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Home My WebLink About198-039 Pages NOT Scanned in this Well History File XHVZE 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. 15'- Q3� File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: ❑ Grayscale, halftones, pictures, graphs, charts - Pages: ❑ Poor Quality Original- Pages: ❑ Other- Pages: DIGITAL DATA o Diskettes, No. ❑ Other, No/Type OVERSIZED ❑ Logs of various kinds O Other COMMENTS: Scanned by: Beverly Mildred Daretha 40 Lowell Date: 2 2 Ce Is! At. ❑ TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /s/ _uCG_4 TT REPORT �O C��. !0?� CL F a P�_NC� R7 PORT of Alaska ALASZA OIL & GAS CONSERVATION CCMMISSIQN • ?Tr No.1 yyy��grr _.03 ? Lease I1T)L tg V -=e c=a= - -l- • =- _ No . Q 9(�- F617 Wel_ Name T" �.�, E —02/ Cperatcr t7 :ccat_o -r. 5',*T 13k.( (2 ( 6‘ CJ Ken Abnd Date LA _. Spud: 3 TD: ) `T 3&6, Completed Vote casing site, wt, j�dept , az vol, & procedure. Sfc Csc: ` Q R `'(z/ I (3 `-°� 5I< A / 5 lone Csc:/ / L_, gO 10) -27 a 3 S PF E 5 s --r-- C. Peri: intervals - tops: Review the well file, and comment on plugging, well head status, and location clearance - provide loc. clear. code. 71 L•gs: t33 -3 ( 2 A �� G Ctrrr, P laoCr 0- E , v. -- 3 II, 3 I!VW Cts v - b d 5 G j C _ �` �� 9 >c c.5 o0 U-J 5 \ � �eVS Well head cut off: A Marker post or plate: - ''1 3�.�" 0 Location Clearance: Q Conclusions: Pdt qL--ft .-c). 14-( fti) a00-' C� cT � �.� -(1 Code Signed (Ke__Ma,/,--- Date (z/be. 20O STATE OF ALASKA ALAS.IL IL AND GAS CONSERVATION CO IISION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 11. Status of Well Classification of Service Well 0 Oil 0 Gas 0 Suspended ®Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 198-039 398-089/300-287 3. Address 8. API Number P.O. Box 196612,Anchorage, Alaska 99519-6612 50-029-22867-00 4. Location of well at surface 9. Unit or Lease Name 3613' NSL, 1936'WEL, SEC. 25,T13N, R10E, UM Milne Point Unit At top of productive interval N/A At total depth 10. Well Number MPE-24 2055'SNL,2970'WEL, SEC. 6,T12N, R11E, 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=57.1' ADL 380110 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp.,or Aband. 15.Water depth, if offshore 16. No. of Completions 3/9/98 04/02/1998 04/02/1998 N/A MSL Zero 17.Total Depth(MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21.Thickness of Permafrost 14366 6563 FT 9800 4402 FT 0 Yes IN No N/A MD 1800'(Approx.) 22.Type Electric or Other Logs Run MWD, CDR, GR, ROP, SWC 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 Surface 113' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 10077' 12-1/4" 2823 sx PF'E',562 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) None N/A MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED 14366'- 13343' Abandonment Plug#1,51 Bbls Class'G' 10009' Set EZSV 10009'-9540' Plug#2,Class'G',33 Bbls Below EZSV,15 Bbls above 6910' Set Bridge Plug (Drilled out 01/2001) 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 GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED 'OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-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 2 1 2001 Form 10-407 Rev. 07-01-80 ORI G I N /AL Alaska 00&nag Cons.Commission Anchorage Submit In Duplicate • • 29. Geologic Markers 30' Formation Tests Marker Name Measured True Vertical Include interval tested,pressure data, all fluids recovered Depth Depth and gravity,GOR, and time of each phase. Top of Schrader Bluff 8882' 4138' Schrader Bluff D-OA 9380' 4272' Schrader Bluff B-OB 9552' 4320' Base HRZ 13664' 6393' Top of Kuparuk 13946' 6655' KC1 14111' 6810' Kuparuk B/B7 14134' 6831' Kuparuk B6 14172' 6847' 31.List of Attachments: Summary of Original Daily Drilling Operations and Surveys were submitted with the 10-404 on 12/16/98. 32. I hereby certify that the fore oing is true and correct to the best of my knowledge Signed Terrie Hubble M A n ,n q �-t Title Technical Assistant Date 03.21-01 MPE-24 Ma 198-039 398-089/300-287 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. ITEM 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection, r- plain. ITEM 28: If no cores taken,indicate'none'. R E E I ORIGINAL MAR 21 2001 Form 10-407 Rev. 07-01-80 Alaska Oil&Gas Cons.Commission Anchorage • • BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Date From -To Hours Task Code Phase Description of Operations 1/1/2001 18:00-00:00 6.00 MOB PRE Rig Down at MPJ-20A-Prepare to move to MPE-24A 1/2/2001 00:00-00:00 24.00 MOB PRE Rig Down, Move Rig from Milne Point J-pad to E-pad-Move Sub with derrick up 1/3/2001 00:00-00:00 24.00 MOB PRE Spot and level sub on well. Spot mud pits,pipe shed and motor complexes.Spot cuttings tank and build berm around it. Move camp, parts house,shop and generator from J pad to E pad. . Start thrawing out and hooking up water,air and hydraulic lines. 1/4/2001 00:00-04:00 4.00 MOB PRE Change out suction valves in pits.Thaw out water lines and repair steam line. Install skate railing on pipe chute. 04:00-07:00 3.00 MOB PRE Remove ice from rig floor. Mop and clean rig. 07:00-12:00 5.00 WHSUR DECOMP Check for pressure and n/d tree. Pull tubing hanger and tubing head. Pull 7'packoff and casing hanger with pup. Accept rig at 0700 hrs. 12:00-18:00 6.00 BOPSUR INTI Install 11"x 11"drilling spool with double valves. N/u bops. 18:00-21:00 3.00 WHSUR PROD1 Fabricate flowline,choke line and fill up line. 21:00-22:00 1.00 BOPSUR PROD1 PJSM. M/U test jt and install test plug. 22:00-23:00 1.00 BOPSUR BARR PROD1 Change out ring gasket on choke line. 23:00-00:00 1.00 BOPSUF PROD1 Test bops.All rams/valves 250/3500 psi for 5/10 minutes.Test annular 250/2000 psi for 5 and 10 minutes. Chuck Scheve with AOGCC waived witnessing test. 1/5/2001 00:00-06:30 6.50 BOPSUR PROD1 Finish testing bops.Chuck Scheeve waived witnessing test. 06:30-10:00 3.50 STWHIP PROD1 Trip in hole picking up and drifting 3-1/2"drill pipe to 2200'. 10:00-11:30 1.50 STWHIP PROD1 Displace freeze protect diesel from annulus and drill pipe with seawater. Circulate until seawater back to surface. 11:30-19:30 8.00 STWHIP PROD1 Continue tripping in hole picking up and drifting 3-1/2"drill pipe. Tagged bridge plug at 6942'. 19:30-20:00 0.50 STWHIP PROD1 Circulate capacity of drill pipe. 20:00-22:30 2.50 STWHIP PROD1 Pooh and stand back drill pipe. 22:30-23:00 0.50 STWHIP PROD1 Service top drive. 23:00-00:00 1.00 STWHIP PROD1 Trip in hole picking up 3-1/2 drill pipe. 1/6/2001 00:00-09:00 9.00 STWHIP PROD1 Finish tripping in hole picking up and drifting 3-1/2"drill pipe 09:00-09:30 0.50 STWHIP PROD1 Circulate capacity of drill pipe. 09:30-12:00 2.50 STWHIP PROD1 Pooh standing drill pipe back in derrick. 137 stands drill pipe in derrick 12:00-13:00 1.00 STWHIP PROD1 Clean rig floor. 13:00-16:00 3.00 STWHIP PROD1 P/u,strap and m/u bha.Test MWD. 16:00- 17:00 1.00 STWHIP PROD1 Clean up seawater spill and had a meeting with hands discussing how to prevent this in the future. 17:00-17:30 0.50 STWHIP PROD1 Service top drive. 17:30-21:30 4.00 STWHIP PROD1 Continue tih to top of plug. Fill drill pipe and lost all pressure on top drive. 21:30-00:00 2.50 STWHIP TDRV PROD1 Waiting on parts to repair top drive. Lost electrical motor on lube pump. 1/7/2001 00:00-07:00 7.00 STWHIP TDRV PROD1 Replace electrical motor on lube pump on the top drive 07:00-08:30 1.50 STWHIP PROD1 Drill bridge plug 08:30-09:30 1.00 STWHIP PROD1 Circulate bottoms up-no gas. 09:30-12:00 2.50 STWHIP PROD1 Continue tih to 9515. Started taking weight. 12:00-15:00 3.00 STWHIP PROD1 Wash and drill through cement stringers 9525'-9789'. 15:00-17:00 2.00 STWHIP PROD1 Pump sweep and displace well with seawater. 17:00-17:30 0.50 STWHIP PROD1 Pooh to 9055' 17:30-22:00 4.50 STWHIP PROD1 Make a mad pass tie-in log from 9055-9789'. 22:00-00:00 2.00 STWHIP WTHR PROD1 Phase III weather conditions. WOW. 1/8/2001 00:00-00:00 24.00 STWHIP WTHR PROD1 Phase III conditions.WOW.Change suction valves in pit#7, install snubbing post,and weather proof rig while waiting on weather.At 1800 hrs Milne Pt went back to Phase II, but Prudhoe Bay and Kuparuk were V1AP 2 1 zcoi Printed: 2/26/2001 3:08:06 PM Alaska Oil&Gas Cons.Commission • S BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From -To Hours Task Code Phase Description of Operations 1/8/2001 00:00-00:00 24.00 STWHIP WTHR PROD1 still Phase III. Remove snow so rig is accessible for water and diesel trucks. Prepare to Pooh. 1/9/2001 00:00-04:30 4.50 STWHIP WTHR PROD1 Pooh recording pu,so,and rotating wt every 10 stands. 04:30-05:30 1.00 STWHIP PROD1 UD bha. 05:30-06:30 1.00 STWHIP PROD1 Pull wear ring. 06:30-08:30 2.00 BOPSUR PROD1 Change top rams to 7" 08:30-11:00 2.50 STWHIP PROD1 Change top drive from 3-1/2"to 4-1/2"for fill up tool. 11:00-14:00 3.00 BOPSUF, PROD1 Set test plug and test door to 1000 psi. 14:00-17:00 3.00 CASE PROD1 Change bails,mu fill up tool and ru casing equipment. 17:00-20:30 3.50 CASE PROD1 PJSM. Run 7"26#L-80 BTC Mod casing. 20:30-21:00 0.50 CASE PROD1 Change out tongs 21:00-00:00 3.00 CASE PROD1 Run 7"26#L-80 BTC Mod casing. total 85 jts. 1/10/2001 00:00-07:00 7.00 CASE PROD1 Finish running 234 jts 7"26#L-80 BTC mod casing.Casing shoe at 9772'. 07:00-09:00 2.00 CASE PROD1 Make up Dowell cement and circulate casing volume at 10 bpm with 800 psi. 09:00-09:30 0.50 CASE PROD1 PJSM with all personel. 09:30-10:30 1.00 CASE LINE PROD1 Demco valve stem on cement line was seized up and would open. Replaced valve. 10:30-14:30 4.00 CASE PROD1 Test lines 3500 psi. Pump 20 bls water and 50 bbls Chemical wash. Mix and pump 264 bbls(335 sxs)ASIII at 10.7 ppg. Tail with 51 bbls (245 sxs)Class"G"at 15.8 ppg.Wash lines,drop top plug and displace with rig pumps. Bumped plug with 95%pump efficiency to 2700 psi. Floats held. CIP @ 1300. Full returns with 10 bbls of 10.7ppg cement back to surface. 14:30-17:00 2.50 CASE PROD1 lay out land jt.,flush cement lines,change elev.clear floor 17:00-17:30 0.50 CASE PROD1 Flush BOP stack 17:30-22:00 4.50 CASE PROD1 Run pack off,wouldn't test,pull pack off,flush head,run new pack off, test to 5000#for 15 min. 22:00-00:00 2.00 CASE PROD1 PJSM,Change rams to 3.5,test door seals to 1000# 1/11/2001 00:00-01:00 1.00 CASE PROD1 Pull test plug and install wear ring. 01:00-02:00 1.00 CASE PROD1 Change top drive from 4-1/2 to 3-1/2. 02:00-04:30 2.50 STWHIP WEXIT Make up for bha for dummy/tie-in run for setting whipstock and MWD. Test MWD. 04:30-08:00 3.50 STWHIP WEXIT Continue tih. Tagged float collar at 9700'. 13'deeper than float collar @ 9687'.Double checked all casing tallies-ok. 08:00-12:00 4.00 STWHIP WEXIT Mad pass from 9701-9200 to confirm depths of sands and RA tag. RA tag was 13'deeper. 12:00-13:00 1.00 STWHIP WEXIT Pooh 15 stands to 8300'.Air line to crown-a-matic froze. 13:00-17:30 4.50 STWHIP DRAW WEXIT Repair air line to crown-a-matic 17:30-23:00 5.50 STWHIP WEXIT Finish trip out,drill pipe strap was same as pipe tally 7"float collar @ 9700 23:00-00:00 1.00 STWHIP WEXIT Test csg to 3500#for 30 min. 1/12/2001 00:00-07:30 7.50 STWHIP WEXIT Finish tih with whipstock. Tag float collar at 9700'. 07:30-08:00 0.50 STWHIP WEXIT Establish up and down weights. Orient and set whipstock at 7 degrees right of high side. Window will be from 9545-9557'. 08:00-09:00 1.00 STWHIP WEXIT Pump sweep and displace well with 9.1 Baradril mud. 09:00-18:00 9.00 STWHIP WEXIT Milling window from 9545-9557,starting mill depth 9572, 85 rpm, 4-5,000 wt., 225 gals min 2000#pump pressure 18:00-19:30 1.50 STWHIP WEXIT Pump sweep RE CE 19:30-22:00 2.50 STWHIP WEXIT Trip out, mill full gauge.6.151 22:00-00:00 2.00 STWHIP WEXIT Lay down BHA 1/13/2001 00:00-03:00 3.00 STWHIP WEXIT Finsh laying down bha and clear rig floor. MAR 2 1 Z001 Alaska Oil b'rtgdOW251mWiSRPP"' Anchorage 410 • BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From -To Hours Task Code Phase Description of Operations 1/13/2001 03:00-03:30 0.50 STWHIP WEXIT Rig up and flush out bop stack. 03:30-04:30 1.00 BOPSUR PROD1 Pull wear ring and install test plug. 04:30-11:00 6.50 BOPSUR PROD1 Test bops. Annular 250/2000 psi 5 min/10 min. All rams and valves 250/3500 psi 5 min/10 min. Test was witnessed by John Crisp with AOGCC. 11:00-12:00 1.00 BOPSUR PROD1 Blow down test lines. Pull test plug and install wear ring. 12:00-15:00 3.00 DRILL PROD1 Make up directional bha and test MWD. 15:00-19:00 4.00 DRILL PROD1 Tih with bha to 9488 19:00-20:30 1.50 DRILL PROD1 Slip and cut drilling line 85 ft. 20:30-23:00 2.50 DRILL POWR PROD1 Rig repair, Elec.breaker in sub, lost all power to floor 23:00-23:30 0.50 DRILL PROD1 Finish cutting drlg line 23:30-00:00 0.50 DRILL PROD1 Orient tools and run tru window 1/14/2001 00:00-00:30 0.50 DRILL PROD1 Drilling directional from 9557-9602 00:30-01:00 0.50 DRILL PROD1 FIT test to 11.0#with 9.1 mud and 430 psi. 01:00-14:30 13.50 DRILL PROD1 Drilling directional from 9,602-10,467 w/4/5000#wt.70 rpm,2300# with 230 gals 14:30-15:30 1.00 DRILL PROD1 circ. 15:30-00:00 8.50 DRILL PROD1 Drilling directional from 10,467-11,153 w/4/5000#wt.70 rpm,2300# with 230 gals,change out mud while drilling 1/15/2001 00:00-01:30 1.50 DRILL PROD1 Drilling directional from11,153-11,200 w/4/5000#wt.70 rpm,2300# with 230 gals 01:30-04:00 2.50 DRILL PROD1 Short trip to window@9,545 no problems, pumped out 04:00-05:00 1.00 DRILL PROD1 Service rig and blow down top drive 05:00-06:00 1.00 DRILL PROD1 Trip in hole,wash 60 ft to bottom 06:00-00:00 18.00 DRILL PROD1 Drilling directional from 11,200-12354w/4/5000#wt.70 rpm,2300#with 230 gals,sliding hrs 6, rot. hrs 8 1/16/2001 00:00-07:30 7.50 DRILL PROD1 Drilling directional from 12354-12860 TD well w/4/5000#wt.70 rpm, 2300#with 230 gals, sliding hrs 1, rot. hrs 5 07:30-10:00 2.50 DRILL PROD1 Circ, high vis sweeps 10:00-15:00 5.00 DRILL PROD1 Tripping up to window @ 9545. pumping out, no problems taking p/u and s/o rt/weights every 5 sds. 15:00-17:30 2.50 DRILL PROD1 Circ bottoms up and hooked up wildcat driller,monitor well 17:30-00:00 6.50 DRILL PROD1 Trip out, lay down BHA taking p/u and s/o rt/weights every 10 sds. 1/17/2001 00:00-01:30 1.50 DRILL PROD1 Finish laying out BHA 01:30-06:00 4.50 DRILL PROD1 Pick up Bha, 6 1/8 porcupine hole opener and two full gauge stab and one under gauge stab,trip in to window@ 9545 06:00-08:30 2.50 DRILL COND PROD1 Circ, putting shaker screens on new circ rate.,shakers wouldn't handle rate. 08:30-18:30 10.00 DRILL PROD1 Reaming with hole opener from 9557-12860 300 ft per hr. 100 rpms and 300 gals min. 18:30-21:00 2.50 DRILL PROD1 Circ 3 bottoms up and change out to new mud 21:00-00:00 3.00 DRILL PROD1 Tripping out for liner,pumping out of open hole, no problems getting pu and so wts every 5 sds. 1/18/2001 00:00-06:00 6.00 DRILL PROD1 Tripping out for liner, pumping out of open hole without rotating, no problems,Take p/u and s/o wts every 5 sds. moniter well @ window- Pump slug-Pooh-Lay down BHA 06:00-08:00 2.00 CASE PROD1 Clear rig foor,-PJSM, Rig up Nabor casing tools 08:00-08:30 0.50 CASE DRAW PROD1 Install wildcat auto-matic driller on drawworks 08:30-09:00/ 1.50 CASE PROD1 Safety meeting with drill crew and service personnel on running 4 1/2" V slotted liner 09:00-14:00 5.00 CASE PROD1 Picking up 84 jts of 4.5, 12.6#,L-80 slotted liner+2 jts of 4.5, 12.6# VIAR 2 1 2001 L80 IBT solid csg&one solid shoe jt. 12.6#L80 IBT-Install one Printed: 2/26/2001 3:08:06 PM MiaSnu!, r > Cons.Commissiol., Anchorage STATE OF ALASKAXi I / • • ALASK AND GAS CONSERVATION COM ION 1h�N / I - Ar LICATION FOR SUNDRY APPROVA 1. Type of Request: sift Abandon 0 Suspend 0 Plugging 0 Time Extension 0 Perforate ❑Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance ®Other ❑Change Approved Program 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Re-Enter Ops Shutdown 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. ® Development KBE=57.1' ❑ Exploratory 7. Unit or Property Name 3. Address 0 Stratigraphic Milne Point Unit ❑Service P.O. Box 196612, Anchorage,Alaska 99519-6612 - 8. Well Number 4. Location of well at surface f f V MPE-24� 3613' NSL, 1936'WEL, SEC.25,T13N, R10E, UM 9. Permit Number At top of productive interval /198-039/398-089 N/A 10.API Number At effective depth 50-029-22867-00'f 3875'SNL,2854' EWL, SEC. 36,T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit/Schrader Bluff 2664' SNL,3617'WEL, SEC. 6,T12N, R11E, UM 12. Present well condition summary Total depth: measured 14366 feet Plugs(measured) Abandonment Plug 14366'-13343'; EZSV set at 10009'; Abandonment Plug 10009'-9800'; Bridge Plug set at 6910' true vertical 6563 feet Effective depth: measured 9800 feet Junk(measured) true vertical 4402 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 113' 113' Surface 10041' 9-5/8" 2823 sx PF'E', 562 sx Class'G' 10077' 4500' Intermediate Production Liner Perforation depth: measured N/A 4 2000 true vertical N/A r C� Co li �.�i�.ALMS�Ailiii:i.aYYiFa$�i,SJ6v:i Anchorage Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13.Attachments ®Description Summary of Proposal 0 Detailed Operations Program ❑ BOP Sketch 14. Estimated date for commencing operation 15. Status of well classifications as: November 30,2000 16. If proposal was verbally approved ®Oil El Gas ❑Suspended Service Name of approver Date Approved Contact Engineer Name/Number: Larry Wolfson,564-59 Prepared By Name/Number: Terrie Hubble,564-4628 17. I hereby certify that the fo ging is true co ect to the best of my knowledge Signed Steve Shultz 7 Title Senior Drilling Engineer Date ///(,,l/66 Commission Use Only Conditions of Approval: Notify Commission so representative may witness �/ Approval No. Plug integrity BOP Test X. Location clearance (� Mechanical Integrity Test Subsequent form required 10- r\c:ix-sc4 *Pk c- c-"NI v.\ s� Mcg Approved by order of the Commission Commissioner Date //%U-00 Form 10-403 Rev. 06/15/88 )PZIKM A 4I 41' I\ L Submit In Triplicate • • HON BP ALASKA DRILLING s WENS Date: November 14, 2000 To: Tom Maunder Alaska Oil & Gas Conservation Commission From: Larry Wolfson RECEIVED Operations Drilling Engineer 7:11 2000 Subject: 10-403, Reenter Ops S/D for MPE-24 Alas ta�i&G c0000mm;ssi,r Anchorace MPE-24 was drilled in 1998 by Nabors Rig 27E to a depth of 14,366'. LWD logs revealed the Kuparuk Sands were water wet. The open hole section was abandoned and the well has been in operations shut-down since 04/04/98. We are requesting permission to reenter this well and prepare it for new sidetracking operations. A new Permit to Drill for MPE-24A and MPE-24AL1 is being submitted along with this 10-403. • Schrader Bluff Tract 14 2000 rogram MPE-24A Drilling Permit 5. MPE-24A Nabors 22E Operations Summary 5.1. Pre-Rig Operations 1. Grade and level pad 5.2. Procedure 1. MIRU Nabors 22E, NU &test BOP on Gen 5 wellhead. 2. PU 3-1/2" drill pipe .ThNs �-��.v.‘ ,\fO� Q.\ 1TNN 3. MU rotary BHA, MWD and 8-3/8" mill tooth bit. ` c� 4. RIH and drill out bridge plug at 6910'. cis( ‘sNp� P\vSS Q\c+�J c,,�N Cleanout to cement plug at±9800'. S\-4pcc..t c� 5-va\\\ 1.,b'i e(j6\ MAD pass from PBTD to top of OA sand (±9380'). 5. Run and cement 7"casing inside 9-5/8"casing to isolate casing patch. -ay t. -\-,3e\ P'-1ss Bring cement to surface to eliminate the need for freeze protecting annulus. 6. Make up rotary BHA, MWD and mill. RIH to float collar,confirm depths. t� _ 7. MU Baker Window Master window milling BHA with bottom trip anchor and MWD. RIH.Orient and set whipstock. Mill window thru 7" and 9-5/8"casing. 8. MU BHA with 6-1/8" PDC bit, 4-3/4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3-1/2"drill pipe. Drill 6-1/8" OB lateral from 9552'to 12753'; geosteering and short tripping as required. Maintain BARADRILn mud properties. 9. Make a hole opener run at TD. 10. Displace OB lateral with clean BARADRILn mud. 11. Run 4'h"slotted liner with 2 7/8" inner string and hang off in 7"casing. 12. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. RIH. Orient and set whipstock. ( Mill window thru 7" and 9-5/8"casing. 13. MU BHA with 6-1/8" PDC bit, 4-3/4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3-1/2"drill pipe. RIH. Displace hole to clean BARADRILn mud. Drill 6-1/8"OA lateral from 9380'to 12,744'geosteering and short tripping as required. Maintain BARADRILn mud properties. 14. Make a hole opener run at TD. 15. Displace OA lateral with clean BARADRILn mud. 16. MU whipstock retrieving tool and pull whipstock. V-\1)"- 17. Run 4 IV slotted liner with 2 7/8"inner string, Baker Hook Hanger and hang off in 7"casing. / 18. POOH laying down 3' "drill pipe. 19. Run in hole with 2 7/8"tubing to top of OA liner. 20. Displace 7"casing to 9.1 lb/gal completion fluid. 21. Land tubing hanger. 22. Set tubing plug and BPV. 23. ND BOP. r 1*- _., ., ,, F ik r. 24. Install and test tree. 25. Pull tubing plug and BPV. 26. Freeze protect the tubing and annulus. 9 ,� 27. Install BPV and secure the well. 28. RD/MO. 9 ! • Tree: 2 9/16"tree. MPU E-24 Orig.DF.elev.=57.1'(N 27E) Wellhead:Gen.5A system.11"csg. spool,7 1/16"X 11"5M FMC tbg. Orig.GL.elev.= 24.3' spool w/ 7"mandrel hgr.and packoff. DF to 9 5/8"csg.hnr.=36.3'(N 27E) 7"x 2 7/8"tbg.hgr.installed. Diesel to 2060' 20"91.1 ppf,H-40 113' n Howco 9 5/8"'ES' 2147'and seawater to top of BP Cementer stage collar KOP @ 300' - 9 5/8"bridge plug 6910'and Max.hole angle=74 to 77 deg. ` f/3650'to 9450' 10.1 ppg drlg.fluid 15 bbl.(200')of Class'G' w\,l �� Hole angle through perfs.= not appl. cement above the retainer. ctx 'Sr C-151%.‘ Howco 9 5/8"EZSV 10,009' 9 5/8",40 ppf,L-80 Mod. 10 077 cementing retainer S�O(� Btrs.surface casing ISOO�IJI� 33 bbl.of Class'G'cement below the retainer. d I. S4 L. Stimulation Summary none performed Alaska Oil �i37a i Perforation Summary Ref loq:Not applicable Size SPF Interval (TVD) TOC=13,343' 51 bbl.(250 sks)Class G cement plug 8.5"hole drilled to 14,366'. Kup.Sands are wet. DATE REV.BY COMMENTS MILNE POINT UNIT 04/05/98 JBF Drilled&Temp.P&A by Nabors 27E WELL E-24 API NO: 50-029-22867 BP EXPLORATION (AK) uoiss►wwo�a6saoyouy •suo0 seg TM wismill S . 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H HHO m (D 0 0 010 (D Fl U1 W 0 �l rhn rt O W W N rt rt H- N) • v H- 0 I H Ol IV H 0 0 W .A 0H O H '0 tt I I I I I H H H H W 0 0 0 0 O W W co co + 0 .A N) l0 01 H1 Z H• 0 -.1 a, In cn rt m co v • • • Cn'CI W U7 .A Ol I H .A 0 .A N CO �1 I I I I co H H H H W U1 co U7 Ci + 0 U7 .A co N I-h C'7 H- -1 OOI .A rt •-•••-(/) v • • • '-O CO 0 CO l0 I H .A N) OO H H H H H H H 0 Si .3 0 00IO -- H• O 01 W 0 -] H m rY CO W W N rt'0 W • H H H Ol N H CO -] IV IV rU Di H H H H Q.. .'ly CD O 0 co O (D N 'fJ CO OO -1 LQ 1-..- (-1-• . • 5 H OOW �1 O —1 W l0 0 II H-- II F-h II 0 a o II O H O O II O (D t' II • • • II F-h LQ cn II O O IV �1 II — II 0 -J O N) II II X II eV et CO II X I Z II (D H'< II 3 CI001 0 0 0 rr,-Q H N N N '0 0 00 I X XC 3C (D H I-- I--.• H- H• H- U) m Cr) S hared L�f ervices WALA KA. ri l l i ng BP Exploration/Arco Alaska Date: December 16, 1998 To: Alaska Oil & Gas Conservation Commission Attn: Blair Wondzell Reference: Milne Point - Well MPE-24 Report of Sundry Well Operations From: Carol ithe I Techn • .! � -istant Ill Blair: Pursuant to our phone discussion on December 15, 1998, we agreed a form 10-404 should be submitted for an operations shut-down rather than form 10-407 as stated on the Application for Sundry Approval. Please contact me if you have questions at 564-4114. Thank you Blair. Cc: Well File RECEIVED DEC 10 1998 Alaska Oil&Gas Cons.Commission Anchorage • STATE OF ALASKA •ALASKA V!C AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ®Operation Shutdown ['Stimulate ❑Plugging ❑Perforate ❑Pull Tubing ❑Alter Casing ❑Repair Well ❑Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. ❑Development KBE=57.3' ❑Exploratory 7. Unit or Property Name 3. Address ❑Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage,Alaska 99519-6612 ❑Service 4. Location of well at surface 8. Well Number 3613' NSL, 1936' WEL, SEC. 25,T13N, R10E, UM MPE-24 9. Permit Number / Approval No. At top of productive interval 98-39 398-089 N/A 10. API Number At effective depth 50-029-22868 2664' SNL, 3617' WEL, SEC. 6,T12N, R11 E, UM 11. Field and Pool At total depth Milne Point Unit/Schrader Bluff 2664' SNL, 3617' WEL, SEC. 6,T12N, R11 E, UM 12. Present well condition summary Total depth: measured 14366 feet Plugs(measured) Abandonment Plug 14366'-13343'; EZSV set at 10009'; Abandonment Plug 10009'-9540' ; Bridge Plug set at 6910' true vertical 6563 feet Effective depth: measured 14366 feet Junk(measured) true vertical 6563 feet Casing Length Size Cemented MD TVD Structural Conductor 75' 16" 250 sx Arcticset I (Approx.) 112' 112' Surface 10041' 9-5/8" 2823 sx PF 'E', 562 sx Class 'G' 10077' 4500' Intermediate Production Liner Perforation depth: measured N/A true vertical RECEIVED Tubing (size, grade, and measured depth) N/A DEC 18 1998 Packers and SSSV(type and measured depth) Alaska Oil&Gas Cons.Commission 13.Stimulation or cement squeeze summary N/A Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15.Attachments 16. Status of well classifications as: Copies of Logs an. ®Oil ❑Gas ❑Suspended Service /1 Daily Report of Well Opera ions 17. I hereby certify t t th/Q/�for goin i true and correct to the best of my knowledge Signed "' Charles oTitle Senior Drilling Engineer Date lel'/G/`, Prepared By Name/Number: Carol Withey, 564-4114 Form 10-404 Rev. 06/15/88 Submit In Duplicate S111 BP► Progress Report Facility M Pt E Pad Well MPE-24 Page 1 Rig Nabors 27E Date 16 December 98 Date/Time Duration Activity 07 Mar 98 06:00-09:00 3 hr Rigged down Drillfloor/Derrick 09:00-15:30 6-1/2 hr Rig waited:Other delays 15:30-16:00 1/2 hr Held safety meeting 16:00-06:00 14 hr Rig moved 75.00% 08 Mar 98 06:00-06:30 1/2 hr Held safety meeting 06:30-17:00 10-1/2 hr Rig moved 100.00% 17:00-18:00 1 hr Rigged up High pressure lines 18:00-18:30 1/2 hr Held safety meetipg 18:30-19:30 1 hr Serviced Additional services 19:30-21:30 2 hr Rigged up Drillfloor/Derrick 21:30-02:30 5 hr Rigged up Divertor 09 Mar 98 02:30-06:00 3-1/2 hr Racked back Drillpipe 06:00-06:30 1/2 hr Held safety meeting 06:30-12:00 5-1/2 hr Racked back Drillpipe 12:00-12:30 1/2 hr Functioned Divertor 12:30-15:00 2-1/2 hr Made up BHA no. 1 15:00-17:00 2 hr Drilled to 112.0 ft 17:00-00:30 7-1/2 hr Drilled to 632.0 ft 10 Mar 98 00:30-01:30 1 hr Repaired High pressure lines 01:30-06:00 4-1/2 hr Drilled to 1087.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-18:00 11-1/2 hr Drilled to 2500.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-19:00 1/2 hr Circulated at 2500.0 ft 19:00-19:30 1/2 hr Pulled out of hole to 1000.0 ft 19:30-20:00 1/2 hr R.I.H.to 2500.0 ft 20:00-03:30 7-1/2 hr Drilled to 3721.0 ft 11 Mar 98 03:30-04:00 1/2 hr Circulated at 3721.0 ft 04:00-05:00 1 hr Pulled out of hole to 1600.0 ft 05:00-06:00 1 hr R.I.H.to 3721.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-16:00 9-1/2 hr Drilled to 5312.0 ft 16:00-17:00 1 hr Circulated at 5312.0 ft 17:00-18:00 1 hr Pulled out of hole to 3700.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-19:30 1 hr R.I.H.to 5312.0 ft 19:30-02:30 7 hr Drilled to 6155.0 ft 12 Mar 98 02:30-03:30 1 hr Repaired Survey instruments 03:30-06:00 2-1/2 hr Drilled to 6438.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-11:30 5 hr Drilled to 7000.0 ft 11:30-13:30 2 hr Circulated at 7000.0 ft 13:30-16:30 3 hr Pulled out of hole to 200.0 ft 16:30-18:00 1-1/2 hr Pulled BHA 18:00-18:30 1/2 hr Held safety meeting 18:30-20:00 1-1/2 hr Made up BHA no.2 20:00-21:30 1-1/2 hr Serviced Block line 21:30-02:30 5 hr R.I.H.to 7000.0 ft 13 Mar 98 02:30-06:00 3-1/2 hr Drilled to 7405.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-18:00 11-1/2 hr Drilled to 8810.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-19:30 1 hr Circulated at 8810.0 ft 19:30-20:30 1 hr Pulled out of hole to 7000.0 ft 111 BP Progress Report Facility M Pt E Pad Well MPE-24 Page 2 Rig Nabors 27E Date 16 December 98 Date/Time Duration Activity 20:30-21:30 1 hr R.I.H.to 8810.0 ft 21:30-06:00 8-1/2 hr Drilled to 9467.0 ft 14 Mar 98 06:00-06:30 1/2 hr Held safety meeting 06:30-16:30 10 hr Drilled to 10100.0 ft 16:30-18:00 1-1/2 hr Circulated at 10100.0 ft 18:00-18:15 1/4 hr Held safety meeting 18:15-19:00 3/4 hr Pulled out of hole to 8800.0 ft 19:00-20:00 1 hr R.I.H.to 10100.0 ft 20:00-22:00 2 hr Circulated at 10100.0 ft 22:00-04:00 6 hr Repaired Top drive pipe handler 15 Mar 98 04:00-06:00 2 hr Pulled out of hole to 9000.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-09:30 3 hr Pulled out of hole to 200.0 ft 09:30-12:30 3 hr Pulled BHA 12:30-14:30 2 hr Serviced Core barrel 14:30-17:00 2-1/2 hr R.I.H.to 2738.0 ft 17:00-19:00 2 hr Circulated at 2738.0 ft 19:00-19:30 1/2 hr Held safety meeting 19:30-22:00 2-1/2 hr R.I.H.to 8816.0 ft 22:00-01:00 3 hr Installed Downhole tools 16 Mar 98 01:00-04:30 3-1/2 hr R.I.H.to 9625.0 ft 04:30-06:00 1-1/2 hr Serviced Downhole measurement tools 06:00-06:30 1/2 hr Held safety meeting 06:30-09:30 3 hr Pulled out of hole to 8816.0 ft 09:30-12:30 3 hr Conducted electric cable operations 12:30-17:00 4-1/2 hr Pulled out of hole to 0.0 ft 17:00-18:00 1 hr Serviced Top drive 18:00-18:15 1/4 hr Held safety meeting 18:15-19:00 3/4 hr Made up BHA no. 3 19:00-00:00 5 hr R.I.H.to 10100.0 ft 17 Mar 98 00:00-05:00 5 hr Circulated at 10100.0 ft 05:00-06:00 1 hr Pulled out of hole to 9000.0 ft 06:00-09:30 3-1/2 hr Pulled out of hole to 779.0 ft 09:30-12:00 2-1/2 hr Pulled BHA 12:00-20:00 8 hr Ran logs on tubulars 20:00-03:00 7 hr Conducted electric cable operations 18 Mar 98 03:00-05:30 2-1/2 hr Conducted electric cable operations 05:30-06:00 1/2 hr Pulled out of hole to 3000.0 ft 06:00-10:00 4 hr Pulled out of hole to 0.0 ft 10:00-11:00 1 hr Serviced Block line 11:00-12:00 1 hr Serviced Top drive 12:00-13:00 1 hr Made up BHA no. 3 13:00-18:00 5 hr R.I.H.to 10100.0 ft 18:00-22:30 4-1/2 hr Circulated at 10100.0 ft 22:30-03:30 5 hr Pulled out of hole to 932.0 ft 19 Mar 98 06:00-06:30 1/2 hr Held safety meeting 06:30-18:30 12 hr Ran Casing to 10076.0 ft(9-5/8in OD) 18:30-22:00 3-1/2 hr Circulated at 10076.0 ft 22:00-01:30 3-1/2 hr Mixed and pumped slurry-578.000 bbl 20 Mar 98 01:30-05:30 4 hr Circulated at 2147.0 ft 05:30-06:00 1/2 hr Held safety meeting 06:00-08:30 2-1/2 hr Mixed and pumped slurry-623.000 bbl 08:30-12:00 3-1/2 hr Rigged down Casing handling equipment 12:00-14:30 2-1/2 hr Rigged down Divertor BP Progress Report Facility M Pt E Pad Well MPE-24 Page 3 Rig Nabors 27E Date 16 December 98 Date/Time Duration Activity 14:30-15:30 1 hr Installed Casing head 15:30-21:00 5-1/2 hr Rigged up BOP stack 21:00-23:30 2-1/2 hr Rigged up BOP stack 23:30-03:30 4 hr Tested BOP stack 21 Mar 98 03:30-05:00 1-1/2 hr Rigged up Rig services 05:00-06:00 1 hr Made up BHA no.4 06:00-08:00 2 hr Made up BHA no.4 08:00-09:00 1 hr Serviced Draw works 09:00-10:30 1-1/2 hr R.I.H.to 2147.0 ft 10:30-11:30 1 hr Drilled installed equipment-DV collar 11:30-13:30 2 hr Drilled installed equipment-DV collar 13:30-16:30 3 hr Pulled out of hole to 0.0 ft 16:30-18:00 1-1/2 hr Serviced Top drive 18:00-18:30 1/2 hr Held safety meeting 18:30-23:30 5 hr Investigated pressure change 23:30-00:00 1/2 hr Pulled out of hole to 0.0 ft 22 Mar 98 00:00-02:30 2-1/2 hr R.I.H.to 0.0 ft 02:30-04:00 1-1/2 hr R.I.H.to 9000.0 ft 04:00-06:00 2 hr Repaired Top drive 06:00-09:30 3-1/2 hr R.I.H.to 8248.0 ft 09:30-10:00 1/2 hr Held drill(H2S) 10:00-13:30 3-1/2 hr Pulled out of hole to 0.0 ft 13:30-14:00 1/2 hr Serviced Top drive 14:00-16:30 2-1/2 hr R.I.H.to 2178.0 ft 16:30-18:00 1-1/2 hr Pulled out of hole to 0.0 ft 18:00-19:00 1 hr R.I.H.to 2166.0 ft 19:00-19:30 1/2 hr Held safety meeting 19:30-20:00 1/2 hr Mixed and pumped slurry-22.000 bbl 20:00-20:30 1/2 hr Pulled out of hole to 1415.0 ft 20:30-21:00 1/2 hr Reverse circulated at 1415.0 ft 21:00-21:30 1/2 hr Repaired Other sub-surface equipment 21:30-06:00 8-1/2 hr Wait on cement 23 Mar 98 06:00-10:30 4-1/2 hr Wait on cement 10:30-11:00 1/2 hr Pulled Drillpipe in stands to 1415.0 ft 11:00-12:00 1 hr R.I.H.to 1895.0 ft 12:00-15:00 3 hr Drilled cement to 2173.0 ft 15:00-15:30 1/2 hr Circulated at 2163.0 ft 15:30-16:00 1/2 hr Performed cement integrity test 16:00-18:00 2 hr Serviced Top drive 18:00-19:30 1-1/2 hr Drilled installed equipment-Bridge plug 19:30-20:00 1/2 hr Circulated at 2180.0 ft 20:00-21:00 1 hr R.I.H.to 3195.0 ft 21:00-21:30 1/2 hr Serviced Dolly track 21:30-03:30 6 hr R.I.H.to 9988.0 ft 24 Mar 98 03:30-04:30 1 hr Drilled installed equipment-Bridge plug 04:30-06:00 1-1/2 hr Circulated at 9990.0 ft 06:00-06:30 1/2 hr Circulated at 9990.0 ft 06:30-09:00 2-1/2 hr Pulled out of hole to 3008.0 ft 09:00-09:30 1/2 hr Circulated at 3008.0 ft 09:30-11:00 1-1/2 hr Pulled out of hole to 0.0 ft 11:00-13:00 2 hr R.I.H.to 3013.0 ft 13:00-15:00 2 hr Pulled out of hole to 0.0 ft 15:00-18:30 3-1/2 hr R.I.H.to 35.0 ft 18:30-00:00 5-1/2 hr Serviced Top drive S BP Progress Report Facility M Pt E Pad Well MPE-24 Page 4 Rig Nabors 27E Date 16 December 98 Date/Time Duration Activity 25 Mar 98 00:00-01:00 1 hr R.I.H.to 35.0 ft 01:00-05:00 4 hr Serviced Top drive 05:00-06:00 1 hr Held safety meeting 06:00-06:30 1/2 hr Held safety meeting 06:30-07:30 1 hr Made up BHA no.6 07:30-10:30 3 hr Milled Casing at 35.0 ft 10:30-11:00 1/2 hr Pulled out of hole to 0.0 ft 11:00-12:00 1 hr Serviced Top drive 12:00-12:30 1/2 hr Held safety meeting 12:30-14:00 1-1/2 hr R.I.H.to 2288.0 ft 14:00-15:30 1-1/2 hr Circulated at 2288.0 ft 15:30-17:00 1-1/2 hr Pulled out of hole to 0.0 ft 17:00-19:00 2 hr R.I.H.to 3002.0 ft 19:00-21:30 2-1/2 hr Pulled out of hole to 0.0 ft 26 Mar 98 06:00-05:30 23-1/2 hr Repaired DV collar 27 Mar 98 06:00-06:30 1/2 hr Tested Internal casing patch-Via annulus 06:30-11:00 4-1/2 hr Tested BOP stack 11:00-12:30 1-1/2 hr Rigged down BOP stack 12:30-18:00 5-1/2 hr Rigged down BOP stack 18:00-22:30 4-1/2 hr Rigged up BOP stack 22:30-06:00 7-1/2 hr Repaired Top drive 28 Mar 98 06:00-21:00 15 hr Repaired Top drive 21:00-23:00 2 hr Made up BHA no. 10 23:00-03:00 4 hr R.I.H.to 3225.0 ft 29 Mar 98 03:00-04:00 1 hr Pulled out of hole to 993.0 ft 04:00-06:00 2 hr R.I.H.to 7500.0 ft 06:00-08:00 2 hr R.I.H.to 9989.0 ft 08:00-12:30 4-1/2 hr Drilled installed equipment-Float shoe 12:30-13:30 1 hr Circulated at 10120.0 ft 13:30-14:00 1/2 hr Performed formation integrity test 14:00-16:00 2 hr Drilled to 10227.0 ft 16:00-18:00 2 hr Circulated at 10227.0 ft 18:00-06:00 12 hr Drilled to 10712.0 ft 30 Mar 98 06:00-06:30 1/2 hr Circulated at 10712.0 ft 06:30-10:30 4 hr Pulled out of hole to 993.0 ft 10:30-12:30 2 hr Pulled BHA 12:30-13:00 1/2 hr R.I.H.to 993.0 ft 13:00-14:00 1 hr Serviced Top drive 14:00-18:30 4-1/2 hr R.I.H.to 10712.0 ft 18:30-03:00 8-1/2 hr Drilled to 11557.0 ft 31 Mar 98 03:00-04:00 1 hr Circulated at 11557.0 ft 04:00-06:00 2 hr Pulled out of hole to 8900.0 ft 06:00-09:00 3 hr Pulled out of hole to 993.0 ft 09:00-10:00 1 hr Pulled BHA 10:00-11:00 1 hr Made up BHA no. 10 11:00-14:00 3 hr R.I.H.to 900.0 ft 14:00-15:00 1 hr Serviced Block line 15:00-15:30 1/2 hr Serviced Top drive 15:30-17:00 1-1/2 hr R.I.H.to 11557.0 ft 17:00-06:00 13 hr Drilled to 12773.0 ft 01 Apr 98 06:00-06:30 1/2 hr Held safety meeting 06:30-08:00 1-1/2 hr Pulled out of hole to 9800.0 ft 08:00-08:30 1/2 hr Serviced Top drive 08:30-10:00 1-1/2 hr R.I.H.to 12773.0 ft • 111 BP Progress Report Facility M Pt E Pad Well MPE-24 Page 5 Rig Nabors 27E Date 16 December 98 Date/Time Duration Activity 10:00-18:00 8 hr Drilled to 13522.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-21:30 3 hr Drilled to 13989.0 ft 21:30-22:30 1 hr Circulated at 13989.0 ft 22:30-23:30 1 hr Pulled out of hole to 12700.0 ft 23:30-00:00 1/2 hr R.I.H.to 13989.0 ft 02 Apr 98 00:00-04:00 4 hr Drilled to 14366.0 ft 04:00-06:00 2 hr Circulated at 14366.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-11:30 5 hr Pulled out of hole to 1000.0 ft 11:30-13:30 2 hr Pulled BHA 13:30-14:30 1 hr Serviced Top drive 14:30-19:00 4-1/2 hr Ran Drillpipe in stands to 14360.0 ft 19:00-19:30 1/2 hr Held safety meeting 19:30-20:30 1 hr Circulated at 14360.0 ft 20:30-21:30 1 hr Mixed and pumped slurry-51.000 bbl 21:30-22:00 1/2 hr Pulled Drillpipe in stands to 12960.0 ft 22:00-23:00 1 hr Reverse circulated at 12960.0 ft 23:00-06:00 7 hr Pulled Drillpipe in stands to 0.0 ft 03 Apr 98 06:00-06:30 1/2 hr Held safety meeting 06:30-10:30 4 hr Ran Drillpipe to 10009.0 ft(5in OD) 10:30-11:00 1/2 hr Set Cement retainer at 10009.0 ft with 0.0 psi 11:00-12:00 1 hr Mixed and pumped slurry-48.000 bbl 12:00-12:30 1/2 hr Pulled Drillpipe in stands to 9540.0 ft 12:30-13:30 1 hr Reverse circulated at 9540.0 ft 13:30-18:00 4-1/2 hr Pulled Drillpipe in stands to 0.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-22:00 3-1/2 hr Ran Drillpipe in stands to 6910.0 ft 22:00-22:30 1/2 hr Set Cement retainer at 6910.0 ft with 0.0 psi 22:30-23:30 1 hr Circulated at 6910.0 ft 23:30-02:00 2-1/2 hr Laid down 4900.0 ft of Drillpipe 04 Apr 98 02:00-03:30 1-1/2 hr Freeze protect well- 160.000 bbl of Diesel 03:30-06:00 2-1/2 hr Laid down 2063.0 ft of 5in OD drill pipe 06:00-06:30 1/2 hr Held safety meeting 06:30-08:00 1-1/2 hr Rigged down BOP stack 08:00-12:30 4-1/2 hr Installed Xmas tree 12:30-14:00 1-1/2 hr Removed Xmas tree • Schlumberger GeoGuest Schlumberger GeoQuest 3940 Arctic Boulevard Anchorage, Alaska 99503 Oct. 22, 1998 (907) 273-1700 (907) 561-8317 (Fax) TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the measurectdenth CDR.CDR LVD for well MPE-24.Job#98494 was sent to: BP Exploration (Alaska) Inc. E-TRANS- 10/15/98 Petrotechnical Data Center, MB3-3 3 Bluelines each 900 E. Benson Blvd. 1 Film each Anchorage, AK 99519-6612 State of Alaska 1 OH LIS Tape Alaska Oil &Gas Conservation 1 Blueline each Attn: Lori Taylor 1 Sepia each 3001 Porcupine Drive Anchorage, AK 99501 OXY USA Inc:` ----- __—---- — 1 OH LIS Tape Attn: Darlene Fairly 1 Blueline each P.O. Box 50250 1 Sepia each Midland, TX 79710 Sent Certified Mail: P 067 695 493 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotectnical Data Center MB3-3 3940 Arctic Blvd 900 E. Benson Blvd. Anchorage, AK 99503 Anchorage, Alask £. ED ATTN: Sherrie Date Delivered: OCT 22 1998 Received :�AAjA Alaska D l&Gas Cons.(.;ommission ' Anchorage 1 0 _ _ k » E E 0 2 co 7 a ) _ �1 j � 6" E 2 / . k � e � o k< q � � . 40 = 8 I • £ k . 3b ■ o - - E% 1 = .a. c % Z. c co282 ` Cl) 7@2 « « � « s ■ ° a \ k < co e2 � .c r) a) co = .0 ti § /Eo Cl) o \ S c Z U E mto < _ r- 0) otoon _ � � 2 Qq � � G22 � ( 13 222222222 0 0) 0 0 0) 0) 0 CO 0) § § § o 0 K 0 o w00 cc cc 0 a a. 2-.-.. ■ cc � 88 8 8 u, ` 0 cc 7.. Z \ 0 � P / § 0202 / § z a o - 000 ) O � -S2 § ` § ciEww < ww w ( ■ a a a aa. Pa a j « ` 2 - § ƒ .0 o a o U) 2 >. CCI- co m 0)0 .7 § §k �� Cr)7C ,7, cc k \ C _ %\ c@ ° �E7._ a t co=E m c _ w / k C ° o o ° �@ • o5 © � « = � � � §� � § § § w d ± _ aaaaa. aa. aa 222222222 w%o(u«U«a � 3 ®e03m± aE� - cq / E <\ § / w e _ 0Q_ = mac « e>kCDa 0 c � \/ R Q / \ 7 _ _ ' � J 0 3— Cr 04/02;98 12:25 FAX 907 564 5193 BP EXPLORATION AOGCC 3001 41113P EXPLORATION (ALASKA)W ANCHORAGE, ALASKA FAX it (907) 564-5193 TELECOPY COVER SHEET TO: Blair Wondzell COMPANY: AOGCC LOCATION: Anchorage FAX # : 276-7542 FROM: Kathy Campoamor SHARED SERVICES DRILLING LOCATION: ANCHORAGE, ALASKA PHONE #: 564-5122 PAGES TO FOLLOW: 4 DATE: 4-2-98 COMMENTS: 10-403 for MPE-24 per conversation with Lance Spencer • ,Rf WM) APR 0.2 ,8 e IF YOU DO NOT RECEIVE ALL PAGES,OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER: (907) 564-5122 04/02/98 12:25 FAX 907 564 5193 BP EXPLORATION AOGCC IZ002 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon ESuspend EPlugging ^Time Extension ❑Perforate J Alter Casing E Repair Well Pull Tubing ❑Variance n Other ❑Change Approved Program iE Operation Shutdown ❑Re-Enter Suspended Well Stimulate 2. Name of Operator 5. Type of well: 6. Datum Elevation(DF or KB) BP Exploration(Alaska)Inc. Development KBE-57.3' 3. Address ❑Exploratory 7. Unit or Property Name ❑Stratigraphic Milne Point Unit P.O. Box 196612,Anchorage,Alaska 99519-6612 ' ❑Service 4. Location of well at surface - 8. Well Number MPE-24 3613' NSL, 1936'WEL,SEC.25,713N, R10E,UM 9. Permit Number At top of productive interval 98-39 N/A 10.API Number At effective depth 50-029-22867 2664' SNL,3617'WEL,SEC.6,712N, R11E,UM 11. Field and Pool At total depth Milne Point Unit/Schrader Bluff 2664'SNL,3617'WEL,SEC.6,T12N. R11 E,UM - 12. Present well condition summary Total depth: measured 14366 feet Plugs(measured) true vertical 6563 feet Effective depth: measured 14366 feet Junk(measured) true vertical 6563 feet Casing Length Size Cemented MD TVD Structural Conductor 75' 16" 250 sx Arcticset I(Approx.) 112' 112' Surface 10041' 9-5/8" 2823 sx PF'E',562 sx Class 'G' 10077' 4500' Intermediate Production Liner t fl,R E C E I VV E D AP ; 021998 Perforation depth: measured N/A SS;; ,',,, true vertical Alaska Oil&Oaelen Anchorage ommissio Tubing(size, grade,and measured depth) N/A ORIGINALPackers and SSSV(type and measured depth) N/A 13.Attachments eiir �C Description summary of proposal El Detailed operations program "BOP sketch 14.Estimated date for commencing operation 15.Status of well classifications as: April 2, 1998 16.If proposal was verbally approved Oil ❑Gas Suspended Blair Wondzell 4/2/98 Service Name of approver Date approved- Contact Engineer Name/Number. Lance Spencer,564-5042 Prepared By NamelNumber. Kathy Csmpoamor,564-5122 17-I hereby certify that the fore. g is tru,/ d e ect to the best of my knowledge Signed T.Brent ReevesItle Drilling Engineering Supervisor Date1///,/ Commission Use Only Conditions of Approval: Notify Commission so representative may witness Approval No- ')S— Plug integrity r BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- s4r 7 OrigillalSi�jl; Approved by order of the Commission David W. �lohiiti;ff Commissioner Date Form 10 403 Rev. 05/15/88 Sub it I Triplicate Approved Copy �� Fed 04/02/98 12:26 FAX 907 564 5193 BP EXPLORATION -) AOGCC 0003 • 0 MP E•24 Proposed Summary of Operations for Shut-down Milne Pt. Well#MP E-24 was drilled by NABORS RIG#27E to a depth of 14,366' md. LWD logs revealed the that the KUPARUK SANDS are "Water WET" therefore non-productive. It is requested that KUPARUK SANDS be abandoned at this location and operations be shut down. Current Status: The 9-5/8', 40#, L-80, BTC casing was set at 10,076' and and 8-1/2" hole was drilled to 14,366'. 1_ POOH after TD Milne Pt Well## MP E-24. 2. PU 5" muleshoe. RIH on 5" drillpipe to TD at 14,366' and (ESTIMATED TOP KUPARUK SANDS 14,110' MD . Circulate and condition hole for cement plug. Spot 51 bbls balanced cement plug. i,), Mf_ 4,1. u'I; y Vi' ;, `{ At 15 stands above the plug ng up and reverse out cement. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. NOTE: Volume based on 8-1/2" hole from TD at ' and to 300' above KUPARUK SAND at 13,810' and +30%. EST TOC after plug set is 13,343' md. PREMIUM G+0,20%HALAD 344+0.20%CFR3+HR5 AS NECESSARY WT: 15.8 PPG YIELD: 1.15 FT3/SK 3. POOH to surface and lay down mule shoe. Pick up HES EZSV and TIH on drill pipe . TIN with retainer and set EZSV at 10,000'±.. Establish injectivity. Un-sting from retainer. Circulate down To Spot 30 bbl high visc mud pill (weight of pill at current mud weight) and cement. Sting into retainer. Pump viscous pill followed by 33 bbls of cement. Un-sting from retainer and spot 15 bbls balanced cement plug on top of retainer. Estimated TOC after setting balanced plug is ® 9,800'. Estimated bottom of cement © 10,376' NOTE: Cement volume equals: 1) 300' of 8-1/2" open hole below the shoe +30% excess (27.4 bbls),and 2) approximately 76' capacity of 9-5/8" casing from shoe to retainer (5.8 bbls ) and 3). capacity of 9-5/8" casing from to 200' above retainer (15.2 bbls). Total cement volume. 27.4+5.8+ 15.2)=48.2 bbls PREMIUM G+0.20%HALAD 344+0.20%CFR3+ HR5 AS NECESSARY WT: 15.8 PPG YIELD: 1.15 FT3/SK 4. POOH with drill pipe and EZSV setting tool. PU and RIH with CIBP on drill pipe and set at 6,900. 5_ Displace mud with 8.6 ppg seawater. Freeze protect 9-5/8"to 2200' md/ 6. ND BOP E. NU and Test Tree. RDMO Nabors 27E drilling rig to drill next well. 4-.--- --i---- Z 4r-• 7 y e Lance Spencer Date ••- :tions Drill'•• n•i•-er I� � . / /VP, =rent • -4 ves :1 e p( A vi Arr //.4_,.-- Pa.l 'mice Date REcE,IV ED Drilling Superintendent APR Ga1998 gkq Oil&Gas Cons.Commission , ATI,C_Wage MP C-25Ai PAGE 1 04/02/98 12:26 FAX 907 564 5193 BP EXPLORATION AOGCC ( 1004 11110 • Casing/Liner Cementing Summary-STAGE II Well IPL-40 Rig Nabors 27E Date 228/98 Started nt 20:30 HRS 2/27/98 265K lbs up On bottom nt 05:00 FTRS 228//98 String wt on bottom 150K lbs down CASING!LINEE SUMMARY: Size 9.5/8^ Connection Jts DTC _ - 182 Type 408 L-80 BTC Makeup Torque 9,000 ft-lbs THREAD LOCK:on bottom 3 Jts CENTRALIZER SUMMARY: Size 9-5/8"X 12" 21St on Its - Type How Spring 1/it on Jts 1 13 Total Used 15 1/Jt on Its 131 & 132 Cement Baskets INSERT FLOAT EQUIPMENT: Landing Collar:DTM OF JT# 3 CID 7,475 Float Collar:TOP OFIT# 1 /9 7,516 Float Shoe:01M OF IT# 1 a 7.560 ES Cementer: SIZE 9-5/8 ® 2.139 LINER HANGER AND PKR DESCRIPTION ID 13CR or LSO Manufacturer Hydraulic Liner Hanger NA _ Liner Top Packer Setting Sleeve Tie Beck Exteassion: Length Manufacrurer CEMENT SUMMARY STAGE II Cog on bottom at 05:00 1-IRS 2/28/98 Circulated for 3:30 F1rsNin 1^umped spacer/eweep: bbls of PPE. from to Circulated sweep so bpm, Pumped spacer/sweep! bbls of ppg. to Circulated sweep at bpm. Pumped spacer/sweep: bbls of ppg. from to Circulated sweep at bpm. Describe any hole problems: Opened ES Cementer w/2750 psi.Cue w/full returns. 200 Bble.contaminated mud/Cement to surface after crania cementer. Circ.Holc while waiting on Guzzlers.No losses- romped prellu-C11: 70 bbls ofWater 8.3 ppg. Pumped pretlu.ch: bbls of ppg. Pumped prefush: bbls of ppg. Start mixing tx:ment at 1430 HRS. Bottom plug used? Stg H cmt volume based on 2139"-Surface plus 250 %excess. Mixed and pumped cement 463 bbls of Permafrost"E" 12.0 ppg. 2604 cu.ft. 1200 SX Cement Additives: Amount Units/Additive Amount Units/Additive • Tail cement volume based on plus %GAGGER. Mixed and pumped cement bbls of ppg. cu.ft. SX Cement Additives: Amount Unita/Additive Amount Units/Additive Follow with water- 10 bbls. Drop plug. Displace with 152 bb1S water. Calculated displacement was: 162 _bbls. Bump plug. Yes Set banger with psi. Set liner top packer with psi Float equipment held? Yes Field cement test: Yes 2/24/98 CI?at 16:30 HRS. DATE; 228/98 Reciprocated pipe during job? No Pump rate while mixing was 7.5 BPM /9 750 psi Pump rate while displacing WAS 12 BPM 3 600-900 psi Released off hanger. Reversed out? NA COMMENTS; Frill returns during Job.170 bbls 12.0 ppg cement to surface.Bumulg CO 2800 psi-OIC Floats held.Cementer held-OK. Revised: 11/10/93 by KKS Rig Supervvisor. Peter Wilson 04/02/98 12:26 FAX 907 564 5193 BP EXPLORATION AOGCC 0 005 41111 411 Casing/Liner Ccmendng Summary-STAGE I Well MPL-40 Rig Nabors 27E Date 2/28/98 Started at 20:30 HRS 2/27/98 265K lbs up On bottom nt 05:00 FIRS 2/28/98 String wt on bottom 150K lbs down CASLNG/LINER SUMMARY: Size 9-5/8" Connection;Jts ETC - 182 Type 40#L-80 BTC Makeup Torque 9,000 ft-lbs THREAD LOCK:on bottom 3 Its CENTRALIZER SUMMARY: Size 9-518-X 12" 2/Jt on Its Type Bow Siring 1/Jt on its 1 - 13 Total Used 15 1/Jt on Jts 131 - 132 Cement Baskets INSERT FLOAT EQUIPMENT: Landing Collar BTM OF T1# 3 @ 7,475 Host Collar.TOP OF JT; I @ 7,516 Float Shoe:ETM OF TT# 1 (/ 7,560 ES Cementer: SIZE 9-5/8 @ 2139 LINER HANGER AND PKR DESCRIPTION ID 13CR or L80 Manufacturer Hydraulic Liner Hanger NA " Lincr Top Packer " Setting Sleeve Tic flack Extension: Length ' Manufacturer CEMENT SUMMARY STAGE I Csg on bottom at 05:00 HRS 2/28/98 Circulated for 2:30 Hrs/Min Pumped spacer/sweep: bbls of ppg. from to Circulated sweep at bpm Pumped spacer/sweep: bbls of ppg. from to Circulated sweep at bpm. Pumped spacer/sweep: bbls of PPg. from to Circulated sweep at bpm. Describe any bole problems: No problems,No losses W/Rlli Cire @ 12 bpm w/1100 psi and no losses, Reciprocated Pipe.Pumped 1400 bbls. Pumped prefInsh: 75 bbls of Water 8.3 ppg. Pumped preflush: bbls of ppg, Pumped preflush: bbls of ppg. Start mixing cement at 08:45 HRS. Bottom plug used? Yes Stg.I cement voL based on 5,500'to 2,139' plus 30 %excess, Mixed and pumped cement 260 bbls of Permafrost E 12 ppg- 1410 cu.ft. 650 SX Cement Additives: Amount Units/Additive Amount Units/Additive Tail cement volume based on 7,585'-5,500' plus 30 %excess. Mixed and pumped cement 157 bbls of Premium"C" 15.8 ppg. 860 cu.ft. 750 SX Cement Additives: Amount Units/Additive Amount Units/Additive ,15#/sk Cello-Flake _ 0.20% CFR-3 0.20% HALAD 344 b 4 Follow with fresh water: 10 bbls. Drop plug, Displace with 556 bbis water. Calculated displacement was: 566 bbls. Bump plug. Yes Set hanger with psi_ Set liner top packer with psi. Float equipment held? Yes Field cement test: Yes 2/24/98 CIP at 11:00 FIRS. DATE: 02/28/98 Reciprocated pipe during job? Yes Pump rate while mixing was 7 RPM @ 900 _ ps1 Pump rate while displacing was 12 BPM @ 800»».1600 Released off hanger. Reversed out? NA COMMENTS:Full returns entire job. Bumped plug to 2000 psi.Floats held,Cement in place @ 11:00 Opened cementer with 2750 psi. Revised: 11/10/93 by KKS Rig Supervisor: Peter Waren • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns , DATE: March 27, 1998 Chairma THRU: Blair Wondzell, FILE NO: awgkc1fe.doc P. I. Supervisor #(2198 FROM: Chuck Scheve, cS SUBJECT: BOPE Test Petroleum Inspector Nabors 27E MPU E-24 PTD # 98-639 Friday March 27, 1998: I traveled to Nabors Rig 27E and witnessed the initial BOPE test on well MPU E-24. As the attached AOGCC BOPE test report shows,the test lasted 8 hours with one failure. The first valve up stream of the Hyd. Choke failed to pressure test; this valve was repaired and retested prior to drilling the surface casing shoe. The extended test time was due to problems with the triplex test pump. I also witnessed the successful 30 minute 1200 psi pressure test of the casing patch run in this well to repair a leaking EZ cementer. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: I witnessed the initial BOPE on Nabors rig 27E drilling BPXs MPU E-24 Well. Nabors 27E, 3/27/98, Test Time 8 hours, one failure Attachment: awgkc1fe.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential • STATE OF ALASKA 4110 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report I, 9(6-'-' p3/ OPERATION: Drlg: X Workovers DATE: 3/27/98 Drlg Contractor: Nabors Rig No. 27E PTD# 98-039 Rig Ph.# 659-4373 Operator: SSD Rep.: Paul Lockwood Well Name: MPU E-24 Rig Rep.: Richard Larkin Casing Size: 9 5/8 Set @ Location: Sec. 25 T. 13N R. 10E Meridian UM Test: Initial X Weekly Other TEST DATA Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign OK Upper Kelly/IBOP 1 250/5,000 P Housekeeping: OK (Gen) DrI. Rig OK Lower Kelly/IBOP 1 250/5,000 P PTD On Location YES Hazard Sec. OK Ball Type 1 250/5,000 P Standing Order Posted YES Inside BOP 1 250/5.000 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 250/3500 P CHOKE MANIFOLD: Pressure P/F Pipe Rams 1 250/5,000 P No.Valves 16 250/5,000 P Lower Pipe Rams 1 250/5,000 P No. Flanges 32 250/5,000 F/P Blind Rams 1 250/5,000 P Manual Chokes 2 Functioned P Choke Ln.Valves 1 250/5,000 P Hydraulic Chokes 1 Functioned P HCR Valves 2 250/5.000 P Kill Line Valves 1 250/5.000 P ACCUMULATOR SYSTEM: Check Valve N/A System Pressure 3000 Pressure After Clue-re 1800 MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 20 sec. Trip Tank OK OK System Pressure Attained 1 minutes 40 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. BtI's: 8 @ 2200 PSI Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK TEST RESULTS Number of Failures: 1 ,Test Time: 8.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No.659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: One valve on choke manifold failed to pressure test. Long test time due to test pump failures. Distribution: STATE WITNESS REQUIRED? Waived By: orig-Well File YES X NO _ c-Oper./Rig Witnessed By: Chuck Scheve c- Database 24 HOUR NOTICE GIVEN c-Trip Rpt File YES X NO c- Inspector FI-021 L(Rev.12/94) awqkclfe _ _ • IP TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3192 PHONE: (907)279-1433 FAX: (907)276-7542 March 3. 1998 Chip Alvord Engineering Supervisor BP Exploration (Alaska) Inc. P 0 Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPE-24 BP Exploration (Alaska) Inc. Permit No.: 98-039 Sur. Loc: 3613'NSL, 1937'WEL. Sec. 25. TI3N. RIDE. UM Btmholc Loc: 3191'NSL, 2956'WEL. Sec. 6, TI2N. RI IE. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies. and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. .nc rely, 4111ftalk _ 111411111111111114 .....,,,, 44-1c, ,, No - David ' Johnston Chairman BY ORDER OF THE COMMISSION dIEenclosures cc: Department of Fish&Game.I labitat Section Iwo encl. Department of Environmental Conservation sc o encl. nuit- � STATE OF ALASKAII ALASKA L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ®Drill ❑Redrill 1 b. Type of well ❑Exploratory ❑Stratigraphic Test ®Development Oil ❑Re-Entry ❑Deepen ❑Service ❑Development Gas ❑Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE=57.3' Milne Point Unit/Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612,Anchorage,Alaska 99519-6612 ADL 380110 t/ 4. Location of well at surface �� */foM�C��. �`rte I4 t 7. Unit or Property Name 11.Type Bond(See 20 AAC 25.025) 3613' NSL, 1937'WEL, SEC--8;T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1895' NSL, 2343'WEL, SEC. 36,T13N, R10E, UM MPE-24 At total depth 9. Approximate spud date Amount $200,000.00 3191' NSL, 2956'WEL, SEC. 6,T12N, R11 E, UM 03/05/98 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) ADL 380109, 1804' No Close Approach 2560 14518' MD/7125'TVD 16.To be completed for deviated wells 17.Anticipated pressure(see 20 AAC 25.035(e)(2)} Kick Off Depth 300' Maximum Hole Angle 75.76° Maximum surface 2841 psig, At total depth(TVD) 7102'/3551 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 10004' 31' 31' 10035' 4424' 2220 sx PF 'E', 562 sx 'G' 8-1/2" 7" 26# L-80 Btrc-Mod 14488' 30' 30' 14518' 7125' 196 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 Production h E I V D Liner i..t.L7 2 1998 Perforation depth: measured ORIGINAL Alaska Oil 3 Gas Cons.Commission Anchorage true vertical 20.Attachments ®Filing Fee ❑Property Plat ❑BOP Sketch 0 Diverter Sketch ®Drilling Program ®Drilling Fluid Program ❑Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report ❑20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer,564-5042 Prepared By Name/Number: Kathy Campoamor,564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /j Chip Alvord /„C�, _ tr” 01-( Title Engineering Supervisor Date 20_6.(1` Commission Use Only Permit Number API Number Ap r v to See cover letter 61.N— 01 9 50-O�.ci— Al y 0— 0 U �I D for other requirements Conditions of Approval: Samples Required ❑ ui e Yes IgNo Mud Log Reqd ❑Yes 12f-No Hydrogen Sulfide Measures ❑Yes ErNo Directional Survey Required JYes ❑No Required Working Pressure for BOPE ❑2M; ❑3M; IN15M; ❑10M; ❑15M Other: Original Sig:,en t i'i by order of Approved By David W. Johnston Commissioner the commission Date"S —i CN Form 10-401 Rev. 12-01-85 Sub t In riplicate I , STATE OF ALASKA ALASKA SAND GAS CONSERVATION COrSSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ®Drill ❑Redrill lb. Type of well ❑Exploratory ❑Stratigraphic Test ®Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone ❑Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska)Inc. Plan KBE=57.3' Milne Point Unit/Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612,Anchorage,Alaska 99519-6612 ADL 380110 4. Location of well at surface ).s-. A-t pv iJ,tie I ivv N0 1114-t 7. Unit or Property Name 11.Type Bond (See 20 MC 25.025) 3613' NSL, 1937'WEL,SEC..8,T13N,R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 25100302630-277 1895' NSL,2343'WEL,SEC.36,T13N, R10E, UM MPE-24 At total depth 9. Approximate spud date Amount $200,000.00 3191' NSL,2956'WEL,SEC. 6,T12N, R11 E, UM 03/05/98 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and ND) ADL 380109, 1804' No Close Approach 2560 14518' MD/7125'TVD 16.To be completed for deviated wells 17.Anticipated pressure(see 20 AAc 25.035(e)(2)) Kick Off Depth 300' Maximum Hole Angle 75.76° Maximum surface 2841 psig, At total depth(TVD) 7102'/3551 psig 18. Casing ProgramSetting Depth Specifications Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD ND MD ND (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 10004' 31' 31' 10035' 4424' 2220 sx PF 'E', 562 sx 'G' 8-1/2" 7" 26# L-80 Btrc-Mod 14488' 30' 30' 14518' 7125' 196 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 MD ND Casing Length Size Cemented Structural Conductor Surface Intermediate L .. ! Production ' ,. Liner t, c! Alaska 011,P r, Cu Perforation depth: measured t�Og3tn1& �'?C.t10f,��8, true vertical 20.Attachments ®Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch ®Drilling Program ®Drilling Fluid Program ❑Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report ❑20 MC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer,564-5042 Prepared By Name/Number: Kathy Campoamor,564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed nn// Chip Alvord /4,4_ e- Title Engineering Supervisor Date 2.(LO t 2c3 Commission Use Only Permit Number _ API Number Approv I Date See cover letter 01 8- 0 1 50- 0)..°1 - XI e(0-1 -00 ) /9S for other requirements Conditions of Approval: Samples Required ❑Yes 12I No Mud Log RequiredYes [ANO Hydrogen Sulfide Measures 1=] [; Yes 'No Directional Survey Required ,,Yes 0 No Required Working Pressure for BOPE ❑2M; ❑3M; j$5M; ❑10M; ❑15M Other: Signe()( ,�i_I Sign60 tJ, by order of , Commissioner the commission Date � Approved By iCy �t�f. Johnston ` , Form 10-401 Rev. 12-01-85 Submit In Triplicate • S . Shared Services Drilling Contact: Lance Spencer 564-5042 Well Name: MP E-24 Well Plan Summary Type of Well (producer or injector): Kuparuk Producer 25 Surface Location: 3613' NSL, 1937'WEL, Sec. 08, T13N ,R10E, UM., AK Target Schrader Bluff 1895' NSL, 2343' WEL, Sec. 36, T13N, R10E, UM., AK Target Kuparuk 3275' NSL, 2930'WEL, Sec. 06, T12N, R11 E, UM., AK Bottom Hole Location: 3191' NSL, 2956' WEL, Sec. 06, T12N, R11 E, UM., AK AFE Number: 337 Rig: Nabors 27-E Estimated Start Date: 5 March 98 Operating days to complete: 17 MD: 14,518' TVD: 7,125' Bkb KBE: 57.3' Well Design: Ultra Slim Hole Long String HAW 9-5/8", 40#Surface X 7", 26# Production Formation Markers: Formation Tops MD TVD (ss) EMW Formation Pressure Base Permafrost 1945 1800 8.4 ppg 786 psi NA Top Schrader Bluff 9033 4075 8.4 ppg 1780 psi OB Base Schrader Bluff 9805 4295 8.4 ppg 1876 psi Top HRZ 13648 6250 8.8 ppg 2860psi Base HRZ 13754 6350 8.8 ppg 2906 psi TKLB(MK-19) 13871 6460 9.4 ppg 3158 psi TKUD 14047 6625 9.4 ppg 3238 psi TKUC 14259 6825 9.6 ppg 3412 psi TKUB8 14286 6850 9.6 ppg 3425 psi TKUB7 14291 6855 9.6 ppg 3427 psi TKUB6 14318 6880 9.6 ppg 3440 psi Total Depth 14518± 7068± 9.6 ppg 3534 psi • *These are estimated maximum pressures and the actual pressures may be lower. Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDlTVD MDlTVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 10,004 31/31 10,035/4,424 8-1/2" 7" 26# L-80 Mod. 14,488 30/30 14,518/7,125 btrc The internal yield pressure of the 7" 26#casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKB2 at ±7,102 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of ±7,102 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,551 psi is 2,841 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7"casing. MP E-24 (E-P) Drilling Permit 1 2/25/98 • 0 • Cementing Program: Halliburton Cementing Services Hole Casing Interval Volume' Spacer Type of Cement Properties` Category Size/Depth Surface Lead" Lead Lead Lead First Stage 9-5/8" @ 2,145-8,533 1199 sx 70ebbls Permafrost"E" Den 12.0 ppg 9 10,035 water Yield 2.17 ft 3/sx Water 11.63 gps TT 4.0 hrs 8,533- Tails Tail Tail 10,035' 562 sx Premium Class"G"w/ Den 15.8 ppg 115 bbls 0.2%CaCI, Yield 1.15 ft 3/sx 0.15#/sk Celoflakes Water 4.9 gps TT 4.0 hrs Second Stage Leadb Lead Lead Lead Stage collar @ 0-1,945' 1021 sx 75 bbls Permafrost"E" Same as above 2,056' 1,945-2,145' 394 bbls Fresh water Production 7"@ 13,249- Lead" Lead Lead Den 15.8 ppg First Stage 19,704 14,518' 196 sx 50 bbls. Premium Class"G"w/ Yield 1.15 ft 3/sx 41 bbls Alpha 0.2%CFR-3 Water 5.0 gps Spacer 0.1%HR-5 TT 3,5-4.5 hrs @140°F 50 bbls 0.45%Halad 344 FL 50cc/30 min Foamed @140°F Alpha Spacer 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8"csg.200'and below the base of the Permafrost at 2,145'MD± 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,145-8,533" md. The estimated first stage lead cement volume from 2,145-8,533" and is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,145' and which is 200 ft and below Base of the Permafrost at 1,945' and(1,857 TVD bkb)to 8,533' and which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 8,533-10,035' and The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 8,533' (500' and above the NA top) to surface TD at 10,035" and (4,425' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8",40#casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-2,145' and The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,145' MD (2,018'TVDbkb)to surface. From 1,945'to surface include 250%open hole excess and from 1,945-2,145' use a 30% open hole excess. 7. Install one(1) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8"casing(required). 8. If the Schrader Bluff is productive install one(1) Bow Spring Centralizers per joint from 9033-10,035' of 9-5/8" casing to cover the top of the NA to Base OB. 9. The production hole will be cemented in a single stage. The Cement Volume covers the interval from 13,259-14,518' and The estimated first stage tail cement volume is equivalent to the annular volume calculated from 13,259"which is 1000'± above the Kuparuk C Sand to TD at 14,518" plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 26#casing. 10. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from 120' above the Kupaurk C-Sand and use two per joint on the shoe joints. 11. Run two(2)7 x 8-1/4"Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8"casing. 12. Install two 7"marker joints and position three joints above the Kuparuk C sand. 13. Place all centralizers in middle of joints using stop collars. 14. Mix all cement slurries in the surface and production holes on the fly-batch mixing is not necessary. MP E-24 (E-P) Drilling Permit 2 2/25/98 • 1110 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP)from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A Final Production 1. M10 Power Plus MWD Directional 8-1/2" 2. LWD (CDR/AND/GR/ROP) (Real Time) 3. DWOB/DTOQ Cased Hole Logs: N/A Mud Logging Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus Directional Inclination and Azimuth IWOB: DWOBB/DTOQ GR: Gamma Ray CDR: Compensated Dual Resitivity ADN: Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) ROP: Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss cyo 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH API HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-9.3 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 <6 Production Mud Properties from HRZ to LSND Freshwater Mud TD. Density Marsh Yield 10 sec 10 min pH API HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 9.3-9.6 35-45 6-20 3-10 7-20 8.5-9.5 <4 8-10 for <6 HRZ Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures.The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. MP E-24 (E-P) Drilling Permit 3 2/25/98 • i Directional: KOP1 300' Start Variable @ 1.0°-2.5°/100 to 75.76° inc. and 197.11°az. EOB C�3 3,621' md. Tangent Hole Angle 75.76°from 3,621-11,512' Build Section to Start Final Curve 11,512' CO 2.5°/100 to 20° incl. and 197.11 Az° EOD 11,512' Horizontal and Maximum Hole Angle 75.76°from 3,621-11,512'. Close Approach Wells All wells may remain flowing while drilling E-24 and no shut-ins are required. Survey Program 1. Surface to 10,035' MWD surveys. 2. 10,035-12,035' MWD surveys 3. 0-12,035' GYRO to surface 4. 12,035' TD MWD with in hole reference correction. 5. 100354TD --44)- tVWF10,after Nabors 27E RDMO. Disposal: No "Drilling Wastes"will be injected or disposed into E-24 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305)with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPU E-24 is planned as high angle 75°, Kuparuk River A Sand producer with a final departure of 11,089' and a measured depth 14,518'. The S-shaped well profile with a final angle of 20°, will intersect the targets in the Schrader Bluff and Kuparuk for optimum production.The surface casing will be deep set below the Schrader Bluff at 10,035'md (4,424' bkb)to isolate the Ugnu and Schraber Bluff from the Kuparuk interval. Geology This well is located to south of E-Pad. The primary targets are the Kupauuk C and B sands with some potential in the Schrader Bluff sands. The deepest known oil in the area is at H-05 at a depth of 7,780' tvd ss. The water contact is expected at 7,045'. The OWC's in the surrounding blocks are 6717 tvdss (south) and 7045' tvdss (east and south). There is only a 30%chance that sufficient productive hydrocarbons will be present at this location and sidetracking to an alternative location is likely. Due to the proximity to and severity of faulting in the area the well profile, drilling target, and survey program have been designed to avoid crossing faults to the north and south of the planned target and bottom hole locations. Recoverable reserves associated with this producer are 1.45 MBO primary and 0.05 MBO from EOR assuming 120 acre drainage area. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be virgin reservoir pressure for the producing scenario (3500 psi at 7000' tvd, 9.6 ppg EMW) in the Kuparuk formation. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk target section. Close Approaches There are no close approaches associated with the drilling of MP E-24, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Injection There is no injection in Hydraulic Unit#41 into which MP E-24 is planned: Annular Injection Currently annular injection is not permitted on E-Pad. MP E-24 (E-P) Drilling Permit 4 2/25/98 • i Lost Circulation: Lost circulation is prevalent while running casing and cementing in the surface but also occurs in the production hole. Losses are extremely probable while cementing the production casing in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing to bottom. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole, bridging, and stuck casing. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk D Shale. This common occurrence has often caused difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Shale instability is possible in the Miluveach and may result in tight hole or packing off so preventative measures must be taken to alleviate this risk if the Miluveach is inadvertently entered. Differential sticking is most likely to occur while running the production string. Formation Pressure: KUPARUK Al SAND 6,825'TVDss 3,412 PSI 9.6 PPG EMW Formation pressures are expected to be normal and the pore pressure is estimated at 9.6 ppg EMW.The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at ± 7102' TVDss. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of ±7,102' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,551 psi is 2,841 psi. The maximum expected pore pressure for this well is 9.1 ppg EMW (3,494 psi @ 7,102' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on`L pad and review recent wells drilled on L Pad. MP E-24 (E-P) Drilling Permit 5 2/25/98 • • MP E-24 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20 Conductor. Weld an FMC landing ring for an FMC Gen 5A Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ)from surface to 12-1/4"TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2,056' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform the Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume during the LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 250' of production rat hole between the top of the Kuparuk A3 sand (after inverting back thru it) and PBTD before running the 7"casing. 11. Run 7"casing. 12. Perform Single Stage Cement Job. Complete the production casing cementing check list. 13. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2200' MD). 14. Test casing to 3500 psig. 15. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 16. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. 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SHARED SERVICES DRILLING 6500 MPE-24 (P05) Tu.-To• s. it-6n ----- - --- ---- ----- -----' VERTICAL SECTION VIEW 6650 Section at: 187.42 TVD Scale.: 1 inch 100 feet _ Dep Scale.. 1 inch 100 feet 6600 Drawn. : 18 Feb 1998 6650Anadr111 Schlumberger ac T fi L>1- Marker Identification MO BKB SECTN INCLN! 6700 AI KUPARUK TARGET 14259 6882 11002 20.001 8) TO / 7' CASING PT 14518 7125 11089 20.00 6750 T ;. v 6800 D 6850 ' II ' - u:6-'i Tg 1FEadiu5 100 fees ) r1---m— - immil 6900 TVza— 6950 -'- TK$�-.. 1111111111m 10111 I • 7000 ._ ---- TKB *lb IIIII1M — 7050 - --- i 7100 11111 Mil MIL Ill . ita'r--iso • i II B 7150 1 RArvii. titC\/.4 ,t I 1111111 7.250 r milliti=11111 7300 7350 i 1 7400 10700 10750 10800 10850 10900 10950 11000 11050 11100 11150 11200 11250 11300 11350 11400 Section Departure _ ,,._— VL( 1V1 1 JJV 1 r . YJ J0 r .7`+'i-4100 HIYHLKILL LI-'L. HAUL Ob 1 • • SHARED SERVICES DRILLING Marker Identification MO m/s E/W M P E-2 4 (P05) •�y�l `t B) KOP/CURVE 1/100 300 O N 0 E A PLAN VIEW Cl CURVE 1.5/100 500 3 5 2 W ,,T '� 0) CURVE 2/100 700 12 S 10 W E) END 2/100 CURVE 1921 406 S 84 W 1 CLOSURE : 11090 feet at Azimuth 188A) F) CURVE 2.5/100 1969 434 5 87 W DECLINATION ' +27.858 fE) G) END 2.5/100 CURVE 3621 1757 S 176 w H) CURVE 3/100 9133 7095 S 409 W SCALE : 1 inch = 1800 feet I) END 3/100 CURVE 9620 7554 S 487 W DRAWN ; 18 Feb 1998 J) SCHRADER TARGET 9933 7838 S 575 W • K) 9-5/8" CASING PT 10035 7930 S 603 W L) CURVE 2.5/100 11572 9325 S 1033 W M) END 2.5/100 CURVE 13639 10695 S 1454 W N) KUPARUK TARGET 14259 10897 S 1517 W Anadri ll Schlumberger 0) TO / 7" CASING PT 14518 10982 S 1543 W - 900 - z a a 0 x 0 i 9 -_, 1; . v 900- -- —I-- 1800 I 0 I 7 2700 ——,,. ,.._,...�......... . . .._..--_.—_.-..i.— 3600 1 4500 - -- — 5400 1 6300 1..—' -hrader Tgt (Radius :00 feet 0 7200 II f 8100 lkj ! ANADf21LL A KA_Dpt' ._ APPROVED FOR PERM 9000 L ONLY PLAN. # „,._a_ 9900 „�.. ,� ... M".1 Pi Tgt (Radius 100 eat ) 10800• )4 11700 6300 5400 4500 3600 2700 1800 900 o 900 1800 2700 3600 4500 5400 300 <- WEST : EAST -> DATE CHECK NO. H 132696 01/06/98 00132696 VENDOR ALASKAST 14 00 DATE INVOICE/CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 010598 C140105961 100. 00 100. 00 HANDLING INST: s/h kathy campoarnor x 5122 HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL 100 00 1 00 00 „Ai o DO NOT WRITE IN THIS SPACE U U) a�a o To u) ow a o LI- O i C u) m LL ❑ LL O °) z N O N N O .a u a) co no. rC -`- rn m > U) ct ° 4t < ❑ i— g a z w a) 2 Q cC0 0 c 0 To 0 U ti., a” m.2 J 7c' N ill w cc Q o w, 0 Oz Z zzzzzzzzzzz z Z z z Z z Z Z Z Z Z Z Z - 0 I Z Z Z Z Z m U as •@ a) � : : _ 0 a� `oa y � o aci n mai co -t O !\ "' N . . C N O ai -.:z N T 0 -0 O 0 o� . E o N .d . O co a cn 7 N ui ' N O 2 U Q -c ca • • ` � 1) cnc )- cNo � 60 00a) � or. O AZO O .0 o N C 0 U . N m • O a a)a) in d C N 0 O 0 0 l 0 > o Z E Eoa c c E `' c c U ' 1- . c o ots ' m � c �Q .c 00 d O O -O 7 O 'D N ° m 7Q.n a•N.0 O .0 CD O > Ta • g � o 0 a .� c o5 �° Y N o 0Uo o (o o f 17,6 ...7.. �Q (�LoO T- 0 co 0 0 00 U . ai E ° <-" c1). c@ • 0 00 a — o c a� ° @ .. ° a3 al -0 L �° 01 Z lii' I— C (a to N a) FE (a U' C N L O O N O n O C ' W z ca c0 -) N •= ° nco 3 30 (n.� • 3 as mo ca °� a� (n 3 � � 4.- 0 w E- a� c m a) -c) c > v o ° m ° an m a (ca 00 m o a) 000 O o o oY oo w � nz Es °) ami n c Z ° n a) m � o > > a a ° a) a) •o o F.12 16 m E rno . a� m c o o 0 �_ J U m E O O a .N N �'0" U CD (a cOn_0 .` p>.c -p 3 2 u) o.N •� CO Z m 0 U (o -o -o U 'N C m s . •�U) U) > o t a) c w v)° U ° . C m qs a) O E N 2 U) U a3 "O O L C C ' O U no (a U a) a)_ N 7•o a)co C E. U C Cl.) (a W w C 3 300 1) 0 0 0 o E U a)o co — a)'a N N a) E N U d U e.) '� E uo) 6= -- a>i m `w E E c c'tf- HF- •uc-i Sri `- m•>-cEn a� o a E (a ,u�) u) c a� a) m o nn � `m m o °222 co-o a) -a-o •c00-c ° a) as m a) o ri F-� 0- � D555cnr-- 0oa_ � U Ucn0000<t= Q OmmU � a_ 0cncnU m� NM4 ([) (0N- COC) O � NM � (O (ON- )C)O NMs}' (17C N. () ) O� NMd' m NNNNNNNNNN MMMlMM C4 1 W z0-' '. CL . 0 --' .. Wa w 0 0(,,?.. o co w °° Z Z J a 0 - o 2 d 0 a Ow Lu o . it 0 < Z Q U` Q °x 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. r. MI CROFILML Date 1 / SO/0a • i g1 ****************************** * * * ALASKA COMPUTING CENTER * * * ****************************** * * * SCHLUMBERGER * } * * E /E OCT 2 2 1998 COMPANY NAME B.P. EXPLORATION Alaska Os!l Gas Cons.Commission WELL NAME : MPE-24 Anchorage FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22867-00 REFERENCE NO : 98494 • • LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 1 Schlumberger Alaska Computing Center **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/10/15 ORIGIN : FLIC REEL NAME : 98494 CONTINUATION # : PREVIOUS REEL . COMMENT : B.P. EXPLORATION,MILNE POINT MPE-24, API #50-029-22867-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/15 ORIGIN : FLIC TAPE NAME : 98494 CONTINUATION # : 1 PREVIOUS TAPE . COMMENT : B.P. EXPLORATION,MILNE POINT MPE-24, API #50-029-22867-00 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: MPE-24 API NUMBER: 500292286700 OPERATOR: B.P. EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 15-OCT-98 JOB DATA BIT RUN I BIT RUN 2 BIT RUN 3 JOB NUMBER: 98494 LOGGING ENGINEER: HETTINGER OPERATOR WITNESS: LOCKWOOD SURFACE LOCATION SECTION: 25 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 3613 FEL: 1937 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 57.10 DERRICK FLOOR: 57.10 GROUND LEVEL: 24.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.375 9.625 10077.0 2ND STRING • 1111 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 2 Schlumberger Alaska Computing Center 3RD STRING PRODUCTION STRING REMARKS: Well drilled 13-MAR through 02-APR-98 with CDR. Data was collected in one bit run. **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 6930.0 14637.0 BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE MWD 1 6930.0 10100.0 MWD 2 10044.0 10713.0 MWD 3 10649.0 11557.0 MWD 4 11407.0 14367.0 REMARKS: No depth adjustments were made to this data as it is the PDC for this well. This file also contains the Very Enhanced ORO resisitivity with 2' average that was reprocessed at GeoQuest. LIS FORMAT DATA II 4111 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 3 Schlumberger Alaska Computing Center ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** 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 4000230 00 000 00 0 1 1 1 4 68 0000000000 RA MWD OHMM 4000230 00 000 00 0 1 1 1 4 68 0000000000 RP MWD OHMM 4000230 00 000 00 0 1 1 1 4 68 0000000000 VRA MWD OHMM 4000230 00 000 00 0 1 1 1 4 68 0000000000 VRP MWD OHMM 4000230 00 000 00 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000230 00 000 00 0 1 1 1 4 68 0000000000 FET MWD HR 4000230 00 000 00 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000230 00 000 00 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 6930.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD 79.710 DEPT. 7000.000 RA.MWD 6.440 RP.MWD 5.840 VRA.MWD 6.214 VRP.MWD 5.959 ROP.MWD -999.250 FET.MWD 0.420 GR.MWD 65.200 DEPT. 7500.000 RA.MWD 29.700 RP.MWD 85.600 VRA.MWD 33.906 VRP.MWD 64.521 ROP.MWD 26.650 FET.MWD 0.152 GR.MWD 33.110 1111 I LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 4 Schlumberger Alaska Computing Center DEPT. 8000.000 RA.MWD 9.170 RP.MWD 10.950 VRA.MWD 12.264 VRP.MWD 12.697 ROP.MWD 353.210 FET.MWD 0.308 GR.MWD 62.830 DEPT. 8500.000 RA.MWD 3.920 RP.MWD 3.230 VRA.MWD 3.041 VRP.MWD 3.062 ROP.MWD 461.950 FET.MWD 0.588 GR.MWD 46.030 DEPT. 9000.000 RA.MWD 6.000 RP.MWD 6.140 VRA.MWD 6.709 VRP.MWD 6.817 ROP.MWD 187.550 FET.MWD 0.377 GR.MWD 66.670 DEPT. 9500.000 RA.MWD 5.360 RP.MWD 5.690 VRA.MWD 6.138 VRP.MWD 6.020 ROP.MWD 147.540 FET.MWD 1.740 GR.MWD 71.090 DEPT. 10000.000 RA.MWD 3.560 RP.MWD 3.310 VRA.MWD 3.240 VRP.MWD 3.180 ROP.MWD 200.160 FET.MWD 0.641 GR.MWD 71.700 DEPT. 10500.000 RA.MWD 3.080 RP.MWD 2.870 VRA.MWD 2.924 VRP.MWD 2.874 ROP.MWD 103.450 FET.MWD 1.267 GR.MWD 86.380 DEPT. 11000.000 RA.MWD 3.370 RP.MWD 3.360 VRA.MWD 3.431 VRP.MWD 3.391 ROP.MWD 239.990 FET.MWD 0.431 GR.MWD 98.600 DEPT. 11500.000 RA.MWD 3.020 RP.MWD 3.030 VRA.MWD 2.718 VRP.MWD 2.965 ROP.MWD 135.340 FET.MWD 0.404 GR.MWD 91.420 DEPT. 12000.000 RA.MWD 3.030 RP.MWD 2.900 VRA.MWD 2.852 VRP.MWD 2.888 ROP.MWD 93.260 FET.MWD 0.540 GR.MWD 102.550 DEPT. 12500.000 RA.MWD 1.670 RP.MWD 1.820 VRA.MWD 1.571 VRP.MWD 1.716 ROP.MWD 360.230 FET.MWD 0.258 GR.MWD 175.400 DEPT. 13000.000 RA.MWD 2.610 RP.MWD 2.350 VRA.MWD 2.696 VRP.MWD 2.349 ROP.MWD 333.570 FET.MWD 0.405 GR.MWD 166.230 DEPT. 13500.000 RA.MWD 2.120 RP.MWD 1.670 VRA.MWD 1.937 VRP.MWD 1.696 ROP.MWD 211.900 FET.MWD 0.393 GR.MWD 148.830 DEPT. 14000.000 RA.MWD 1.950 RP.MWD 1.650 VRA.MWD 1.746 VRP.MWD 1.603 ROP.MWD 117.690 FET.MWD 0.430 GR.MWD 130.760 DEPT. 14367.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 153.940 FET.MWD -999.250 GR.MWD -999.250 ** END OF DATA ** 411 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 5 Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE • **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE 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: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 6930.0 10100.0 LOG HEADER DATA DATE LOGGED: 02-APR-98 SOFTWARE: SURFACE SOFTWARE VERSION: 5B68 DOWNHOLE SOFTWARE VERSION: 4.0 DATA TYPE (MEMORY or REAL-TIME): MEMORY TD DRILLER (FT): 14367.0 TOP LOG INTERVAL (FT): 6930.0 BOTTOM LOG INTERVAL (FT): 14367.0 BIT ROTATING SPEED (RPM): 85 HOLE INCLINATION (DEG) MINIMUM ANGLE: 69.4 MAXIMUM ANGLE: 74.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CDR RESIST./GR CDR8044 # LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 6 Schlumberger Alaska Computing Center BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.375 DRILLERS CASING DEPTH (FT): 10077.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (5): 52.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (011MM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1.750 70.0 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.590 70.0 MUD CAKE AT (MT): 2.870 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 7000'-10100' CDR*** *** RUN 2 10100'- 10713' CDR*** *** RUN 3 10713'-11557' CDR*** *** RUN 4 11557'-14367' CDR*** DATA FROM DOWNHOLE MEMORY, V4.OC SOFTWARE LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 • 1111 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 7 Schlumberger Alaska Computing Center TYPE REPR CODE VALUE 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 4000230 00 000 00 0 2 1 1 4 68 0000000000 ATR LW1 OHMM 4000230 00 000 00 0 2 1 1 4 68 0000000000 PSR LW1 OHMM 4000230 00 000 00 0 2 1 1 4 68 0000000000 ROP5 LW1 F/HR 4000230 00 000 00 0 2 1 1 4 68 0000000000 TABR LW1 HR 4000230 00 000 00 0 2 1 1 4 68 0000000000 GR LW1 GAPI 4000230 00 000 00 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 6930.000 ATR.LW1 5.911 PSR.LW1 5.570 ROP5.LW1 -999.250 TABR.LW1 0.000 GR.LW1 79.713 DEPT. 7000.000 ATR.LW1 6.443 PSR.LW1 5.840 ROP5.LW1 -999.250 TABR.LW1 0.420 GR.LW1 65.205 DEPT. 7500.000 ATR.LW1 29.695 PSR.LW1 85.601 ROP5.LW1 26.646 TABR.LW1 0.152 GR.LW1 33.105 DEPT. 8000.000 ATR.LW1 9.173 PSR.LW1 10.950 ROP5.LW1 353.212 TABR.LW1 0.308 GR.LW1 62.831 DEPT. 8500.000 ATR.LW1 3.922 PSR.LW1 3.232 ROP5.LW1 461.955 TABR.LW1 0.588 GR.LWI 46.027 DEPT. 9000.000 ATR.LW1 6.004 PSR.LW1 6.143 ROP5.LW1 187.553 TABR.LW1 0.377 GR.LW1 66.670 DEPT. 9500.000 ATR.LW1 5.358 PSR.LW1 5.691 ROP5.LW1 147.541 TABR.LW1 1.740 GR.LW1 71.094 DEPT. 10000.000 ATR.LW1 3.562 PSR.LW1 3.307 ROP5.LW1 200.156 TABR.LW1 0.641 GR.LW1 71.703 DEPT. 10100.000 ATR.LW1 3.691 PSR.LW1 3.790 ROP5.LW1 100.052 TABR.LW1 0.497 GR.LW1 81.783 ** END OF DATA ** • 1111 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 8 Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE • **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE 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: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 10044.0 10713.0 LOG HEADER DATA DATE LOGGED: 02-APR-98 SOFTWARE: SURFACE SOFTWARE VERSION: 5B68 DOWNHOLE SOFTWARE VERSION: 4.0 DATA TYPE (MEMORY or REAL-TIME): MEMORY TD DRILLER (FT): 14367.0 TOP LOG INTERVAL (FT): 6930.0 BOTTOM LOG INTERVAL (FT): 14367.0 BIT ROTATING SPEED (RPM): 40 HOLE INCLINATION (DEG) MINIMUM ANGLE: 67.8 MAXIMUM ANGLE: 69.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CDR RESIST./GR CDR 752 • • LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 9 Schlumberger Alaska Computing Center BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.375 DRILLERS CASING DEPTH (FT): 10077.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 52.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1.750 70.0 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.590 70.0 MUD CAKE AT (MT): 2.870 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 7000'-10100' CDR*** *** RUN 2 10100'- 10713' CDR*** *** RUN 3 10713'-11557' CDR*** *** RUN 4 11557'-14367' CDR*** DATA FROM DOWNHOLE MEMORY, V4.OC SOFTWARE LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64E13 ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 • • LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 10 Schlumberger Alaska Computing Center TYPE REPR CODE VALUE 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 4000230 00 000 00 0 3 1 1 4 68 0000000000 ATR LW2 OHMM 4000230 00 000 00 0 3 1 1 4 68 0000000000 PSR LW2 OHMM 4000230 00 000 00 0 3 1 1 4 68 0000000000 ROP5 LW2 F/HR 4000230 00 000 00 0 3 1 1 4 68 0000000000 TABR LW2 HR 4000230 00 000 00 0 3 1 1 4 68 0000000000 GR LW2 GAPI 4000230 00 000 00 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10043.500 ATR.LW2 0.124 PSR.LW2 20.696 ROP5.LW2 -999.250 TABR.LW2 0.000 GR.LW2 29.830 DEPT. 10500.000 ATR.LW2 3.075 PSR.LW2 2.870 ROP5.LW2 103.448 TABR.LW2 1.267 GR.LW2 86.382 DEPT. 10713.500 ATR.LW2 3.039 PSR.LW2 3.005 ROP5.LW2 109.777 TABR.LW2 0.616 GR.LW2 93.883 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE .• • 4111 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 11 Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE • FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 10649.0 11557.0 LOG HEADER DATA DATE LOGGED: 02-APR-98 SOFTWARE: SURFACE SOFTWARE VERSION: 5B68 DOWNHOLE SOFTWARE VERSION: 4.0 DATA TYPE (MEMORY or REAL-TIME): MEMORY TD DRILLER (FT): 14367.0 TOP LOG INTERVAL (FT): 6930.0 BOTTOM LOG INTERVAL (FT): 14367.0 BIT ROTATING SPEED (RPM): 40 HOLE INCLINATION (DEG) MINIMUM ANGLE: 67.8 MAXIMUM ANGLE: 70.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CDR RESIST./GR CDR 752 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.375 DRILLERS CASING DEPTH (FT): 10077.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 52.0 MUD PH: MUD CHLORIDES (PPM): • • LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 12 Schlumberger Alaska Computing Center FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1.750 70.0 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.590 70.0 MUD CAKE AT (MT): 2.870 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 7000'-10100' CDR*** *** RUN 2 10100'- 10713' CDR*** *** RUN 3 10713'-11557' CDR*** *** RUN 4 11557'-14367' CDR*** DATA FROM DOWNHOLE MEMORY, V4.0C SOFTWARE LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64E13 ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 4111 4111 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 13 Schlumberger Alaska Computing Center ** 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 4000230 00 000 00 0 4 1 1 4 68 0000000000 ATR LW3 OHMM 4000230 00 000 00 0 4 1 1 4 68 0000000000 PSR LW3 OHMM 4000230 00 000 00 0 4 1 1 4 68 0000000000 ROP5 LW3 F/HR 4000230 00 000 00 0 4 1 1 4 68 0000000000 TABR LW3 HR 4000230 00 000 00 0 4 1 1 4 68 0000000000 GR LW3 GAPI 4000230 00 000 00 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10649.000 ATR.LW3 3.048 PSR.LW3 3.168 ROP5.LW3 *********** TABR.LW3 0.000 GR.LW3 92.915 DEPT. 11000.000 ATR.LW3 3.368 PSR.LW3 3.362 ROP5.LW3 239.991 TABR.LW3 0.431 GR.LW3 98.597 DEPT. 11500.000 ATR.LW3 3.015 PSR.LW3 3.033 ROP5.LW3 135.344 TABR.LW3 0.404 GR.LW3 91.424 DEPT. 11557.000 ATR.LW3 3.207 PSR.LW3 3.392 ROP5.LW3 104.044 TABR.LW3 0.423 GR.LW3 91.424 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE .• **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE .• 4111 • LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 14 Schlumberger Alaska Computing Center FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11407.0 14367.0 LOG HEADER DATA DATE LOGGED: 02-APR-98 SOFTWARE: SURFACE SOFTWARE VERSION: 5B68 DOWNHOLE SOFTWARE VERSION: 4.0 DATA TYPE (MEMORY or REAL-TIME): MEMORY TD DRILLER (FT): 14367.0 TOP LOG INTERVAL (FT): 6930.0 BOTTOM LOG INTERVAL (FT): 14367.0 BIT ROTATING SPEED (RPM): 35 HOLE INCLINATION (DEG) MINIMUM ANGLE: 19.0 MAXIMUM ANGLE: 70.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CDR RESIST./GR CDR 752 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.375 DRILLERS CASING DEPTH (FT): 10077.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 52.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1.750 70.0 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1.590 70.0 MUD CAKE AT (MT): 2.870 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): • LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 15 Schlumberger Alaska Computing Center TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 7000'-10100' CDR*** *** RUN 2 10100'- 10713' CDR*** *** RUN 3 10713'-11557' CDR*** *** RUN 4 11557'-14367' CDR*** DATA FROM DOWNHOLE MEMORY, V4.0C SOFTWARE LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 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 4000230 00 000 00 0 5 1 1 4 68 0000000000 ATR LW4 OHMM 4000230 00 000 00 0 5 1 1 4 68 0000000000 PSR LW4 OHMM 4000230 00 000 00 0 5 1 1 4 68 0000000000 ROP5 LW4 F/HR 4000230 00 000 00 0 5 1 1 4 68 0000000000 TABR LW4 HR 4000230 00 000 00 0 5 1 1 4 68 0000000000 GR LW4 GAPI 4000230 00 000 00 0 5 1 1 4 68 0000000000 ** DATA ** 0 • LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 16 Schlumberger Alaska Computing Center DEPT. 11406.500 ATR.LW4 4.375 PSR.LW4 4.367 ROP5.LW4 102.276 TABR.LW4 0.000 GR.LW4 99.093 DEPT. 11500.000 ATR.LW4 3.135 PSR.LW4 2.943 ROP5.LW4 1337.053 TABR.LW4 0.037 GR.LW4 92.031 DEPT. 12000.000 ATR.LW4 3.029 PSR.LW4 2.904 ROP5.LW4 93.261 TABR.LW4 0.540 GR.LW4 102.552 DEPT. 12500.000 ATR.LW4 1.675 PSR.LW4 1.817 ROP5.LW4 360.225 TABR.LW4 0.258 GR.LW4 175.396 DEPT. 13000.000 ATR.LW4 2.607 PSR.LW4 2.346 ROP5.LW4 333.575 TABR.LW4 0.405 GR.LW4 166.232 DEPT. 13500.000 ATR.LW4 2.118 PSR.LW4 1.670 ROP5.LW4 211.901 TABR.LW4 0.393 GR.LW4 148.834 DEPT. 14000.000 ATR.LW4 1.946 PSR.LW4 1.654 ROP5.LW4 117.686 TABR.LW4 0.430 GR.LW4 130.760 DEPT. 14367.000 ATR.LW4 2.198 PSR.LW4 1.866 ROP5.LW4 153.939 TABR.LW4 0.289 GR.LW4 88.185 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/15 ORIGIN : FLIC TAPE NAME : 98494 CONTINUATION # : 1 PREVIOUS TAPE . COMMENT : B.P. EXPLORATION,MILNE POINT MPE-24, API #50-029-22867-00 • 1111 LIS Tape Verification Listing 15-OCT-1998 14:17 PAGE: 17 Schlumberger Alaska Computing Center **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/15 ORIGIN : FLIC REEL NAME : 98494 CONTINUATION # : PREVIOUS REEL . COMMENT : B.P. EXPLORATION,MILNE POINT MPE-24, API #50-029-22867-00