~., ~_-)"~/~._ Title Senior Drilling Engineer Date ~7//Z b/.~; ~7 Commission Use Only Permit Number I APl Number I Approval Date See cover letter 1 50- 7Ifor other requirements Conditions of Approval: Samples Required []Yes J~No Mud Log Required []Yes J~l No Hydrogen Sulfide Measures ~Yes ~No Directional Survey Required J~[lYes [] No Required Working Pressure for BOPE 1--12M; 1--13M; []5M; I--I10M; I--I15M Other: .. ~y. nal Signed By by order of Approved By navid W, Johnston Commissioner the commission Date '~.-. ~/- ~7 Form 10-401 Rev. 12-01-8~ Submit In Triplicate Shared Services Drilling Contact: I Well Name: Mark Brofka IMP G-12 Well Plan Summary IType of Well (producer or injector): IKUPARUK PRODUCER 564-48O9 I Surface Location: Schrader Tar~let (Secondary): Kuparuk Tar~let (Primary): Bottom Hole Location: 1784 FSL, 3365 FEL, S27 T13N R10E UM., AK 2347 FSL, 3830 FEL, S27 T13N R10E UM., AK 2944 FSL, 4009 FEL, S27 T13N R10E UM., AK 2944 FSL, 4009 FEL, S27 T13N R10E UM., AK I AFE Number: 1337090 I Estimated Start Date: I 31 JULY 97 MD: 17,577' I I Rig: I Nabors22E Well Design: Formation Markers: I J Operating days to complete: I 10 I'rVD: 17,417 bkb I I KBE: 158.50' IMilne Point Ultra Slimhole Longstring 9-5/8", 40# Surface X 7", 26# Longstdng Formation Tops MD TVD (bkb) base permafrost 1878 1800 Top Ugnu 3582 3445 Top "M" Sands 3827 3685 NA 4067 3920 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 4322 4170 Base of Schrader Bluff Sands (_8.3 ppg) HRZ 6470 6275 High Resistivity Zone MK-19 6670 6470 Top Kuparuk 6843 6640 Kuparuk Cap Rock Target Sand -Target 7180 6800 . Target Sand (9._6 ppg) Total Depth 7577 741'7 TD at 300' MD past base of Schrader Casin~'l'ut in~l Program: Hole ~ize 'Csg/ Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112 / 112 12 1/4" 9-5/8" 40# L,80 btm 4491 31/31 4522 / 4424 8-1/2" 7" 26# L-80 btrc- 7547 30/30 7577 / 7417 mod Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at +7025 TVDSS. Maximum anticipated surface ~3't~{s.~..re~ilq~i!~ (~a~assuming a rese~oir pressure of 3550 psi (9.66 ppg EMW) is 2848 psi, well below the inter~l ~ ~r~_~ti~g of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional surface to TD. LWD Gamma Ray/Resistivity surface to TD. Cased Hole Logs: N/A Intermediate Final MWD Directional and LWD Triple Combo CDR/CDN (GR/RES/Dens/Neu). N/A Mudloggers are NOT required for this well. Mud Program: Special design considerations I None-SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to t° to 9.4 150 35 15 30 10 15 Intermediate Mud Properties: N/A I DenSity Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 35 6 3 7 8.5 6-12 to to. t° to to to to 10.0 50 20 10 20 9.5 4'6 Well Control: Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon historical drilling experience on G-Pad in the Milne Point Unit. To date, there have been 12 wells drilled on Milne Point G-Pad. None of these wells experienced any significant difficulties with shallow gas or hydrates in the interval prior to placement of surface casing to depths not exceeding 5000' TVDSS. In light of accumulated historical evidence indicating virtually no risk due to shallow gas at Milne Point Unit G-Pad within the surface hole interval mentioned previously, it is requested that MPG-12 be permitted to be drilled without installation of the diverter system. A 20" riser will be installed to act as a conduit to facilitate drilling mud flow for the duration of the surface hole section. After setting 9-5/8" casing, the standard BOP stack will be installed for the 8-1/2" production hole interval. Nabors 22E well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. -., Directional: I KOP: I soo' MD I Maximum Hole Angle: ] 15.36° Close Approach Well: I NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluid Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on G-pad have been permitted for annular injection. . 2. 3. 4. 5. , . 11. 12. 13. 14. 15. MP G-12 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. MPG-12 has been permitted to drill surface hole without a diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR/Res from surface to TD. Run and cement 9-5/8" casing. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. Drill 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig for 30 min. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: See the latest Milne Point G-Pad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: Hydrates have occurred on nearby E and H and there is a possibility that hydrates may be encountered in the drilling of MPG-12. In the eight wells previously drilled on G-pad, only G-08 encountered gas, but only a minor amount and probably due to a small gas pocket rather than hydrates. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-12. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. The Kuparuk has not been drilled before from G-pad, however. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. The expected pore pressure in the Kuparuk sands is 9.6 ppg EMW (3,500 psi @ 7,000' 'I'VD). MPG-12 will be the first penetration in a new fault block and is expected to be normally pressured. 6. Directional Drillinq Concern~ The directional plan for the MPG-12 well is fairly simple in comparison to previous Schrader Bluff wells drilled from G-Pad and should not pose any significant difficulties to the directional drilling team. 7. Cement Note that the surface cement job in the 12-1/4" x 9-5/8" annulus will be different from previous Kuparuk wells in that perforation-quality cement will be brought above the Ugnu "M" Sands as well as the Schrader sands to allow for potential testing in the future. As such, the surface cement job will require special attention to pump rates and returns. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. MP G-12 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder + CELLO-FLAKES (1/4 lb/sack) 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 184 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF TAIL TO STAGE COLLAR @ 2100' MD (200' MD BELOW BASE OF PERMAFROST) +30% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 540 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (4522' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (3082' MD) + 30% EXCESS + 82' OF 9-5/8" 40# CASING CAPACITY FOR SHOE TRACK. TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 1212 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. WELLHEAD STABILITY CEMENT TYPE: Permafrost E ANNULAR VOLUME FROM STAGE COLLAR AT 2100' MD TO SURFACE+ 300% EXCESS. NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVEL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSlBLE/PRAC ~" i~ ,: ,' ~ !.,J CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above the Ugnu "M" Sands with one (1) Bowspring centralizer per joint of 9-5/8" casing on bottom 20 joints of casing (20 required). 2. Run two (2) Bowspring centralizers on either side of the ES cementer tool (2 additional). 3. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is .not necessary. MP G-12 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. SPACER: 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 241 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 22 joints of 7" casing (44). This will cover ±300' above the KUPARUK Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. AnadrLL1 Schlumberger Alaaka District AiLL East 80th Avenue AnchorAge, AK 99518 (907) 349-451L Fax 3~4-2~60 DIRECTIONAL ~ELL PLAI~ for SHARED SHRVICBS DRILL~I~3 ~ell ......... : ~ield ........ : ~tlue Point, ~PAD Co~putation..~ ~inl~umCur~at~re Units ........ : ~E~T Surface bat-.: 70.4~948483 ~ Surface bong.: 149.53301964 W Legal Description Surface ...... ; 1~83 PSL 3~65 Schrader Tgt,: 2347 PSL 38'30 Kuparuk Tgt..: 2944 PSL 4009 BHL .......... ; 3020 PSL 4032 STATION M~ASURED IDEI~TIFICAT~ON DHPT~[ KB 0.00 KOP/BUILD 1/100 300.00 400.00 ; 500.00 BUILD [.25/100 600.00' LOCATIONS - ALASKA Zone: 4 X-Coord Y-Ooord S27 ~L3N R]0H ~M 557239.46 60£4219.92 S27 T/3N R]0H UM $56770.00 60L4~B0.O0 S27 T[3N RIOH UIW $56585.00 6DL5~75.00 S27 TL3N R]OH ~ 556561.4~ 60L54S0.B~ PROPOSED W~LL PRO~]LH Prepared ..... ~ 25 Jul 1997 Uert sect az.: 343.17 KB efevation.~ 58.~0 ft Magnetic Dcln~ ~28.020 sca~e Factor.: 0.99990372 Convez~jence..: ~0.4%005836 - · ANADRILL APPROVED FOR. PERMITTING PLAN D[~ION ~RTI~-DH~9 SH~I~ C00~[NA~S-~M ~S~ ~e 4 ~L AZ~H T~ S~-fl~ DEPOT ~~ X Y FACH 100 0.00 0.00 G,O0 -~8.~0 0.00 0.00 N 0.O0 H 5~7239.46 6014219.92 HS 0.O0 0.00 0.00 300.00 241.~0 0.00 0.00 N 0.00 H 557239.46 6014219.92 ~6L 0.00 ~,00 304.00 399,99 ~1.49 0.68 0.49 N 0.72 ~ ~57238.73 60~4220.40 56b ~.00 2.00 304;00 499.96 441.46 2.71 1.95 N 2.89 H 557236.55 6014221.85 56~ 1.00 3.00 304.00 599.86 5~1.36 6.09 4.39 N 6.51 W 5~7232.92 60~4214.26 56L 1.00 BurLo L.s/~.oo 700.00 4.25 304.00 699.66 641.16 10.99 9.93 N 11.75 W 559227.65 6014227.~6 ~6L 1.2~ 800.00 5.50 304.00 799.30 740.80 17.S8 ~2.68 N ~8.80 W ~7220-57 6014232.45 ]{S 1.25 900.00 6.7S 304.00 B98.~2 640.22 2S.85 18.6& N 27.64 W 557211.66 6014238,35 HS 1.25 1000.00 B.25 304.00 997.8~ 939,37 35.97 2~.94 N 38.46 W ~57200.80 601424~.~6 }{9 1.50 %L00.0G 9.75 304.00 L096.63 1038,13 48-10 34.69 N 61.43 W 5~?L87.77 6014254.21 HS 1.50 ~200.00 11-29 304.00 1194.95 1136.45 62.23 44.88 N 66.54 W 557L72.5fl 6014264.28 HS -0 Fq (Anadrtll (c) 97 ML~I2P6 3.0C 2:17 ~ P) ~O MPc.,- L2 (p6) STAT[ON M92L~URED I N~ BH~ l FICTION DH~ 1.5/LO0 BUI~ 1388,72 ,[4.08 PB~F~ST 1883 . 01 ~4.08 1/~00 19~3.30 ~4.08 2000.00 t3.9~ ~ro ~/too cu~ ctraw ~/~oo TO~ UGNU T~)P M SAND~ END L/200 CUR%'H UA 21OD.00 13.78 2200.00 13.72 2300.00 13.72 2400.00 13.81 2S00.00 13.96 2560.84 34.08 3492.78 34.08 3500.00 ~4.03 3570-16 ~3.45 3600.00 13.29 3700.00 12.60 3800.00 LL.94 3824.09 LL.79 3863.96 LL.5S %063.96 LL.55 SCHI~.DHR TARGS'T 4063.96 11.55 OA 4222.k6 11.55 O8 4293,6L 11.55 BASE OG 4319.12 11.55 9-5/8' CASING PO£NT 4519,12 11.55 TOP HRZ 6467.61 33.55 ~J~SE H~Z 6579.88 11.55 MK-19 6666.64 Z1.55 (Anadrlll (c) 97 NPUL2P6 3.0C 2:L7'PM P) PROPOSED WHY.Y. PROFILE D£RECTION VHRTXCA~-OHPTHS AZ1MUTH TVD 30~ .00 1292-77 304.00 1379.06 1320.$6 304.00 1858.50 18OO.00 304.00 1887,69 307.52 197~,03 SRCTXON DEPART 78.34 94.30 187.54 193,2~ 209.90 25 Jul 1997 Page 2 mm{{mmmm{mms#nn~=~u~ mmummmmmmmmmm{m~=m~= g=== COORDINATES-FROM AhASKA Zone 4 TOOL flEJ.,L,.q]IAD X Y FACE 56.~ N 83,78 W 557155.26 6014205.~8 68.02 N 100.84 W ~7138.LL 6014287.15 1~5.26 N 200.54 W ~57037.91 6014353,63 139.36 N 206.6L W ~5703~.83 6014357.67 151.65 N 223.65 W ~570£4.69 6014369.8~ 311.67 2069.~1 2010.6L 229.82 166.87 N 242.08 31~.87 2166'.25 2107.75 250.5] 183.29 N 259.23 320.08 2263.39 2204.89 27~.95 200.90 N 27~.~0 324.27 2360.53 2302.03 294.16 2£9.69 N 289.68 328.40 2457.61 2399.~ 317.10 239164 N 302.96 330.85 2516.63 2458.13 33L.43 252.36 N 330.85 3420.5.7 3362,07 552.94 450.38 N 33].05 3427.58 3369,08 554.66 451.9£ N 333.28 3503.50 3445.00 572.87 468.32 N 333.93 3524.75 3%66,25 577,86 472.85 N 337.13 3622.2L 3563.71 600.05 493.22 340.69 3719.93 3661.43 621.23 613.03 34~.60 3743.50 3685.00 626.~8 51~.72 343.L~ 3782.55 3724.05 634.24 625.40 343.L7 3978.50 3920.00 674.27 563.72 343.L7 3978.S0 3920-00 343.[7 4133.50 4075-00 343.L7 4203.S0 4L%5.00 343.17 ~228.50 4L70.00 343,L7 ¢424,45 4365.95 674.27 705.94 720.24 725.35 765.39 563.72 594.04 607.72 612.6L 650.93 ~00 ~S 1.50 HS 1.50 HS 0.00 LO3R 0.00 343.17 6333.50 6275.0G LL55,43 ]024,27 343.17 6443.50 6385.00 LLqV,9L 3045.78 343.1~ 6528.~0 6470.00 LL95.27 ]062,40 100R L.O0 556996.13 60t4384.~L 96R L.00 ~56~62.0~ 60t4~18.68 8~ ~.oo{ 3~o..4~ . 556~2~.1~ 6o,4~69.,6 ~s ,.oo/ 420.84" 5568£5.22 ~0Z~667.03 13~R 0-001 421.69 ~ 5568L4.35 60Z4668.54 Z39R 1.00 430.36 W 556805.56 6014684.88 136R l.oo BS 3-OOL 441.90 W 556793.83 6014709.69 449.55 W 556786.02 6014729.43 45L.t6 W 556784.39 6014~34.11 453.60 W 556781.89 601454£.77 465.L9 W 556770.00 6014780.00 HS 0.00 465.L9 W 556770,00 6014780.00 HS 0.00 474.36 W 556760.60 60148L0.24 HS 0.00 478.50 W 556756.35 6034823.89 HS O.O0 479.98 W 556754.84 6014820.7~ NS 0.00 491.57 W 556742.95 6034867.a0 HS 0.00 604.5L W 556627;16 6015239.42 RS 0.00 611.02 W S56620.48 6035260.88 HS 0.00 616,05 W $566L5,33 6035279.46 HS 0.00 "U ITl m~-12 (P61 STATION NEASURSD INCLN £DENTIFICATION DEPTH AEGhB TKUI) 6fl~0.L5 11.55 ~KUC 700].46 ~.55 TIGJ~ ~0~3.66 11.55 KUP~UK TARGHT 7176 . 9~ 11 , 55 T~ 7~6 . 9~ 11.~ TKA2 TI(A1 T~7~V q" CASII~3 PO£1~' TD 7209.63 13.55 7270.87 7273.93 11.55 7573.93 £1.55 ~573.93 PROPOSHD WHLL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD S~/B-BEA mmmmtmm~= =nm~mm 343.17 669fl,$0 6640.00 343.17 6858.50 6800.00 343,17 6868,50 6810.00 343,17 7028.50 6970.00 343.17 7628,S0 6970.00 SRCTIOR C001%D/NATHS-FRON DEPART WELLHHAD 1230,01 1095.65 N 626.11 1262,70 ~126.9~ N 635,57 3299,43 ~60.18 N 1297,43 ~160.18 ¥ 5s660s.02 6015~L0.62 556595.3L 601534L.B4 636.17 W 556594-70 60L5343.79 645.63 W 556585.00 60L5375.00 645.63 ~ 5~6585.00 60L5375.00 ~rr mmmm ~L pb/ FACE LOO ~S 0 -00 HS 0.00 ~S 0. O0 HS O.OO HS 0.00 343,17 7060.50 7002.00 3303,97 L£66.44 N 343.17 732O.50 7062.00 1316,23 ~178.18 N 343.17 7123.S0 7065.00 1316.84 LL78.~6 N 343.17 7417.43 7358-93 13~6,89 1236.24 N 343.17 7437.43 7358.93 L376,B9 1236.2~ N 647,52 W 556583.06 60L5383.24 HS 0.O0 651.07 W 556579.42 60L5392.95 HS 0.00 651.25 W 556579.2~ 60L5593.53 RS 0.O0 668.64 W 55656L.41 60L5450.87 0.O0 668.64 W 55656L.41 60L54§0.87 0.00 ANADRILL AKA-DPC APPROVED. FOR, PERMI ING PLAN Z '0 m (Anadr//L (c)97 HPO12P6 $.0C 2;~? ~ P) CD SHARED SERV ICE'S OR ILL ING MPG- ~2 (P6) VERTICAL SECTION VlEN Section at: 343. ~7 TVD Scale ' ! knch : 1000 feet Dep Scale ' ~ inch : 1000 feet <KB> o A Drawn ' 25 Jul 1997 ~---- 50O c-- ~nadr~ 1] Sc~]umaerger ~OOO D" M~rker I~entif~cat~on HO BKB SECTN INCLN A} KB 0 0 0 0.00 , . B} KOP/BUILD ~/iO0 300 300 0 0.00 C) BUILD ~.25/~00 600 600 6 3.00 E, ... D) BUILD 1,5/100 900 899 26 6,75 1500 ] i - ' E] END 1.5/100 BUI~ t389 ~37g g4 14.OB '~ Fl CURVE t/t00 JgJ~ ~888 tg~ t~,08 '-'-''' ' ~~ ~r'~ G) E~ ~/~00 CURVE 256~ 25%? 33~ tq.Oe 553 t~.OB 2000 r%. H) CURVE t/t00 I] ~D ~/~00 CURVE 3864 3783 634 ~1.55 . J) SCHRADER. TARGET 4064 ~978 674 ~.55 T ~00 .... K) 9'5/8' CASING POINT 45~g 4424 765 ~1,55 L) KUP~RUK T~RGET 7t77 70~8 1297 11.55 V .MI 7' CASING POINT 7574 74~7 t977 1~,55 ' ' N) TO 7574 7~7 1977 ~J,55 D ~ooo . ~ .. ~ -. .- . H _ i1 . ..... · ..... ---' ~ ..... ~ m~'~ ~' t A,NADRI'.L~nm m~VC~ P~ ..... , .......~~ F~R PERM! i--t IN~ 5000 ,-, . . . 5500 .~ '. . ' 6000 : .. J ' ' " ~' 1 ~ . .. ~ ' ' "' =' 6500 ~ m~ ~ ........ ......... ~-~ ....... ~ ',~ ? ~-,, :~.~ ~ ........ ~ooo- : ........ ~'~ ~"~ '"' ~ ~ ~") .' '~i, ,.. 7500 .K' 8000 · I. ' 0 500 ~000 -~00 2000 ~5°0 3000 ~5~. .,000 ,500 sooo 5500 ~uuu ~500 sect ion geg~rture i i L~aOrill [c)97 ~i2P6 2.0C ~.40 P~ PI O?/25/i997 i5: ei ANADRILL DPC PAGE 06 'SHARED SERVICES Marker Identification MD BKB SECTN INCLN A) END t/I00 CURVE 3864 3783 634 11.55 8) SCHRADER TARGET 4064 3978 674 1t.55 C) 9-5/8' CASIN6 POINT 45t9 4424 785 1~.55 D! KUP~RUK TARGET 7177 70~B ~97 il.SS EJ 7' CASING POINT 7574 7417 1377 ~i.55 F] TD 7574 74t7 t377 1t.55 DRILLING ..... i! MPG- 12 (PC) VERTICAL SECTION VIEW _ i ~ · Section at: 343.17 l.VO Scale.' 1 inch = 100 feet ,I Dep Scale.' ~ inch = loo feet '"~'"~"'" ' "'~" ............ - ..... ,4nadr.i ] ] $ch ] uf~b£r'ger' · . APP ;D i CNLY it,,, . ~;;i ql~ ........ ~ ~d ii I iI . ~nrh, r T~;~ (Radiu: ~00 feet ) '~ ~ ........ -- . , . . i _~ ~ 400 450 ' 500 550. 600 650 700 750 800 850 900 950 ~000 ~050 110o Section Oepartupe {A~odri]] {c)97 f~6121~ 3.0C 2.: 42 PH P) 07/25/1997 15'81 907-344~2158 ~NADRILL DPC . PAGE 87 SHARED SERVICES DRILLING MPG-12 (P6) "' / I~ICLT-- J' ~ ~F Ul VERTICAL SECTION VIEW '- ' Section at; 343.~7 IVD Scale ' 1 inch = ~00 feet . Dep Scale' 1 inch = 100 feet · Drawn ' 85 Jul 1997 · · ~-~. ..... : Anadnl ]] Sch]umDerger Marker Ident~ficetion RD BKB SECTN INCLN A) KUPARUK TARGET 7177 7028 1~g7 11,55 B) 7" CASING POINT 7574 7417 t377 11.55 C) TD 7574 7417 ~377 tt,55 . , . KiJn~r',lJkTgt (Ra, lius 200 feet ~-d~! -/b~. . . . ,~ ~ I ' . '~,~"~¢J; .... . - - ......... . =~tr~=t~,l==--==-: :====- . ---======= · -I APF ROV F.D _ · ,. ,, . ~ "',FOR PER'MIl, i IN ' I [ pLAN~~'~ . · · . . - · - : - · · - . . ! I ~, . _ ! ~ooo to5o ~oo ~15o t~oo ~5o 1300 ~aso 1400 1450 tsoo ~550 1600 ts50 1700 ,, Sec[ ~on Depa~tu, ee [jtna~rj]] (c)97 ~t~P6 3.0{; 3:0~ FN P) 07/25/1997 15:01 907-244-21G0 ANADRILL DPC ~ PAGE 08 SH'A EO SERVTCES DRTL "TI '6 .............. i iii i ii · · · i i i ,~! ~o,:,/~,u~,..o u~,:,o ~oo o, o ~ ~ PLAN VIEW ,:i ~,.,,:,.,:, :,.~s/,oo ~o,:, ., ,,, -,, fl) BUILD :t.§/:~OO 900 ]9 N 28 W El END 1.5/100 BUILD t389 68 N lOt U CLOSURE. ' J405 feet et Azimuth 33~.59 F) CUFIVE !/100 t913 139 N 207 W G! END J/tO0 CURVE 2561 252 N 310 W DECLINATION.' +28.020 (E) H) CURVE 1/100 3493 450 N 421 W SCALE ' 1 inch : 4DO feet l) ENO l/lOO CURVE 3864 5~5 N 454 W J) SCHRADER TARGET 4064 564 N 465 W DRAWN ' 25 Jul 1997 K) 9-5/8' CASING POINT 4519 651 N 492 W L) KUPARUK TARGET 7i77 1160 N 646 W M) 7' CASING POINT 757,4 t~38 N 869 W · N) TD 7574 ~3~ N ~" ,4nadr'.i]],, Sch]umberger i · immm ' · iANADRILL AKA-DPC / ' ', APPROVED FOR P£RMll'TING . ' . ~' .ONLY - '~ ~ ' ' - ......... 11100 . '- ..... JCO0 . · . . . ..... "" i" . ' ' - i<u.~.-~__~..~ ..... 200 fun ) 1400 · ' - - -""~ - tOOO . ,. - :. .- _ .- . _ I ~oo · ..... . . i , ' ' .~ . -' ' . 200 ..~ ..... ~ ~00 2800 2400 2200 2000 1800 1600 -1400 1200 t000 BO0 600 400 200 0 200 <- WEST ' EAST -> m mm m lmmm I 8madnil) (c)q7 1~o6t~5 3,0C ~.4t Pt,I pi N 2BO0 G-8 · ~ G-15 G-7 · -~ G-14 G-fi · ~ G-13 G-5 · G-4 mm G-3 · ~ G-11 G-2 · ~ G-10 G-1 · LEGEND · EXISTING WELL CONDUCTORS AS-BUILT WELL CONDUCTORS NOTES 1. DATE OF SURVEY: MAY 20, 1997 2. REFERENCE FIELD BOOK ~ MP97-04 l(p~---~. 48--53) 5. ALASKA STATE 'PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS 0.999905725 5. HORIZONTAL/VERTICAL CONTROL IS BASED ON G PAD MONUMENTS G-1 AND G-2. 6. ELEVATIONS ARE BPX MIl_NE POINT DATUM M.S.L VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE - .. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 20, 1997. LOCATED WITHIN PROTRACTED SEC. 27, T. 15 N., R. 10 E., UMIAT MERIDIAN, ALASKA . WELL ~S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATE. S POSITION(DMS) POSITION(O,OD) 'BOX ELEV. OFFSETS Y= 6,014,O4-1.66 -N 2,170.07 70'26'56.390' 70.4489972" 29.2""' _.1,605~.. FSL G-9 X= 557,264.59 E 1,184.86 149'51'58.173'~ 14-9.5528258' 3,342" FEL Y= 6,014,100~83 N 2,1229.81 70'26'56.973" 70.4491592' 29.2' 1,665' FSL G-lO X= 557,256.42 E 1,185.10 149'51'58.400" i49.5328889' 3,350' FEL G-11 Y= 6,014,160.28 N 2,289.82 70'26'57.558" 70.4493217' 1,724' FSL X= 557,248.29 E '1.185.42 149'51'58.626' 149.5329517' 29.3' 3,357' FEL :Y= 6,014,391.14 N 2,530.21 70'26'59.855" 70.4499542' 1,956' FSL G--15 X= 557,1'64.45 E ' 1,154.92 149'52'01.036" 149.5356211' 29.6' 3,459' FEL Y= 6,014,450.44 N 2,590~02 70'27'00.419' ".70.4501164' 2,015' FSL G--14 X= 557,156.65 E 1,155.55- 1.~9'52'01.251' 149.5336808' 29'5'' 3,446' FEL Y= 6,014,509;68 N 2,649.94 70"27'01.002" 70.4502783' 2,074' FSL G--15 X= 557,.147.69 E 1,155.02 149'52'01.501" 149.5337505' 29.8' 3,455' FEL ~ KH BY C~K! CHECKED: KH DATE: 5/22/97 MPUGASAB .K)B NO;. SCAL[: {'= 200' EXPLORATION MPU G-PAD AS-BUILT WELL CONDUCTORS WELLS 9. 10. 11. 1,5, 14 & 15 · WELL PERMIT CHECKLIST COMPANY ~P FIELD & POOL ,.,q'-~-~/<~ ~.3 INIT CLASS ~)~_.z.,'" WELL NAME ,/¢~~ _ ,,~____.. PROGRAM: exp [] dev~drll [] serv [] wellbore seg E] ann. disposal para re, q I.;:l // GEOL AREA ~ ~ UNIT# z/,/,.~.. <~2 ON/OFF SHORE ~ ~ ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. D&TE~ 12, 43. Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N ENGINEERING APPF~ DATE z]zaL 7 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... (~ N Surface casing protects all known USDWs ........... ~ N CMT vol adequate to circulate on conductor & surf csg ..... (~ CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... (~ N Casing designs adequate for C, T, B & permafrost ....... ¢ N Adequate tankage or reserve pit ................. (~ N If a re-drill, has a 10-403 for abandonment been approved... Y N Adequate wellbore separation proposed ............. ~ N If diveder required, does it meet regulations .......... .Y., N Drilling fluid program schematic & equip list adequate ..... (-Y) N BOPEs, do they meet regulation ~Y~ N BOPE press rating appropriate; te'st' t(~ ~';'0o'~ ..... I~sigl~ U Choke manifold complies w/APl RP-53 (May 84) ........ 4~ N Work will occur without operation shutdown ........... (¢ N Is presence of H2S gas probable ................. ~ N REMARKS GE©LOGY :~R D]ATE / 30. Permitcan be issued w/o hydrogen sulfide measures ..... Y,,~ ,/¢2~ ,~ 31. Data presented on potential overpressure zones ....... Y , 32. Seismic analysis of shallow gas zones ............. /Y/ N ' - 33. Seabed condition survey (if off-shore) ............. .,¢/Y N 34. Contact name/phone forwe.eklypro~lress re@o. rts ..... ~ Y N /exp~ora[ory omyj GEOLO,,GY: ENGINEERING: CO~,LSSION: RP~~___~_ JDH RN Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 07197 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Sep 18 16:07:39 1997 Reel Header Service ha/ne ............. LISTPE Date ..................... 97/09/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... %7NKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/09/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... I/NKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUlViBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB Nq3MBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 1 AK-MM-7023 0 PIEPER ANGLEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MPG-12 500292279200 BP EXPLORATION (ALASKA), INC. SPERRY-SI/~ DRILLING SERVICES 18-SEP-97 MWD RUN 2 AK-MM-70230 PIEPER LOCKWOOD 27 13N 10E 1784 3365 .00 58.10 29.00 F(ECEiVED SEP 2 6 1997 Alaska Oil & Gas Cons. Commi,~.on An~orage WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 4531.0 8.500 7452.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO DENSITY (SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND MARK VANDERGON OF BP EXPLORATION (ALASKA), INC. ON 08 SEPTEMBER, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7452'MD, 7302'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRDN POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR~' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY - COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... 500 PPM 8.6 - 9.8 PPG 14545 PPM 1.0 G/CC 2.65 G/CC SANDSTONE Version Number ........... 1.0.0 Date of Generation ....... 97/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SLIMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 53.5 7385.0 RPD 62.5 7366.0 RPM 62.5 7366.0 RPS 62.5 7366.0 RPX 62.5 7366.0 FET 112.0 7366.0 ROP 113.5 7452.0 FCNT 4521.0 7340.0 NCNT 4521.0 7340.0 NPHI 4521.0 7340.0 PEF 4535.0 7374.5 DRHO 4535.0 7374.5 RHOB 4535.0 7374.5 $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 114.0 4550.0 2 4550.0 7452.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPX MWD RPS MWD RPM MWD RPD MWD ROP MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD OHP/M 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 P.U. 4 1 68 CTS/ 4 1 68 CTS/ 4 1 68 G/CC 4 1 68 G/CC 4 1 68 BARN 4 1 68 8 12 16 20 24 28 32 36 4O 44 48 52 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 53.5 9.241 0.2299 0 1718 0 2014 0 1488 4 0476 0 1268 17 6934 408 2040 1.4353 -0.148 1.4961 Max Mean Nsam 7452 3752.75 14798 354.157 70.9187 14664 2000 10.9462 14608 128.71 15.1613 14608 2000 26.9246 14608 2000 30.2454 14608 939.551 199.067 14678 67.2561 1.15922 14509 81.7622 42.3714 5639 1035 652.784 5639 3624 2669.25 5639 2.9987 2.38739 5680 0.3142 0.0304279 5680 14.7197 2.57096 5680 First Reading 53 5 53 5 62 5 62 5 62 5 62 5 113 5 112 4521 4521 4521 4535 4535 4535 Las t Reading 7452 7385 7366 7366 7366 7366 7452 7366 7340 7340 7340 7374.5 7374.5 7374.5 First Reading For Entire File .......... 53.5 Last Reading For Entire File ........... 7452 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/18 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 ....... 97/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.O01 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 53 5 62 5 62 5 62 5 62 5 112 0 113 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 4490.5 4500.0 4500.0 4500.0 4500.0 4500.0 4550.0 07 -AUG- 97 5.06 5.46 MEMORY 4550.0 114.0 455O.O .0 16.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0814CGR8 P0814CGR8 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: 12.250 12.3 SPUD 8.90 80.0 9.5 5O0 9.0 2.600 2.090 2.500 3 .500 30.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 53.5 4550 2301.75 GR 9. 241 104. 389 53. 7578 RPX 0. 3254 61. 7636 16. 0786 RPS 0.33 08 128.71 23. 4489 RPM 0. 2014 2000 33. 2554 RPD 0. 1717 2000 38. 0442 ROP 4. 0476 638. 976 185. 664 FET 0. 1268 4. 3892 0. 584181 Nsam 8994 8875 8876 8876 8876 8876 8874 8777 First Reading For Entire File .......... 53.5 Last Reading For Entire File ........... 4550 First Reading 53 5 53 5 62 5 62 5 62 5 62 5 ' 113 5 112 Last Reading 455O 4490.5 4500 4500 4500 4500 4550 4500 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/18 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 ....... 97/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 BIT RUN NUMBER: DEPTH INCREMENT: FILE S~RY VENDOR TOOL CODE GR FET RPD RPM RPS RPX FCNT NCNT NPHI PEF DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. 2 .5000 START DEPTH 4487.0 4495.0 4495.0 4495.0 4495.0 4495.0 4521.0 4521.0 4521.0 4535.0 4535.0 4535.0 4546.0 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: 7340 7340 7374 7374 7374 7452 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREMOLE CONDITIONS STOP DEPTH 7385 0 7366 0 7366 0 7366 0 7366 0 7366 0 7340 0 0 0 5 5 5 .0 il-AUG-97 5.06 5.46 ~MEMORY 7452.0 455O.0 7452.0' 7.4 13.0 TOOL NUMBER P0811CRDGP6 P0811CRDGP6 P0811CRDGP6 P0811CRDGP6 8.500 8.5 MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHlViM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAIKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.80 45.0 9.5 5OO 5.5 1.300 .980 1.300 3 .100 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHlV~4 4 ~1 68 RPS MWD 2 OHMI~ 4 1 68 RPM MWD 2 OHlVIM 4 1 68 RPD MWD 2 OHMM 4 1 68 NPHI MWD 2 P.U. 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MW-D 2 HOUR 4 1 68 FCNT MWD 2 CNTS 4 1 68 NCNT MWD 2 CNTS 4 1 68 RHOB MWD 2 G/CC 4 1 68 DRHO MWD 2 G/CC 4 1 68 PEF MWD 2 BARN 4 1 68 Code Offset Channel 0 1 4 2 ' 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 50.0 Name Min Max Mean DEPT 4487 7452 5969.5 GR 23.3809 354.157 97.1439 RPX 0.2299 2000 2.9981 RPS 0.1718 23.7363 2.33378 RPM 0.204 2000 18.897 First Last Nsam Reading Reading 5931 4487 7452 5797 4487 7385 5743 4495 7366 5743 4495 7366 5743 4495 7366 RPD 0.1488 2000 21.6198 NPHI 17.6934 81.7622 42.3714 ROP 14.0602 939.551 220.033 FET 0.1725 67.3276 2.16472 FCNT 408 1035 652.784 NCNT 2040 3624 2669.25 RHOB 1.4353 2.9987 2.38739 DRHO -0.148 0.3142 0.0304279 PEF 1.4961 14.7197 2.57096 5743 5639 5813 5743 5639 5639 5680 5680 5680 4495 4521 4546 4495 4521 4521 4535 4535 4535 7366 7340 7452 7366 7340 7340 7374.5 7374.5 7374.5 First Reading For Entire File .......... 4487 Last Reading For Entire File ........... 7452 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer ' Service name ............. LISTPE Date ..................... 97/09/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
