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197-215
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~' ~- '~/~ File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: /~ Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED n Logs of various kinds Other COMMENTS: Scanned by: aeve~y Mildred Daretha~~ll Date: ~/// TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si P L U G G r_ '~,~ ~ & L 0 C_% T ! 0 N C L E~.4~_~ C E R E P 0 R T StaUa cf Alaska ~ wet ~ -~-' ~ - a:~- cmmme, uu czz ~:tuqzj~-~, well haad Rev! aw ~..m ...... , . Well hea~ · Locauio~ Clea~axxca: · o STATE OF ALASKA ALASK,-~ ~IL AND GAS CONSERVATION COM .... .3SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for gidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service , 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 197-215 300-226 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ...... ............ ~ 50-029-22832-00 4. Location of well at surface , ~ ...... - ......... ' ~"' ~ 9. Unit or Lease Name . . .- 2207' NSL, 3288' WEL, SEC. 28, T13N, R10E, UM ~';.~_,'~_ ) Milne Point Unit At top of productive inte~al 2379' NSL, 3553' WEL, SEC. 29, T13N, R10E, UM At total depth ' 10. Well Number ~ "' MPJ-20 2390' NSL, 3824' WEL, SEC. 29, T13N, R10E, UM · 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 64.22' ADL 025517 ~' ~'~ ~~~ ~,~,~ I o 'o °r 1,30,97 11,14,2000 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsZero 17. Total8085 Depth (MD+TVD)I 18'4196 FT Plug Back Depth (MD+~D)7982 4109 FTI.'ID' Directional Sumey 1 20. Depth where SSSV setl 21. Thickness of Permafrost~ Yes . No N/A MDI. 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, ESS, G~CCL, G~JB 23. CASING, LINER AND CEMENTING RECORD CASING SE~ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOSOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 ~ H-40 32' 112' 24" 250 sx Arcticset I (App'rox.) 7" 26~ L-80 30' 8066' 8-1/2" 1476 sx PF 'E', 132 sx Class 'G' 24. Pedorations open to Production (MD+~D of Top and 25. TUBING RECORD BoSom and inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None MD ~D MD ~D 7" Gravel Pack Screen 7541' - 7665' 26. ACID, F~CTURE, CEMENT SQUEAL, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6213' Set EZSV 6213' P&A with 65 Bbls Class 'G', Sqzd to 400 psi 6218' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OiL G~w~-API (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. RECEIVED MAR 200 . 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 recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. TSBF 7580' 3770' SBF1 7612' 3796' TSBD 7773' 3932' TSBB 7852' 3999' 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~'~.~~. ~ Title TechnicalAssistant Date MPJ-20 197-215 300-226 Prepared By Name/Number: Terrie Hubble, 564-4628 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. Sh I h ~n' D ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, ~ ~(~0~ ~ ITEM 28: If no cores taken, indicate 'none'. MAR 2(.)01 Form 10-407 Rev. 07-01-80 OPerations,sUmma i Repo :i :.i i · ; ~: : ! : ii:ii:i~!: :i~: ~ i: ii: i ~ ~ : i:; :i i ;::~;: :;! i:; ;i !:i:~i~ : ;: Legal Well Name: MPJ-20 Common Well Name: MPJ-20 Spud Date: Event Name: PLUG+ABANDON Start: 11/10/2000 End: Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Date From To HOurs Task Sub Phase l ii i:i'::':~:~i:i!~:::i:-i!:'De~'CriPti?°foPerati°n~i: ~ :~: 1111012000 12:00 - 23:5g 11.98 CONS POST wait on weather (phase 3) 1111112000 00:00 - 23:50 23.98 GO~S ~OSI wait on weather (pha~o 3 down to ph~so ~ ) Held safe~ stand down w~h both crews and ro~iowod all ro~nt incidents to soo what we ~uld do to avoid future incidents. ~ 8:30 hfs to 23:50 hfs clear snow on pad and prepare for ~ move. ~ ~/~ ~2000 00:00 - 0fl:00 ~.00 GO~S ~OST Standby woathor ~nditions. Gloat snow on pad and prepare for ~0~8. 0~:00 - 0~:00 3.00 MO~ ~Rfi S~ down ~o~i~, Move fl~ ~om M~ ~-~0 to M~H ~-20 0~:00 - ~4:00 5.00 RIGH ~RE Spot Modules ~nd ~mp. ~aiso and S~po out ~or~ck> Hook Hp all M~ulos. Ri~ a~pted aU4:00 Hfs ~ ~-~2-00. ~4:00 - ~8:00 4.00 KIk~ DfiGOM~ Hook up Unes to kill well. ~ickod up [u~tor ~nd pu~led ~8:00 - 2~:30 3.50 KIk[ DECOM~ Heat Hp and take on 4~0 bbls of ~0.2 fluid. Heated to ~50 2~ :30 - 23:30 2.00 Klkk DfiCOM~ ~u~ and spot Ti~or tank & ~ up hard 23:30 - 23:fi0 0.48 KIkk DfiGOM~ Cmssure test lino~ to 3,500 psi ~ ~/~ 3/2000 00:00 - 05:00 5.00 KIkk ~fiGOM~ Kill well with ~ 0.2 pp~. brine 05:00 - 07:30 2.50 W~S~R DfiGOM~ 8et ~c & test same to ~000 & nipple down tree. 07:30- ~0:30 3.00 BO~8~ DECOM~ Ripple up bop ~ 0:30 - ~ ~ :30 ~.00 BO~SH~ DEGOM~ test hop's to 250~3500 psi. Test waived by dohn Gdsp with ~ ~ :30 - ~ 2:30 ~.00 WHSHR DEGOM~ ri~ lub~mtor & pull ~2:30-~3:30 ~.00 WHS~R ~fiGOM~ mulandin~jt.&eheckforpressurounderhan~or&ba~outdlds&pull han~or & lay dn same. ~ 3:30 - 23:50 ~ 0.48 ~Hkk ~GOM~ pull osp ~mpletion. layin~ dn tbS. & romovin~ heat tra~ tape & lay dn same. at pump. ~ ~/~ 4~2000 00:00 - 0~ :30 ~.50 ~kk DfiCOM~ finish layin~ dn t~. & osp completion, lost 5-~ands in hole found 3-on su~a~ equipment. 0~:30 - 02:00 0.50 ~Hkk ~fiGOM~ Glean floor & ri~ up to run 5.05" reverse ~askot. 02:00 - 02:30 0.50 ~HSH~ DfiGOM~ Make Hp ~akor 8t~n~ Mill with ~.~ 5~" OD ~au~o RIH 3~'. ~ ~' han~er and into 7" ~sin~ 02:30 - 10:30 8.00 CLaN DECOMP Pi~ed up Baker S~op and and Tdp in the hole while pi~ing up single 3 1/2" ddll pipe. TIH to 6517' and pi~ up to 6,425' 10:30 - 12:00 1.50 CLaN DECOMP Cir~late hole clean 12:00 - 14:30 2.50 CLaN DECOMP laid down 3 1/2" drill Pipe to 6,206'. POH and stand ba~ in stands. 66 stds and double. Lay down Baker S~op. Re~vered I fiat band. 14:30 - 15:30 1.00 P~ DECOMP Pi~ up HallibuAon 7" EZSV Squeeze Pa~er and ~ Drill SV drag BIo~ SeEing tool 15:30 - 19:00 3.50 P~ DECOMP Run in the hole with HallibuAon 7" ~SV Squeeze Pa~er to 6,213'. Broke circulation at 3 BPM at 600 psi. 19:00 - 20:00 1.00 P~ DECOMP Set Hallibu~on 7" ~SV Squeeze Packer at 6,213' (4ES RT-GL ~rre~ed ba~ to Nabors 27E at 6,224' ). Pulled 50 k over to set. Stung back into HallibuAon 7" EZSV Squeeze Pa~er and tested annulus to 2,500 psi. tested OK. Establish~ and inje~ion rate of 1100 psi at 2.5 bpm. Pumped a total of 7.7 bbls. 20:00 - 22:30 2.50 P~ DECOMP Held PJSM with Schlumberger, Hallibu~on, Peak, and Rig crew. Un Stung from Hallibu~on 7" EZSV Squeeze Packer. Pumped 10 bbls of freshwater ahead and shut in and tested sufia~ lines to 3,500 psi. Released pressure and pureed 10 bbls of Fresh water followed by 20 bbls of 15.8 ppg, 1.17 fl3/sk yield Class G ~ment. Held 400 psi on ~ ,annulus. Stung into Hallibu~on 7" EZSV Squeeze Pa~er and EIVED ]~ntinued to pump an additional, bbls of 15.8 ppg, ,.17f13/sk yield Class G ~ment. Pumped a total of 65 bbls of slu~ at 2.1 bpm at J1~7 psi at end of job. Pumped 4 bbls of freshwater followed by 36 MAR. ~ ~ ~()0] :bbls. of 10.1 ppg brine. Shut down and stung out of Hallibu~on 7" ~SV Squeeze Pa~er at 6,213'. Printed: 11/28/2000 8:54:00 AM Bp :AMoCoi , ' Page 2 of 3: : : . oPeratiOn's summa~iRep°~ ~-. ~ : ~::~::: : i~ ~ Legal Well Name: MPJ-20 Common Well Name: MPJ-20 Spud Date: Event Name: PLUG+ABAN DON Start: 11/10/2000 End: Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Date From-To Hours TaSk :Sub PhaseI , : Code 1111412000 22:30 - 23:00 0.50 PXA DFOOMP Reverse circulated well with 10.1 brine at 6,212'. Recovered show of cement after reverse circulating 40 bbls. Continued to reverse circulate and returns quickly cleaned up. Reverse circulated a total of 2 pipe volumes 80 bbls. Returns clean. 23:00 - 23:30 0.50 PXA DECOMP SWI and tested casing to 3,500 psi. recoreded on chart for 30 minutes. Lost 200 psi after 30 minutes. Released pressure 23:30 - 23:59 0.48 PXA DECOMP Filled pits with 8.5 ppg seawater and reverse circulated well at 5 bpm at 1,200 psi. 11/15/2000 00:00 - 02:00 2.00 PYA DECOMP Reverse circulated well at 5 bpm at 1,200 psi. 8.5 ppg seawater all the way around 02:00 - 07:00 5.00 PYA DECOMP Laid down 3 1/2" drill pipe to 2,115' 07:00 - 08:00 1.00 PYA DECOMP Rigged Up HB & R and Displace hole with diesel for freeze protect, at 2115'. 08:00 - 09:30 1.50 PXA DECOMP Continued to lay down 3 1/2" drill pipe. Break out and lay down Halliburton setting tool. 09:30 - 10:00 0.50; PYA DECOMP Top off casing with diesel. Rigged down and released HB & R. 10:00 - 10:30 0.501 PYA DECOMP Land hanger and locked down same. Set TVVCV and tested to 2,500 psi. 10:30 - 12:30 2.00 PXA . DECOMP Drain Stack, blow down lines, and Nipple down BOPE. 12:30 - 13:30 1.00 PYA DECOMP Nipple up tree and test hanger seals and body to 5000 psi 13:30 - 14:00 0.50 PYA !DECOMP Set BPV and secure well. Pdnted: 11/28/2000 8:54:0OAM BP AMOCO ~ page 1 of 4 Operations Summary RepOrt : Legal Well Name: MPJ-20A Common Well Name: MPJ-20A Spud Date: 12/22/2000 Event Name: REENTER+COMPLETE Start: 12/22/2000 End: 1/1/2001 Contractor Name: NABORS Rig Release: 1/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase ' DesCription of Operations Date From-To Hours Task Code : : ::: ~,~ ~ ~ 12/19/2000 00:00 - 18:00 18.00 RIGU PRE Repair top drive and repair #4 Gen, commison #2 pump and I & 4 Gen. rig total commison @ 1800 hrs. rig was accepted @ 1800 hrs 12/19/2000 ( time was back up 8 hrs for the bop test so it would be 10:00 hrs 12/19~2000) 18:00 - 19:00 1.00 CLEAN DECOMP Prejob safety and spud meeting with crew on well 19:00 - 20:30 1.50 CLEAN DECOMP prep rig floor 20:30 - 23:30 3.00 CLEAN DECOMP Picking up mule shoe and 6 1/8 watermelon mill and drlg pipe pushing ice plug from 104-170ft, pull out for 6 1/8 bit 23:30 - 00:00 0.50 CLEAN DECOMP Pick up 6 1/8 bit and watermelon mill and trip in 12/20/2000 00:00-01:30 1.50 CLEAN DECOMP Trip inw/bitto 170 ft. pressure up, bit plug 01:30 - 02:30 1.00 CLEAN DECOMP Pulled out, bit plug w/scale from hw pipe, knock out jets trip into 170 ft. 02:30 - 05:00 2.50 CLEAN DECOMP Wash and drlg ice plugs from 170 ft to 525 ft 05:00 - 06:00 1.00 CLEAN DECOMP Picking up 3.5 13.3~ G drill pipe 06:00 - 07:00 1.00 CLEAN DECOMP Pre job and spud meeting with new crews 07:00 - 11:00 4.00 CLEAN DECOMP Picking up 3.5 13.3~ drill pipe to 2200 11:00 - 12:00 1.00 CLEAN DECOMP Cir¢ diesel out of hole 12:00 - 17:00 5.00 CLEAN DECOMP Picking up 3.5 13.3~ G pipe to 5747 17:00 - 19:00 2.00 CLEAN DECOMP circ hole to clear scale and rust out of pipe 19:00 - 19:30 0.50 CLEAN DECOMP Pulled one stand of pipe 19:30 - 21:00 1.50 CLEAN DERK DECOMP Repair crown-a-matic 21:00 - 00:00 3.00 CLEAN DI=COMP Trip out and clear floor 12/21/2000 00:00 - 01:30 1.50 CLEAN DECOMP trip in w/bit and dc, hw pipe 01:30 - 06:00 4.50 CLEAN DECOMP picking up 3.5 pipe 13.3~ G to 6218 06:00 - 06:30 0.50 CLEAN DECOMP Circ to clear pipe 06:30 - 09:30 3.00 CLEAN DECOMP Pull 12 sds and stand back in derrick, pick up 3.5 pipe to 6218 09:30 - 12:30 3.00 CLEAN DECOMP Circ, and displace hole with mud 12:30 - 17:00 4.50 CLEAN DECOMP Tripping out SLM, no correction 17:00 - 17:30 0.50 CLEAN DECOMP Clear floor and pre job safety meeting 17:30 - 20:30 3.00 STWHIP WEXlT Pick up whipstock and odent tools, test MWD 20:30 - 00:00 3.50 STWHIP WEXlT Trip in ,set whipstock w/20,000~ @ 60 L, 6218 12/22/2000 00:00 - 05:30 5.50 STWHIP WEXlT Shear off of Whipstock w/35K - Mill window in 7" 26~ casing 6,202 to i6,216' with Baker Window Master system - 3-5K wob, 80 rpm, 5,000 fi/# !torque, Pumping at 251 gpm at 1600 psi 05:30 - 06:30 1.00 STWHIP WEXlT i Pump high vis sweep and Circulate hole clean at 272 gpm 2000 psi 06:30 - 09:00 2.50 STWHIP WEXlT = Monitor well - Pump slug - Pooh - stand back drill pipe 09:00 - 11:00 2.00 STWHIP WEXlT !Lay down BHA -Top mill full gauge at 6.151" 11:00 - 12:00 1.00 STWHIP WEXlT Prejob safety meeting. Wash out BOP stack with wash tool - Clear rig floor - Service Top Drive 12:00 - 16:00 4.00 DRILL PROD1 i Make up BHA #2: Pick up Sperry 5" Mud motor, adjust motor to 1.5 deg :bent housing, Make up Sperry MWD/GR/Res/PWD - Make up Security 6 1/8" PDC bit - difficulty getting 5" motor with 1.5 deg BH down casing, Pooh adjust motor to 1.25 deg BH - Orient & Program logging tools 16:00 - 18:30 2.50 DRILL PROD1 Trip into 6216, fill pipe every 25 sd. 18:30 - 19:30 1.00 DRILL PROD1 Orient motor and slide tru window @ 6216 19:30 - 20:00 0.50 DRILL PROD1 Side drill from 6216 to 6235 20:00 - 20:30 0.50 DRILL PROD1 Cir¢ 20:30 - 21:00 0.50 DRILL PROD1 Preform FIT: test formation to 325 PSI wi~819, p~;~gii~:t~inll~eli~t 2990 TVD = 11.0 EMW- NO bled off ~ ~ ~_ J V 21:00 - 00:00 3.00 DRILL PROD1 Drill and slide from 6,235 to 6,290'- Art 1.0 hrs-~ As--t 'E0'hr§, A~e?age TorqueR°P 27.5 fi/hr with 5-10,000 wt. 254 gpm at5,000 fi/lb M/~R2°°° 'P~i ~ r~e0~t 7° rpm2 ~ STATE OF ALASKA ALASK,._ alL AND GAS CONSERVATION CON .... SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 197-215 300-226 ~3. Address 18. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22832-00 4. Location of well at surface ~; .:~:.:j.'::~ ¥~ ~.':. 9. Unit or Lease Name 2207' NSL, 3288' WEL, SEC. 28, T13N, R10E, UM ~ ;;'~ ~";':~;-'~'~:':~'~: Milne Point Unit At top of productive interval NSL, 3553' WEE, SEC. 29, T13N, R10E, UM 2379' At total depth ~--. ,,~.~.,~j;~-~, 10. Well Number ;~-~.~ ~- ~..~__-.~...,~.~ .... MPJ-20 2390' NSL, 3824' WEL, SEC. 29, T13N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. 11. Field and Pool Milne Point Unit / Schrader Bluff KBE = 64.22' ADL 025517 12. Date Spudded 11/26/97 113' Date T'D' Reached 114' Date C°mp'' susp'' °r Aband' 11/30/97 11/14/2000 115' Water depth' if °"sh°re N/A MSL,.116' N°' °f C°mpleti°ns Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 8085 4196 FTI 7982 4109 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, ESS, GR/CCL, GR/JB 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I IApprox.) 7" 26# L-80 30' 8066' 8-1/2" 1476 sx PF 'E', 132 sx Class 'G' 24. Perforations op. en to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and imerval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None MD 'I-VD MD 'I-VD 7" Gravel Pack Screen 7541' - 7665' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6213' Set EZSV 6213' P&A with 65 Bbls Class 'G', Sqzd to 400 psi 6218' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (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. 00i Form 10-407 Rev. 07-01-80 '~'~ ~iSub~it In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. TSBF 7580' 3770' SBF1 7612' 3796' TSBD 7773' 3932' TSBB 7852' 3999' 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ..-~.~'~, ~ Title TechnicalAssistant Date MPJ-20 197-215 300-226 Prepared By Name/Number: Terrie Hubble, 564-4628 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. ITE~a 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). IT£M 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. l'r£M 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, ~lr[~O~ei-~lFD ~ 28: If no cores taken, indicate 'none'. MAR 22 2001 Alaska 011 & ~s Cons, Oommi~!o~ Form 10-407 Rev. 07-01-80 BP AMOCO : : ~:': !~: ipage I of 3 Operations Summa Rep:o . , Legal Well Name: MPJ-20 Common Well Name: MPJ-20 Spud Date: Event Name: PLUG+ABANDON Start: 11/10/2000 End: Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: Task· Sub · Date· From-To HOurs ~. - .- Phase : '::. ::::::::::::::::::::: , Code 11/10/2000 12:00 - 23:59 11.98 CONS POST wait on weather (phase 3) 11111/2000 00:00 - 23:59 23.98 CONS POST wait on weather (phase 3 down to phase 1 ) Held safety stand down with both crews and reviewed all recent incidents to see what we could do to avoid future incidents. 18:30 hrs to 23:59 hrs clear snow on pad and prepare for rig move. 11/12/2000 00:00 - 06:00 6.00 CONS POST Standby weather conditions. Clear snow on pad and prepare for rig move. 06:00 - 09:00 3.00 MOB PRE Scope down Derrick, Move rig from MPU J-10 to MPU J-20 09:00 - 14:00 5.00 RIGU PRE Spot Modules And camp. Raise and Scope out Derrick> Hook Up all Modules. Rig accepted at14:00 Hrs 11-12-00. 14:00 - 18:00 4.00 KILL DECOMP Hook up Lines to kill well. Picked up Lubricator and pulled BP¥. 18:00-21:30 3.50 KILL DECOMP Heat Up and take on 410 bbls of10.2 fluid. Heated to150 degrees. 21:30 - 23:30 2.00 KILL DECOMP Burro and spot 'l-~jer tank & rig up hard lines. 23:30 - 23:59 0.48 KILL DECOMP Pressure test lines to 3,500 psi 11/13/2000 00:00 - 05:00 5.00 KILL DECOMP Kill well with 10.2 ppg. brine 05:00-07:30 2.50 WHSUR DECOMP i Set twc & test same to 1000 & nipple down tree. 07:30- 10:30 3.00 BOPSUF DECOMP Nipple up bop 10:30 - 11:30 1.00 BOPSUF DECOMP ;test bop's to 250/3500 psi. Test waived by John Crisp with AOGC 11:30 - 12:30 1.00 WHSUR DECOMP rig lubricator & pull twc. 12:30 - 13:30 1.00 WHSUR DECOMP I mu landing jt. & check for pressure under hanger & back out rilds & pull hanger & lay dn same. 13:30 - 23:59 10.48 PULL DECOMP i pull esp completion, laying dn tbg. & removing heat trace tape & lay dn same. at pump. 11/14/2000 00:00 - 01:30 1.50 PULL DECOMP 'finish laying dn tbg. & esp completion, lost 5-bands in hole found 3-on :surface equipment. 01:30 - 02:00 0.50 PULL DECOMP Clean floor & rig up to run 5.95" reverse basket. 02:00 - 02:30 0.50 WHSUR DECOMP , Make Up Baker String Mill with 6.151" OD gauge RIH 31°. 11' below . hanger and into 7" casing 02:30 - 10:30 8.00 CLEAN DECOMP Picked up Baker Scoop and and Trip in the hole while picking up single 3 1/2" drill pipe. TIH to 6517' and picked up to 6,425' 10:30 - 12:00 1.50 CLEAN DECOMP Circulate hole clean 12:00 - 14:30 2.50 CLEAN DECOMP laid down 3 1/2" drill Pipe to 6,206'. POH and stand back in stands. 66 stds and double. Lay down Baker Scoop. Recovered 1 fiat band. 14:30 - 15:30 1.00 PXA DECOMP Pick up Halliburton 7" EZSV Squeeze Packer and EZ Drill SV drag Block Setting tool 15:30 - 19:00 3.50 PXA DECOMP Run in the hole with Halliburton 7" EZSV Squeeze Packer to 6,213'. Broke circulation at 3 BPM at 600 psi. 19:00 - 20:00 1.00 PXA DECOMP Set Halliburton 7" EZSV Squeeze Packer at 6,213' (4ES RT-GL corrected back to Nabors 27E at 6,224' ). Pulled 50 k over to set. Stung back into Halliburton 7" EZSV Squeeze Packer and tested annulus to 2,500 psi. tested OK. Established and injection rate of 1100 psi at 2.5 bpm. Pumped a total of 7.7 bbls. 20:00 - 22:30 2.50 PYA DECOMP ~Held PJSM with Schlumberger, Halliburton, Peak, and Rig crews. Un Stung from Halliburton 7" EZSV Squeeze Packer. Pumped 10 bbls of freshwater ahead and shut in and tested surface lines to 3,500 psi. : Released pressure and pumped 10 bbls of Fresh water followed by 20 ibbls of 15.8 ppg, 1.17 ff3/sk yield Class G cement. Held 400 psi on ;annulus. Stung into Halliburton 7" EZSV Squeeze Packer and :continued to pump an additional 44 bbls of 15.8 ppg, 1.17 ft3/sk yield E ~VE ~, ~ClassGcement. Pumped a total of 65 bbls of slurry at 2.1bpm at ~ EC i1447 psi at end of job. Pumped 4 bbls of freshwater followed by 36 .bbls. of 10.1 ppg brine. Shut down and stung out of Halliburton 7" NAR 2 ~ Z00~ :EZSV Squeeze Packer at 6,213'. BP AMOCO : Page 2 of 3 Operations Summary Report . · , Legal Well Name: MPJ-20 Common Well Name: MPJ-20 Spud Date: Event Name: PLUG+ABANDON Start: 11/10/2000 End: Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: · Sub ~ : Date From-To Hours TaSk .c~e Phase ;:~ .;'.' ::: :' Description of OPerati°nS 11/14/2000 22:30 - 23:00 0.50 PXA DECOMP :Reverse circulated well with 10.1 bdne at 6,212'. Recovered show of cement after reverse circulating 40 bbls. Continued to reverse circulate and returns quickly cleaned up. Reverse circulated a total of 2 pipe volumes 80 bbls. Returns clean. 23:00 - 23:30 0.50 PXA DECOMP SWI and tested casing to 3,500 psi. recoreded on chart for 30 minutes. : Lost 200 psi after 30 minutes. Released pressure 23:30 - 23:59 0.48 PXA DECOMP i Filled pits with 8.5 ppg seawater and reverse circulated well at 5 bpm at : 1,200 psi. 11115/2000 00:00 - 02:00 2.00 PXA DECOMP Reverse circulated well at 5 bpm at 1,200 psi. 8.5 ppg seawater all the way around 02:00 - 07:00 5.00 PXA DECOMP Laid down 3 1/2" ddll pipe to 2,115' 07:00 - 08:00 1.00 PXA DECOMP :Rigged Up HB & R and Displace hole with diesel for freeze protect, at 2115'. 08:00 - 09:30 1.50 PXA DECOMP Continued to lay down 3 1/2" ddll pipe. Break out and lay down ;Halliburton setting tool. 09:30 - 10:00 0.50 PXA DECOMP iTop off casing with diesel. Rigged down and released HB & R. 10:00 - 10:30 0.50 PXA DECOMP Land hanger and locked down same. Set TWCV and tested to 2,500 !psi. 10:30 - 12:30 2.00 PXA DECOMP Drain Stack, blow down lines, and Nipple down DOPE. 12:30 - 13:30 1.00 PXA DECOMP i Nipple up tree and test hanger seals and body to 5000 psi 13:30 - 14:00 0.50 PYA DECOMP Set BPV and secure well. RECEIVED MAR 22 2001 BP AMOCO Page I of 4 Operations Summary Report Legal Well Name: MPJ-20^ Common Well Name: MPJ-20A Spud Date: 12/22/2000 Event Name: REENTER+COMPLETE Start: 12/22/2000 End: 1/1/2001 Contractor Name: NABORS Rig Release: 1/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From-To Hours Task Code Phase Description of OperatiOns 12/19/2000 00:00 - 18:00 18.00 RIGU PRE Repair top drive and repair #4 Gen, commison #2 pump and I & 4 Gen. dg total commison @ 1800 hrs. dg was accepted @ 1800 hrs 12/19/2000 ( time was back up 8 hrs for the bop test so it would be 10:00 hrs 12/19/2000) 18:00 - 19:00 1.00 CLEAN DECOMP Prejob safety and spud meeting with crew on well 19:00 - 20:30 1.50 CLEAN DECOMP prep dg floor 20:30 - 23:30 3.00 CLEAN DECOMP Picking up mule shoe and 6 1/8 watermelon mill and drlg pipe pushing ice plug from 104-170ft, pull out for 6 1/8 bit 23:30 - 00:00 0.50 CLEAN DECOMP Pick up 6 1/8 bit and watermelon mill and tdp in 12/20/2000 00:00 - 01:30 1.50 CLEAN DECOMP Trip in w/bit to 170 ft. pressure up, bit plug 01:30 - 02:30 1.00 CLEAN DECOMP Pulled out, bit plug w/scale from hw pipe, knock out jets tdp into 170 ft. 02:30 - 05:00 2.50 CLEAN DECOMP Wash and drlg ice plugs from 170 ft to 525 ft 05:00 - 06:00 1.00 CLEAN DECOMP Picking up 3.5 13.3~ G drill pipe 06:00 - 07:00 1.00 CLEAN DECOMP Pre job and spud meeting with new crews 07:00 - 11:00 4.00 CLEAN DECOMP Picking up 3.5 13.3~ drill pipe to 2200 11:00 - 12:00 1.00 CLEAN DECOMP Circ diesel out of hole 12:00 - 17:00 5.00 CLEAN DECOMP Picking up 3.5 13.3~ G pipe to 5747 17:00 - 19:00 2.00 CLEAN DECOMP circ hole to clear scale and rust out of pipe 19:00 - 19:30 0.50 CLEAN DECOMP Pulled one stand of pipe 19:30-21:00 1.50 CLEAN DERK DECOMP Repaircrown-a-matic 21:00 - 00:00 3.00 CLEAN DECOMP Trip out and clear floor 12/21/2000 00:00 - 01:30 1.50 CLEAN DECOMP trip in w/bit and dc, hw pipe 01:30-06:00 4.50 CLEAN DECOMP picking up3.5pipe 13.34¢Gto6218 06:00 - 06:30 0.50 CLEAN DECOMP Circ to clear pipe 06:30 - 09:30 3.00 CLEAN DECOMP Pull 12 sds and stand back in derrick, pick up 3.5 pipe to 6218 09:30 - 12:30 3.00 CLEAN DECOMP Circ, and displace hole with mud 12:30 - 17:00 4.50 CLEAN DECOMP Tripping out SLM, no correction 17:00 - 17:30 0.50 CLEAN DECOMP Clear floor and pre job safety meeting 17:30 - 20:30 3.00 STWHIP WEXlT Pick up whipstock and orient tools, test MWD 20:30 - 00:00 3.50 STWHIP WEXlT Tdp in ,set whipstock w/20,000~ @ 60 L, 6218 12/22/2000 00:00 - 05:30 5.50 STWHIP WEXlT Shear off of Whipstock w/35K - Mill window in 7" 26g casing 6,202 to 6,216' with Baker Window Master system - 3-5K web, 80 rpm, 5,000 ft~ torque, Pumping at 251 gpm at 1600 psi 05:30 - 06:30 1.00 STWHIP WEXIT Pump high vis sweep and Circulate hole clean at 272 gpm 2000 psi 06:30 - 09:00 2.50 STWHIP WEXlT Monitor well - Pump slug - Pooh - stand back drill pipe 09:00 - 11:00 2.00 STWHIP WEXIT Lay down BI-IA - Top mill full gauge at 6.151" 11:00 - 12:00 1.00 STWHIP WEXIT Prejob safety meeting. Wash out BOP stack with wash tool - Clear dg floor - Service Top Drive 12:00 - 16:00 4.00 DRILL PROD1 Make up Bt-lA #2: Pick up Sperry 5" Mud motor, adjust motor to 1.5 deg bent housing, Make up Sperry MWD/GPJRes/PWD - Make up Secudty 6 1/8" PDC bit - difficulty getting 5" motor with 1.5 deg BH down casing, Pooh adjust motor to 1.25 deg BH - Orient & Program logging tools 16:00 - 18:30 2.50 DRILL PROD1 Tdp into 6216, fill pipe every 25 sd. 18:30 o 19:30 1.00 DRILL PROD1 Orient motor and slide tru window @ 6216 19:30 - 20:00 0.50 DRILL PROD1 Side drill from 6216 to 6235 ~2~: 0,~ ~.~ 0.50 DRILL PROD1 Circ ~,ECI~:~'~V' ~,J.l~: 0.50 DRILL PROD1 Preform FIT: test formation to 325 PSI with 8.9 ppg mud in hole at 2990 'I'VD = 11.0 EMW - No bled off 2~1:0a r~g0~:00 3.001 DRILL PROD1 Ddll and slide from 6,235 to 6,290'-Art 1.0 hrs, Ast 1.0 hrs, Average ' ~~..~ /__UU I Rop 27.5 ft/hr with 5-10,000 wt. 254 gpm at 2000 psi - rotate at 70 rprn MAP,, iTorque 5,000 ft/Ib ~ska 0il & Ga~-Cons. Oommi ;sion A! R,~: PropoSed abandonment J20 revision to approval 300-226 Subject: Re' Proposed abandonment J20 revision to approval 300-226 Date: Fri, 10 Nov 2000 07:42:05 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To' "Laule, Robert B" <LauleRB@BP.com> MPJ-20, APD (197-215), abandonment sundry (300-226) Bob, I received your fax of the proposed change to the abandonment for J-20. As we discussed, the key to being able to set the retainer at 6224' md ~11 be having successfully established the injection rate as described in step 4 of your procedure. If this operation is successful, it is reasonable to conclude that you will be able to bullhead the cement into place as planned in step 11. You have approval to modify the abandonment as proposed. However if you are not able to successfully establish the injection rate as planned it will be necessary to employ alternate means to get cement to the screened interval. As discussed this could involve spotting a balanced cement plug on top of the screens. Good luck. Please call if you need to discuss further. Tom "Laule, Robert B" wrote: . seawater. 3. 4. annulus 5. 6. 7. 8. 9. retainer. MRU Nabors 4ES,. Circulate out freeze protecion and displace weft to ND tree and NU BOPE & te,~ to 2000 psi Establish injection rate and pressure by bullheading the Puff 2 7/8" L-80 tubing and ESP¢ and LD same. Drift ~asing hanger. NotifyAOGCC RIH and ~at cement retainer on DP to 6, 224' Establish injection rate and pressure. Un sting from the Mx and pump cement. Circulate cement to retainer. Stab through retainer and ~queeze cement to abandon N, OA, and OB pens. 12. . Unsting from retainer and circulate out excess cement. 13. RIH uith bit and scraper to top of retainer. Circulate sweep while rotating. 14. Pre~sure test casing to 3500 psi for 30 minutes 15. POH. Circulate to freeze protect from 2200' MD. 16. RDIVD. <<PROPOSED. CDD>> Narre: PROPOSED. CDD PROPOSED. CDD T~e: unspecified type (application/octet-stream) Eno)ding: base64 1/10/00 7:42 AM Re.. Propos"ed abandonment J20 revision to approval 300-226 Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission '~ ,'-,f '~ 11/10/00 7:42 AM NOV 10 '00 08:21AM BP MILME POIMT GROUP P.1 IIIII Y~/_e.[[bg_~.c[; 11" 5M FMC Gan 6 ,, Orig. GL F_lev, .- 35,10' ~ 2 7/8" x 11" FMC w/~- 7/8"'- DF to 7" osg. hng. -- 30,13' (N 22E) N$CTT&B and 2.5" CIW H BPV profile 20' 91.1ppf, H-40 !116' I~ Camco 2 7/8~ x 1 n I KOP @ 400' sldepocket KSMM GLM 157' Max, hole angle = 79 to 82 deg. : f/3300 to 6200' Hole an~le ~hru' parts -- 32 deg. ) 7" Howco "ES" Cementer [ 2194' heat tTace. Rayahem Oamco 2 7/8" x 1" ~idepocket KBMM GLM I 2820' 2 7/8' 6,§ ppf, L.80, 8 rd EUE tbg,. ( drift ID = 2.347", sap, = 0,00592 bpf 7" 26 ppf, L-80, Mod, Btm. prod. casing ( drift ID = 6,151", cap, = 0,0383 bpf ) Two 7" short joints from 6879' to 6920' md. _S_tJ.~p_l_~tlon gummarv Cement rata;nar I '6~'24'MDi N.. Frae Pack - 6~',~-00 lbs 16/20 set for whip~tock 2090 TVI~ Carbollte CA: Frac. 73,400 lbs 12/2..0 san(:l with 3/8 gal/100 lbs of Proplok OB: Frae - 67,B00 lbs 1 ~J~0 sand with gal/100 Ibc of Proplok i ~4~'~ P_eJ'~LO.y. aLtj_oJI3_~..U~~ ~ ~ 7" HE~ versalrleve p~cker 3738' 'TVD lie_fJ_o_qLAtlas GR/CCL 7/3/95 ~ ~ ~.~fety~ub Size Interval (TV~) .020 gsuge screen 4,5 1~. N 781~,'.78~1' 803.,3833 4,6 4 )B 7850'-7870' 999-4015 7" HES BWD Sump packer 7' landing collar (PB'rD) 708~-' md j ~ k 7" float collar 8022' md 7" float shoe B068' md DATE REV, BY ~ COMMENTS., J~.~__oIa~ U_~ 11/9.7/97 JBF D..rJ[I. ed and Cased by Nabom 22E 07/lg/98 U. Under Frae and Completion I~¥ Nailers 37-E APl N.O;_.51:N_Q29z228_32 BP EXPLORATION (AK) IIII BIIII THE MATERIAL UNDER THIS cOVER HAs BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 PL M A T --'~'-~ H C:LOR.IhM~FILM.DOC E IA L W U N D E R IS M ARK E R -W li COmplianCe Report. File on Left side of folder 197-215-0 MD 08085 TVD 04196 Microfilm Roll / - MILNE POINT UNIT SB J-20 50- 029-22832-00 BP EXPLORATION (ALASK A \ HxT~-~ Completion Date: c~/98 Completed Status: 1-OIL Current: Roll 2 / -- Name D 8708 L DGR/EWR4-MD L DGR/EWR4-TVD L GR/CCL L GR/CCk-PERF T 8613 Interval Sent Received T/C/D . ~ SPERRY MPT/GR/EWR4 OH 8/19/98 8/19/98 6F4N~rL 112-8085 I[/'?.q/ciq.~ l[/.~o//~ OH 8'26/98 8/26'98 ~'AL 112-4196 ~ OH 8/26/98 8/26/98 "FINAL 6800-7964 r']/"x~[qi~ CH 5 7/8/98 7/15/98 :-HN~L 6800-7964 ~l~]~t'~ CH 5 7/8/98 7/15/98 ~'" SCHLUM PCD CH 8/12/98 8/20/98 Daily Well Ops/I/,~l/q? Was the well cored? yes fi~o:~ Comments: Are Dry Ditch Samples Required? yes ~___.~_ And Received?'"y%W~r6~" Analysis Description Receive .d~-yes no Sample Set ~- Tuesday, August 01, 2000 Page 1 of 1 08/25./00 14'5I FAX 1. Type of request; Abandon_)( 907 564 5193 BP EXPLORATION · ; STATE OF ALASKA ALASKA elL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend_ OpetationaJ shuldown _ Re.enter suaper~cled weft_ OO2 ARer casing _ Repair well _ Plugging _X Change approved program _ Pull tubing _ 2. Name of Operator BP Exploration (.Alaska), inc. 3. Addreas P. O. Box 196612 Anchorage, AK 99.51,9-6612 4. Location of well at sur~ce 2207' NSL, 3288' WEL, SEC. 28, T13N, RIOE, UM At top of produclJve InterVal 2382' NSL, 3571' WEL, SEC. 29, T13N, R10E, UM At effective depth At total depth 2392' NSL, 3824' WEL, SEC. 29, T13N, RIOE, UM 12. Present well condition summary Total depth: measured 808~ l~et flue vertical 4196 feet Effectfl/e depth: measured 7982_ feet true vertical 4109 feet Casing Conductor Surface Intermediate Liner Uner Size Cemented 5. Type of Well: Developrne~t Exploratory ~ Stratlgmphic Se~ice__X Plugs (measured) Junk (measured) Time sxl~neion _ Stimulate_ Varlallce _ Pedomte _ Otl~er_X 6. Datum ~levation (DF or K{~ feet) KBE -- 6~4.22. ~eet 7. Unit er Property halle : Milne Point Unit I~. Well number MP 9. Permi{ number / approval number 197-21S 10. APl number 50-029-22832 11. Field / Pool Milne Point Unit/Schrader Bluff ,ORIGINAL 80' 20" 8036' 7" Measured Depth True vertical Depth Perforation depth: measured 2.,¢0 ~xArctlc.3et 1 (eppmX) 1476 s× PF 'E', 132 sx Class 'G' 112', 8066' 7778-7798; 78E~0-7870; 7616.-76EH ~ flue vertlc~ ! . ITublng (size, grade, and measured depth PacKers & SSSV (type & measured depth) 3@36-3955; 3997-4014; 3BOO-.3829 2 7/8" 6...~ L-80 @ 7S1~ MD 13. Attachments Description summary of proposal ~X Detailed operatJorls program ~ ' BOP sketch -- 14. Estimated date for commencing opera{ion 15. Status of wet) ~lassifigation as: August 30, 2000 16. If proposal was verbally approved Oil __ Gas ~ Name of ap. prover Da~e ap. proved Service Shut in Producer 17, I hereby certify I~hal the 1oregoing isirue and correcl to 1he besl of my knowledge. Suspended__ Date FOR COMMISSION USE ONLY Conditions of approval: Nolify Commission so represent~ti~,e may witness Plug inlegdty _ BOP Test ~ Location clearance Mechanical Integrlb/,..Ta~t . ~ ~.~, Subsequent folrrl I'~i~ltfired iO-~l'~ {~)r'~_ Approved by order of the Colmmi Commissioner Date Form 10-403 Rev 06/15/88 · O F~,~..~NAL SIGNED BY D cay!or Seamount approved Copy, Returne~ SUBMIT IN TRIPLICATE 14'51 FAX 907 564 5193 BP EXPLORATION ~004 · .. 08/25/00 I I I i ii 1/Ve.l[he~d~ 1 l" ~M FMC G~ 6 -~ ~ ~ ~- Odg. GLE[~.=35.10' ~q Hno' 27/8"xll"FMCw/27JS" ~/ I~ , J ~m,o2718"x1" , Max, hole angle ' 3300 to ~oo' / .I 2 718" 6,5 ppf, L~0, 8 rd EUE ~g.. / [ ~ ~1 ' [ ~o 7" sho~ joints from 6879',0 6920 md. N: Fmc Pack- 52,200 lbs 16/20 / ~ seal section Ca~olite / ~ CentnhE GMF 562 serl~ OA: Fmc- 73,400 '~S 1~20 sand ~ 3~ I ~ 63h m~lio[o. 1~- / 26 ' gal/100 lbs of Pmplok / ~ P , 6~, OB: Fmc - 67,800 lbs 1~0 ~nd wi~ 3/e ~ ~ amps. gal/100 lbs O~ Pmplok Peroration Summa~ , Re[IoR: Atlas G~CL 7/3/98 ~ I~ . _ - ~ ' ~ · Size SPF Intawal - ' - - 4,5 12 N 7616'-76~1' ~80~833 I~! ~4.~ . ~ 7~0'-7~70' ~9~0~ ~ I~ ..................... ' 7" ~oat shoe [ 8~6' m~ mm DATE R~. ~Y COUM~S MILNE POi~ UNIT 11/27/97 JBF Drifted and Cas~ by Na~m 07119198 M. Linder Fmcand Compled0n by Ne~m 27-E ~PI NO: 50~29-22832 ,,, m _ m, m BP EXPLOSION I I 08/25/00 14'51 FAX 907 564 5193 BP EXPLORATION ~003 To: From: Subject: References: Tom Maunder -- AOGCC ' Robert Laule / Barbara M. Holt MPJ-20 Application for Sundry Permit - P&A for Sidetrack Operations AP1 #50-029-22832 Well MPJ-20 was drilled in November of 1997 as a Schrader production well. Shortly after this well was brought on production, the ESP failed. As it was not economic to replace the pump, this well has been shut-in. This well is presently plknned for a Schrader injector sidetrack. Pre-Rig Work: *Notify the field AOGCC representative with intent to plan a~:d abandon. 1. RU Wireline for a robing hole punch at +/- 7400'. 2. Displace the well to clean seawater by cimulating down the tubing through the hole punch. Circulate until clean seawater returns to surface_ Freeze protect top 2200' MD with diesel. 3. Test wellhead packoff to 5000 psi for 30 min. 4. Bleed annulus and tubing to 0 psi pressure. Secure well. 5_ Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Rig Operations: . 4. 5. 6. 7. 8. Estimated Pre-rig start Date: 08/30/00 MmU Nabors 41~S, ND tree and NU BOPE. ~ Circulate out freeze protecion and displace well to seawater. · Pull 2 7/8" L-80 tubing and ESPcp and LD same. RIH and set cement retainer at +/- 7500' MD. Stab through retainer and squeeze cement to abandon N, OA, and OB peffs. ~' v,~, '<'"~,~,-,,x -~c~ Leave well for drilling fig to set kickoff whipstock above 6100'. Circulate to freeze protect from 2200' MD. ' ~q-% *'~'"~%. RDMO Nabors 4ES_ Robert Laule Drilling Engineer 564-5195 Barbara M. Holt Drilling Engineer 564-5791 · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1 Status of Well Classification of S...ei~ic · ,~".,~,:~!'d.~ ~' '~ [] Oil E~] Gas I--J Suspended [--~ Abandoned [--] Service., 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-215 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 - 50-029-22832 4. Location of well at surface " ~:11~~' 9. Unit or Lease Name 2207' NSL, 3288' WEL, SEC. 28, T13N, R10E, UM. . - ..~ ..7"~2--~ "~~[1~ !! Milne Point Unit At top of productive interval~~' , 10. Well Number 2382' NSL, 3571' WEL, SEC. 29, T13N, R10E, UM ~; .... MPJ-20 At total depth !i. :-: ~--~'~': , .. 11 . Field and Pool 2392' NSL, 3824' WEL, SEC. 29, T13N, R10E, uM Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE -- 64.22'I ADL 025517 ~ 2. D~,~ Spudd~d~ ~ ~26~97 I ~ ~' ~to *' ~' ~°"~° I ~ 4' ~ °°~" ~s~" °r ^~n~'l ~ ~' W~'or ~oPt"' '* °"s~°ro I~ ~' ~°' °* c°~p'ot~°ns~ ~/~o/~ w/~ ~/~ ~/^ ~ O~ 8085 4196 [-rI 7982 4109 Pr []Yes ~-I No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, ESS, GR/CCL, GR/JB 23. CASING, LINER AND CEMENTING RECORD CASING SE'FI-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 30' 8066' 8-1/2" 1476 sx PF 'E', 132 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 4 spf 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5#, L-80 7510' MD TVD MD TVD 7778'-7798' 3936'-3953' 7616'-7651' 3800'-3829' 7850'-7870' 3997'-4014' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 60 bbls dead crude & 15 bbls diesel Frac, 7850'-7870' 67850# 12/20 Proplok behind pipe Frac, 7778'-7798' 73400# 12/20 Proplok behind pipe Frac, 7616'-7651' 47555# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) , . ½;' ~? July 30, 1998 E ectric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL iCHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure OALCULATED OIL-BBL GAS-MCF WATER-BBL 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. 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. TSBF 7580' 3770' SBF1 7612' 3796' TSBD 7773' 3932' TSBB 7852' 3999' 31. List of Attachments Summary of Daily Drilling Reports, Surveys , I hereby certi~e foregoing,i~'~e and co~.rect to the best of my knowledge 32. Sig ned~~~~~~~~~ Title Drilling Engineering Supervisor Date. MPJ-20 97-215 Prepared By Name/Number: Kathy Campoamor, 564-5122 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 27: 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 Facility Date/Time 25 Nov 97 26 Nov 97 27 Nov 97 28 Nov 97 29 Nov 97 30 Nov 97 01 Dec 97 M Pt J Pad 14:00-14:30 14:30-15:30 15:30-00:00 00:00-01:30 01:30-06:00 06:00-09:00 09:00-09:30 09:30-10:00 10:00-12:00 12:00-14:00 14:00-15:30 15:30-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-10:00 10:00-11:00 11:00-12:30 12:30-20:30 20:30-21:30 21:30-22:30 22:30-23:00 23:00-00:00 00:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-12:00 12:00-23:00 23:00-00:00 00:00-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-08:00 08:00-14:00 14:00-17:00 17:00-18:00 18:00-06:00 06:00-07:00 07:00-08:30 08:30-12:00 12:00-15:00 15:00-17:00 17:00-22:30 22:30-01:00 01:00-02:30 02:30-03:00 03:00-06:00 06:00-13:00 13:00-13:30 13:30-15:30 15:30-16:00 16:00-17:30 Duration 1/2 hr 1 hr 8-1/2 hr 1-1/2 hr 4-1/2 hr 3hr 1/2 hr 1/2 hr 2hr 2 hr 1-1/2 hr 14-1/2 hr 1/2 hr lhr 1-1/2 hr lhr lhr 1-1/2 hr 8hr 1 hr lhr 1/2 hr 1 hr 6 hr 2 hr 1 hr lhr 2 hr llhr lhr 4 hr lhr 1 hr 1 hr 1 hr 6 hr 3hr lhr 12hr lhr 1-1/2 hr 3-1/2 hr 3hr 2 hr 5-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 3 hr 7 hr 1/2 hr 2 hr 1/2 hr 1-1/2 hr Progress Report Well MPJ-20 Rig Nabors Page Date Activity Held safety meeting Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Additional services Installed Divertor Rigged up Divertor Held safety meeting Tested Divertor Made up BHA no. 1 Drilled to 133.0 ft Made up BHA no. 1 Drilled to 2401.0 ft Drilled to 2585.0 ft Circulated at 2585.0 ft Pulled out of hole to 97.0 ft Pulled BHA Serviced Top drive R.I.H. to 2585.0 ft Drilled to 3971.0 ft Circulated at 3971.0 ft Pulled out of hole to 2216.0 fi Serviced Top drive R.I.H. to 3971.0 ft Drilled to 4902.0 ft Drilled to 5379.0 fi Circulated at 5379.0 ft Pulled out of hole to 3879.0 fi R.I.H. to 5379.0 ft Drilled to 6903.0 ft Circulated at 6903.0 ft Pulled out of hole to 199.0 fi Serviced Block line Serviced Top drive Serviced Top drive R.I.H. to 4617.0 ft R.I.H. to 6808.0 ft Rigged down Top drive R.I.H. to 6903.0 ft Drilled to 8048.0 ft Drilled to 8085.0 fi Circulated at 8085.0 ft Pulled out of hole to 925.0 ft R.I.H. to 8085.0 fi Circulated at 8085.0 fi Pulled out of hole to 925.0 fi Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 2290.0 ft (7in OD) Ran Casing to 8065.7 ft (7in OD) Removed Casing handling equipment Circulated at 8065.0 fi Held safety meeting Mixed and pumped slurry - 201.600 bbl 1 12 August 98 Progress Report Facility M Pt J Pad Well MPJ-20 Rig Nabors ;t~g-,9~- Page 2 Date 12 August 98 Date/Time 02 Dec 97 17:30-21:00 21:00-23:00 23:00-03:00 03:00-06:00 06:00-09:00 Duration 3-1/2 hr 2 hr 4 hr 3hr 3hr Activity Circulated at 2193.0 fl Mixed and pumped slurry - 417.000 bbl Rigged down Divertor Rigged up Xmas tree primary components Cleared Sand traps Facility Date/Time 29 Jun 98 30 Jun 98 01 Jul 98 02 Jul 98 03 Jul 98 04 Jul 98 M Pt J Pad Progress Report Well MPJ-20 Page 1 Rig Nabors 27E Date 12 August 98 Duration Activity 21:00-22:00 22:00-22:30 22:30-06:00 06:00-06:30 06:30-00:00 00:00-02:00 02:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-10:00 10:00-13:00 13:00-13:30 13:30-15:30 15:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-18:00 18:00-18:30 18:30-19:30 19:30-00:00 00:00-01:00 01:00-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-10:30 10:30-11:30 11:30-12:30 12:30-13:30 13:30-18:00 18:00-18:15 18:15-19:00 19:00-19:30 19:30-20:30 20:30-21:00 21:00-21:15 21:15-22:45 22:45-23:30 23:30-06:00 06:00-06:30 06:30-09:00 09:00-11:00 11:00-16:00 1 hr 1/2 hr 7-1/2 hr 1/2 hr 17-1/2 hr 2 hr 4hr 1/2 hr 1/2 hr lhr 2hr 3 hr 1/2 hr 2hr 1/2 hr 1 hr lhr 1/2 hr lhr 1 hr 6-1/2 hr 2 hr 1 hr 1/2 hr 3-1/2 hr 1 hr 7 hr 1/2 hr lhr 4-1/2 hr 1 hr 1-1/2 hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1 hr 1 hr lhr 4-1/2 hr 1/4 hr 3/4 hr 1/2 hr lhr 1/2 hr 1/4 hr 1-1/2 hr 3/4 hr 6-1/2 hr 1/2 hr 2-1/2 hr 2 hr 5 hr Rigged up High pressure lines Held safety meeting Rig moved 25.00 % Held safety meeting Rig moved 100.00 % Removed Xmas tree Rigged up BOP stack Held safety meeting Installed BOP test plug assembly Tested BOP stack Rigged down BOP stack Tested BOP stack Installed Wear bushing R.I.H. to 2194.0 ft Circulated at 2194.0 ft Drilled installed equipment - DV collar Tested Casing - Via string Held safety meeting Pulled out of hole to 0.0 ft Made up BHA no. 2 R.I.H. to 7982.0 ft Reverse circulated at 7982.0 ft Tested Casing Held safety meeting Pulled out of hole to 0.0 ft Made up BHA no. 3 R.I.H. to 7982.0 ft Held safety meeting Reverse circulated at 7982.0 ft Pulled out of hole to 0.0 ft Removed Bell nipple Rigged up Lubricator Conducted electric cable operations Perforated Held safety meeting Pulled out of hole to 3550.0 ft Perforated Rigged down Lubricator Rigged up Bell nipple Repaired Top drive Ran Tubing in stands to 7345.0 ft Held safety meeting Rigged up Drillfloor / Derrick Held safety meeting Injectivity test - 188.000 bbl injected at 5245.0 psi Injectivity test - 83.000 bbl injected at 1804.0 psi FRAC job - 205.000 bbl injected at 5200.0 psi Monitor pressures FRAC job - 644.000 bbl injected at 3800.0 psi Monitor pressures Held safety meeting Monitor pressures Reverse circulated at 7345.0 ft Reverse circulated at 7820.0 ft Progress Report Facility M Pt J Pad Well MPJ-20 Page 2 Rig Nabors 27E Date 12 August 98 Date/Time 16:00-16:30 16:30-20:30 20:30-21:30 21:30-22:00 22:00-01:00 05 Jul 98 01:00-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-12:00 12:00-13:30 13:30-14:00 14:00-14:45 14:45-15:15 15:15-18:00 18:00-18:30 18:30-19:30 19:30-06:00 06 Jul 98 06:00-06:30 06:30-07:00 07:00-07:30 07:30-11:30 11:30-13:00 13:00-19:00 19:00-19:30 19:30-22:30 22:30-23:30 23:30-00:30 07 Jul 98 00:30-04:30 04:30-06:00 06:00-06:30 06:30-09:00 09:00-11:00 11:00-15:00 15:00-20:00 20:00-03:00 08 Jul 98 03:00-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-11:30 11:30-12:30 12:30-14:30 14:30-15:00 15:00-16:00 16:00-17:00 17:00-21:30 21:30-22:30 22:30-23:30 23:30-01:30 09 Jul 98 01:30-02:30 Duration 1/2 hr 4 hr 1 hr 1/2 hr 3 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1 hr 1 hr 1 hr 2-1/2 hr 1-1/2 hr 1/2 hr 3/4 hr 1/2 hr 2-3/4 hr 1/2 hr lhr 10-1/2 hr 1/2 hr 1/2 hr 1/2 hr 4hr 1-1/2 hr 6 hr 1/2 hr 3hr 1 hr 1 hr 4 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2hr 4 hr 5 hr 7hr 1 hr lhr 1 hr 1-1/2 hr 4hr 1 hr 2hr 1/2 hr lhr 1 hr 4-1/2 hr lhr lhr 2hr 1 hr Activity Injectivity test - 3.000 bbl injected at 1175.0 psi Flow check Circulated at 7820.0 ft Flow check Pulled out of hole to 0.0 ft Rigged down Bell nipple Rigged up Lubricator R.I.H. to 6000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Removed Lubricator Rigged up Bell nipple Ran Tubing to 7313.0 ft (3-1/2in OD) Rigged up Drillfloor / Derrick Held safety meeting Injectivity test - 183.000 bbl injected at 4800.0 psi FRAC job - 198.000 bbl injected at 4500.0 psi Monitor pressures FRAC job - 202.000 bbl injected at 1200.0 psi FRAC job - 644.000 bbl injected at 4350.0 psi Monitor pressures Held safety meeting Reverse circulated at 7313.0 ft Ran Tubing in stands to 7600.0 ft Reverse circulated at 7982.0 ft Circulated at 7982.0 ft Reverse circulated at 7982.0 ft Flow check Pulled out of hole to 0.0 ft Rigged up Bell nipple Rigged up Lubricator Perforated Perforated Held safety meeting Pulled out of hole to 0.0 ft Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Set downhole equipment (wireline) Rigged down Lubricator Rigged up Bell nipple Rigged up sub-surface equipment - Downhole equipment Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 7656.0 ft Rigged up High pressure lines Set packer at 7541.0 ft with 3000.0 psi Held safety meeting Rigged up High pressure lines Injectivity test - 100.000 bbl injected at 4889.0 psi Gravel pack - 52155.000 bbl pumped at 3200.0 psi, screen out at 6200.0 Reverse circulated at 7541.0 ft Gravel pack - 0.000 bbl pumped at 0.0 psi, screen out at 0.0 psi Reverse circulated at 7541.0 ft Rigged down High pressure lines ,si Progress Report Facility M Pt J Pad Well MPJ-20 Rig Nabors 27E Page 3 Date 12 August 98 Date/Time 10 Jul 98 11 Jul 98 12 Jul 98 02:30-03:30 03:30-06:00 06:00-08:30 08:30-14:00 14:00-15:00 15:00-18:00 18:00-22:30 22:30-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-20:30 20:30-23:30 23:30-06:00 06:00-13:30 13:30-20:00 20:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 Duration lhr 2-1/2 hr 2-1/2 hr 5-1/2 hr 1 hr 3 hr 4-1/2 hr 6hr 1-1/2 hr 1/2 hr lhr 3 hr 10hr 3hr 6-1/2 hr 7-1/2 hr 6-1/2 hr 4-1/2 hr 3-1/2 hr lhr lhr Activity Pulled out of hole to 7656.0 ft Pulled Tubing in stands to 2000.0 ft Pulled Tubing in stands to 7541.0 ft Tested BOP stack Serviced Top drive R.I.H. to 7532.0 ft Reverse circulated at 7532.0 ft Pulled out of hole to 7532.0 ft Worked on BOP - BOP stack Worked on BOP - BOP stack Rigged up Tubing handling equipment Serviced Other sub-surface equipment Ran Tubing to 5202.0 ft (2-7/8in OD) Rigged up Completion string handling equipment Ran Tubing to 6397.0 ft (2-7/8in OD) Ran Tubing to 7509.9 ft (2-7/8in OD) Ran Tubing to 7509.9 ft (2-7/8in OD) Rigged down BOP stack Rigged up Xmas tree Racked back drill pipe Rig moved 0.00 % Milne Point Unit, Alaska TO: FROM' Well Name: Main Category: Sub Category: Operation Date: Bixby/March Spearman MPJ-20 PERF Eline Perf 7-3-98 Date: 17--98 I Objective' Eline convey perforate the Schrader Bluff "OB" Sequence of Events: RU Atlas MU GR on rollers PJSM P/T lubricator to 500 psi RIH with GR/CCL for Markline log Able to roll through 85 degree and 4.6 dogleg at 3636' MD Make markline GR/CCL logging pass. POOH RIH with guns and GR/CCL on rollers to 3583'. Could not get deeper. POOH Install tractor RIH to 3583' Tractor tools from 3583' to 6400' Make correlation pass to tie into MWD log Depth correct. Drop back down and tag PBTD @ 7950' MD Position guns in OB Perforated OB based on markline log from 7850' to 7870' with 4 %" gun 4 spf Big Hole charges @ 0-180 phasing POOH All shots fired RD Atlas Results: Perforated the Schrader Bluff OB sand from 7850-7870' (20') with 4 %" gun with 4 spf Big Hole charges at 0-180 degree phasing Tie in log/date Atlas 7/3/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter 7850 Shot Density Orientation Phasing 7870 4 ~ 4 none 0-180 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: B Hill/J Hendrix FROM: J. Spearman DATE: 07/03/98 RE: MPJ-20 DATA FRAC AND FRAC ( OB Sand) SERVICE CO'S.: DS, Peak, Howco , , An injectivity test was performed by circulating the gel at 8 BPM to the end of the tubing tail. 74 bbls of gel was pumped instead of 64 bbls, therefore 10 bbls of gel was circulated up the annulus. Once this was noticed we slowed down to 2 bpm and the pipe ram were closed. The gel was squeeze to the perforations. When annulus pressure indicated gel was on perforation, we shut down to let pressure bleed down to close any micro fracs. Performed injectivity test flushing the treatment with source water. Next we performed the data frac by circulating the gel to the tubing tail with the pipe rams open. Oil was noticed in the mud pits during this circulation. The completion brine was 8.6 ppg. The gel was squeezed to the perforation and then shut down for an ISIP. Once pressure fell off, the data frac was started. The data frac was over displaced by 5 bbls. NWFP drop by 160 psi. With the available fluids and the intent to reduce the sand concentration ramp, a scour treatment was not pumped. The data was analysis based on the recent finding of Steve Cooper and NSI indicating height growth. The data frac was flushed with source water The redesign frac was Pumped based on the running Stimplan in design mode with the history match from the data frac. For a frac length of 62', the pad required was +6,000 gallons which equated to a 17% excess. Another consideration for the design was to compare the percent pad and ensure that we were lower than typically pumped. The pad was reduced to 4,000 gallons and the slurry was ramped at 1 ppg to 50 bbls based on clean volume. The job went to flush placing 67,850 lbs of 12/20 sand coated with 3/8 gallons per 100 lbs of Propiok. No net pressure rise was seen, but hydrostatic effects have not been accounted for. TSO time based on the design was 8 minutes. No spills or job problem encountered O7/O6/98 5:39 PM DATA FRAC & FRAC SENT VIA MICIdL}SOFT MAIL PUM[ UMMARY RATE STAGE CUM '~-~bOMMENTS BPM BBL BBL k...,' INJECTIV. ITY TEST , . Design Rate, Bbls Max Rate, Final ANN, ISIP2, NWB friction, Treat grad, BPM Pumped bpm , psi PSI psi psi/ft +25 100 26 1464 1096 368 0.71 DATA FRAC Bbls Bbls XL gel Time XL gel Final STP, ISlP, psi NWB Treat grad, Pumped to Perfs on perfs psi friction, psi p.si/ft 100 1296 1089 207 0.71 FRAC Sand Lead prop Ta'ii prop Design total pumped, behind pipe, behind behind pipe, Liner Sand, Job was M# M# pipe, M# M# M#' Tailoff, M#' 71,191 67,850 3341 , . . o . Ft of Estimated Final ISIP, psi ISIP Incr Actual TSO, TSO, sand in · sand top STP, over sand:pad design, min Nolte Pipe psi datafrac ratio Plot 157 7825 0 17% '7 none Operational problems No Operation problems encountered. We did circulated 74 bbl instead of 63 bbls during the injectivity test which put 10 bbls of HEC in the annulus. Comment.~ DATE/TIME 07/05/98 '19:05 19:43 19:49 19:59 20:05 20:11 20:36 20:44 ' 0P'ERATIdNS suMMARY" "' - Pre-job Safety meeting on 27E Pressure Test lines to 7644 psi Start injectivity test circulat!ng gel to tbg tail, at 8 BPM Slowed rate to 2 bpm then close pipe rams. Displaced gel to perforations Start Injectivity Test Shut down Injectivity test ISIP = 1096 Start DF by Circulating get to tbg tail at 8 BPM Slow to 2 bpm Closed Ram 20:58 Shut down 20:59 Perform Data Frac 21:09 SD DF to collect pressure falloff ISIP = 1089 21:47 Start Frac Job 22:22 Flushed Frac ISlP = 1071 PUMPING SUMMARY TIME ' RATE ANNP! WHP ISTAGEi CUM I COMMENTS I BPM PSIG PSIG BBL BBL ,. OT/O / s .... INJECTIVITY TEST DISPLACEMENT ='81.6 BBLS 19:49 8 0 0 0 0 CircUlated HEC to tbg tail 19:59 8 0 13.27. 74 74 Gel at tb~l tail 10 bbls of HEC passed tbg tail 20:00 2 0 0 74 Siowed rate to 2 BPM 20:00 2 965 1923 2 76 Shut down and Closed Pipe Rams Missed tubing tail. ISlP 1040. Opted to start injectivity test 20:06 6 1134 2242 1 77 Starting Injectiv!ty Test 20:07 24 1686 4316 28 105 Switch to source water , , 20:08 27.2 1546 5227 31 136 Max rate 20:09 20 1380 · 4375 19 155 Slow down to 20 BPM for stable rate 20:12 0 33 188 SD for ISlP 970 PSI 90 bbls of gel behind pipe DATA FRAC 20:36 8 0 0 0 0 Start Data Frac by circulating gel to tubing tail 20:45 2 1250 1803 19 64 Slowed rate to 2 BPM then closed pipe rams 20:54 0 83 Shut down to let any fracs close ISlP = 1040 20:58 0 83 Start DF , , 21:03 20.6 1321 3432 100 183 100 bbls through perforations 21:05 20 1332 4143 17 200 Switch to MP Source Water 21:09 88 288 SD DF ISIP: 953 Monitor pressure for decline Analysis. Over Displace data frac by 5 bbls '~-'1 PUMPING, i SUMMAI:'V TIMEI RATE IAr. BPM . PSTG ..-.CIG BBL~I'"HP STAGE CUMBBL ....... ' COMMENTS Frac , , 22:47 0 95 0 Start Pad 22:52 20 1253 3928 83 Pad on pefs 22:54 1312 Good Pad on perfs 22:57 20 1299 3345 50 178 1ppg on perfs 22:59 20 1299 3322 52 228 2 ppg on perfs 23:02 20 1277 3281 54 280 3 ppg on parrs 23:05 19.8 1263 3382 56 . 334 4 ppg on perfs 23:08 19.7 1264 3579 58 390 5 ppg on perfs 23:12 19.9 1272 3730 91 448 6 ppg on perfs 23'17 Start gel displacement 23:17 20.2 1290 3849 63 539 7 ppg on perfs 23:18 Start source water flush 23:20 20 1274 3853 32 602 8 ppg on perfs 23:21 0 644 Shut down ISIP 997 Page 5 FLUIDS PUMPED DOw-NI-,__E THROUGH PEFORAT1ON$ INJ TEST: 90 Bbls DATA FRAC: 205 Bbls FRAC: 576 Bbls Tubing Vol 166 Bbls ****TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WINDOW NONE JWater SEA H20 pH GEL' QUALITY CONTROL CHECK Gel TEMP 84 86 5.7 } 132 3 62 GEL I GEL pH VISCOSITY 5.6 I 125 PIPE TIME XL TIME XL Milne Point Unit, Alaska TO: Bixby/March FROM: H. Thackeray Well Name: MPJ-20 Main Category: DRLG Sub Category: Eline Perf Operation Date: 7-5-98 Date: 17-5-98 I Objective: Eline convey perforate the Schrader Bluff"OA" using tractor tool. Sequence of Events: RU Atlas. MU 20'gun & GR/CCL with rollers and tractor tool. PJSM P/T lubricator to 500 psi. RIH - tools able to roll to 3300'. Start tractor. Tractor tools from 3300' to 6300'. Roll rest of way and find sand PB at 7812'. Make correlation pass. Still on depth with 7/3/98 GR/CCL log (2' shallow to MWD log) as same marked and flagged line used. Drop back down and log up to position guns in OA. Perforated OA based on GR/CCL log from 7778' to 7798' with 4 %" gun 4 spf Big Hole charges @ 0-180 phasing. POOH. All shots fired. RD Atlas. Results' Perforated the Schrader Bluff OA sand from 7778-7798' (20') with 4 %" gun with 4 spf Big Hole charges at 0-180 degree phasing Tie in log/date Atlas GR/CCL 7/3/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 7778 7798 4~ none 0-180 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: B. Hill/J. Hendrix FROM: J. Spearman DATE: 07~05~98 RE: MPJ-20 DATA FRAC AND FRAC ( OA Sand) SERVICE CO'S.: DS, Peak, Howco ...... .'Zi'.... "l ", ' ' 30BSU ARY ....... '11 80 ppt gel was ordered for the job. From the viscosity data, it appears that the gel loading is in the high 60 ppt. An injectivity test was performed by pumping 100 bbls of HEC. 62 bbls of gel was circulated down at 8 bpm to the tbg tail with the pipe rams open. Rate was dropped to 2 bpm. Pipe rams where closed and the gel was squeezed to the perforations. The injection test was done and displaced with HEC to save gel and circulation time. This also decrease the friction pressure for the injectivity test thus enabling to goto 30 BPM. The well was shut in for 8 rains until annulus pressure was less than 800 psi. The data frac was designed by pumping an additional 120 bbls of HEC (81+120 = 201 total). The data frac was pumped, but the crew shut down early. Also, they pumped for about a 1 minute at 2 bpm before getting off the pumps. A total of 190 bbls of gel was placed into the perforations. A data frac was not repeated due to gel availability on locations. Since NWFP was higher than 200 psi, a scour treatment'was performed. With the high NWFP, I ppg was the maximum sand concentration pumped. With the gel shortage, only 10 bbls of HEC overflushed was pumped followed by 15 bbls of water. The job design used the decline analysis t© pick the Pc and get an idea for the starting point for the fluid loss coefficient to history match the data. With the recent work by Steve Cooper and the NSI group, stress contrast were lowered to allow for height growth. Once the data frac was matched, the design was ran. From the design output the pad was lowered from 100 bbls to 72 bbls. The sand ramp was based on increasing sand concentration 1 ppg every 48 bbls until the 5 ppg stage where 71 bbls where pumped. This was repeated for the 7 ppg and was done due to past experience when +6 ppg sand stages showed near wellbore pressure increases. Based on the Nolte-Smith plot and not accounting for hydrostatic head between the tubing and perforates with increasing sand Concentrations, the TSO began around 15-16 minutes after pad was on perforations. Before the slope indicating a TSO, breaks and builds are noticed. A 100 psi sharp pressure rise when 7.5 ppg was going through the perfs. The pressure level out after this rise. The job was flushed. 73,300 pounds of 12/20 sand coated 3/8 gal per 100 lbs of sand was placed behind pipe. 07/06/98 1:49 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL INJECTIVITy TEST Design Rate, Bbls Max Rate, Final ANN, ISI'P~, NWB friction, Treat grad, BPM Pumped bpm psi PSI . psi ps.i/ft +25 100 30 1336 970 366 .. 0.70 DATA FRAC Bbls Bbls gel to Time gel on Final STP, ISIP, psi ' NWB Treat grad, Pumped Perfs perfs psi friction, psi psi/ft 200 82 4 1301 953 348 0.70 Scour Rate Slurry Pumped Sand Pumped Final STP, ISlP, psi NwB Treat grad, BPM psi friction, ps! psi/ft 20 50 bbls I pp9 2100 1313 997 316 .70 FRAC Sand Lead prop Tail prop Design total pumped, behind pipe, behind behind pipe, Liner Sand, Job was M# M# pipe, M# M# M# Tailoff, M# FI u s h ed 76,300 73,400 2830 2830 Ft of Estimated Final ISIP, psi ISlP Incr Actual TSO, TSO, sand in sand top STP, over sand:pad design, min Nolte Pipe psi datafrac . ratio Plot 130 7681 1330 997 0 17% $'7 +10 ,, O.oerational .Droblern~ Waited 1.5 hrs for clean vac truck to load and off load water from MPU Source water Comments *** treesaver rubber left in hole. -~' ! I J I I II I DATE/TIME I OPERATIONS SUMMARY irt i i~ i i [ iii ' 7 · 111 iI · I i i i I i i 07/05/98 . ,, 13:30 Pre-job Safety meeting on 27E 14:18 Pressure Test lines to 7388 p.si , . 14:22 Start injectivity test circulating, gel. to tbg tail at 8 BPM 14:31 Slowed rate to 2 bpm then close, pipe rams !14:42 Shut down injectivity test. Pump 100 bbls throu, gh perfs. Flush with HEC 14:55 Start Data Frac . 15:06 Shut down Data Frac 18:14 Start Scour treatment 18:24 SD 18:54 Start Frac Job 19:23 Flushed Frac , . PUMPING sUMMARY T",nEI RATE I ANNPIWHP ISTAGEI CUM i COMMENTS , I BPM..J.p_.SIG !..PSIG ! ..BBL I BBL I ......... 07/03/98 : INJECTIVITY TEST DISPLACEMENT = 81.6 BBLS , 14:22 8 0 0 0 0 Circulated HEC to tbg {ail 14:29 8 0 1392 60 60 Gel at tbg tail 14:30 2 0 2 62 Slowed rate to 2 BPM 14:31 2 1411 1923. 1 63 Closed pipe Rams : 14:39 2 1349 2055 17 80 Pump gel to peroration 14:40 0 SD pumps ISIP = 970 psi 14:42 10 1325 2962 3 83 Starting Injectivity Test 14:43 Started Flush with HEC 14:44 29 1358 4852 31 114 Max rate · 14:46 20 1336 4083 59 173 Slow down to 20 BPM for stable rate , , 14:47 183 'SD for ISIP 970 PSI DATA FRAC 14:55 9.35 1360 2866 2 2 Start Data Frac (annulus down to < 800 psi frac assumed to be closed) 83 bbls of HEC in the Tbg 15.:00 20.6 1334 4143 98 100 100 bbls thro.ugh Rerforations , . 15:01 20 1332 4143 21 119 Switch to MP Source Water 15:04 19.89 1301 4770 84 203 pumping data frac (5 bbls source through perfs) 15:05 0 SD DF ISIP = 953 Monitor pressure for decline Analysis Scour Treatment 18:14 50 0 Start HEC pad for Scour 18:17 20.4 1184 4198 .50 50 Start sand 18:19 19.7 133 3960., 82 Pad on perfs PUMPING SUMMARY . . .... BPM PSIG PS!,G BBL BBL , , ,.., ....... 18:20 10 100 Start Gel overflush 11 110 Switch to source water, overflush 121 Start Flush , , 18:21 132 Sand on pefs 181 Gel overflush on perfs 192 Water overflush on perfs 18:25 0 82 201 SD down ISIP = 997 psi , Monitor pressure until < 850 less Pc pick and 150 net pressure based on ISIP Frac 18:54 0 72 0 Start Pad 18:59 20 1197 3928 82 Pad on pefs 19:00 1240 Good Pad on perfs 19:03 20 1335 47 154 1ppg on perfs 19:05 20 1213 4028 48 201 2 ppg on perfs ~ 19:07 20 1197 4129 48 249 3 ppg on perfs ....... 19:09 19.8 1184 .4184 48 297 4 ppg on perfs 19:12 19.7 1186 71 352 5 ppg on perfs , 19:16 20 1196 4344 48 407 6-ppg on peds 19:17 20 450 S{a~"~el displacement 19:18 20 1195 4325 71 454 7 ppg,on perfs 19:21 51 501 Start source water flush 19:21 20 1221 50 518 8 ppg on perfs 20 557 On HEC flush 50 577 Switch to Source water Flush , ,, 19:26 626 Shut down ISIP 997 .. Page 5 FLUIDS PUMPED DOWNHO~E THROUGH PEFORATIONS ~- INJ TEST: 100 Bbls DATA FRAC: 200 Bbls Scour 125 Bbls FRAC: 557 Bbls Tubing Vol 162 Bbls ****TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME iL.°". ' 'pETREDAT W'INDOW Tank 1 Tank 2 SEA H20 pH " GEL QUALITY CONTROL cHEcK ..... 90 5.7, 118 PIPE TIME XL TIME Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Bixby/March H. Thackeray MPJ-20 DRLG Eline Perf 7/6-8 198 Date: 17-9-98 Objective: Eline convey perforate the Schrader Bluff "N" using tractor tool. Eline convey sump packer on tractor also. Sequence of Events: 716198 RU Atlas. MU 20'gun & GR/CCL with rollers and tractor tool. PJSM P/T lubricator to 500 psi. 7~7~98 RIH - tools able to roll to 3300'. Start tractor. Tractor tools from 3300' to 6575'. Roll rest of way to 7800'. Make correlation pass and depth correct to with 7/3/98 GR/CCL marked line log (4' shallow to MWD log at N zone depth). Drop back down and log up to position guns across N zone. Perforated N sand based on GR/CCL log from 7631' to 7651' with 4 %" gun 12 spf Big Hole charges @ 45-135 phasing. POOH. All shots fired. MU 15' gun for run #2. Tractored from 3300 - 6550' Correlate depth and perforated N sand based on GPJCCL log from 7616' to 7631' with 4 %" gun 12 spf Big Hole charges @ 45-135 phasing. POOH. All shots fired. MU gauge ring and junk basket with tractor tool. Tractor shorted out ~3600'. POOH. Some trash in junk basket. Replace tractor and run back with GPJJB. Made two runs, recovered some rubber and gun debris with first run, very small amount of trash on 2®. MU Halliburton Sump Packer on tractor tool. 7/8/98 Tractoring going even slower due to larger OD of packer. Stalled out at 6140'. Had rig pump to help tractor down. Started falling again at 6800'. Make correlation pass and depth correct to 7/3/98 GR/CCL log. Set sump packer at 7656'. POOH. RD Atlas. Results: Perforated the Schrader Bluff N sand from 7616-7651' (35') with 4 ~" gun with 12 spf Big Hole charges at 45-135 degree phasing. Made GR/JB runs and set sump packer at 7656'. [[ Tie in log/date Atlas GR/CCL 7/3/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter 7651 4 ~ Shot Density Orientation Phasing 7616 12 none 45-135 Page 1 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Bill Hill et al FROM: Herb Thackeray DATE: 718/98 RE- J-20 (N) DataFRAC AND FRAC SERVICE CO'S.: DS, Halliburton (Tools), Peak, Nabors JOB SUMMARY Halliburton's Pre-packed screen (40') and 29' of blank pipe was run on rig 27E to cover the Schrader Bluff N Sand. The circulating pressure was extremely high (1140#) so we shut down and manipulated the tool. Afterwhich, a circulating pressure of 525 psi at 2.5 BPM was attained. The job continued with a 100 bbl injectivity test being circulated to the MPT tool where rate was decreased to allow for the choke to be closed. Once gel was on perfs, pumps were shutdown before bringing rate to 24 BPM. The last 20 BBL was dropped to 12 BPM. ISIP was recorded after shutdown and the net wellbore friction was determined to be 80 psi. A 200 bbl DataFRAC followed. It was also circulated down the tubing, the choke closed, and the fluid was injected at 2 BPM to the perfs where pumps were shutdown. Rate was regained at 12 BPM to inject the entire 200 BBL of 70# HEC plus a 5 BBL seawater over-displacement. Pumps were shutdown and pressure monitored and data sent to Houston for analysis. The redesigned pump schedule added %, 9 and 10 PPA stages and adjusted the inbetween stages for a proposed sand total of 99M # of 16/20 CarboLite. The job was pumped with minor pressure build until the 9 ppg stage hit the perfs and when it spiked up to 6200 psi and screened out. The MPT tool was shifted and sand in the tubing was reversed to the slop tank with the rig pumps. The tool was shifted back and the pack was re-stressed and held. There was 52.2M # sand placed behind the pipe, 4.6M # between the casing and screen and blank pipe and 12.8M # reversed to the slop tank. A lot was happening prior to the job screening out. The 12 BPM rate was attainable with two pumps. One of them was faltering and the second was brought up to keep the rate near 12 while another pump was being kicked in to replace the faltering one. We were also ramping to t0 PPA at the surface at this time. This all actually went pretty smooth but might have been contributing factors? When rigging down the equipment, DS noted their missile and blender had significant amounts of proplock from previous jobs which will require several days to clean out. A chunk of this may have broken loose during the job and affected the 2® pump. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final ANN P ANN ISIP NWB Treat grad, BPM Pumped bpm psi psi friction, psi psilft max 100 24 1020 940 80 0.72 DATA FRAC Bbls Bbls get to Rate Final ANN P ANN ISIP NWB Treat grad, Pumped perfs BPM psi psi friction, psi psi/ft 200 67 12 1082 1006 76 0.72 Page 2 ,~ FRAC Sand Prop Prop Proppant Prop Tresaver pumped, behind pipe, left in size/type reversed rubber left Job was # # csglscree out, # in hole? ~ n# Screened out 52,155 00 4,600 16120 12,755 NIA , ~, CarboLite Comments TIME ' OPERATIONS SUMMARY 1515 Safety Meeting 1602 Pressure Test treating lines - 6,998 psi 1607 Determine circulating pressure 1640 Start Injectivity test 1726 Start DataFrac 2054 FRAC 2130 Screenout 2221 Restress TIME RATE ~ BPM PUMPING SUMMARY r ANNP; WHP i STAGE ': CUM PSlG PSIG BBL BBL COMMENTS INJECTIVITY TEST DISPLACEMENT = 67.4 BBLS 1607 2.5 13 525 10 - Determine circulating pressure, seawater 1640 8 9 87 100 24 Circulate HEC to packer HEC 1648 2 0 1056 89 Close choke 1650 - 950 1100 91 Shutdown 1656 , 0-24 302 415 91 Start Injectivity Test 1658 24 1115 4889 72 124 Displace gel seawater 1700 12 1150 4600 176 Slow rate to 12 BPM 1703 1020 2750 196 Shutdown WH/IA ISIP - 1045/940 psi NWBF- 80 psi Grad. - 0.72 Page 3 DATA FRAC DISPLACEMENT-= 67.4 BBLS 1726 8 20 2008 200 - Circulate HEC to packer 1735 2 555 1482 64 Slow rate to shut choke 1736 0 903 1449 66 Shutdown 1740 12 490 600 66 Start DataFRAC 1752 12 1090 2860 72 200 Start seawater displacement 1758 - 1082 2770 272 Shutdown WH/IA ISIP- 1123/1006 psi NWBF - 76 psi Grad. - 0.72 FRAC DISPLACEMENT = 52 BBLS 2054 12 33 155 71 - Start PAD 2101 12 1046 2970 36 71 Start ~ PPA 2104 12 1104 2906 37 108 Start 1 PPA 2107 12 1102 2910 139 1/2 PPAonZone 2107 12 1101 2901 26 145 Start2 PPA 2109 12 1097 2906 27 171 Start 3 PPA 2110 12 1096 2915 175 1 PPonZone 2112 12 1097 2983 28 198 Start4PPA 2113 12 1100 3000 212 2PPAonZone 2114 12 1101 3110 29 226 Start 5 PPA 2115 12 1100 3167 238 3PPAonZone 2116 12 1106 3226 30 255 Start 6 PPA 2117 12 1106 3244 265 4 PPA on Zone 2119 12 1t10 3264 31 285 Start7 PPA 2120 12 1112 3300 293 5 PPA on Zone 2122 12 1117 3295 32 316 Start8 PPA 2122 12 1121 3299 322 6 PPA on Zone 2124 12 1128 3295 50 348 Start 9 PPA 2125 12 1135 3286 352 7 PPA on Zone 2127 12 1163 3153 383 8 PPAon zone 2128 12 1196 3038 164 398 Start 10 PPA 2130 12 1247 6200 414 9 PPA on Zone SCREENED OUT 2135 Bleedoff annulus - Reverse out 2 tubing volumes 2222 - 750 2100 Re-stress gravel pack - Held Page 4 FLUIDS PUMPED DOWNHOLEt INJ TEST 196 BBLs DATA FRAC: 272 BBLs FRAC: 424 BBLs ~ seawater DF/FRAC ! 7.5 GEL QUALITY CONiI~OL CHECK HEC i HEC TEMP i pH i VISCOSITY i 70 ! 6.0 PIPE TIME XL XL TIME ,~pH N/A N/A FLUID ADDITIVES J-134 (enzyme breaker) - 2.5# / 1000gal F-75N (surfactant) - 2 gal/1000 gal MILNE POINT, ALASKA TO: FROM: WELL# Main Category: Sub Category: Operation Date: Bill Hill Matthew Linder J-20 Pumping Post Completion freeze protect. 7/12198 Objective: 27-E has moved off location. HB&R will freeze protect wellbore using dead crude and diesel. Operation' Rigged up HB&R, Pumped 60 bbls of dead crude down annulus and 15 bbls of diesel down tubing. Well is freeze protected. Conclusion: Freeze protected annulus using dead crude and tubing using diesel. SIWHP: IA: OA: Diesel Used L 15 bbls I Methanol Used I J SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING MPU / MPJ-20 500292283200 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/11/97 DATE OF SURVEY: 120197 MWD SURVEY JOB NUMBER: AKMM80016 KELLY BUSHING ELEV. = 64.22 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -64.22 0 0 N .00 E .00 .00N .00E .00 112.00 112.00 47.78 0 0 N .00 E .00 .00N .00E .00 141.27 141.27 77.05 0 14 S 2.57 E .82 .06S .00E -.01 232.58 232.58 168.36 0 22 S 3.66 E .15 .55S .03E -.06 322.57 322.57 258.35 0 30 N 89.28 W .73 .85S .35W .31 413.61 413.59 349.37 1 9 N 80.08 W .73 505.79 505.75 441.53 1 25 N 89.77 W .37 595.54 595.35 531.13 4 51 S 85.63 W 3.84 685.37 684.71 620.49 6 45 S 85.36 W 2.12 780.02 778.64 714.42 7 20 S 87.65 W .69 .68S 1'.66W 1.63 .52S 3.72W 3.70 .80S 8.63W 8.58 1.52S 17.69W 17.60 2.22S 29.29W 29.15 870.06 867.77 803.55 8 51 S 89.57 W 1.70 963.09 959.34 895.12 11 27 N 89.35 W 2.80 1054.45 1048.42 984.20 14 7 N 89.28 W 2.91 1148.62 1139.23 1075.01 16 31 S 89.81 W 2.56 1238.66 1224.96 1160.74 19 1 S 86.55 W 3.00 2.51S 41.98W 41.81 2.46S 58.39W 58.20 2.21S 78.61W 78.41 2.11S 103.49W 103.26 3.04S 130.95W 130.64 1332.14 1312.37 1248.15 22 27 S 85.76 W 3.67 1423.68 1395.94 1331.72 25 42 S 88.51 W 3.76 1518.36 1481.06 1416.84 26 13 N 89.33 W 1.14 1610.75 1563.25 1499.03 28 6 S 88.08 W 2.39 1704.41 1644.48 1580.26 31 34 S 86.83 W 3.77 5.28S 163.97W 163.52 7.09S 201.25W 200.67 7.38S 242.70W 242.05 7.87S 284.86W 284.14 9.96S 331.41W 330.53 1795.09 1720.94 1656.72 33 26 S 87.64 W 2.11 1887.20 1796.19 1731.97 36 58 S 87.17 W 3.85 1978.73 1868.27 1804.05 39 6 S 89.55 W 2.83 2069.29 1936.84 1872.62 42 27 N 89.95 W 3.71 2162.63 2003.86 1939.64 45 44 S 89.04 W 3.60 12.30S 380.08W 379.03 14.72S 433.12W 431.89 16.30S 489.50W 488.12 16.50S 548.64W 547.18 17.03S 613.57W 612.02 2254.39 2066.18 2001.96 48 41 S 89.35 W 3.22 2344.44 2124.17 2059.95 51 8 N 89.01 W 3.06 2437.00 2179.48 2115.26 55 26 N 89.37 W 4.66 2527.40 2228.28 2164.06 59 12 S 89.96 W 4.22 2617.39 2274.41 2210.19 59 6 N 88.89 W 1.10 17.98S 680.90W 679.22 17.75S 749.79W 748.04 16.71S 823.97W 822.18 16.33S 900.05W 898.18 15.61S 977.30W 975.39 2709.26 2320.44 2256.22 60 45 N 87.56 W 2.18 2802.55 2363.95 2299.73 63 39 N 89.29 W 3.51 2895.46 2402.80 2338.58 66 54 S 89.43 W 3.72 2987.86 2437.90 2373.68 68 26 S 89.49 W 1.68 3080.97 2470.14 2405.92 71 1 N 89.47 W 2.96 13.14S 1056.76W 1054.87 10.89S 1139.24W 1137.36 10.80S 1223.61W 1221.64 ll.60S 1309.08W 1306.96 11.58S 1396.42W 1394.20 ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MPU / MPJ-20 500292283200 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/11/97 DATE OF SURVEY: 120197 MWD SURVEY JOB NUMBER: AKMM80016 KELLY BUSHING ELEV. = 64.22 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3172.57 2496.56 2432.34 75 26 N 88.23 W 4.99 3265.71 2517.82 2453.60 78 10 N 86.30 W 3.56 3357.54 2533.43 2469.21 82 15 N 86.76 W 4.47 3448.81 2545.27 2481.05 82 50 N 85.81 W 1.22 3542.85 2554.88 2490.66 85 25 N 85.38 W 2.79 9.81S 1484.08W 1481.85 5.47S 1574.65W 1572.51 .00S 1664.95W 1662.98 5.86N 1755.26W 1753.46 13.05N 1848.52W 1846.97 3636.18 2565.79 2501.57 81 8 N 85.42 W 4.60 3729.37 2582.46 2518.24 78 15 N 85.73 W 3.12 3821.45 2601.85 2537.63 77 26 N 87.16 W 1.75 3912.36 2620.79 2556.57 78 30 N 88.66 W 1.99 4003.15 2639.06 2574.84 78 16 N 88.24 W .51 20.48N 1940.89W 1939.59 27.55N 2032.30W 2031.23 33.14N 2122.13W 2121.23 36.38N 2210.97W 2210.12 38.78N 2299.87W 2299.03 4095.20 2655.10 2590.88 81 39 N 88.10 W 3.66 4186.80 2668.20 2603.98 81 54 N 88.00 W .30 4280.09 2682.21 2617.99 80 48 N 88.13 W 1.19 4371.89 2698.38 2634.16 78 54 N 87.46 W 2.20 4464.60 2715.59 2651.37 79 41 N 87.16 W .92 41.68N 2390.45W 2389.65 44.76N 2481.06W 2480.30 47.88N 2573.23W 2572.51 51.35N 2663.52W 2662.86 55.63N 2754.51W 2753.96 4559.14 2731.98 2667.76 80 19 N 87.16 W .67 4653.69 2747.98 2683.76 80 11 N 86.62 W .58 4749.28 2764.27 2700.05 80 11 N 85.95 W .69 4842.50 2780.58 2716.36 79 39 N 85.84 W .59 4937.79 2798.27 2734.05 78 56 N 86.04 W .76 60.24N 2847.50W 2847.06 65.30N 2940.55W 2940.25 71.40N 3034.55W 3034.42 77.97N 3126.09W 3126.18 84.60N 3219.49W 3219.79 5033.46 2814.19 2749.97 81 54 N 87.12 W 3.28 5127.93 2827.33 2763.11 82 6 N 86.81 W .39 5223.23 2841.13 2776.91 81 13 N 86.74 W .93 5319.26 2855.80 2791.58 81 11 N 86.78 W .05 5411.33 2869.72 2805.50 81 24 N 86.24 W .62 90.22N 3313.64W 3314.11 95.17N 3407.06W 3407.66 100.48N 3501.21W 3501.95 105.84N 3595.96W 3596.85 111.38N 3686.80W 3687.85 5506.52 2883.73 2819.51 81 40 N 86.15 W .31 5601.77 2897.58 2833.36 81 35 N 85.95 W .22 5696.28 2911.20 2846.98 81 49 N 86.42 W .54 5793.53 2924.92 2860.70 81 57 N 86.12 W .34 5890.04 2938.47 2874.25 81 54 N 85.81 W .32 117.63N 3780.75W 3781.99 124.12N 3874.76W 3876.21 130.34N 3968.07W 3969.71 136.61N 4064.15W 4065.98 143.33N 4159.46W 4161.51 5986.03 2952.10 2887.88 81 46 N 85.58 W .27 6080.39 2965.20 2900.98 82 15 N 85.24 W .61 6175.57 2980.35 2916.13 79 26 N 87.31 W 3.65 6270.26 2999.75 2935.53 76 54 N 87.64 W 2.69 6365.71 3024.14 2959.92 73 28 N 88.61 W 3.74 150.46N 4254.21W 4256.49 157.94N 4347.36W 4349.89 164.05N 4441.11W 4443.83 168.14N 4533.68W 4536.49 171.16N 4625.89W 4628.74 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MPU / MPJ-20 500292283200 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/11/97 DATE OF SURVEY: 120197 MWD SURVEY JOB NUMBER: AKMM80016 KELLY BUSHING ELEV. = 64.22 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6461.14 3054.00 2989.78 70 3 N 88.94 W 3.59 6556.61 3089.23 3025.01 66 37 S 89.75 W 3.82 6650.95 3129.55 3065.33 62 46 S 89.72 W 4.08 6746.55 3175.97 3111.75 59 7 S 87.85 W 4.17 6842.11 3227.20 3162.98 56 1 N 89.40 W 4.05 173.10N 4716.50W 4719.33 173.74N 4805.21W 4807.97 173.35N 4890.48W 4893.12 171.60N 4974.01W 4976.47 170.47N 5054.65W 5056.96 6939.35 3284.16 3219.94 52 14 N 89.82 W 3.91 7034.52 3344.61 3280.39 48 52 S 88.65 W 3.74 7130.21 3409.96 3345.74 44 57 S 89.33 W 4.13 7225.25 3479.87 3415.65 40 16 S 89.91 W 4.94 7320.40 3554.26 3490.04 36 50 N 89.19 W 3.65 171.02N 5133.44W 5135.68 170.29N 5206.92W 5209.03 169.05N 5276.78W 5278.76 168.60N 5341.12W 5343.00 168.96N 5400.42W 5402.25 7415.41 3631.97 3567.75 33 22 N 88.57 W 3.67 7511.46 3712.25 3648.03 33 12 N 86.72 W 1.07 7604.91 3790.51 3726.29 33 3 N 87.26 W .35 7699.29 3869.75 3805.53 32 44 N 87.13 W .35 7794.61 3950.06 3885.84 32 26 N 87.96 W .56 170.01N 5455.06W 5456.87 172.18N 5507.73W 5509.58 174.86N 5558.74W 5560.67 177.37N 5609.95W 5611.93 179.57N 5661.24W 5663.27 7892.13 4032.43 3968.21 32 17 N 88.24 W .22 7987.98 4113.57 4049.35 32 2 N 88.11 W .27 8027.59 4147.15 4082.93 32 1 N 87.83 W .38 8085.00 4195.82 4131.60 32 1 N 87.83 W .03 181.30N 5713.41W 5715.47 182.93N 5764.41W 5766.49 183.67N 5785.41W 5787.49 184.82N 5815.84W 5817.94 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5818.77 FEET AT NORTH 88 DEG. 10 MIN. WEST AT MD = 8085 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 272.79 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 8,085.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MPU / MPJ-20 500292283200 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/11/97 DATE OF SURVEY: 120197 JOB NUMBER: AKMM80016 KELLY BUSHING ELEV. = 64.22 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 MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -64.22 1000.00 995.44 931.22 2000.00 1884.68 1820.46 3000.00 2442.33 2378.11 4000.00 2638.42 2574.20 .00 N .00 E .00 2.37 S 66.06 W 4.56 4.56 16.40 S 503.02 W 115.32 110.76 11.69 S 1320.38 W 557.67 442.36 38.69 N 2296.79 W 1361.58 803.90 5000.00 2809.17 2744.95 6000.00 2954.09 2889.87 7000.00 3322.19 3257.97 8000.00 4123.76 4059.54 8085.00 4195.82 4131.60 88.45 N 3280.61 W 2190.83 829.25 151.53 N 4268.00 W 3045.91 855.08 170.78 N 5180.68 W 3677.81 631.91 183.14 N 5770.79 W 3876.24 198.43 184.82 N 5815.84 W 3889.18 12.94 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA. PAGE 5 SHARED SERVICES DRILLING MPU / MPJ-20 500292283200 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/11/97 DATE OF SURVEY: 120197 JOB NUMBER: AKMM80016 KELLY BUSHING ELEV. = 64.22 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 -64.22 64.22 64.22 .00 164.22 164.22 100.00 264.22 264.22 200.00 364.23' 364.22 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .16 S .01 E .00 .00 .76 S .04 E .00 .00 .83 S .75 W .01 .00 464.25 464.22 400.00 564.32 564.22 500.00 664.74 664.22 600.00 765.48 764.22 700.00 866.46 864.22 800.00 .52 S 2.70 W .03 .02 .64 S 6.34 W .10 .08 1.32 S 15.27 W .52 .42 2.14 S 27.44 W 1.26 .74 2.50 S 41.44 W 2.24 .99 968.08 964.22 900.00 1070.74 1064.22 1000.00 1174.74 1164.22 1100.00 1280.38 1264.22 1200.00 1388.67 1364.22 1300.00 2.45 S 59.41 W 2.16 S 82.59 W 2.22 S 111.09 W 3.94 S 145.05 W 6.57 S 186.45 W 3.86 1.61 6.52 2.66 10.52 4.01 16.16 5.64 24.45 8.29 1499.58 1464.22 1400.00 1611.86 1564.22 1500.00 1727.58 1664.22 1600.00 1847.60 1764.22 1700.00 1973.53 1864.22 1800.00 7.47 S 234.40 W 7.89 S 285.39 W 10.63 S 343.52 W 13.60 S 409.77 W 16.26 S 486.23 W 35.36 10.91 47.64 12.27 63.36 15.72 83.38 20.02 109.31 25.93 2106.83 1964.22 1900.00 2251.45 2064.22 2000.00 2410.56 2164.22 2100.00 2597.54 2264.22 2200.00 2803.20 2364.22 2300.00 16.58 S 574.31 W 17.95 S 678.71 W 16.97 S 802.38 W 15.94 S 960.27 W 10.89 S 1139.83 W 142.61 33.30 187.23 44.62 246.34 59.11 333.32 86.98 438.98 105.66 3063.02 2464.22 2400.00 3625.50 2564.22 2500.00 4158.54 2664.22 2600.00 4749.01 2764.22 2700.00 5374.55 2864.22 2800.00 11.70 S 1379.47 W 19.64 N 1930.36 W 43.79 N 2453.10 W 71.38 N 3034.28 W 109.01 N 3650.51 W 598.80 159.82 1061.28 462.48 1494.32 433.04 1984.79 490.47 2510.33 525.54 6073.10 2964.22 2900.00 6490.29 3064.22 3000.00 6723.33 3164.22 3100.00 6906.27 3264.22 3200.00 7063.96 3364.22 3300.00 157.34 N 4340.16 W 173.50 N 4743.79 W 172.26 N 4953.99 W 170.90 N 5107.04 W 169.81 N 5228.87 W 3108.88 598.55 3426.07 317.19 3559.11 133.04 3642.05 82.94 3699.74 57.69 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 SHARED SERVICES DRILLING MPU / MPJ-20 500292283200 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/11/97 DATE OF SURVEY: 120197 JOB NUMBER: AKMM80016 KELLY BUSHING ELEV. = 64.22 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 7204.55 3464.22 3400.00 7332.79 3564.22 3500.00 7454.03 3664.22 3600.00 7573.55 3764.22 3700.00 7692.72 3864.22 3800.00 168.64 N 5327.57 W 3740.33 40.59 169.07 N 5407.79 W 3768.57 28.24 170.54 N 5476.30 W 3789.81 21.25 174.04 N 5541.65 W 3809.33 19.51 177.19 N 5606.40 W 3828.50 19.17 7811.39 3964.22 3900.00 7929.73 4064.22 4000.00 8047.73 4164.22 4100.00 8080.00 4191.58 4127.36 179.89 N 5670.23 W 3847.17 18.67 181.92 N 5733.49 W 3865.51 18.35 184.08 N 5796.08 W 3883.51 17.99 184.72 N 5813.19 W 3888.42 4.91 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS m F:! I I_1_1 f~ G SEI:I~ICE S WELI~ LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor ,/ 3001 Porcupine Dr. '-~.. k c_~ Anchorage, Alaska 99501 0-~V~ ,~ ~._~ · MWD Formation Evaluation Logs - MPJ-20, AK-MM-80016 August 26, 1998 MPJ-20: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22832-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22832-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE A~'FACHED COPIES OF THE TRANSMITFAL LETFER TO THE ATYENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVE Date: Slgned~ AUG 26 1998 Alagkj Oil & Gas Cons. Commission Ar~orage ..... 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPJ-20, AK-MM-80016 August 19, 1998 1 LDWG formatted LIS tape with verification listing. API#: 50-029-22832-00 PLF~ASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THF~ ATYACHED COPIES OF THF~ TRANSM1TYAL LETTER TO THE ATYENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchor~lm .~., ~i!~ BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date4.' ~ '," . ,~;.:~s. ~mm~ss~c.8,igned: 5631 Silverado Way1 Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. 8/12/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11424 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 MIIne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPG-13 ~ ~.~l~_... 98396 SBT (PDC) 980603 1 MPJ-20 .,,,r ..~/'...,}-2~ 98401 GR/CCL (PDC) 980703 1 , , 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: RECEIVED AUG 2 0 1998 Alas~ Oil & Gas Cons.. Commission Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 08-Jul-98 Transmittal of Final Prints. Please sign and return copy to the following: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 and BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Well Name MPJ-20 Services Bluelines R/F Sepia Film GR/CCL PERF, PACKER I 1 MPJ-20 MARKED LINE GR 1 1 Received by: \ Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 17. 1997 Chip Alvord Senior Drilling Enginccr BP Exploration (Alaska). Inc. POBox 196612 Anchorage, AK 99519-6612 Rez Milne Point Unit MPJ-20 BP Exploration (Alaska). Inc. Permit No 97-215 Sur. Loc.: 2207'NSL. 3288'WEL. SEC. 28. T13N. R10E. UM Btmholc Loc: 2404'NSL. 3837'WEL. SEC.29. T13N. RIOE. UM Dear Mr. Alvord' Enclosed is the approved application for permit to drill thc above rcfcrcnccd wcll. Thc pcrmit to drill docs not exempt you from obtaining additional permits rcquircd by lax,,' from other governmental agcncics, and docs not authorize conducting drilling opcrations until all other required permitting determinations arc made. Blov,'out prevention cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25.035. Sufficicnt notice (approximately 24 hours) of thc BOPE test pcrformcd before drilling below the surf'acc casing shoc must bc given so that a representative of the Commission may witness thc test. Notice may bc given by contacting thc Commission pctrolcum ficld inspcctor on thc North Slope pager at 659-3607. Robert N. Christcnson. P.E. Commissioner BY ORDER OF THE COMMISSION dlf, ench~sures l)eparlmcnt o1' Fish & Game. l labitat Section w..'(~ encl. l)¢panmcnt of l';m'iromncnt Conservation w,o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork I~Drill DRedrill Ilb. Typeofwell •Exploratory [-I Stratigraphic Test I~ Development Oil [] Re-Entry F'] DeepenI [] 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 KBE = 64.6' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4. Location of well at surface :7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2207' NSL, 3288' WEL, SEC. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2390' NSL, 3542' WEL, SEC. 29, T13N, R10E, UM MPJ-20 At total depth 9. Approximate spud date Amount $200,000.00 2404' NSL, 3837' WEL, SEC. 29, T13N, R10E, UM 11/18/97 12. Distance to nearest property line~ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515, 2876'I No Close Approach 2555 8074' MD / 4180' TV• 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 80.71 o Maximum surface 1284 psig, At total depth (TVD) 3694' / 1653 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stagedata) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' ;)50 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 8043' 31' 31' 8074' 4180' 911 sx PF 'E', 132 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 MD TVD Structural Conductor Surface Intermediate.._ , / ' .~.~, ~ '.::?i ".;' ~ Production '~ ': ~---~ Liner ~ :- '':' "" ' .' ,: . ,, ,- ,-,.L-'%')';"';~ Perforation depth: measured ¥~,~.'.:'.?'.":'"" :'" true vertical , i'i'-?', 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: James Robertson, 564-5159 Prepared By Name/Number: Kathy Carnpoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipNvord ~ ~ ~ Title Senior Drilling Engineer Date 'lj~lz-/)-7- Commission Use Only Permit Number APl Number IAp@r~0vakDate \¥',~ ~,0¥-~ Isee c°ver letter ~.~-- ~./'~, ~' 50- 4::> ~_. ~'- ~ 2_ (~.~.2. '~ for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes []No Hydrogen Sulfide Measures DYes ~ No Directional Survey Required I~]Yes D No Required Working Pressure for BOPE [~M; []3M; •5M; •10M; []15M Other: ORIGINAL SIGNED. BY by order of Approved By ,obert N, Chdstenson Commissioner the commission Date [~, Form 10-401 Rev. 12-01-85 Submit lr~Trinticat~ Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): James E. Robertson IMP J-20 Well Plan Summary ISCHRADER BLUFF PRODUCER 564-5159 Surface Location: 2207 FSL, 3288 FEL, S28 T13N R10E UM Target Location: 2390 FSL, 3542 FEL, S29 T13N R10E UM Bottom Hole Location: 2404 FSL, 3837 FEL, S29 T13N R10E UM I AFE Number: I 337100 Estimated Start Date: I 18 Nov 97 I IMD: 18074' I ITv°: I Well Design: Formation Markers: Rig: I Nabors 22E I Operating days to complete: 14180' I 18.0 IKBE: 164-6ft Schrader Bluff Producer Formation Tops MD TVDSS KOP 300 300 Base of Permafrost 1946 1775 Top of Ugnu 6893 3198 Top M Sand 7235 3432 Top NA (Target) 7559 3694 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 7595 3723 NCND 7636 3757 NE 7659 3776 NF 7718 3824 OA 7764 3862 OA4 7804 3895 OB 7845 3928 Top of Seabee 7874 3952 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 8074 4115 TD at 200' MD past base of Schrader Casing/Tut ing Program: Hole ,~ize -Csg/ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 8-1/2" 7" 26# L80 BTC-MOD 8043' 31'/31' 8074'/4180' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +3694' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1653 psi (8.60 ppg EMW), is 1284 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: MWD from surface to TD LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. Cased Hole Logs: NONE Mudloggers are NOT required for this well. Mud Program: Spud Mud ISpecial design considerations See "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 150 15 8 10 9 10-15 (initial) to to to to to to to 10.2 80 35 15 30 10 8-10 (final) Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.8 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter. Line. 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 pressu.re~...~ Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 1300'MD IMaximum Hole Angle: Close Approach Well: 80.71° NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on J-Pad have been permitted for annular injection. MP J-20 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 8074' MD/4180' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/ROP from the top of the Ugnu to TD. NOTE: Fill hole with mud and check diverter for leaks before spudding in. NOTE: Short trip no deeper than 300' md past the base of permafrost. NOTE: Utilize lubricants as necessary to enhance sliding performance. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer at 2200' md (set at least 200' MD below the permafrost). 9. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. Note that MP J-20 will have 2-7/8" tubing. RDMO- Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point I-Pad Data Sheet prepared by Pete Van Dusen for information on J 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: NO HYDRATES HAVE BEEN ENCOUNTERED ON ANY WELLS DRILLED AT MILNE POINT 'J' PAD TO DATE. If hydrates are encountered 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 MP J-20. 3. Lost Circulation: 7 Schrader Bluff wells have been drilled on Milne Point 'J' pad since 1990 and none of them experienced any problems associated with lost circulation. In an effort to continue this trend maintain slow, steady running speeds while running casing and ensure mud is in good shape before POOH to run casing. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have been associated with the ddlling of Schrader Bluff wells on Milne Point 'J' Pad to date. Some tight hole on trips has been encountered in the 2000' 'I'VD to 3500' TVD range. Once tripped through the tight hole problems went away. The wells on Milne Point 'H' Pad drilled during the summer of 1997 encountered severe tight hole problems; especially swabbing problems while POOH. We will also break circulation at the first indication of swabbing on short trips. If heavy gravels are encountered while drilling the surface hole section, 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. 6. Directional Drillinq Concerns Care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 7. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. A 'C' cement for the second stage tail cement will be incorporated into the cementing program only if hydrates are encountered. MP J-20 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL water STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 397 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 6735' MD TO THE ES CEMENTER STAGE TOOL (2200' MD · 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) ;WEIGHT: i APPROX #SACKS: FLUID LOSS: 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 132 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F TAIL CEMENT FROM TD (8074' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (7235' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 6735' MD SPACER: 50 BBL water STAGE2 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk 514 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM ES CEMENTER TOOL AT 2200' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST Retarder 15.6 ppg 000 SACKS YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8' x 8-1/4' Rigid Straight Blade Centralizers - one (1) per joint on the bottom thirty-one (31) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (31+2 = 33 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: , Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also 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 8.0-10.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with water a volume equal to the capacity of the 7" casing from TD up to the ES Cementer at 2200' md followed by mud at TD mudweight. 2. After bumping the plug, quickly check to ensure that the floats aro holding and then shear the ES cementer to the open position. 3. Circulate mud through the ES cementer for a minimum of two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for rouse on another well. ' ~madrlll SchLumberger Alaska District lilt Hast 8a~h Avenue Anchorage, AK 995t8 (907) ~49-4511 PAx'344'2160 DIRHCTIO~AL ~HLL P/_A~ ~o: SHARHD EHRYZCgS Well ......... : HPJ-20 (P6) FLeld ........ = Milne Point ComputatLon..: Minimum Curvature Unite ........ : PHHT Surface ~ak..: 70.45064200 N gurface bong.: 149.57547081 W begal.Descrlption Surface ...... : 2207 PSL 3288 PHL .828 T13N R10E UM Tar~e~ ....... :'2390 PS~ ~542 ~EL 829 TI3N RLOEUM B/il .......... = 2404 FSL 3837 ~Eb 829 T13N R10R UM LOCAT£O~S ~ ALASKA ~one: 4 X-Coord Y-Coord 552033.2t 6014605.30 ~464~8.00 6014~52.O0 ~46202.90 6014~64.'00 PROPOSED ~BbL PROFZLH STATION MHA~URED 1DHNT~P~CAT£ON DBPTH KB 0.00 r, OP/BUXhD L/tOO 300.00 gUI~D 1.S/X00 400.00 S00.0a BUll. a) 2/100 600.00 m~mm~m /~CbN 0.00 1.00 2.$0 4.00 ~mam~ = mme=.a=mm ~ al DIRRC~EON V'ERTICRL-DRPTHS AZIHUT.H TVD IUB-SSA 0.00 0.00 ~64.60 268.00 300.00 235.40 268.O0 399.99 335.39 26~.00 499.95 435.35 ,26&.00 S99.78 535.18 Prepared ..... , L2 Nov 1997 Vert ~ect az.: 272.68 KB elevation.: 64.60 Magnetic Dclo: +27.847 ~ca~e ~actor.: 0,9999~308 Convergence.,: .0,4000~742 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY C00RDIHAT~S-FROM AbASKA ~one 4 WEnhHllAD X Y ! ~ ~ mm e 0..00 N O.OO R 0.00 N 0.00 E 0.03 B 0.87 W 552032.34 6014605.26 92b 1.00 0.14 S 3.92 W 552029.29 6014605.14 92b 1.50 0.33 ~ 9.59 W 552023.62 6014604.90 92h L.50 2.5/100 700.00 6.00 800.00 0.OO 900.00 L0'.00 1000.00 12;50 1300.00 15.00 268.00 699.40 634,80 268.00 798.65 734.05 '268.O0 897.41 832.81 268.00 995.48 930.88. 268.00 1092.6L 1028.01 L8,25 30:40 45.99 65.43 89.12 0.64 S L8.30 W 552014.92 6014604.53 HS 2.00 L.06 S 30.48 W 552002.74 60L4604.02 HS 2.00 1.6L $ 46.11 N 551987.L2 60~4603.37 tls 2.00 2.29 S 65.61 W '~967.63 6014602.55 HS 2.~0 3.[2 ~ 89.36 W S5L943.88 60t460L.56 H8 2.50 BUIhD 3/L00 1200,00 17.50 ~)oo.oo 20.50 268,00 LL86,60 1124.00 Lt. 7.00 268.00 1~63.L5 3218.55 149.45 4.10 S t£q.32 N 5.63915.93 60-14600.38 HS 2.50 5.23 S 149:06 . 55L88~.4i 6014599.02 l*[g 3.00 t~PJ-20 (~6) STATION BAST PSRMAPROST eu~w 3/zoo ZZND 3/100 CURVE DROP 4/100 m~:~mm~:~ MEASURSD DEPTH m~m m ~: :~ mm m ~: 1400.00 1~00.00 ~600.00 ~?00.00 ~800. O0 P~%OP08ED WELL P~0PILH INCI~ D~REC?£ON VERTICAL-DEPTHB SECTION AI~3LH AZ£MOTH TVD SUB-SHA DEPART 23.50 268.00 1375.85 131Z.25 186.78 26.50 268.00 1466.47 1401.09 228,90 29.S0 268,00 1554.96 1490,16 295.68 32.S0 268.a0 1640.47 1575,8~ 327.01 35.50 268.00 '1723.36 ~658.76 382.74 12 ~OV 1997 Page 2 OOORD~NAT~-PRO~ ALABKA Zone 4 TOOb Db/ WHL~H~.kD X Y PACH L00 6.54 ~ ~87.29 ~ 5~8&$.99 6014597.4S ~ 3.00 8.02 S 229.52 W 551803.77 6014595.68 HS 3.00 9.65 a 276.43 ~ 551756.88 6014593.72 HS 3.00 l£.45 S 327.90 W 551705.43 60~4591.56 H~ 3.00 13.40 S 383.78 ~ ~5~649.~? 6014589.22 HS 3.00 1900.00 38.50 268.00 1803.21 1738.~Z. 442.91 15.50 1921.O3 ~9.33 268.'00 1819.60 1755.00 455.85 15.96 1946.81 39.~3 268.00 1839.60 1775.00 472.07 16.53 1972.60 39.13 268.00 1859.60 L795.00 488.28 17.10 2000,00 39.95 268.~6 1880.73 18£6.13 S05.67 17.68 42.93 268.68 1955.69 %89~.09 571.66 L9.50 g 573.20 45..91 269.16 2027.21 1962;5l. 641.49 20.81 B 643.~6 48.89 269.58 2094.79 2030.19 714.97 21.61 S ~16.76 ~1.88 269.97 2158.55 2093.9~ 793.90 2~.90 S 793.98 54.86 270.33 2218.21 2L53.6~ 892.06 21.68 S 874.03 2~00.00 '2200.00 2300.00 2400.00 2500.00 57.85 270.69 2273.60 2209:00 955.24 20.95 S 957.26 60.84 270.98 2324.59 2259.99 k041.21 L9.71 S 1043.2~ 63.83 27~.28 2371.02 2306.42 1129.73 17.96 B l'131.81 6'6.82 271.56 2412.76 2348.16 1220.57 15.7~ 8 1222.63 69.8[ 273.82 2449.72 2385.12 13Z'3.46 12.97 ~ 13L5.~0 26oo,aa 2700.00 2800.00 2900.00 3000.00 443.92 H S51589.45 6014686.q0 457.09 W 551576.29 6014586,15 H8 3.00 473.35 ~ 55L560.'03 6014585.47 HS 0.00 489.61 ~ 551543.97 6014584.79 ~R 0.00 507.0~ .W 551526.34 60L4584.08 9R 3.00 ~. S51460..22 6034S8~.80 6R 3.00 W 551390.27 6014580.01 6R 3.00 ~ 551336.69 6014578.69 6R 3.00 ~ 551239'.67 6014577.86 6R 3;00 W 551159.44 6014577.52 5R 3.'D0 '~ 55k076.21 60145?7.67 SR 3.00 W 550990.21 6Ol4~78.3l 5R 3.00 ~ ~50901.67 6014579.44 ~R 3.00 # $50810.83 6014581.05 SR 3.00 W ~50717.96 6014583.£4 ~R 3.00 3100.00 72.80 272;08 2481.77 2417.17 3408,17 9,~4 9 1410.16 W 550623.29 6014585.71 5R 3.00 3200.00 75.79 272.33 2508.05 2444.25 1504.42 6.04 S 1506.34 W 550527.09 6014588.75 5R 3,00 3300.00 78.78 272.57 2530.86 2466,26 160L.95 1;86'S 1603.79 W 550429,63 6014592.24 5R 3.00 3364.70 fl0.71 272.73. 2542.38 247~.98 1665,61 3.08 N 1667.38 ~ 550366.03 6014594.74 HB 3.00 6216.83 80.71 272.73 3002.75 2938.15 4480.35 135.06 N 4478.93 W 547553.89 60L4705.07 I.,5 0.00 NB 3. O0 _ CS3 I I -) 6300.00 77.38 272.?~ 3018.54 2953.94 .4561.99 138,94 N 4'560.47 # 547472.32 60Z4712.39 hg 4.00 6400.00 73.38 272.7J 3043.'77 2979.£7 4658.73 143.55 N 46S7.1k W S47375.67 60£47~6.32 L~ 4,00 6500.00 69.38 272,73 3075.69 3011.09 4753.48 148.06 N 4751.75 W 547281.00 601~720.]7 LB 4.00 'O (AnadrllL (C) 97.M~O20r06 3.2b.2 7=0~ AM P) .__i .................................................................................................................. jED 8TAT I ON I D~NI ! FI CJ[T ION 'FOP UGNU TOP M SANDS ~ 4/100 DROP TARORT TOP SCHRADER / NA ' NCND N~ OA OA4 OB MF. ASURF_,D INCLR 66oo.0o 6s.30 6700.00 6t.38 6B00.00 57.38 6893.21 53.66 6900.00 53.38 7000.00 49.38 7100,00 45.38 7200.00 41;38 7235.88 39..95 7300,00 37~38 7359.6~ 35.00 7559~61 35,00 7559,6Z 35.00 7595.02 35..00 ~636.52 35.00 7659.72 35.00 77'18.32 35,a0 7764,90 35.00 7804.99 35,*00 7845.28 3'5.G0 BA,S~ $~HR 7874.57 35.00 TO / 7" CASI~ DO~I' 8074.57 35,00 PROPOSED ~HLL PROFILE .GRCTION DEPART 4845.77 4935.16 ~02~.20 ~098.02 DIRECTION VHRT~CAL-DHL>THS AZ~MUTH '/'VD SUB-SEA 272.73 3tL4.13 3049.53 272.73 3158.92 3094.32 · 292,73 1208,84 3145.24 292.73 3262.60 $198.00 272.73 3266;64 3202.04 ' S£03,48 · .272.73 332~.03 3264.43 ·5181.60 '272.73' 3396,73 3332.L3 '",5255,L8 272.73 3469,39 ~404~79 ":'::5323.85' 2~2.73 3496.60 3432,00 -5347.23 272,'~3 3546.66 3482.06 ~3~7.29 '272,73 3594.7~ 3~30.19 5422.49 272.93 375'8.60 3694.00 ";'-~537.21 272.73 3758.60 3~9~.O0' ".272.73 3787.60 3723,00 5559,51 '292.73' 3821.60 3759.00 558t.32 32 Nov 1997 Pa~e 3 CO0~.DZ~AT~S-~ROM A~ASKA Zone ( TOOL DL/ WEGLHHAD X Y FACE LO0 ~mm:xm~mm ~mm==mtu mm ~ ~m:qmm~ mb:m~s=m:~ m:mm m~:m kS~.~ ~ 4~43,~4 ~ 5471BS.BO ~0~4~3.9~ ~8 4.00 160.B0 ~ 50£9.~? ~ 54~0£3.~3 6014731.04 L~ 4.00 ~64.4~ ~ 5095.90 ~ 5~6936.78 ~0~4734.~6 L8 4.00 L68.44 N ~179.39 W 546853.28 6014737.56 LS 4.00 17L.94 N 5252.88 W 546779.77 60£4740.54 LS 4.00 ~75.21 N ~321.48 W 546711.16 60147~3.33 L~ 4.00 L76.32 N 5344.83 W 546689.80 60~4944.28 LS 4.00 ~78.23 N 5~84.84 ~ 546647.78 60£4745.91 ~S 4.00 £79.90 N 5420.00 W 546612,61 6014747.34 ~ 4.00 185&36 N 5534,59 W 546498.00 60L4752,00 HS 0.00 ~85.36 N 5554.59 ~ 546498.O0 6014752.00 NS 0.00 £86.33 ~ 5554,87 W 546477.71 6034752.82 KS O.O0 187.~6 R 5578,65 ~ 5464~.93 60L4753.79 HS 0.GO 292.73 3840.60 3776,00 5594.62 198.10 N 559L,94 272,73 3888.60 3824'.00 5628.23 189.70 N 5625.51 272.73 3926.60 3862,O0 S654.84 190.96 N 5652.09 272.73 3959.60 3895.00 5677.95 292.06 N 567~.L7 272.73 3992.60 3928,00 570~.06 ~93.36 N 5698.25 272.73 4016.60 3952,00 5917.86 272.73 4L80.43 4~15.83' 5832,58 546440.64 6014754,33 ~ 0.O0 546407.06 6OL4755.70 HS 0.00 5~6380.47 6014756.78 H8 0.00 546~57.39 60~4757o72 HS 0.00 546334.30 6OL4758.66 H~ 0o00 193.96 ~ 5715.04 W 5463L7,51 6014759,34 L99,42 N 5829.62 N 546202.90 6014964.00 HS 0. O0 0.00 Z ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN #' .6 (AnadrLL1 (c]'97 M~J20P06 3,2b.2 7:07 AN P) ................. '-: ......................................................................................................... ..... ~ ................. .--- ~ ...............................~ ......-~ ....................~ ..............................~ -.~ 3~ C) .m ......... ix ' iii SHARED 'SERVICES DRILLING ii i Al ~B c) D) El FI 6) H) I) J) K) LI H) ilmm mm .MD I]KB SECTN INCLN 0 0 0 0.00 KOP/BUILO t/t00 300 300 -0 0.00 BUILO 1.5/100' 400 400 1 1.00 BUILD 2/100 600 600 lO 4.00 BUILD 2.5/100 900 897 46 10.00 BUILD 3/100 1200 llBg ~t7 17.50 END 3/100 BUILD 1921 lB20 456 39.13 CURVE 3/100 lg73 lB60 4BB 3g.13 EhID 3/100 CURVE 3365 2?-J42 tBBB 80.71 D~P 4/100 6217 3003 4480 80,71 Em 4/100 I)l:10P 73~ 3595 5422 35.00 IARGET 7560 3759 5537 35.00 TO / 7' CASING POINI 8075 4190 5833 35.00 :2' ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN '~ ~, ;" 4nadrill Schlumberger,, MPJ-20 (PB) VERTICAL SECTION VIEW ion at: 272.68 ITVD Sca]e.:! ~nch 1000 feet ~Dep Scale.: '! inch ~000 feet u , ;uu il;~;~, iL,,J~ ;5.1~b,' ~b00, 300~ 354~ 4wu. 4~)uu bOOO 55110 6000 ~00 7000 7500 8000 6500 , section Departur,,e ,,,. , ilm' i ' ' (cl 06 3.2~.~. 1:5~ P# P) , , ' ' ' ' ,, , ,, , , . Z "O m 11/12/1997 88:13 907-344-'"60 ANADRILL SHARI~ D SERVICES OR'ILLIN6 PAGE i. '~-- i MVd-~O. ! VERTICAL SECTTON VTEW i "- -~isection at:: 272.68 ~ ITVD scale,; !~inCh = ~00 ,o- . , JDep Scale.: .1 .inch = 100 feet " o-- ~ . /nadPi]l SchJu~benger-..~ 0-- , - Marker Ia'entJfi. cation MD BKB SECTN INCL~ A) E~ 4/100 DROP 7360 3595 5422 35.00 81 TAR6ET' '- .-7560 3759 5537 35..0~ C) 1~ / 7' C~SIN~ POINr .8075. . '4t80 5833 35,0~ . . i m. ,,, .~.~ ................... . I. " I - .. )-~ · ' · ' ~_~-~ - H'.. . . --'- . . . - ~ . ' : : '.' ~.' .:. ~ - ~ . - . ~ ,.~ · . ' ' ~ .'I ': . ' - : . .. ' " I- -~: ' - ''~" ANiAD~ILL A~ ,DpC .- .' APPFLOVED ~,, -- . ' : FO~',PEFM':'IT1 i~i '.' . - -- - ---.~-~ " · . , . ~ . . g~c~ . .. ,- ~.. .-. ....-. .. : ~. . . . . . . - ~ _ ~ . ., '-:~ =- .... ~-: ~ ~ :' -... . . . . : . . .. ... . . . . · . . . . . 5aO0 5450 5500 5550 5600 5650 5700 - 5750 5800 SB50' 5gO0 5950 6000 6050 I~ tOO Section Departure '~ (*nadrill (c]97 ~dL~oO~ ~.~.8 ~:56 ~ P) I lira SHARED SERVI.CES DRTLLIN6 ii 14arker [denti fication HD N/S E/W A] KB 0 '0 N 0 E B) XOP/BUILD t/tO0 300 0 N 0 E C] BUILO t.5/tO0 400 0 S t D) BUILD 2/tO0 600 0 S 10 N E) BUILD 2.5/100 900 2 S 46 N F) BUILD 3/tO0 1200 4 S 1i7 W GJ END 3/tO0 BUILD t92~ I6 S 457 W HJ CURVE 3/100 t973 t7 S 490 W [) END 3/i00 C~VE 3365 ~ N i667 J) DROP 4/t00 62J7 i35 Id 4479 K) END 4/tOO OROP 7360 ~80 N 5420 L) lARGE1 7560 185 N 5535 M 14) TD / 7' CASING POINT 8075 ~99 N 5830 N ANADRILL AKA-DPC A?PP, OVED 'FOR PERMITTING ON PLAN -- m im mi Anadri Y] $ch]umber#£r · mm f4PJ-20 (P6) PLAN VIEW. CLOSURE · 5833 feet at Azimuth 27~.96 DECLINATION.' +27,847 [E) SCALE ' I ~nch = 800 feet DRAWN · ~0 Nov 1997 ;;.,,.:; c.'...r,,;',; 'b;,-'gU "4iJUO' .' 440~' J~Ug '..l~UUU ~400 1(500 800 ~ , .., iii i · . , '. ', ,' ." ' .... .,. . , , ......... q · ] ' . , . . , . . , . , . , . , 400 ..0 40~'" j ,, <- ~EsI' EAST-> i i . mllm I I I I III ,. 3> '7' ~ MON d-1 NORTH ,600 + 600 4- · J-O1 · J-11 · J-02 · J-08 · J-03 · J-lO · J-04 ~ J-16 +J-17 -~ J-19 -~ J-20 · ,I-06 · J-12 · J-09 · J-13. · J-05 · J-14 · J-07 ~ MON J-2 SOUTH MPU J-PAD NOTES 1. DATE OF SURVEY: SEPTEMBER 26, 1995. 2. REFERENCE FIELD BOOK: MP95-19 (pgs. 52-36). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 4. GEODETIC COORDINATES ARE NAD 1927. 5. PAD SCALE FACTOR IS 0.9999031. 6. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS J-1 AND J-2. 7. ELEVATIONS ARE BASED ON MILNE 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 SEPTEMBER 26, 1995. LEGEND AS-BUILT CONDUCIOR · EXISTING WELL LOCATED WITHIN PROTRACTED SECTION 28, T. 13 N., R. 10 E., UMIAT MERIDIAN ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSiTION(D.DD) BOX ELEV. OFFSETS ,Y: 6,014,714.85 N: 970.08 70-27'05.592" 70.4509422' ~2,317' FSL J-16 X= 551,98¢.5~, E= 1~024.83 149'34~53.101' 149.5758614' 35.2' '3,336' FEL Y=6,014,687.85 N= 940.54 70"27'05.125' 70.4508681' - 2,290' FSI. J-17 X: 551,996.51 E= 1,024.92 149'34'32.756" 149.5757655' 35.2' 3,324' FELi Y=6,014,632.23 N= 880.00 70-27'02.577" 70.4507158' 2,234' FSI.: J-19 X= 552,020.4,5 E,=.lf024.54 149'34'32.064" 149.5755733' 35.O' 5,301' FEL Y=6,014,605.30 N= 850.20 70'27'02.511" 70.4506419' 2,207' FSI. J-20~ X,= 552,053.21 E,= 1~025.43 149'34'31.695"1 149.5754708' 55.1' . . 3,288' FEL BARNHART CH£CK~O: F~RAUOO ~o l~ los ~^'~C: MPU-J-A~ JOG NO: 1'=200' EXPLORATION MILNE POINT UNIT J PAD CONDUCTOR AS-BUILT WELLS J-16, J-17, J-19 & J-20 lSHEE'I':I O¢ 1 Hi283G3 · DATE lO0197 PYMT HANDL INVOICE / CREDIT MEMO CKIOOlg7H ;OMMENTS' INO INST' pe~ s/h ,ru= a~-rA~,u~n ~w~_~ I~ I~1 PAYMENT FOR ITEMS DESCRIBED ABOVE. DESCRIPTION ~it to d~ill Kath§ Campoa GROSS 100. O0 application mot, x5122 DATE CHECK NO. 00128363 VENDOR Al ASKANT 14 OD NET 100.00 DISCOUNT · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~'.~.~ ? ~"¢_.3 INIT CLASS ~ i v WELL NAME ../~p /~'"'"..2-.-('~ PROGRAM: exp [] dev~redrll [] serv [] wellbore seg E; ann. disposal para req D .//-,..-~..,."/ GEOL AREA ~>"~,~' ¢_2 UNIT# /,/¢F~_ ~' ON/OFF SHORE 42:) ~ ADMINISTRATION R D,~TE) ENGINEERING APPR D?//~.~ GEOLOGY 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N '12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... (~ N 17. CMT vol adequate to tie-in long string to surf csg ........ ¢ N 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved....,~ N 22. Adequate wellbore separation proposed ............. ~(~ N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ..... ,,,,2.~ .... N 26. BOPE press rating appropriate; test to c----- - psigl N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~;> N 28. Work will occur without operation shutdown ........... ~2 N 29. Is presence of H2S gas probable ................. Y ~ 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ,, 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for we,ekly,progress rep?ts ..... / Y N lexploratory omyy REMARKS GEOLOGY: RPC,~, ENGINEERING: COMMISSION: BEW_~~_ DWJ .... JDH ~ RNC~ Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09/97 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. * ALASKA COMPUTING CENTER * . . ****************************** RECEIVED * .... WESTERN ATLAS LOG ..... * ........ PRO~ES~E~ B~' ........ AU(; ~ 0 1998 * ....... SCHLUMBERGER ....... * ............................. *Alaska Oii& Gms Cons. ¢~mmis"jon COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : MPJ-20 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : AlaSKA API NUMBER : 500292283200 REFERENCE NO : 98401 Date~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 08:47 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 98/08/11 ORIGIN : FLIC REEL NAME : 98401 CONTINUATION # : PREVIOUS REEL : COFfl~-~Ff : BP EXPLORATION, MILNE POINT, MPJ-20, API #50-029-22832-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/11 ORIGIN · FLIC TAPE NAME : 98401 CONTINUATION # : 1 PREVIOUS TAPE : CO~_2TT . BP EXPLORATION, MILNB POINT, MPJ-20, API #50-029-22832-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPJ- 20 API ~ER: 500292283200 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: WESTERN ATLAS TAPE CREATION DATE: il-AUG-98 JOB AUJM~ER: 98401 LOGGING ENGINEER: L KOENN OPERATOR WITNESS: J SPEARMAN SURFACE LOCATION SECTION: 28 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2207 FEL: 3288 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 64.20 GROUND LEVEL: 35.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 7982.0 26. O0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 08:47 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ CONTAINED HEREIN IS THE LDWG FORMATTED GR/CCL DATA AQUIRED ON BP EXPLORATION'S MPJ-20 WELL. PER DALE CAIN AT WESTERN ATLAS, THERE WAS A TAPE DRIVE FAILURE SO THE ONLY DATA AVAILABLE IS THE GR CURVE. THIS LOG IS THE PRIMARY DEPTH CONTROL. $ $ PAGE: **** FILE H~ER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~DER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 7963.0 6804.0 $ CURVE SHIFT DATA - PASS TO PASS (PIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVAL~iNT UNSHIFTED DEPTH GRCH LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 08:47 PAGE: REMARKS: THIS FILE CONTAINS THE EDITED GR CURVE. THE DATA HAS BEEN CLIPPED AT FIRST ANDATLAST READINGS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 128 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 0 ** SET TYPE - CHAN ** NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194636 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 194636 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7963.000 GRCH. CNTD 55.749 DEPT. 6804.000 GRCH. CNTD 40.835 ** END OF DATA ** LIS Tape Verification Listing Sc*hlumberger Alaska Computing Center 12-AUG-1998 08:47 PAGE **** FILE TRAILER **** FILE NAME : EDIT . 001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O0!CO1 DATE . 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1VUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 1 DEPTH INCREMENT: O . 5000 FILE SU~4~D%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 7972.0 6800.0 GR LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~k~A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 03-JUL-98 JO01 1.1 7980.0 7977.0 6804.0 7963.0 TOOL NUMBER 8262XA GR 7982.0 LIS Tape Verification Listing sc'hlumberger Alaska Computing Center 12-AUG-1998 08:47 PAGE: LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STA~OFF (IN): REMARKS: LOG RAN ON WIRELINE MARKS. THIS FILE CONTAINS THE RAW GR DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 08:47 PAGE: TYPE REPR CODE VALUE 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194636 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 194636 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7963.000 GR.PS1 55.749 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~4E : EDIT DATE : 98/08/11 ORIGIN · FLIC TAPE NANIE · 98401 CONTINUATION # : 1 PREVIOUS TAPE : CO~ff4ENT : BP EXPLORATION, MILNE POINT, MPJ-20, API #50-029-22832-00 LIS Tape Verification Listing S~hlumberger Alaska Computing Center 12-AUG-1998 08:47 PAGE: **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 98/08/11 ORIGIN : FLIC REEL NAME : 98401 CONTINUATION # : PREVIOUS REEL : CO~2VT : BP EXPLORATION, MILNE POINT, MPJ-20, API #50-029-22832-00 Sperry-Sun Drilling Services LIS Scan Utility Sat Aug 15 22:58:53 1998 Reel Header Service name ............. LISTPE Date ..................... 98/08/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/08/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION MWD RUN 1 AK-MM-80016 HALL LOCKWOOD (FT FROM MSL 0) RECEIVED AUG 19 1998 Alaska Oil & Gas Cons. ~,omm~sslon MPJ-20 An~orago 500292283200 BP EXPLORATION (ALASKA) , INC. SPERRY-SUN DRILLING SERVICES 15-AUG- 98 MWD RUN 2 AK-MM-80016 ZIEMKE LOCKWOOD 28 13N 10E 2207 3288 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 64.20 35.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 8085.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGERMUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. ELECTROMAGNETIC WAVE RESISTIVITY EXTRA-SHALLOW SPACING IS NOT PRESENTED FROM 3660'MD, 2570'TVD TO 8085'MD, 4196'TVD DUE TO SENSOR FAILURE. 4. ALL MWD RUNS REPRESENT MPJ-20 WITH API# 50-029-22832-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8085'MD, 4196'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM S PACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 0'0808 S'8008 0'9108 §'I~9C ~'8008 ~'8008 ~'8008 HL~ ~OLS 6CIL OOIL 960L S60L 560L 980L ~80L ~LOL OLOL L~OL I~OL I~OL CEOL I~OL LOOL ~OOL O00L L669 8869 ~869 S'I869 ~'LL69 W'§L69 ~'IL69 ~'L969 S'~969 I§69 ~69 C~69 C~69 ~I69 ~069 6689 L989 0989 9C89 CC89 9~89 0'§~89 0'LI89 S'6§ ICIL 960L I60L 060L 880L g80L 6LOL 890L ~90L I90L I~OL 9COL O~OL 9IOL COOL O00L 9669 C669 L869 I869 6L69 ~L69 CL69 0 6969 0'C969 ~'L§69 g'L969 0'6C69 S'9C69 ~'SI69 8069 8689 C689 I989 C§89 8~89 9E89 0 LI89 ~'§I89 g'8089 O'Iq :SLSIHS ~0~ ZAH~O ZMIqZS~S S'CEI 0 ~I 0 6S 0 IS 0 IS 0 IS 0 IS ~OD qO0£ 7135.0 7140.0 7162.5 7168.0 7171.5 7181.5 7186.5 7188 5 7196 5 7199 5 7204 0 7206 5 7220 0 7223 5 7257 5 7259 5 7278.0 7281.5 7284.0 7299.0 7301.0 7314.0 7327.5 7330 0 7331 5 7333 5 7335 0 7345 5 7363 5 7370.0 7438.0 7442.5 7532.5 7535.0 7539.0 7541.0 7542.5 7570.5 7581.5 7613.0 7622.5 7652.0 7654 5 7660 5 7735 0 7775 5 7788 5 7812 5 7829 5 7846 5 7867 0 7878 0 7917 5 7919 0 8080 0 $ 7143.0 7147.5 7165.5 7173.5 7177.0 7185.0 7189.5 7191.0 7200.5 7206.5 7211.0 7212.5 7225.5 7231.0 7263.0 7265.0 7282.5 7286.5 7288.0 7303.5 7306.5 7319.0 7332.5 7334.5 7337.0 7339.0 7340.0 7350.5 7369.0 7376.5 7442.0 7446.0 7536.5 7539.5 7544.0 7546.5 7547.5 7573.5 7585.0 7617.0 7626.5 7655.0 7657.5 7663.5 7736.5 7777.0 7791.0 7814.0 7830.5 7851.0 7872.5 7881.5 7923.0 7924.0 8085.0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 112.0 2582.0 2 2582.0 8085.0 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 DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMS4 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHM~ 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Min 51 13 7476 12 2426 0 1455 0 1203 0 0872 0 0856 0 0512 Max 8080 4884.08 144.324 2000 2000 2000 2000 19.3933 Mean Nsam 4065.5 16059 361.149 15914 59.9083 15868 94.9164 7202 55.1569 15916 67.2154 15916 80.9498 15916 0.786158 15774 First Reading 51 123.5 59 51 51 51 51 122 Last Reading 8080 8080 8016 3651.5 8008.5 8008.5 8008.5 8008.5 First Reading For Entire File .......... 51 Last Reading For Entire File ........... 8080 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/15 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 ....... 98/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 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 SUMY~ARY VENDOR TOOL CODE START DEPTH RPX 59.5 RPS. 59.5 RPM 59.5 RPD 59.5 GR 67.5 FET 130.5 ROP 132.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 2511.0 2511.0 2511.0 2511.0 2518.5 2511.0 2582.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA 27-NOV-97 5.07 5.46 MEMORY 2582.0 112.0 2582.0 .2 59.2 TOOL NUMBER P0893PCRGM6 P0893PCRGM6 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 (OHN~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/~DOFF (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 8.500 8.5 SPUD 8.60 88.0 9.5 80O 8.0 2.900 2.368 2.175 4.350 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 23.9 First Name Min Max Mean Nsam Reading DEPT 59.5 2582.5 1321 5047 59.5 GR 12.2426 144.324 55.5551 4903 67.5 RPX 0.1455 2000 132.583 4904 59.5 Last Reading 2582.5 2518.5 2511 RPS 0.1203 2000 150.652 4904 RPM 0.0872 2000 190.034 4904 RPD 0.0856 2000 233.823 4904 ROP 21.263 4884.08 395.563 4902 FET 0.0512 0.8945 0.443044 4762 59.5 59.5 59.5 132 130.5 2511 2511 2511 2582.5 2511 First Reading For Entire File .......... 59.5 Last Reading For Entire File ........... 2582.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/15 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 ....... 98/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2511.5 2511 5 2511 5 2511 5 2512 0 2520 0 2584 0 SURFACE SOFTWARE VERSION: STOP DEPTH 8013.5 8013.5 8013.5 8013.5 3660.0 8021.0 8085.0 30-NOV-97 5.07 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.46 MEMORY 8085.0 2582.0 8085.0 32.0 85.4 TOOL NUMBER P0893PCRGM6 P0893PCRGM6 8.500 '8.5 SPUD 9.10 70.0 9.5 600 5.2 2.900 2.087 2.175 4.350 30.0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 2 API 4 1 RPX MWD 2 OHMM 4 1 RPS MWD 2 OHM~ 4 1 RPM MWD 2 OHM~ 4 1 RPD MWD 2 OHMM 4 1 ROP MWD 2 FT/H 4 1 FET MWD 2 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max DEPT 2511.5 8085 GR 12.5604 127.053 RPX 2.2758 50.9132 RPS 1.1601 84.2768 RPM 0.5178 163.551 RPD 0.5701 128.534 ROP 11.6452 4172.17 FET 0.0893 19.3933 Mean Nsam 5298.25 11148 61.8683 11003 14.5341 2297 12.5992 11005 12.4836 11005 12.8356 11005 345.903 11003 0.922519 11005 First Reading 2511.5 2520 2512 2511.5 2511.5 2511.5 2584 2511.5 Last Reading 8085 8021 3660 8013.5 8013.5 8013.5 8085 8013.5 First Reading For Entire File .......... 2511.5 Last Reading For Entire File ........... 8085 File Trailer' Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/08/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/08/15 Origin ................... STS Reel Name ................ UNKNOWN Scientific Technical Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Physical EOF Physical EOF End Of LIS File
