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Home My WebLink About195-071 WELL HISTORY FILE COVER PAGE oversize material and digital infonnation available for this individual and weather or not it is available in the LaserFiche file. XHVZS This page identifies Well History file page in this file. History File # the first it remains as ) 9) tJ7/welJ Please insure that Added to LaserFiche File Data Digital No Yes # s CD No Yes Yes # Diskettes - # DVD's - No Added to LaserFiche File Oversized Material No Yes # Maps No Yes Mud Logs # No If any of the infonnation listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us Yes # Notes or Comments about this file Other General ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: D Oil D Gas IBI Plugged 181 Abandoned D Suspended D WAG 20AAC 25.105 20AAC 25.110 D GINJ D WINJ D WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3637' NSL, 1955' WEL SEC. 25, T13N, R10E, UM Top of Productive Horizon: NIA Total Depth: 3815' NSL, 2282' WEL, SEC. 25, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 569191 y- 6016175 Zone- ASP4 TPI: x- NIA y- NIA Zone- NIA Total Depth: x- 568862 y- 6016349 Zone- ASP4 18. Directional Survey DYes 181 No Zero Other 5. Date Comp., Susp., or Aband. 3/24/2004 ,¡ 6. Date Spudded 5/24/95 7. Date T. D. Reached 6/6195 8. KB Elevation (ft): KBE = 56.0' 9. Plug Back Depth (MD+TVD) 2489 + 2465 10. Total Depth (MD+TVD) 4700 + 4663 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL r- Ir"~ ,. ï 11), '~I'ìOO4 ,.IU- 'Ü ). -- .. '-01 . :, 1b. Well Class,¡\ 181 Development D Èxploratory D Stratigraphic D Service 12. Permit to Drill Number 195-071 304-056 13. API Number 50- 029-22561-00-00 14. Well Name and Number: M PE-20 15. Field I Pool(s): Milne Point Unit I Schrader Bluff Ft Ft 16. Property Designation: ADL 025518 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: DLL , MLL , ZDL , CN , RG , CHT , GR , MWD 22. CASING, LINER AND CEMENTING RECORD :'illll¡lII;'III';,'I:,IIII"!',,I:,II"I:::I:,I,:II:I'"I::'I!',I"II',IIII',:I"I:' ';:,il'I~~~I~~I'I:~š~ii~i,IMgl""" '11$Ei~IN@:,il~¡;~¡¡¡~IIWM~:II, ',:!II:'.,I )1 Ge».SE: I': '1:1 I,! I: """"'~';:"\P'I'I'¡I::\' 1,,8'0' '~TrÐM' Iha" T:r~a'A'I,: III';, I""~;"~"~ I ,,'I' ':"'1""" ,,,,::,,', ::.1 11'1:",,1 :,:l!'~ ,,',"':" 1,1.: ,'; ".,I~:!;'h, I ;:Q, ",1,:, '.;W-_V,I:¡ 20" 91.1# H-40 32' 112' 32' 112' 24" 250 sx Arcticset I (Approx.) 13-3/8" 54.5# K-55 31' 2587' 31' 2561' 16" 784 $X PF 'E', 250 sx 'G', 150 sx PF 'E' 9-5/8" 47/40E L-80 2520' 4681' 2495' 4644' 12-1/4" 375 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): N/A MD MD TVD 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-BBl Press. 24-HoUR RATE 27. None ØIDIS BFL Form 10-407 Revised 12/2003 ',:'i,'~~~:H~W"II',:" l:iRtJ~ßED', : SIZE NIA DEPTH SET (MD) PACKER SET (MD) TVD DEPTH INTERVAL (MD) 4220' AMOUNT & KIND OF MATERIAL USED Set 9-5/8" EZSV with 35 Bbls 'G', placed 30 Bbls below retainer and 5 Bbls on top Set 9-5/8' CIBP with 27 Bbls Arctic Set I on top Set 13-3/8" CIBP GAs-McF WATER-BBl 2700' 2489' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-BBl CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 1l6aJ1.c/¿'?h~....t- t~~I"I~~~;'~~I;":~",'\I'~',~;~': ~ oof,{.. ~"~:...: ¡ IJ" : JUl 1 2 ?OO~. ,0 ~ ' ~, II I \~:~'P'Î .~~,~~ I'n?)v1 ~ ..-Q4 ?:":r;Jþ' ~ \n..~" ~ I \~ ., ,.~ ..-'. ""; 0.: C~mNUED ON REVERSE SIDE ~ GAs-McF WATER-BBl CHOKE SIZE I GAS-OIL RATIO Oil GRAVITY-API (CORR) GP 28. ( GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Schrader Bluff 4297' 4260' None N Sands 4320' 4283' 4403' OA Sands 4440' OB Sands 4504' 4467' 30. List of Attachments: Summary of Daily Drilling Reports MPE-20 Well Number :egoing is true and correct to the best of my knowledge. /' ~~~ ''--'' 195-071 304-056 Permit No. I Approval No. INSTRUCTIONS Title Technical Assistant Date (~-~O-o1 Signed Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Walter Quay, 564-4178 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only f (' BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-20 MPE-20 PLUG+ABANDON NABORS ALASKA DRILLING I NABORS 4ES Start: 3/22/2004 Rig Release: 3/27/2004 Rig Number: 4ES Spud Date: 5/21/1995 End: 3/27/2004 Date From - To Hours Task Code NPT Phase Description of Operations 3/22/2004 00:00 - 18:00 18.00 MOB P PRE Move Rig and related equipment from DS 16-20 to MPE-20 location. 18:00 - 21 :00 3.00 RIGU P PRE Position and assemble rig. Rig accepted 2100 hrs. 21 :00 - 23:00 2.00 KILL P DECOMP R/U hard lines to tree and test to 300/3000 psi. Bleed down lines. R/U line to Tiger Tank. 23:00 - 23:30 0.50 KILL P DECOMP P/U lubricator, pull BPV, lay down same. 23:30 - 00:00 0.50 KILL P DECOMP PJSM for well kill operations. Begin bleed down of tubing and casing. Start pressures: TP = 1100 psi; CP = 1100 psi. 3/23/2004 00:00 - 04:30 4.50 KI LL P DECOMP Bleed down well for 45 minutes: Tp = 1040, CP = 980. Circulate 140F seawater at 3 BPM, 780 psi. Pressures dropped to TP 390 psi, CP 130 at a rate of 4 BPM. Well dead after 7,000 strokes or 410 Bbls. Monitor Well. 04:30 - 06:00 1.50 WHSUR P DECOMP Install and test TWC. Blow down lines. 06:00 - 08:00 2.00 WHSUR P DECOMP Nipple down Production Tree. 08:00 - 10:00 2.00 BOPSUP P DECOMP Nipple up BOP Stack. 10:00 - 10:30 0.50 BOPSUP P DECOMP Function test BOPE. Fill BOP Stack and Choke Manifold. Test lines. 10:30 - 14:00 3.50 BOPSUP P DECOMP Perform BOPE test per BP/AOGCC requirements at 250/3,500 psi. State's right to witness test waived by J. Jones. 14:00 - 15:30 1.50 WHSUR P DECaMP RID test equip. Blow down lines & choke manifold. Pull TWC. BOLDS. 15:30 - 16:30 1.00 WHSUR P DECaMP M/U landing it. Pull tubing hanger to floor. LID hanger & landing it. P/U wi 40k hanger came free. 16:30 - 18:00 1.50 PULL P DECOMP POOH & LID 2 7/8" tubing & heat trace lines. Have to cut bands on flat guards protecting heat trace line. 18:00 - 18:30 0.50 PULL P DECOMP Re-Ievel rig. Change slip dies. Empty basket wi flat guards. 18:30 - 21 :30 3.00 PULL P DECOMP Con't to POOH wi 27/8" tubing & heat trace lines. 21 :30 - 22:30 1.00 PULL P DECOMP Pull heat trace line over sheave. Clear floor of flat guards. 22:30 - 00:00 1.50 PULL P DECOMP Can't to POOH wi 27/8' tubing & heat trace lines. LID tubing recovered 129 its tubing, 1 GLM Assy. ESP: 68 Flat Guard Bands, 248 Pre-form Bands. Heat Trace Raychem: 6' 377, 4' 13, 1157 Bands. 3/24/2004 00:00 - 02:00 2.00 PULL P DECOMP Break out "Y" tool. Inspect ESP Assy. Highly corroded around seal section. Drain & break down ESP. Crate up & remove from rig. 02:00 - 04:00 2.00 PULL P DECOMP RID elephant trunk. RID tubing handling equip. Clear & clean rig floor. Rlu handling tools for 3 1/2" DP. 04:00 - 06:00 2.00 CLEAN P DECOMP M/U BHA #1 as follows: 8 1/2" Bit, 95/8" Scraper, Bit Sub, X-over. BHL = 8.71'. P/U 3 1/2" DP & RIH wi BHA #1. 06:00 - 06:30 0.50 CLEAN P DECOMP Service Rig. 06:30 - 10:00 3.50 CLEAN P DECOMP Finish single in hole with Bit/Scraper and 3 1/2" Drill Pipe. Tagged hard bottom (Halco Pkr) at 4,238-ft 4es rkb. (134 Jts) 10:00 - 11 :30 1.50 CLEAN P DECOMP POOH and stand back Drill Pipe. 11 :30 - 12:00 0.50 CLEAN P DECOMP Lay down BHA. 12:00 - 12:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 12:30 - 13:00 0.50 PXA P ABAN Pick-up Halco 9 5/8" EZSV Cement Retainer and Running Tools. 13:00 - 14:30 1.50 PXA P ABAN Run in hole with Retainer and 31/2" Drill Pipe to 4,220-ft. (133 Jts). 14:30 - 15:00 0.50 PXA P ABAN Set Retainer. Rig up to circulate. 15:00 - 15:30 0.50 PXA P ABAN Perform Injection Test at 3 bpm/450 psi (15 bbls) and at 5 bpm/1150 psi (15 bbls). 15:30 - 17:00 1.50 PXA P ABAN Un-Sting from Retainer. Circulate down Drill Pipe and fill Annu Printed: 3/29/2004 8:46:51 AM ~rogranlS for MPE-20 and MPJ-22 revised /~ , i I Subject: Programs D MPE-20 a d MPl-22 revised From: "Reem, David" <Ree C@BP.com> Date: Wed, 25 Peb 20 09: :42 -0900 To: tom_maunder@admin.state.ak.us «AOGCC ProcedureE-20.doc» «AOGCC Procedure. doc» Tom, as requested per our phone conversations, here are the revised I-page programs for the proposed Milne pt abandonments for E-20 (pre-sidetrack) and J-22 (complete abandonment). Let me know if further details are needed. Thanks! Dave Reem Sr. Workover Engineer 564-5743 C t t D . f AOGCC on en - escrlp Ion: ProcedureE-20.doc ProcedureE-20.doc Content- Type: applicationlmsword Content-Encoding: base64 r--:- .._.__._.-----_.._-_._-~--~-_._._-"--"",_._.__..__._,~~--.-.'---'---"" Content-Description: AOGCC Procedure.doc Procedure. doc Content-Type: applicationlmsword Content-Encoding: base64 1 of 1 2/25/20049:32 AM STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ff.-~, ~,,( "~,,'''''~ . \' II ¡ .... t ~~ ~ ~'í ~". ~I.:...;.II~ . \",'1....1'1' ~ ~. ~"p.,.,o,I J [J/ I)~ ...: ,').' FES 2 4 2004 ¡\~ f.:', :,;:¡, ~_:->:.~ :f):;~~, Cm'rF::i~S¡Q:1 :\n~r'~)r\1: :~ 1. Type of Request: 181 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 56.0' D Suspend 0 Repair Well 0 Pull Tubing D Operation Shutdown 0 Perforate 181 Plug Perforations D Stimulate 0 Perforate New Pool D Re-Enter Suspended Well 4. Current Well Class: IBI Development D Exploratory D Stratigraphic Test D Service D Waiver D Time Extension Plug back for Sidetrack D Annular Disposal 5. Permit To Drill Number 195-071 ,. 6. API Number: "" 50- 029-22561-00-00 \/" iii Other 9. Well Name and Number: MPE.20 8. Property Designation: 10. Field / Pool(s): ADL 025518 Milne Point Unit / Schrader Bluff PRESENT,WElLG'ONDITION SUMMA~Y , Total Depth TVDlft): Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): 4663' ./ 4637' 4600' N/A ,Length, . Size 'MD. TVDBurst H. Total Depth M,D (ft, ): 4700' ./ Casing Structural Conductor Surface I ntermed iate Production Liner Junk (measured): N/A COllapSe 112' 2256' 20" 13-3/8" 112' 2587' 112' 2561' 1490 2730 470 1130 4653' 9-5/8" 4681' 4644' 6870 / 5750 4750/3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4312' - 4528' 4275' - 4291' 2-7/8',6.5# L-80 4173' Packers and SSSV Type: (Gravel Pack Screen Assembly) - 9-5/8" Halliburton 'VTL Packers and SSSV MD (ft): 4249',4366' & 4553' Pkrs and a 9-5/8" x 4" Bore HES 'BWD' 12. Attachments: 181 Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby c that the foregoing is true and correct to the best of my knowledge. Printed N e ¡!DaVid Ree I (~ /J, Title Drilling Engineer Sianature.. ,I (' f(Rt1#J-. Phone 564-5743 Commission Use Only . 13. Well Class after proposed work: D Exploratory IBI Development D Service March 04, 2003 Date: 15. Well Status after proposed work: DOil DGas D WAG D GINJ IBI Plugged DWINJ B Abandoned D WDSPL Contact David Reem. 564-5743 Date 2/l~ J Of Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness ~Ug Integrity "Fop Test 0 Mechaniællntegrity Test 0 location Clearance I Sundry Number: 3Df-tPSfo Other: ~ÇA~N[Eli) Mt\~~ 1. @ 200l~ ORIGINAC- , 8ft ;e#~~t Approved By. Form 10-403 BY ORDER OF COMMISSIONER THE COMMISSION ~?E.-d-O AOGCC Permittine Requirement 1. 10-403 must be submitted and approved prior to abandonment and sidetrack ofMPE- 20. 4ES Scope - Abandonment procedure per AOGCC Reeulations .~ 1. MIRU Nabors 4ES & kill well '--'"t \"'~~ \\ ~ ~'>-\- \SO ~ 2. Pull existing tandem ESP completion (GPMT ARC 84 GC1200, PHD gauges, Raychem heat trace, and logging by-pass tool - "Y" tool) 3. Set 9 5/8" cement retainer @ -4230' MD a. Retainer must be set 50' to 500' above the top perforated interval (4312' MD) 4. Pump cement through retainer to isolate perforated intervals a. Volume pumped needs to fill at least 100' below lowest perforated interval (4528' MD) b. Minimum cement volume -33 bbls (including cement cap on top of EZSZ) 5. Record the location and integrity of plug/retainer by either: 6. Placing sufficient weight on plug to confil111 location and competency 7. ii. Testing of plug to hold a surface pressure of 1500 psig -or- (0.25 psi/ft)(TVD casing shoe) whichever is greater i. (0.25)(4644) = 1161 psi Use 1500 psi surface pressure if this option used ii. Note: Surface pressure cannot subject casing to a hoop stress of greater than 70% of the casing's minimum yield (burst). iii. For new 9 5/8" 40 ppf (above 4637' MD) L-80 min yield (burst) is 5750 psi, 70% = 4025 psi (There is 9 5/8" 47 ppfbelow 4637' MD) 8. Cap cement retainer with at least a 50' cement plug (,..,,4190' MD) 9. PUR and fill wellbore with a fluid of sufficient density to exert a hydrostatic pressure greater than the highest fOl111ation pressure (plan on 9.8 ppg brine) a. 1/22/04 FL shot 1841 psi @ 4326' TVD (1702 psi @ 4000' TVD) b. Has been SI for over a year (SI 8/17/2002) 10. Set 9 5/8" CIBP at ,..,,2700' MD. Run USIT log to detel111ine top of cement in 9- 5/8" x 13-3/8" annulus. ~ \5,O\>'~ ~Cè~~'\~~~ ~l <;,S-/8 U rù-\V\.> 11. Cut & pu119 5/8" from ,..,,2450' MD to surface. 12. Lay in 300' cement plug from 9-5/8" CIBP at ,..,,2700'md. (NOTE: a MITOA was perfol111ed 2/22/04 to 2000 psi. The MITOA failed under stabilization criteria, ~le to establish a measurable injection rate). 13. Set 13 3/8" EZSV CIBP -2400' MD just above cement top. 14. POOH filling wellbore with a fluid of sufficient density to exert a hydrostatic pressure greater than the highest fonnation pressure (plan on 9.8 ppg brine) 15. RDMO 4ES / 4ES Sco e. Abandonment rocedure er AOGCC Re ulation 1. MIR U Nabors 4 ES & kill well 2. Pull existing tandem ESP completion (GPMT ARC 8 C1200, PHD gauges, Raychem heat trace, and logging by-pass tool - "Y" 01) 3. Set 9 5/8" cement retainer @ -4230' MD a. Retainer must be set 50' to 500' above t top perforated interval (4312' MD) ..../ 4. Pump cement through retainer to isolate pe orated intervals a. Volume pumped needs to fill at Ie t 100' below lowest perforated interval (4528' MD) b. Minimum cement volume -33{)bl~S . eluding cement cap on top of EZSZ) J 5. Record the location and integrit); of pI tainer by either: 6. Placing sufficient weight on pl/g t\ ~firm location and competency 7. ii. Testing of plug to hold a s r~\r'e'ssure of 1500 psig -01'- (0.25 psi/ft)(TVD casing shoe) whichever is /1' i. (0.~5)( 4644 =¿o/61 psi Use 1500 psi surface pressure if this optIon us ii. Note: Sf' pressure cannot subject casing to a hoop stress of greaterJ~O% of the casing's minimum yield (burst). 111. For ~5/8" 40 ppf (above 4637' MD) L-80 min yield (burst) is 575 3~?0% = 4025 psi (There is 9 5/8" 47 ppf below 4637' 8. Cap cement re iner with at least a 50' cement plug (-4190' MD) 9. PUH and fill ellbore with a fluid of sufficient density to exert a hydrostatic pressure gr tel' than the highest formation pressure a. 1/2 ï04 FL shot 1841 psi @ 4326' TVD (1702 psi @ 4000' TVD) b. H s been SI for over a year (SI 8/17/2002) 10. Set 95 "CIBP at -2600' MD d-~ CJ a ,.", 11. Cut pull 9 5/8" from -2550' MD to surface d <;Õ (",) 12. Set/ 3 3/8" EZSV retainer at -2500' MD la. Doyon 14 will mill a window -2480' MD 13. l}úmp cement through retainer from top of CIBP to bottom of EZSV a. Estimated cement volume -11.5 bbls 14. POOH filling wellbore with a fluid of sufficient density to exert a hydrostatic pressure greater than the highest formation pressure . RDMO 4ES AOGCC Permittin2 ReQuirement 1. 10-403 must be submitted and approved prior to abandonment and sid 20. \" \, '("'1("', ..:~" ", ",- , Jr' O~, '\ t,." \ \", .'...") "--'oi" / .I ./ ,I Tree: 2-9/16" - 5M Wellhead 13-5/S" FMC 5M New Std. Big Bore Actuator. Conductor Casing ~ KOP @ 1200" Max Hole Angle: 13.40 @ 2300 MD NO.4 CEE Power Cable w/ Cable bands every 20' 13-3/S" . 54.5 ppf, K-55, Btre. 25S7' 2-7/S" , 6.5 ppf, EUE 8rd tbg. ( capacity = 0.00579 bpf ) 9 5/8" . L-80 production casing 40 ppf NSCC above 4637' MD 47 ppf Btrc below 4637' MD Logging bypass tool 4106' Centrilift ESP. GPMT ARC 84 GC-1200 4117' Tandem Seal Section 4134' GSTDBH Centrilift Motor, 82 hp, 4147' 1230 Volts ,35 Amps, KM E-1 Centrilift PHD 4157' Stimulation Summarv: 'N' Sands: 26,900 Ibs.16-20 '0' Sands: 73,000 Ibs 16-20 Perf Of at ion Summarv: Ref. Log: DLL 6/6/95 Interval 4312' - 4332' 4332' - 4357' 4440' - 4465' 4487' - 4490' 4502' - 4528' 4.5" 4.5" 4.5" 4.5" 4.5" Jumbo Jet ("big hole") 26 gr. charges. 135/45 deg phasing. EHD = 0.74", TIP = 5.8" except for 4487' to 4490' which were 32gm.. Alpha Jet w/ TIP = 32.1" 0.44" EHD DATE COMMENTS .BY MPU E- 20 KB = 53.S' (N22E) GL = 24.7' RKB (N22E) to 9 5/S" Hng. = 30.8' 2-7/8 x 1" KBMM GLM Raychem down hole heat trace cable to 2250' MDwith 6' channel guards banded every 2" Centrilift Dart Check Valve 2-3/8" Otis X nipple (1.875" Id) 125' 4116' 4130' (Otis X nipple equiped with 2-3/8" shear plug, plug pinned to sheaf at 3500 psi.) 2-3/S" WLEG RA Collar at 4229' WLM RKB 9-5/S" Halliburton "VTL" Pkr 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen 9-5/S" Halliburton "VTL Pkr 4.5" Otis X nipple 3.S13" id 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen 9-5/8" x 4" bore HES "BWD" 4.5" Otis XN nipple 3.75" Id 4.5" WLEG PBTD MILNE POINT UNIT Well E-20 API NO: 50-029-22561 prD NO~ 1'150'710 BP EXPLORATION (AK) JBF ESP / Frac Pack Completion by N 4ES diagram update: 09/ 02/ 95 09/05/96 M. Linder 4173' 4249' 4310' 4365' I 4366' I 4432' 4537' 4553' 4556' 4637' 4681' Conductor Casing ~ KOP @ 1200" Max Hole Angle: 13.40 @ 2300 MD 13-3/8" , 54.5 ppf, K-55, Btrc. 2587' 2-7/8" , 6.5 ppf, EUE 8rd tbg. ( capacity = 0.00579 bpf) 9 5/8" . L-80 production casing 40 ppf NSCC above 4637' MD 47 ppf Btrc below 4637' MD Stimulation Summary: 'N' Sands: 26,900 Ibs.16-20 '0' Sands: 73,000 Ibs 16-20 Perforation Summarv: Ref. Log: DLL 6/6/95 Interval 4312' - 4332' 4332' - 4357' 4440' - 4465' 4487' - 4490' 4502' - 4528' 4.5" 4.5" 4.5" 4.5" 4.5" Jumbo Jet ("big hole") 26 gr. charges, 135/45 deg phasing, EHD = 0.74", TIP = 5.8" except for 4487' to 4490' which were 329m., Alpha Jet wI TIP = 32.1" 0.44" EHD DATE .BY 09/ 02/ 95 09/05/96 JBF MPE-20 Proposed KB = 53.8' (N22E) GL = 24.7' RKB (N22E) to 9 5/8" Hng. = 30.8' Existing Cement 13 3/8" EZSV Cement Retainer I -2500' I Top of 9 5/8" Casing I -2550' I Bottom of Cement 9 5/8"" CIBP 9 5/8"" EZSV Cement Retainer RA Collar at 4229' WLM RKB 9-5/8" Halliburton "VTL" Pkr 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen 9-5/8" Halliburton "VTL Pkr 4.5" Otis X nipple 3.813" id 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen 9-5/8" x 4" bore HES "BWD" 4.5" Otis XN nipple 3.75" Id 4.5" WLEG PBTD COMMENTS ESP / Frac Pack Completion by N 4ES diagram update: MILNE POINT UNIT Well E-20 API NO: 50-029-22561 M. Linder BP EXPLORATION (AK) I -2600' I I -2600' I I -4190' I -4230" I 4249' 4310' 4365' I 4366' I 4432' 4537' 4553' 4556' 4637' 4681' ANNULAR INJECTION DATA ENTRY SCREEN Asset Nliln.e. .......................................... Rig Name ~.~I~.QI'~..~[F,, ............................. Inj Well Name M....P..I~.:~.0. ..................................... Sur Csg Dep :~.5.~.7.. ................ Legal Desc 3.6.;3Z'.NS~...1..9.55.'.W. EL,..~.e.q.2~.T.~I.;3.bI.,.B.l.O/i .................................. Research Permit End ........1.~:3.1/.~.5. ....... Permit Start ......... .7.:.3.: .~.,5 ......... Cumulative Data Rig cOmpletion FOrmation intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze ......... .4~.6.3 .................. ..4,7.~1.8. ...................................................... ~ .................................................................................... 7.5. ............ MPUE-23 07/09/95 200 200 MPUE-23 07/10/95 60 60 · B~IE-23 07/12/95 1,000 . 1,000 MPUE-23 07/13/95 838 75 913 Daily Data Mud, Glgs, Grr~ i . i[-[~i~-i~ult Free2~ Freeze Fn:ql ~ We~ I~ ~ ~ ~ ~ ~ ~ T~ MPUE-23 07/04/95 250 250 MPUE-23 07/05/95 150 150 MPUE-23 07/06/95 300 300 MPUE-23 07/07/95 350 350 MPUE-23 07/08/95 300 300 ,, eared rvices rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request DEC 14 1998 Dear Ms. Mahan: Alaska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular DispoSal Records from July 25, 1995 through preSent time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected.into. These wells are identified as follows: ·Endicott wells lrO3/P-16, 1-65/N-25, 1-59/0-24 Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & #2, 1{-05, K-02,1t-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because 'the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide-you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: e ~Annular Disposal Letter .' · 12/14/98 ! / · Endicott wells ~-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdough #3 - ~%° o ~4 ~ ~.~ - · Mi~ePointwellsF-06, H-05, H-06, J'13, L-24 - · PBU wellZ18-30, 18-31, 14~,~43, E-34, E-36, G-~A, ~d S-33- · hdlwdu~ logs ~e provided m you for these ~gs ~ we~ 1... . q~-oS~ '33-~ 'q~.o~ · Finally, our records shoW that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED 1998 ~aska Oil & Gas Cons. Commissio~ Anch0rag0 lar(~d SerVice DHIling ~n~ar Injection Volumes ly 25, 1995 until December 1998 ~mulative Report Surface Casing ' ' Inj Well Depth Legal Desc licott Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Cum Total & Ctgs Wash Fluids Fluids F[eeze . ~ Freeze Start End Status on 15 1-19/I-18 5000 Sec. 36, T12N, R16E 8,960 7,848 992 120 12/5/95 12/5/96 Open on 15 1-23/O-15 4246 2o2o'FNL,.2087'.FEW, SEC:3.6,T12N!R!6E 32,084 3.0,6.04 1,.?.67 200 !2.0, 9/30!~5 r}n 15 1-33/M-23 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 150 8/31/95 12/31/95 Broached ~)n 15 1-61/Q-20 4236 .3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open : :~.n !.5 ...... 2;.4..0/S:.27 ....... ..4..5~.1 ............. 2~.Oi.F._NI;,.._2~8.9.'?.E.L..,...~.e.c_..36!.T?..N! .R...!~.E .............. .3.1__,..1...9.5 ........... 2.9.~..9.5_2. ............... !.,.06__~_3 ........................................................................ 1_2_0. ................... ..6._0..i.- 7/25/05 12/01/95 . Open ~n 14 15-47 3515 3648'NSL 4956'WEL Sec22T11N R14E 3002 903 2,009 90 11/7/95 12/31/95 . Open : ....................................... ;....J ............................ ~ ....................... ,. .................................................... ~ .................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................. 3n 14 DS 15-45 3829 4749' NSL, 5180' WEL, Sec. 22, T11 N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached ~n 14 DS 15-48. 3548 Sec. 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open )n 14 DS 15-49 3667 4676' NSL,. 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open )n9 18-30 3930 1499'SNL 26'WEL, Sec 24,T11N, R14E 2,266 936 380 800 150 7/25/95 12/31/95 Open 171 7/26/95 12/31/95 Open )n 9 18-31 3680 3719'NSL, 64'WEL, Sec 24,T11N, R 14E 6,086 2,250 1,100 2,565 8/24/95 Open )n 9 18-32 3830 3632'NSL 41'WEL Sec 24 T11N R14E 3 311 1 861 200 1,100 150 12/31/95 )n 9 18-33 4140 3690'NSL, 56'WEL Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open )rs 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open )rs 18E 12-36 3452 63'FSL 899'FEL Sec 18T10N R15E 4 002 1,961 50 1,871 120 10/13/95 12/31/95 Open !.r..s...!.?~ ........................ !...3..-...3..~ ........................................ 3.4....3..! ................................... !..5...8.5..?.$.1;L.5_ !...8.. . .7. '. ~ .E_ L.L~.e..c.?.~.,..T.!...0_N._, _~.!..4...E_ ....................... ..4..,._1..?. ............................ _3..,.5?_3_ ................... .4.._6_4_ ..................................................... 150 10/26/96 12/31/96 Open )rs 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open oration 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed e ~ MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR 11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open ,rs 22E MPC-23 4941 1038 NSL 2404 WEL Sec 10 T13N 2 060 1,800 130 130 1/25/96 1/25/97 Open ,rs 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open ,rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open 425 350 75 2/15/96 2/15/97 Open ,rs 22E MPC-28 5405 Sec 10,T13N, R10E . . Page 1 ,DEC 1 4 1998 Anchora~o ;ha,r,~d oervice Drilling i, nn'~l'ar Injection Volumes ~uly 25, 199~, until December 1998 :umulative Report Surface Casing ig Inj Well , Depth abors 22E MPF-06 8766 ,, ~bors 22E MPF-14 6690 ~bors 22E MPF-70 7919 ~bors ,22E MPH-05 5335 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Lega! Desc Cum To!al & Ctgs Wash Fluids Fluids . Freeze ..... I~reeze Start End, S!alus Sec 06,T 13N, R 10E 1,927 1,731, 196 1/25/96 1/25/97 Open .. Se?061T13N, R10E.' UM !..8~7!..~ .....1.7! ?7 1..L2.7.? ... ......... 3..4. ~.'6/3/96 ..... 6!.3!9.7 .... 0Pe~ 2189'ESL, 2591'WEL, .Sec 6!T13N, R!0E, . !9,775 .... 18,794 .... 7,~5 .... . ..... 19.0 ..5..6 6/17/96 .... 6/17/97 OPen 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Open , . ~bors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8 515 8,335 180 8/5/95 12/31/95 Open ~b°rs 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 12/31/95 Open ~b0rs 22E MPJ-13 2835 2319'NSL 3179'WEL Sec 28 T13N R10E 14 127 13 292 645 60 130 10/17/95 12/31/95 Open ..................................................................................................................................... ~ ....................................... ~ ........................ ~ ..................... .'. ......................................................... ~ ..................................................... .'. ................................................................................................................................................................................................................................................................................................................................................................................................................ ~bors 2'2[ MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 , Open ~bors27E B-24 4080 Sec 18,T13N, RllE UM 1,468 1,396 72 , 1/25/96 1/25/97 Open lbors 27E , MPF-22 8841 Sec 06,T13N, R10E UM 6,536 6,466 70 12/12/95 12/12/96 Open Ibors 27E MPF-25 3405 1857'NSL, 2696'WEL, Sec 6,T13N, R10E ' 9,897 9,357 250 225 65 12/26/95 12/26/96 Open ibors 27E ' MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open ibors 27E MPF-38 8561 1994'NSL, 2731'WEL, Sec 6,T13N, R10E 9,232 9,157 75 12/6/95 12/31/95 Open ~bors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' Open tbors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open LbOrS 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 91665 . 75 8/31/95 12/31/95 Open ~bors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open ,bors 27E MPL-24 6515 3654'NSL, 5180'WEL, Sec 8,T13N, R10E 6,790 4,900 1,320 165 335 70 11/27/95 12/31/95 Open 3A E F-33 3570 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open E F~36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1,998 1,359 3,471 135 12/18/95 12/18/96 Open yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11 N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open yon 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96. 4/10/97 Open yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11 N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open bors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN Page 2 Shared Sei~vice Dr. illing ~,nni~i~'r injection Volumes luly 25, 1995~ until December 1998 ;umulative Report Sudace Casing .ig Inj Well Depth 'abors 28E B-33 3504' abors 28E E-34 3664 · abors 28E E-36 3648 abors 28E E-37 3810 abors 28E E-39 3638 .3358'NSL, 501'WEL, Sec 6,.T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open ab.ors.2~.E G-~4A .. 35(~.9 291.7.,N~i:.,..!.9.7?.,~N..E.L, .sec !~.~.1.1N, R.!.3.~ ........................... ~'...9.3...7 .................... !.!.77~ ...... !..!~? .............. ~.,..3..!..~ .................................................................. !0/20!95 ..... !2/3.1!9.5.. ................... ?@e.n abels 28E G.21 3509 2911'NSL, 2368'WEL, Sec 12,T11N, R14E 11,430 3,956 3,072 4,270 70 62 9/8/95 12/31/95 Open abors 2.8E. ..... s~2~ ................ :... ?.750 .......... ! 6331.S.1~L.~ ~.2...28..i~E.!:.,....S..e~. ~.,...T..!.~N,?..!?.E ........................ ~?.'..2_.6.! ........................... !.! ,.7.7.3. ........... ~.,..!..7..? ....................... 5.~.~5.? ................................................ ~?..5. ................... 28~ . 12/9/95 ....... 12/9/.?~ ...................... 077.. .......... abors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc . Cu.m TogaI & ctgs Wash .Flui.ds Fluids Freeze Freeze Start End Status 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 857 . 195 80 5/1/96 12/31/96 Broached 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 Open 1706'SNL, 822'WEL, Sec6,T11N, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95' 12/31/95 Open 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 374 80 9/16/95 12/31/95 Open abors 28E S-41 3331 4152' NSL 4504' WEL Sec 35 T12N 8 062 4 159 2 034 1 754 115 2/8/96 2/8/97 Open ~bors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 Open ~bors 2ES H-35 3157 4535'NSL 1266'WEL Sec 21 T11N R13E 4 860 3 725 555 480 20 80 10/26/95 12/31/95 Open ........................................................................................................................................................ : ........................................................ ~ ......................................... .'. ................................ ., .................... ,. ........................................... ,. ........................................... ~ ................................................ ~ ....................................................................................................................................................................................................................................................................................................................... ~bors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 ' 85 10/26/95 12/31/95 Open Page 3 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 22, 1997 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Howard Oakland Dear Mr. Oakland, Please find enclosed the Core chips from the MPE-20 core. Along with the previous mailed core descriptions, core analysis, PVT analysis. This should meet the AOGCC's data submission requirements. If not, please contact me at 564-4049 directly. On behalf of the Schrader Bluff Team I apologize for our oversight in not sending the appropriate information to you at the completion of MPE-20 well. Sincerely, Mark Vandergon Senior Geologist £ 5 1997 .Gas Eons. BP Exploration Schrader Bluff MPE-20 Alaska TerraTek Project: 5955 Physical Inventory Plug End Pieces Updated: 8113/97 i End Piece ~ End Piece Sample Orientation Depth ~ Sample Orientation Depth Number ~1 Number 101 V 4295.6-{)5.8,~. 53 H 4437.80 '---- 1 H 4296.20 ~ 54 H 4438.10 ''.'~' 3 H 4301.20 ~ 126 H ~.~.3.{~)0~,~ 102 H 4305.20 127 H ~. ~. ~ ~..90 ,/ 103 H 4306.20 128 , H 4447.95 ~ 104 H 4307.20 129 V ~.'H7.95-48.25 105 H 4308.20 130 H ~,~.~,8.95 106 H 4309.20 131 V 4448.95-49.25 '~ 07 ,, H 4310.20 133 , H 4453.90 5 H 4311.60 , 134 , V 4454,2-54.5 108 H 4312.20 31 H 4454.35 -, 109 H 4313.20 ~1~ 139 , V 4454.5-54.8 6 H 4319.80~ ,138 H 4454.80 ~ 110 H 4320.20 34 H 4455.50 ,, 111 H ,4321.20 ~ 135 " V 4457.9-8.2 > 112 V 4325.1-25.~ 36 H 4458.30 ~ 113 H 4325.40 ,.~.~ 37 H 4459.~25' 9 H 4329.20~ 38 H "' ~t60.25 ~ "'10 H 4332.20 136 H 4463.80 ~ 11 H 4333.20 40 H 4465.45 ~ 13 H 4336.20 ~= 41 H 4467.20/ 14 H 4337.20/i~ 42 H 4468.20 114 H 43~.20 ~.,F !~1 '43 H 4469.20 16 H 4343.20 ~ ~ 137 H 4470.25 ~ 115 H 4344.20 ~ 55 H 4485.20- 18 H 4345.20 V'~ 56 H ' 449:~'.25 ~ 19 H 4346.20~ 57 H 4497.50 20 H 4347,20 58 H 4516.30 / 21 H ' ~348,20 ~.. 142 V .i 4517.1-17.4~ 23 H 4355,20 ~ 59 H 4517.20' 24 H 4361.15 ~,~ 60 H 4518.20 ~ 1~6 H ~ '4367.85 ~j~ ' 61 -H~-, 4519.70 ~ 121 ~ ' V. 4367.85-6~5~ 62 H '4~20.20 ~' 119 V 4372.3-.6 ~ 64 ~- ' H' 4522.20 120 H 4373.20 ¢~ 63 H ' " 4522.50 ~ 27 H 4375.20,~] 65 H 4524.20 28 H 4376.00 ~ 66 H 452~.20 ~' 123 H 4378.'.20 ,/~ 6~F H 4526.20 ~ '4~5 H 4381.30~ 68 H 4527.20 ~ 125 V 4381.6-81.85~ 69 H 4529.40 ,/ 46 H 4382.20 '"'1~ 7b H 4530.70 47 H 4383.15 ~--~ 145 V .. 4530.~3i.3~ 48 H 4384.60 ~/~ 72 H 4532.20 g,, 49 H 4385.15 ~ 73 H 4533.70 ~ 50 H 4,386.10 ~ 74 H .4534.20 ~ 51 H , 4387.15~ 75 H 4535.20 ,~ 52 H 4436.20 [ :~ ~. .[4. '- ~ :! ~7~, '~ Page 1 ,J 6 £ 5 199 Alas .0.it .& .Gas Cons, BP SCHRADER BLUFF MPE-20 WELL CHIP SAMPLES DEPTH DEPTH DEPTH 4297.2 4377.0 4433.0 4298.0 4379.0 4434.0 4300.1 '4388.0 4435.0 4302.0 4389.0 4303.0 4390.0 4441 4314.0 4391.0 4442.0 4315.0 4392.0 4443.0 4316.0 4393.0 4445.0 4317.0 4394.0 4446.0 4318.0 4395.0 4322.0 4396.0 4450.0 4323.0 4397.0 4451.0 4324.0 4400.0 4452.0 4326.0 4401.0 4327.8 4402.0 4457.0 4403.0 4462.2 4330.0 4405.0 4464.0 4330.8 4406.0 4471.0 4334.0 4407.0 4484.0 4335.8 4408.0 4339.0 4409.0 4487.0 4340.0 4410.0 4488.0 4341.0 4411.0 4412.0 4490.0 4350.0 4413.0 4491.0 4353.3 4414.0 4492.0 4354.0 4415.0 4494.0 4356.0 4416.0 4495.0 4357.0 4417.0 4496.0 4359.0 4420.0 4498.0 4358.0 4499.0 4360.0 4422.0 4500.0 4362.0 4423.0 4501.0 4425.0 4502.0 4364.0 4426.0 4503.0 4365.0 4504.3 4366.0 4428.0 4505.0 4368.0 4429.0 4369.0 4430.2 4507.0 4371.0 4431.0 4508.0 4374.0 4432.0 4509.0 DEPTH 4510.0 4511.0 4512.0 4513.0 4514.0 4515.5 4521.0 4523.5 4528.0 4536.0 4537.0 4538.0 ~ 4539.0 4540.0~ 4541.0 4542.0 4543.0 4544.5 4545.0 4546.0 4547.0 4548.5 4549.0 4550.0 4551.0 4552.5 4543.0 4554.0 4555.0 4556.0 4557.0 4558.0 4559.0 4559.7 8/14/97 TTCS 5955 · '-",d~$ 2 5 1997 Alaska .Oil & Gas Cons. C_o. miaiss~ 'Aritho. raga BP EXPLORATION - BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 - (907) 561-5111 August12,1997 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Howard Oakland Dear Mr. Oakland, q 4- C)'~ t I am writing to you too inform you that we have put together a package of Core data for well E-20. The package consists of the following in order: 1. MPU E-20 Core Description Log 2. MPU E-20 Core Analysis 3. MPU E-20 PUT Analysis Also, MPU E-20 Core Chips are to follow under a separate shipment. Sincerely, I ~,.'.,,r.._ Senior Geologist Mark Vandergon ,'S e o i o g 'i c a I k1 a '~c e r'-i a 'i s .?.2 n v e n 'k o r" y 95 - 07 i 68 35 ¢_..~]~ 294 - 2587 i;~ W D 95--, 07 I BI--iP/FIN/-tL ..-d~".~ 200 .... a. 6a 2, 95-,- 07 'i DLL/B~LL ~,~ 200--4 69~.~ 95---071 GR/CCL PERF REC 95--071 PDLS PRZSH 95--071 F'RZSF~ L. OG/TEB~P ~4.190 .... ~550- 95--071 F'RZSB~ LOG/'TEF'iP 95.-'07 I SLII4 GR ~2600.-/~00 95---07 i S S VD/'I,~WD ~200 ..... 95 .... 07 i TEkiP g5~-07i ZDI.../GN ~4.200 .... ~6a2 SLIki GR Page; 'i .Da't;e'.: 07/'08/'97 RUN DATE .....RECVD 09/' i 06 / 'i 6 / 9 5 06 / 16 / 9 S 06/26.,/9 S 06/'26/95 06 / o 6 / . -~.. 95 06/" ;~ 0,./95 09 / I a. / 95 09 / 'i ,~.~ / 9 S 06/29/95 06/26/95- 06/; 0/95 09/I i/95 06 / i 6 / 95 09 / 'i/~/95 06/i6/95 iO--'a. 07 R COkiPLET..'EON DATE ~"/'O.3/'q)~' D A Z L '"," W E L L 0 P S R J?'C...'-f / ¢I-/" T 0 ~/0) / Ar'e dr'y d'¥'l:ch sampl es.,. r'equ'~ fed? yes ~ And r'ece'i red .~ '/~ , . c,4~ W,4qC'-¥3 ,~/~/~AJ-''/"~ J'a l°''''-- ,, ~'~/,'~/~/-~oi~/,,~"/q~ ~ -'/qp¢t v'/cc'~' ~"v~"x/~'-~,I. , ~ -, Was t:he wel'l ' Ar"e wei'i '~es'I;s r'equ'~r'ed? yes ~.._Rece'~'ved? ~~-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-71 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22561 14. Location of well at surface 9. Unit or Lease Name 3637' NSL, 1955' WEL, SEC. 25, T13N, RIOE i~ :~.'::! ~,i~ ?~...~ ~ Milne Point Unit ? ~.:?f~?.~i~:~ ilO. Well Number At Top Producing Interval ) MPE-20 3817'NSL, 2280' WEL, SEC. 25, T13N, RIOE I ?-'"""r~"~' ~'-i 11. Field and Pool At Total Depth ! ?"~! Milne Point Unit/Schrader Bluff 3815' NSL, 2282' WEL, SEC. 25, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 53.8' ADL 025518 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 05/24/95 06/06/95 09/03/95I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ]20. Depth where SSSV set 121. Thickness of Permafrost 4700' MD / 4663' TVD 4637' MD / 4600' TVD YES [] NO []I N/A feet MDI 1800'(Approx.) 22. Type Electric or Other Logs Run DLL, MLL, ZDL, CN, RG, CHT, GR, MWD 23. CASING, UNER AND CEMENTING RECORD SE'I-hUG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING R~ AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 SX Arcticset I (Approx.) 13-3/8" 54.5# K-55 31' 2587' 16" 784sxPF'E;250sx'G; 150SX PF'E' 9-5/8" 4 7/40# L-80 28' 4681' 12-1/4" 375 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" gun diameter, 12 spf 2-7/8", L-80 ESP set @ 4159' Gravel Packpacker @ 4249' MD MD TVD _~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4312'-4357' 4276;4321' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 'f'!. ~0;4528' 4403'-4491' Freeze protect w~ 14 bbls diesel 'N' Sands Frac'd w/26,900# 16-20 mesh carbofite '0' Sands Frac'd w~ 73,000# of 16-20 mesh carbolite 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 01/30/96 ESP Date of Test Hours Tested =RODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO lEST PERIOD ~ I Flow Tubing Casing Pressure 3ALCULATED DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithoiogy, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED ORI¢I AL Alaska Oil & Gas Cons. Colnmlssior~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONT1NUEDON REVERSE SIDE · -9. 30. GEOLOGIC MARr,,ERS r-oRMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) Top Schrader Bluff 4297' 4204' N Sands 4320' 4226' OA Sands 4440' 4347' OB Sands 4504' 4410' J 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~--~~d.~.-..- Title $¢niorDrfl/ingEngineer Date ~./~::~'/~-¢' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in-item-24~how-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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none'. Form 10-407 WESTPORT TECHNOLOGY CENTER INTERNATIONAL RECE]VE' ,) '~Jaska Oil & Gas Cons. Commission Anchorage Date~-~ ' -- liT RESEARCH INSTITUTE liT RESEARCH INSTITUTE Westport Technology Center International RESERVOIR FLUIDS WTCI-95-181 October 1995 RESERVOIR FLUID STUDY SCHRADER BLUFF (E-20) By C. Irani Work by R. Troupe Sponsored by: W. O. #HO8529H200 Approved by: R. J. Drozd liT Research Institute (Westport Technology Center International) makes no representations or warranties, either express or implied, and specifically provides the results of this report "as is" based on the information provided by client. WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE DISCUSSION Six MDT samples were collected at Schrader Bluff well (E-20) and shipped to IITRI's Westport Technology Center in Houston for further evaluation. Only one of the bottles, MDT Sample #2, bottle S/N 25, Tool #5-23 at 4446 ft depth, gave a sample fit for PVT analysis. The rest all showed drilling mud. A single stage flash of the oil gave the composition shown in Table 1. A constant composition expansion study at 92°F showed a bubble point at 1533 psia and a density at reservoir pressure (1972 psia) of 0.9150 g/cc. These results were reported to Dr. S-T Lee who confirmed that the Psat value was good and the reported density was only slightly higher than counterpart samples from similar depth-temperature regimes. He recommended that the experimental program be completed as scoped on the available sample. The only discrepancy observed was the possibility of a trace amount of water in the sample trapped in emulsion form. The results from a single stage separator study are presented in Table 3. The evolved GOR was measured to be 164 SCF/STB, and the formation volume factor was 1.066. The API of the spent oil was 16.7. Gas and liquid compositions from the separator study are presented in Tables 4 and 5. A five stage differential vaporization study was also undertaken with the results summarized in Tables 6 and 7. Compositions of the gas and liquid phases generated during the differential liberation study are presented in Tables 8 and 9. The API of the residual oil from the differential vaporization study was measured to be 15.8. Table 10 presents the results of a viscosity study in the one and two phase region on the recombined sample. Viscosity measurements were kept above 597 psia so as to avoid venting any of the gas phase and compromising the sample. After the viscosity measurements were completed the sample was made one phase again and returned to the original container so as to keep as much of the sample as possible intact for further studies. It is estimated that there is about 100 cc of live oil left. Prepared for BP Exploration Page 1 WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 1 Schrader Bluff MDT Sample Single Flash Composition Component Wt.% Mole. Wt. Mole.% Nitrogen 0.006 28.01 0.048 Carbon Dioxide 0.006 44.01 0.030 Methane 2.131 16.04 30.755 Ethane 0.043 30.07 0.331 Propane 0.025 44.10 0.132 iso-Butane 0.022 58.12 0.086 ;n-Butane 0.049 58.12 0.196 iso-Pentane 0.055 72.15 0.176 n-Pentane 0.069 72.15 0.223 Hexanes 0.218 84 0.600 Benzene 0.007 78.12 0.021 Heptanes 0.421 96 1.015 Toluene 0.038 92.15 0.096 Octanes 0.631 107 1.366 Nonanes 0.726 121 . 1.389 Decanes 1.045 134 1.806 Undecanes 1.398 147 2.202 Dodecanes 1.784 161 2.566 Tridecanes 2.285 175 3.023 Tetradecanes 2.583 190 3.148 !Pentadecanes 3.050 206 3.428 Hexadecanes 2.889 222 3.013 Heptadecanes 2.924 237 2.857 Octadecanes 2.550 251 2.352 Nonadecanes 2.992 263 2.634 Eicosanes 2.797 275 2.355 Henicosanes 2.589 291 2.060 Docosanes 2.498 305 1.897 Tricosanes 2.112 318 1.538 Tetracosanes 2.126 331 1.487 Pentacosanes 1.955 345 1.312 Hexacos anes 1.958 359 1.263 Heptacosanes 1.900 374 1.176 Octacosanes 1.995 388 1.191 Nonacosanes 1.821 402 1.049 Triacontanes + 50.302 550 21.178 GOR from single flash= 175.75 scF/STB Prepared for BP Exploration Page 2 ,-- , WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 2 Sachrader Bluff MDT Sample CCE at 92 °F Pressure Relative Liquid (psia) Volume Fraction 40O0 0.987 3500 0.989 3000 0.991 2500 0.993 2000 0.995 1972 0.995 1886 0.996 1800 0.996 1715 0.997 1628 0.998 1544 0.999 1533 1.000 1511 1.003 1490 1.006 1470 1.009 1447 1.014 1412 1.020 1384 1.021 1353 1.024 1323 1.029 1299 1.033 1272 1.039 1234 1.044 0.981 1227 1.047 0.979 1212 1.051 0.971 1190 1.056 0.968 1158 1.065 0.959 1119 1.075 0.950 1047 1.097 0.926 931 1.140 0.891 761 1.225 0.824 576 1.389 0.726 435 1.624 0.620 291 2.099 0.475 Density at 4000 psia=0.9283 g/cc Density at 1972 psia=0.9150 g/cc Page 3 Prepared for BP Exploration WESTPORT TECHNOLOGY CENTER INTERNATIONAL lit RESEARCH INSTITUTE TABLE 3 Schrader Bluff MDT Sample Multistage Separation Summary Stage 1 2 Pressure (psia) 75 15 Temperature (°F) 75 75 GOR (SCF/STB) 156 8 Oil Density (g/cc) 0.9436 0.946 Gas Gravity 0.5735 0.6344 Separator Volume 1.01332 1.0095 Factor Total GOR (SCF/STB) : 164 Formation Volume Factor**: 1,066 APl Spent Oil ' : 16.7 * Oil Densities at Separator Conditions **Based on Reservoir Pressure=1972 psia and Temp.=92°l: Prepared for BP Exploration Page 4 WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 4 Schrader Bluff MDT Sample Wellstream Analysis Stage I 2 Pressure (psia) 75 15 Temperature(°F) 75 75 Gas Gravity 0.5735 0.6344 Component (Mole %) (Mole %) Nitrogen 0.043 0.072 Carbon Dioxide 0.087 0.252 Methane 98.163 93.684 Ethane 0.928 2.648 Propane 0.236 0.892 i-Butane 0.086 0.061 n-Butane 0.138 0.596 i-Pentane 0.063 0.338 n-Pentane 0.057 0.334 Hexanes 0.055 0.347 Benzene 0.002 0.008 Heptanes 0.062 0.389 Toluene 0.007 0.035 Octanes 0.031 0.177 Nonanes 0.022 0.108 Decanes 0.011 0.039 Undecanes 0.005 0.014 Dodecanes 0.002 0.002 Tridecanes plus 0.002 0.004 Prepared for BP Exploration Page 5 WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 5 Schrader Bluff Sample Multistage Separation Residual Oil Analysis Component Weight % Ethane 0.002 Propane 0.011 i-Butane 0.015 n-Butane 0.040 i-Pentane 0.050 n-Pentane 0.066 Hexanes 0.217 Benzene 0.010 Heptanes 0.441 Toluene 0.051 Octanes 0.670 Nonanes 0.772, Decanes 1.065 Undecanes 1.393 Dodecanes 1.799 Tridecanes 2.324 Tetradecanes 2.675 Pentadecanes 3.006 i Hexadecanes 2.853 i Heptadecanes 2.898 Octadecanes 2.863 Nonadecanes 2.911 Eicosanes 2.736 Henicosanes 2.610 Docosanes 2.381 Tricosanes .2.239 Tetracosanes 2.127 Pentacosanes 1.993 Hexacosanes 1.946 Heptacosanes 1.954 Octacosanes 2.006 Nonacosanes 1.813 Triacontanes 1.909 Henitriacontanes 1.652 Dotriacontanes 1.634 Tritriacontanes 1.505 Tetratfiacontanes 1.461 Pentatriacontanes 1.356 Hexatriacontanes + 42.542 API of Residual Oil =16.7 Prepared for BP Exploration Page 6 WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 6 Schrader Bluff MDT Sample Oil Properties From Differential Vaporization Study Pressure Oil Density Oil Relative For. Vol. Factor Sol. GOR Oil Viscosity (psia) (g/cc) Volume (Res. Bbls/STB) (SCF/STB) (cP) 1972 0.9180 1.000 1.150 171 62.100 1200 0.9195 0.994 1.143 135 73.000 900 0.9256 0.984 1.131 103 91.700 600 0.9302 0.975 1.121 71 117.600 300 0.9352 0.966 1.111 38 15 0.9440 0.952 1.094 0 API Spent Oil =15.8 TABLE 7 Schrader Bluff MDT Sample Gas Properties From Differential Vaporization Study Pressure Gas Density Gas Evolved Z Total Evolved Gas (psia) DV Step* STP** Gravity G O R Factor Gas Density Viscosity (g/cc) (g/cc) (SCF/STB) (g/cc) (cP) 1972 1200 0.0599 0.00069 0.5623 36 0.8822 0.000688 0.01338 900 0.0438 0.00069 0.5650 68 0.9528 0.000705 0.01268 600 0.0288 0.00069 0.5683 100 0.9737 0.000712 0.01211 300 0.0143 0.00069 0.5639 133 0.9739 0.000715 0.0117 15 0.0013 0.00076 0.6244 171 0.000734 0.0112 * At reservoir temperature and stage pressure **At 60°F and 14.65 psia Prepared for BP Exploration Page 7 WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 8 Schrader Bluff MDT Sample Gas Compositions from Differential Vaporization Study Stage 1 2 3 4 5 Pressure 1200 900 600 300 15 Component Mole % Mole % Mole % Mole % Mole % Nitrogen 0.798 0.378 0.049 0.061 0.009 Carbon Dioxide 0.046 0.060 0.061 0.089 0.191 Methane 98.504 98.942 99.145 98.769 94,495 Ethane 0.351 0.398 0.478 0.729 2.490 Propane 0.065 0.072 0.087 0.125 0.750 iso-Butane 0.022 0.025 0.019 0.039 0.308 n-Butane 0.032 0.033 0.036 0.059 0.544 iso-Pentane 0.024 0.016 0.019 0.028 0.249 n-Pentane 0.024 0.015 0.018 0.026 0.251 Hexanes 0.028 0.017 0.018 0.026 0.261 Benzene 0.001 0.000 0.000 0.000 0.005 Heptanes 0.035 0.018 0.019 0.024 0.234 Toluene 0.007 0.004 0.003 0.003 0.011 Octanes 0.021 0.010 0.009 0.011 0.123 Nonanes 0.014 0.006 0.005 0.006 0.053 Decanes 0.007 0.003 0.002 0.002 0.019 Undecanes 0.005 0.001 0.001 0.001 0.005 Dodecanes 0.003 0.001 0.001 0.001 0.001 Tridecanes + 0.013 0.001 0.030 0.001 0.001 Prepared for BP Exploration Page 8 WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 9 Schrader Bluff Differential Liberation Spent Oil Analysis Component Weight % Ethane 0.003 Propane 0.013 i-Butane 0.017 n-Butane 0.044 i-Pentane 0.055 n-Pentane 0.075 Hexanes 0.248 Benzene 0.023 Heptanes 0.536 Toluene 0.091 Octanes 0.820 Nonanes 0.964 Decanes 1.266 Undecanes 1.520 Dodecanes 1.933 Tridecanes 2.459 Tetradecanes 2.791 : Pentadecanes 3.092 Hexadecanes 2.951 Heptadecanes 2.977 Octadecanes 2.944 Nonadecanes 2.960 Eicosanes 2.834 Henicosanes 2.599 Docosanes 2.521 Tricosanes 2.244 Tetracosanes 2.146 Pentacosanes 2.079 Hexacosanes 1.967 Heptacosanes 1.971 Octacosanes 2.056 Nonacosanes 2.025 Triacontanes 1.780 Henitriacontanes 1.742 Dotriacontanes 1.635 Tritriacontanes 1.522 Tetratriacontanes 1.470 Pentatriacontanes 1.345 Hexatriaconmnes + 40.283 API of Residual Oil =15.8 Prepared for BP Exploration Page 9 WESTPORT TECHNOLOGY CENTER INTERNATIONAL liT RESEARCH INSTITUTE TABLE 10 Schrader Bluff Oil Viscosity Pressure' Viscosity (psia) (cP) 4003 89.7 3001 75.5 2502 67.9 1971 62.1 1598 60.1 1193 73.0 898 91.7 597 117.6 cP =0.012669922 *(psia) +37.9496 Viscosity above Psat Prepared for BP Exploration Page 10 TKv6-09 BP Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, 1995 Page 48 Table 6. Measured Properties sample Number 101V 2 3 4 102H 103H 104H _ - Core Number C1 C1 C1 C1 C1 C1 C1 Tube Number F1 F2 F2 F2 F3 F3 F3 __ ,S__a_m_ .p_,!e. De~th. !_ft) 4295.6-95.8 ..... 4~._0.? :.~. ..... 4301.2 4302.2 4305.2 4306.2 4307.2 Zone Mudstone Top NA NA NA NA Heterolithic Heterolithic Heterolithic Grain Density (g/cm3 ) 2.71 2.65 2.64 2.64 2.68 2.68 2.66 Porosity at 500 psi (%) 16.9 31.9 32.0 31,3 18.4 20.8 21.7 Klinkenberg Permeability at 500 psi (md) 5.45 246 245 256 6.92 4.17 2.3 Porosity at 1300 psi (%) 16.3 31.2 31.3 30,8 17.9 20.1 21.0 Klinkenberg Permeability at 1300 psi (md) 1.04 200 208 208 0.916 1.52 0.804 ,, Oil Saturation at 500 psi (%) 2.3 51.2 53.0 51.5 0.0 10.6 12.9 Water Saturation at 500 psi (%) 97.7 32.9 '32'.3 35.3 99.7 86.3 82.4 -- Total Fluids at 500 psi (%) 99.9 84.0 85.3 86.8 · 99.7 96.9 95.3 ..... Oil Saturation at 1300 psi (%) 2.3 52.8 54.7 52.8 0.0 10.9 13.5 W__a_!.,e_.r__.s_S__a.~t.~_r_at_!o_.n.. a~_!.~_.0_0,__p__s i' (?_o..) _9_7__7_ ................. _3_3_ ._ .9_ ............... 33.3 .................................. 36.2 100.0 89.1 85.7 Total Fluids at 1300 psi (%) 100.0 86.7 88.0 89.0 100,0 100.0 99.1 Sample Number ' ' 105H 106H 107H 5 108H 109H 6 Core Number C1 .... C1 Cl C1 C1 C1" Cl Tube Number F4 F4 F4 F5 F5 "F5 F8 Sample Dep{h ' (ft) 4308.2 4309.1 4310.2 4311.6 4312.2 4313.2 4319.8 Zone Heterolithic Heterolithic Heterolithic Heteroli'thic Heterolithic 'Heterolithic Heterolithic Grain Density (gT~c~TM) .... 2.69 .............. 2.64 " 2.65 2.67 .... 2.77 2.67 2.63 Porosity at 500 psi (%) 23.1 '2214' , 19.7 21.'6' 14.8 18.4 28.7 '" Klinkenberg Permeability at 500 psi (md) 3.'i9 ........... 18.80 4.85 3.27 7.77 3.45 157 !Porosity at 1300 psi (%) 22,4 21'.3 19.0 20.9 14.4 ....17.8 28.0 Klinkenberg Permeability at 1300 psi (md) 1.31 .......... 7.65 0.7,41 1.33 1.12 0.851 111 Oil Saturation at 500 psi (%) 22.5 3,9 3.0 10.6 0.0 0.0 35.9 Water Saturation at 500 psi (%) 69.4 82.3 92.8 80.5 99.7 99.8 41.8 Total Fluids at 500 psi (%) 91.9 -- 86'.'2 '95.'8 91.1 '99.7 99.8 77.8 Oil Saturation at 1300 psi (%) 23.3 4,2 3.1 11.1 0.0 0.0 37.1 Water Saturation at 1300 p-si (%) 7i'.8 ..... 87.7 96.9 83.8 100.0 100.0 43.3 Total Fluids at 1300 psi (%) 95.1 .... 91.9 100.0 94.9 i00.0 100.0 80.4, .... RECEiVI ;B MI ( ~ 0 FILMED Univ~"er~siryl'R~esTaI~ch~Park I 1{SI 420 Wakara Way * Salt Lake City , Utah 84108 Date [ ~ Telephone (801) 584-2400 I - ~ Fax (801) 584-2432 AUG 15 1997 Alaska Oil & Gas Cons. Commission Anchorage TR~6-09 BP Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, 1995 Page 49 Sample Number 111H 110H 112V 113H 8H 9H 10H -- Core Number C1 C1 C2 C2 C2 C2 C2 Tube Number F8 F8 F1 F1 F2 F2 F3 Sample Depth (ft) 4321.05 4321.75 4325.1-25.35 4325.4 4328.4 4329.2 4332.2 Zone Heterolithic Heterolithic Heterolithic Heterolithic NB Heterolithic NB Grain Density (g/cms ) 2.61 2.63 2.70 2.68 2.68 2.67 2.69 Porosity at 500 psi (%) 26.7 24.3 20.5 18.5 32.5 23.3 28.6 Klinkenberg Permeability at 500 psi (md) 35.9 9.77 1.95 4.87 257 30.5 46.1 Porosity at 1300 psi (%) 25.5 23.7 19.9 18.1 31.6 22.5 27.9 Klinkenberg Permeability at 1300 psi (md) I 24.2 6.35 0.616 1,06 232 17.7 38.8 Oil Saturation at 500 psi (%) 17.6 16.5 0.0 0.0 56.3 18.1 40.4 --. , Water Saturation at 500 psi (%) 61.5 71.8 98.2 99.9 26.4 74.1 44.6 Total Fluids at 500 psi (%) 79.0 88.3 98.2 99.9 82.7 92.2 85.0 Oil Saturation at 1300 psi (%) 18.7 17.0 0.0 0.0 58.8 18.9 41.7 Water Saturation at 1300 psi (%) -- 65.4 74.2 100.0 100.0 27.5 77.5 46. i Total Fluids at 1300 psi (%) 84.0 91.2 100.0 100.0 86.3 96.4 87.8 Sample Number 11H 12H 13H 14H 114H 15H 16H Core Number C2 C2 C2 C2 C2 C2 C2 Tube Number F3 F3 F4 F4 F4 F5 F6 Sample Dep{h (ft) 4333.2 4334.2 ---4336.2 4337.2 4338.2 4339.55 4343.2 Zone NB NB Mudstone Mudstone/Siltstone Mudstone NB NB Grain Density (g/cm3 ) 2.68 2.69 2.66 2.67 2.66 2.69 2.7 Porosity at 500 psi (%) 32.0 26.8 17.3 22.0 17.4 30.3 29.9 Klinkenberg Permeability at 500 psi (md) 251 23.6 1.33 16.3 4.91 195 52.1 Porosity at 1300 psi (%) 31.2 26.1 16.8 21.3 16.9 29.5 29.0 ._ Klinkenberg Permeability at 1300 psi (md) 213 14.8 0.712 7.69 1.1 7 166 43.5 Oil Saturation at 500 psi (%) 52.6 35.4 0.0 18.1 0.0 53.7 53.9 Water Saturation at 500 psi (%) 36.0 50.7 95.8 72.1 99.8 35.4 36.8 !Total Fluids at 500 psi (%) 88.6 86.1 95.8 90.2 99.8 89.1 90.7 Oil Saiuration at 1300 psi (%) 54.5 36.6 0.0 18.9 0.0' 55.6 56.2 Water Saturation at 1300 psi (%) 37.3 52.5 99.0 75.1 100.0 36.6 38.3 Total Fluids at 1300 psi (%) 91.8 89'.2 99.0 94.0 100.0 92.2 94.5 , , Terrc Tek University Research Park 420 Wakara Way * Salt Lake City, Utah 84108 Telephone (801) 584-2400 Fax (801) 584-2432" TRy6-09 BP Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, 1995 Page 50 Sample Number I 115H 20H 18H 19H 21H 22H 23H -- Core Number ! C2 C2 C2 C2 C2 C2 C3 Tube Number F6 F7 F7 F7 F8 F8 F1 Sample Depth (ft) 4344.2 4345.5 4346.5 4347.5 4348.2 4349.2 4355.2 Zone Mudstone Mudstone/SiltstoneMudstone/Siltstone Heterolithic NC NC Heterolithic Grain Density (g/cm3) 2.70 2.66 2.66 2.65 2.65 2.66 2.66 Porosity at 500 psi (%) 19.9 26.7 19.7 18.3 29.3 35.2 21.1 Klinkenberg Permeability at 500 psi (md) ! 0.652 42.6 4.49 4.33 617 600 25.4 Porosity at 1300 psi (%) 19.4 _ 26.0 19.1 17.8 28.8 33.9 20.'2 Klinkenberg Permeability at 1300 psi (md) 0.491 30.3 0.875 0.432 571 485 7.13 Oil Saturation at 500 psi (%) 0.0 42.3 2.5 0.0 45.1 54.3 7.8 Water Saturation at 500 psi (%) 100.0 44.1 92.0 93.0 54.6 26.0 88.7 Total Fluids at 500 psi (%) 100.0 86.4 94.4 93.0 99.7 80.3 96.5 Oil Saturation at 1300 psi (%) 0.0 43.7 2.6 0.0 45.3 57.4 8.1 Water Saturation at 1300 psi (%) 100.0 45.6 95.3 96.0 54.7 27.4 91.9 Total Fluids at 1300 psi (%) 100.0 89.3 97.9 96.0 100.0 84.8 100.0 Sample Number 24H 116H 121V 25H 117H 118H 119V Core Number C3 C3 C3 C3 C3 C4 C4 Tube Number F3 F6 F6 F6 F6 F1 F1 Sample Depth (ft) 4361.15 4367.85 4367.85-68.25 4368.2 4368.85 4372.2 4372.3-.6 Zone Siltstone/Mudstone ND ND ND ND Heterolithic Heterolithic Grain Density (g/cm3 ) 2.7 2.67 2.66 2.67 2.65 2.66 2.66 Porosity at 500 psi (%) 2912 33.5 32.2 33.3"' 25.6 19.7 20.4 Klinkenberg Permeability at 500 psi (md) 37.8 .............. 312 ' " 148 156 15.7 12.0 3.47 Porosity at 1300 psi (%) 28.1 32.5 31.3 '" 32.1 24.9 18.9 " 19.8 Klinkenberg Permeability at 1300 psi (md) 28.8 262 126 127 11.1 1.83 0.680 Oil Saturation at 500 psi (%) 37.0 62.7 55.4 56.8 30.9 0.0 '" 0.0 .... Water Saturation at 500 psi (%) 53.2 27.7 34.5 29.0 56.6 99.8 99.9 ITotal Fluids at 500 psi (%) 90.2 90.4 89.9 85.8 87.6 99.8 99.9 Oil Saturation at 1300 psi (%) 38.9 65.5 57.7 60.0 "32.0 0.0 0.0 'Water Saturation at 1300 psi (%) 56.0 28.9 35.9 30.6 58.5 100.0 100.0 ,, Total Fluids at 1300 psi (%) 94.9 94.4 93.6 90.6 90.5 100.0 100.0 Terrc Tek University Research Park 420 Wakara Way · Salt Lake City, Utah 84108 Telephone (801 ) 584-2400 Fax (801) 584-2432 TRy6-09 BP Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, 1995 Page 51 Sample Number~I 120H 26H 27H 28H 122H 123H 124H Core Number C4 C4 C4 ...... C4 C4 C4 C4 Tube Number F1 F2 F2 F3 F3 F3 F3 ___ __. Sample Depth (ft) 4373.2 4374.2 4375.2 4377 4377.2 4378.2 4379.2 Zone Mudstone/Heterolithic N E N E N E N E N E N E Grain Density (g/cm3) 2.63 2.7 2.66 2.7 2.7 2.67 2.68 POrosity at 500 psi (%) 17.9 32.1 29.9 15.2 25.5 30.0 27.3 Klinkenberg Permeabilit--y at 500 psi (md) 3.69 202 143 4.75 94.4 98.4 26.9 Porosity at 1300 ps~i (%) 17.4 31.3 29.1 _ 14.7 24.8 29.3 26.4 Klinkenberg Permeability at 1300 psi (md) 0.813 179 126 1.81 77.9 78.2 20.0 Oil Saturation at 500 psi (%) 0.0 53.3 40.9 40.6 51.1 43.1 37.9 Water Saturation at 500 psi (%) 97.9 25.3 38.6 32.3 35.5 42.0 52.3 Total Fluids at 500 psi (%) 97.9 78.6 79.4 72.9 86.6 85.2 90.2 Oil Saturation at 1300 psi (%) 0.0 55.4 42.3 42.3 53.0 44.6 39.6 Water Saturation at 1300 psi (%) 100.0 26.3 40.0 33.7 36.9 43.4 54.6 Total Fluids at 1300 psi (%) 100.0 81.7 82.3 76.0 89.8 88.0 94.2 Sample Number ', 45H 125V 46I-t ' 47H 48H 49H 50H Core Number C4 C4 C4 C4 C4 C4 C4 -- Tube Number F4 F4 F4 F4 F5 F5 F5 Sample Depth (~) 4381.3 4381.6-.85 4382.2- 4383.15 4384.6 4385.15 4386.1 Zone -'- NE NE NE NE NE Heterolithic Heterolithi'c Grain Density (g/cms ) 2.71 2.68 2.7 2.68 2.67 2.68 2.67 , Porosity at 500 psi (%) 28.5 26.6 30.9 27.0 30.5 22.6 21.0 Klinkenberg Permeability at 500 psi (md) 46.3 10.4 92.3 32.0 99.7 5.31 9.74 Porosity at 1300 psi (%) 27.6 25.8 30.1 26.2 29.5 21.9 20.4 Klinkenberg Permeability at 1300 psi (md) 31.4 4.98 82.2 24.4 70.3 1.65 2.12 Oil ,Sa! u__r .a.!!o_n__a!_.5__0p_.p_.?!._( _¥_o!' 35.1 36.6 ......................... 55.0 39.5 38.3 21.9 5.9 Water Saturation at 500 psi (%) 51.4 55.1 31.6 48.9 51.9 70.0 90.8 Total Fluids at 500 psi (%) 86.6 91.7 86.6 88.4 90.3 91.9 96.8 Oil Saturation at 1300 psi (%) 36.7 38.1 57.2 41.1 40.2 22.9 6.1 ,, Water Saturation at 1300 psi (%) 53.7 57.3 32.8 50.8 54.5 73.2 93.9 Total Fluids at 1300 psi (%) 90.3 ...... 95.4 .... 90.0 91.8 -- 94.7 '96.0 ' 100.0 Terro,Tek University Research Park 420 Wakara Way · Salt Lake City, Utah 84108 Telephone (801) 584-2400 Fax (801) 584-2432 TR~96-09 BP Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, 1995 Page 52 Sample Number i 51H ___ 52H 53H 54H 126H 127H 129V Core Number C4 C6 C6 C6 C6 C6 C6 Tube Number F5 F4 F4 F4 F6 F6 F7 Sample Depth (ft) 4387.15 4436.2 4437.8 4438.1 4443.9 4444.9 4447.95-48.25 Zone Heterolithic Heterolithic, Top OA Heterolithic,Top OA Heterolithic, Top OA Heterolithic, Top OA Heterolithic, Top OA Heterolithic, Top OA _. Grain Density (g/cm3) 2.67 2.67 2.65 2.65 2.68 2.67 2.66 Porosity at 500 psi (%) 24.1 21.0 24.8 22.9 19.6 18.7 17.9 Klinkenberg Permeability at 500 psi (md) 7'.12 ...... 44.5 20.7 16.7 11.30 1.1 2.06 Porosity at 1300 psi (%) 23.4 20.3 24.3 22.2 18.8 18.2 17.3 Klinkenberg Permeability at 1300 psi (md) 4.26 19.2 16.0 9.37 2.05 0.623 0.425 Oil Saturation at 500 psi (%) 18.1 13.2 31.2 22.5 2.6 0.0 0.0 -- Water Saturation at 500 psi (%) 75.5 72.1 50.6 64.6 88.4 92.7 97.3 -- Total Fluids at 500 psi (%) 93.6 85.4 81.8 87.1 91.0 92.7 97.3 Oil Saturation at 1300 psi (%) 18.8 13.8 32.0 23.4 2.7 0.0 0.0 Water Saturation at 1300 psi (%) 78.5 75.2 51.9 67.1 92.6 96.0 100.0 Total Fluids at 1300 psi (%) 97.3 89.0 83.9 90.5 95.3 96.0 100.0 Sample Number 128H 130H 131V 29H 30H 132H 133H __ -- Core Number C6 C6 C6 C6 C6 C6 C6 Tube Number F7 F7 F7 F7 F8 F8 F9 Sample Depth (ft) 4447.95 4448.95 4448.95-49.25 4449.95 4450.9 4451.9 4453.9 Zone Heterolithic, Top OA Heterolithic, Top OA OA OA OA Heterolithic OA Grain Density (g/cm3 ) 2.66 2.70 2.69 2.66 2.7 2.7 2.68 Porosity at 500 psi (%) 17.8 19.0 19.9 29.5 16.1 4.9 30.8 Klinkenberg Permeability at 500 psi (md) 8.48 16.9 3.07 130 6.47 3.88 167 Porosity at 1300 psi (%) / 1'7.2 " i8.3 19.'1 28.6 15.8 4.7 30.1 T Klinkenberg Permeability at 1300 psi (md) 1.63 4.75 0.594 109 3.96 1.14 161 Oil Saturation at 500 psi (%) 0.0 0.0 0.0 39.0 46.5 0.0 57.8 Water Saturation at 500 ~-~-~'-(a~o'i .................... 93.0 ................. 88.3 91.8 ....... 35.6 24.1 79.3 27.3 Total Fluids at 500 psi (%) 93.0 88.3 91.8 74.6 70.5 79.3 85.2 , Oil Saturation at 1300 psi (%) 0.0 0.0 0.0 40.6 47.6 0.0 59.7 -- Water Saturation at 1300 psi (%) 96.8 92.2 96.3 37.1 24.6 81.6 28.2 Total Fluids at 1300 psi (%) 96.8 92.2 96.3 77.7 72.2 81.6 87.9 Terrc Tek University Research Park 420 Wakara Way · Salt Lake City, Utah 84108 Telephone (801) 584-2400 Fax (801) 584-2432 TRy6-09 BP Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, 1995 Page 53 Sample Number 134V 31H 139V 138H 32H 33H 34H Core Number C6 C6 C6 C6 C6 C7 C7 _., Tube Number F9 F9 F9 F9 Fl0 F1 F1 Sample Depth (ft) 4454.2-54.5 4454.35 4454.5-54.8 4454.7 4455.75 4454.4 4455.5 Zone / OA OA OA OA OA OA OA Grain Density (g/cm3 )I 2.67 2.68 2.69 2.69 2.68 2.69 2.69 Porosity at 500 psi (%) 32.2 31.8 29.6 29.7 30.5 28.8 31.1 Klinkenberg Permeability at 500 psi, (md) 156 253 32.3 114 132 29.9 83.5 Porosity at 1300 psi (%) 31.4 31.1 28.7 29.0 29.7 27.8 30.3 Klinkenberg Permeability at 1300 psi (md) 136 223 25.5 84.0 113 19.3 73.5 Oil Saturation at 500 psi (%) 59.3 57.6 48.1 52.7 55.9 36.4 50.4 -- Water Saturation at 500 psi (%) 25.8 24.6 38.1 34.1 29.0 50.5 36.3 Total Fluids at 500 psi (%) 85.1 82.2 86.2 86.8 84.9 86.9 86.7 Oil Saturation at 1300 psi (%) 61.6 59.5 50.4 54.6 58.2 38.1 52.4 Water Saturation at 1300 psi (%) 26.8 25.4 39.9 35.3 30.2 52.9 37.7 Total Fluids at 1300 psi (%) 88.4 84.9 90.3 89.8 88.5 91.0 90.1 Sample Number 35H 135V '36H 37H 38H 39H 136H Core Number C7 C7 C7 C7 C7 C7 C7 -- Tube Number F2 F2 F2 F3 F3 F4 F4 Sample Dept'h (ft) 4457.7 4457.9-8.2 - 4458.3 4459.25 4460.25 4462.8 4463.8' ..-- -- Zone OA OA OA OA OA OA OA Grain Density (g/cm3 ) 2.69 2.04 2.68 2.69 2.69 2.67 2.17 Porosity at 500 psi (%) 32.3 32.6 33.2 34.1 30.6 30.9.. ' 25.4 ._ Klinkenberg Permeability at 500 psi (md) 130 ,112 182 266 100 70.3 8.47 Porosity at 1300 psi (%) 31.5 31.8 32.3 33.1 29.5 30.0 24.7 Klinkenberg Permeability at 1300 psi (md) 109100 97.4 168 231 71.0 54.7 4.45 Oil Saturation at 500 psi (%) 54.3 58.1 63.0 67.1 49.4 53.9 22.8 Water Saturation at 500 psi (%) 34.6 29.9 32.2 25.7 47.1 37.5 71.1 Total Fluids at 500 psi (%) 88.9 88.0 95.2 92.8 96.4 91.4 93.9 .... Oil Saturation at 1300 psi (%) 56.4 60.3 65.7 70.0 51.2 56.2 23.7 Water Saturation at 1300 psi (%) 35.9 31.0 33.6 26.9 48.8 39.1 74.1 Total Fluids at 1300 psi (%) 92.3 91.3 99.3 96.9 100.0 95.3 97.8 ,, Terr Tek University Research Park 420 Wakara Way · Salt Lake City, Utah 84108 Telephone (801 ) 584-2400 Fax (801) 584-2432 TR')4-09 I~P Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, ! 995 Page 54 Sample Number/i 40H 41H 42H 43H 137H 44H 55H Core Number I C7 C7 C7 C7 C7 C7 C8 Tube Number F5 F6 F6 F6 F7 F7 F1 Sample Depth (fl) 4465.45 _ 4467.45 4468.45 4469.45 __ 4470.55 4471.2 4485.2 Zone i OA ..... OA OA OA OA OA Heterolithic Grain Density (g/cm3 ) I 2.68 2.68 2.68 2.68 2.77 2.66 2.66 Porosity at 500 psi (%) j 36.0 _ 29.6 31.5 36.0 _ 3.0 32.8 31.6 Klinkenberg Permeability at 500 psi (md) I 448 54.3 94.5 336 15.9 197 153 Porosity at 1300 psi (%) I 34.7 28.6 30.5 _. 34.3 2.7 31.7 30.7 Klinkenberg Permeability at 1300 psi (md) ! 391 34.7 80.6 255 3.13 163 133 Oil Saturation at 500 psi (%) 61.7 42.0 40.8 63.4 3.7 40.3 34.8 . Water Saturation at 500 psi (%) 28.6 47.3 43.3 36.5 89.9 42.1 52.5 Total Fluids at 500 psi (%) 90.3 89.4 84.1 100.0 93.6 82.4 87.3 Oil Saturation at 1300 psi (%) 65.0 44.1 42.6 63.4 4.0 42.4 36.1 Water Saturation at 1300 psi (%) 30.2 49.6 45.2 36.5 96.0 44.3 54.6 .. Total Fluids at 1300 psi (%) 95.2 93.7 87.8 100.0 100.0 86.7 90.7 Sample Number 56H 57H 140H 141H 58H 142V 59H ._ : Core N umber C8 C8 C9 C9 C9 C9 C9 Tube Number F3 F5 F3 F3 F4 F4 F4 Sample Depth (ft) 4493.25 4497.5 4513.35 4514.35 4516.3 4517.1-17.4 4517.2 Zone Heterolith ic Heterolithic Mudstone, Top OB Mudstone, Top OB OB.'? (Fracture) OB OB . Grain Density (g/cm3 ) 2.69 2.68 2.71 2.67 2.66 2.68 2.68 Porosity at 500 psi (%) 28.0 27.6 19.4 19.6 33.8 30.8 29.7' Klinkenberg Permeability at 500 psi (md) 9.14 15.5 6.79 5.13 503 29.6 32.3 Porosity at 1300 psi (%) 26.9 ......26.8 18.9 .............. 19.0 33.3 30.0 29:0 Klinkenberg Permeability at 1300 psi (md) 5.85 11.6 1.09 0.489 455 22.3 28.3 Oil Saturation at 500 psi (%) 32.6 28.6 0.0 0.0 50.7 39.2 38.2 Water Saturation at 500 psi (%) 60.9 65.2 99.9 98.8 24.7 49.5 52.4 Total Fluids at 500 psi (%) 93.5 93.8 99.9 98.8 75.5 88.7 90.6 Oil Saturation at 1300 psi (%) 34.5 ........ 29.7 0.0 , __ 0.0 51.9 40.7 39.5 Water Saturation at 1300 psi (%) 64.3 67.8 100.0 100.0 25.3 51.3 54.1 Total Fluids at 1300 psi (%) 98.8 97.5 100.0 100.0 77.3 91.9 93.6 Terr Tek University Research Park 420 Wakara Way · Salt Lake City, Utah 84108 Telephone (801) 584-2400 Fax (801) 584-2432 TRy6-09 E~P Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, 1995 Page 55 Sample Number L 60H 61H 62H 143H 63H B4H 65H Core Numb%'~- ..........t C9 C9 C9 C9 C9 C9 C9 Tube Number F4 F5 F5 F5 F5 F5 F6 Sample Depth (ft) 4518.2 4519.7 4520 4521.1 4521.5 4522.2 4524.2 Zone OB OB OB OB OB OB OB Grain Dens'iiy ~-~n-3) 2.68 2.68 2.68 2.68 2.68 2.68 2.67 Porosity at 500 psi (%) 29.6 30.3 _ 29.8 28.6 27.7 ~30.5 31.1 Klinkenberg Permeability at 500 psi (md) 42.8 74.8 48.0 24.6 23.1 66.6 157 'Porosity at 1300 psi (%) 28.9 29.7 29.2 27.9 26.8 29.8 30.5 Klinkenberg Permeability at 1300 psi (md) 36.7 66.4 40.5 20.7 9.28 59.8 145 Oil Saturation at 500 psi (%) 39.9 38.1 39.7 34.3 22.3 39.7 43.7 Water Saturation at 500 psi (%) 50.6 50.0' 49.7 57.5 67.5 48.7 44.0 Total Fluids at 500 psi (%) 90.5 88.2 89.4 91.8 89.8 88.4, 87.7 Oil Saturation at 1300 psi (%) 41.1 39.3 40.9 35.5 23.4 41.0 44.8 ._ Water Saturation at 1300 psi (%) 52.2 51.5 51.2 59.5 70.7 50.3 45.1 Total Fluids at 1300 psi (%) 93.2 90.8 92.1 95.1 , ,94.0 ,,, 91.3 89.9 ,, ,, Sample Number 66H 67H 68H 144H 69H 70H 145V , Core Number C9 C9 C9 C9 C9 C9 C9 Tube Number F6 F6 F7 F7 F7 F8 F8 Sample Depth (f't) 4525.2 4526.2 4527.2 4528.2 4529.4 4530.7 4530.9-31.3 . ,, Zone OB OB (Fractures?) OB Mudstone? OB OB OB Grain Density (g/cms ) 2.68 2.65 2.68 2.70 2.70 2.69 2.68 Porosity at 500 psi (%) _ 29.3 36.2 ........ 31.7 1.6 31.6, ._ 25.4' 31.7 , Klinkenberg Permeability at 500 psi (md) 30.2 1060 237 7.71 144 83.3 133 , Porosity at 1300 psi (%) 28.6 34.9 ___ 31.0 1.4 31.0 24.7 31.0 Klinkenberg Permeability at 1300 psi (md) 23.5 944 218 1.72 114 64.7 109 Oil Saturation at 500 psi (%) 38.2 53.5 ...... 51.1 0.0 _ ""44.8' 28.1 44.5 - Water Saturation at 500 psi (%) 53.0 40.0 34.2 85.4 39.4 61.8 44.2 , Total Fluids at 500 psi (%) 91.2 93.5 85.3 85.4 84.3 89.9 88.6 Oil Saturation at 1300 psi (%) 39.6 56.2 52.6 0.0 46.1 29.1" 45.9 Water Saturation at 1300 psi (%) 54.9 42.0 35.2 97.1 40.5 64.1 45.7 Total Fluids at 1300 psi (%) 94.4 98.2 87.9 97.1 86.6 93.2 91.6 Terrc Tek University Research Park 420 Wakara Way · Salt Lake City, Utah 84108 Telephone (801) 584-2400 Fax (801) 584-2432 TRY6-09 BP Exploration, (Alaska) Inc. Routine Core Analysis Schrader BluffMPE-20 October 2, t 995 Page 56 Sample Number I 71H 72H 73H 74H 75H 146H 147H Core Number C9 C9 C9 C9 C9 C10 C10 -- --ube Number F8 F8 F9 F9 F9 F1 F1 Sample Depth (ft) 4531.1 4532.2 4533.7 4534.2 4535.2 4537.2 4538.2 Zone OB OB OB OB OB OB OB/Transitional -- Grain Density (g/cm3) 2.68 2.69 2.69 2.69 2.7 2.71 2.71 Porosity at 500 psi (%) 30.8 31.3 33.7 28.9 31.5 21.3 22.8 Klinkenberg Permeability at 500 psi (md) 202 218 363 23.0 103 12.2 22.0 Porosity at 1300 psi (%) 30.1 30.7 33.1 28.1 30.7 20.7 22.1 Klinkenberg Permeability at 1300 psi (md) 184 198 345 16.4 86.2 5.33 8.50 Oil Saturation at 500 psi (%) 38.3 42.0 48.6 28.8 42.7 12.6 12.4 Water Saturation at 500 psi (%) 47.3 44.6 35.2 60.0 46.0 82.9 83.3 Total Fluids at 500 psi (%) 85.6 86.6 83.8 88.7 88.7 95.5 95.6 Oil Saturation at 1300 psi (%) 39.6 43.1 50.0 29.9 44.3 13.1 12.9 Water Saturation at 1300 psi (%) 48.8 45.8 36.2 62.4 47.7 86.1 86.6 __ Total Fluids at 1300 psi (%) 88.4 89.0 86.2 92.3 92.0 99.2 99.5 Sample Number 148H 149H Core Number C10 C10 -- Tube Number F1 F2 -- Sample Depth (ft) 4539.2 4540.2 Zone Heterolithic Heterolithic Grain Density (g/cm3 ) 2.68 2.67 Porosi__ty at ,.5_0_~0...p..s.!.. (.%.! ............. i .2_.6_..2_ .......................... _2_2_.0___ Klinkenberg Permeability at 500 psi (md) 8.62 9.48 ...... Porosity at 1300 psi (%) 25.4 _ 21.4 Klinkenberg Permeability at 1300 psi (md) 5.14 3.07 Oil Saturation at 500 psi (%) 20.6 0.0 Water Saturation at 500 psi (%) '7~.~ ..........~6.4 -- __-. Total Fluids at 500 psi (%) 99.9 96.4 Oil Saturation at 1300 psi (%) 20.6 0.0 -- Water Saturation at 1300 psi (%) 79.4 99.9 Total Fluids at 1300 psi (%) 100.~ 99.9 ..... Terr Tels University Research Park 420 Wakara Way ,, Salt Lake City, Utah 84108 Telephone (801) 584-2400 Fax (801) 584-2432 BP/AAI SHARED SERVIC~ DAILY OPERATIon, S PAGE: 1 WELL: MPU E-20 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/24/95 03:00 SPUD: RELEASE: 09/03/95 02:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 4ES 05/24/95 ( 1) TD: 112'( 0) 05/25/95 (2) TD: 327' ( 215) 05/26/95 (3) TD: 2060' (1733) 05/27/95 (4) TD: 2607' ( 547) RIG UP MW: 0.0 VIS: 0 MOVE RIG F/ MP E-15 TO MP E-20. BUILD BERMS. MIX SPUD MUD. NU DIVERTER. GENERAL RIG UP. DRILLING MW: 0.0 VIS: 0 FINISH BUILD BERMS AND RIG INSPECTION. FINISH NU 20" DIVERTER. NU FLOWLINEAND DIVERTER LINE. LOAD FLOOR W/ BHA #1. PU MOTOR. FUNCTION TEST DIVERTER. BROKE PINS ON ANADRIL STAB BREAKER PLATE. REPAIR SAME. CHANGE OUT STAB. TAG CEMENT @ 52'. PU STAND OF HWDP. FINISH REPLACE BULL PLUGS IN SUCTION LINES AND INSTALL SAFETY CLAMP ON PUMP LINE. DRILL 60' CEMENT. PLUGGED FLOWLINE. CIRC AND CONDITION MUD FOR CEMENT CONTAMINATION. DRLG 112 - 327'. DRILLING MW: 0.0 VIS: 0 DRLG 16" HOLE 327 - 330'. POH. PU REMAINING BHA. DRLG 16" HOLE F/ 330 - 1070'. SHORT TRIP TO JARS. NO PROBLEMS. DRLG 16" HOLE F/ 1070 - 2020' PUMP SWEEP. CBU. SHORT TRIP TO HWDP. NO PROBLEMS. ~RLG 16" HOLE F/ 2020 - 2060' CIRC AND COND F/ CEMENT MW: 0.0 VIS: 0 DRLG F. 2060 - 2607'. CIRC SWEEPS. COND MUD. SHORT TRIP TO HWDP. SLM. NO CORRECTION. NO HOLE PROBLEM. CIRC SWEEPS. COND MUD. POH. LD MWD. NO PROBLEMS. LEVEL RIG. RU TO RUN 13 3/8" CSG. RIH W. 13 3/8" CSG TO 2554'. FILL. WASH AND WORK PIPE TO 2587'. LAND CSG. CIRC AND COND MUD FOR CEMENT JOB. WELL : MPU E-20 OPERATION: RIG : NABORS 22E PAGE: 2 05/28/95 (5) TD: 2607' ( 0) 05/29/95 (6) TD: 3937' (1330) 05/30/95 (7) TD: 4295' ( 358) 05/31/95 (8) TD: 4295' ( 0) 06/01/95 (9) TD: 4353' ( 58) RIH W/ BHA 92 MW: 0.0 VIS: 0 CIRC AND CONDITION MUD W/ NO LOSS. FINISH INJ EXCESS MUD. HALLIBURTON PUMPED 10 BBLS H20, TESTED LINES, PUMPED 65 BBLS, H20, 784 SX 'E' PERMAFROST CEMENT, 250 SX PREMIUM 'G' W/ ADDITIVES AND 5 BBLS H20. DISPLACE W/ RIG PUMPS. BUMPED PLUG. CHECK FLOATS. OK. HAD SMALL AMOUNT OF CEMENT CONTAMINATED MUD TO SURFACE. HAD FULL RETURNS THROUGH OUT JOB. RD CEMENT HEAD AND CSG TOOLS. ND 20" DIVERTER. UNABLE TO WDRK 3/4" TOP JOB PIPE BELOW 1ST CSG CPLG. WELD UP NEW 3/4" PIPE AND RIH TO 112'. PERFORM 150 SK TOP JOB. INSTALL BIG BORE FMC WELL HEAD AND TEST SEAL. NU BOPE. INSTALL TEST PLUG. TEST ALL BOPE W/ ANNULAR TO 3500 PSI. RD TEST EQUIPMENT. PULL TEST PLUG. INSPECT AND INSTALL WEAR BUSHING. CHANGE PLATE ON TORQUE TUBE WHILE SERVICE TOP DRIVE. RIH W/ BHA. CHANGE STAB BLADES F/ 16" TO 12 1/4". DRILLING MW: 0.0 VIS: 0 FINISH MU BHA. RIH TO 1089'. TEST MWD. CUT AND SLIP DRAG LINE. LEVEL RIG. RIH. TAG CEMENT AT 2490'. TEST CSG. BLOW DOWN CHOKE MANIFOLD. DRILL OUT FLOAT EQUIP, CEMENT AND 10' OF NEW FORMATION TO 2617' CBU. PERFORM 12.0 PPG FIT. DRAG AND MWD SURVEY F/ 2617 - 3625'_ CBU_ SHORT TRIP TO SHOE. HOLE SWABBING. BACK REAM F/ 2900' TO SHOE. RIH. TIGHT F/ 3230 - 3240'. DRAG AND MWD SURVEY F/ 3625 - 3680'. CIRC OUT SWEEPS AND CLAY. SCREENS BLINDING. DRAG AND MWD SURVEY F/ 3680 - 3937'. CLEAN PITS/MIX CORE FLUID MW: 0.0 VIS: 0 CIRC HOLE CLEAN. DRAG 12 1/4" HOLE F/ 3937 - 4200'. CIRC SWEEPS. POH TO SHOE. NO PROBLEMS. PUMP PILL. POH. LD BHA. CLEAR FLOOR. SERVICE WEAR BUSHING. MU BHA 93. TEST MWD. RIH TO 4100'. MAD PASS W/ GR F/ 4100 - 4295' TO TIE IN LOGS. DRAG 9 7/8" HOLE F. 4200 - 4295'. CIRC SWEEPS. COND MUD. PUMP PILL. POH TO SHOE. NO PROBLEMS. INJECT MUD. CLEAN PITS. MIX CORE FLUID. CIRC AND COND MUD F/ CORE MW: 0.0 VIS: 0 MIX 1000 BBLS CORE FLUID. RIH TO 4295'. NO PROBLEMS. PUMP 30 BBL XANVIS/DESCO SPACER. DISPLACE WELL W/ CORE FLUID. MONITOR WELL. PUMP PILL. POH TO SHOE. MONITOR WELL. POH LD JARS AND MW/). CLEAR FLOOR. SERVICE WEAR RING. MU CORE BBL ASSEMBLY AND RIH TO 4261'. WORK THROUGH SMALL BRIDGE AT 4261' WASH TO 4295'. CBU. POH W/ CORE BBL #2 MW: 0.0 VIS: 0 FINISH CIRC BOTTOMS UP. DROP BALL AND ESTABLISH PUMP RATES. CORE FROM 4295 - 4325'. MONITOR WELL AND POH SLOW. L/D CORE BBL 91. RECOVERED 29' OUT OF 30'. CHECK CORE BIT AND M/U CORE BBL #2. RIH FOR 92 CORE RUN. CIRC AND COND MUD. CORE FROM 4325 - 4353'. MONITOR WELL AND POH SLOW. WELL : MPU E-20 OPERATION: RIG : NABORS 22E PAGE: 3 06/02/95 (10) TD: 4400'( 47) 06/03/95 (11) TD: 4454'( 54) 06/04/95 (12) TD: 4484'( 30) 06/05/95 (13) TD: 4530' ( 46) 06/06/95 (14) TD: 4560' ( 30) 06/07/95 (15) TD: 4700' ( 140) POH W/ CORE BBL #4 MW: 0.0 VIS: 0 FINISH POH. LD CORE #2. RECOVERED 26' OUT OF 28' CHECK BIT AND RIH WITH CORE BBL #3. CIRC AND COND 1C3D. DROP BALL. CORE FROM 4353 - 4371'. CORE BBL JAMMED. MONITOR WELL. POH SLOW. RECOVERED 17' OF 18' CORED. CHECK BIT AND RIH WITH CORE BBL #4. CIRC AND COND MUD. DROP BALL AND CORE FROM 4371 - 4400'. MONITOR WELL AND POH SLOW. POH W/ CORE BBL #6 ~ MW: 0.0 VIS: 0 POH W/ CORE #4. RECOVERED 27' OF 29' CORED. CHECK BIT AND RIH WITH CORE BBL #5. CIRC AND COND MUD. DROP BALL AND CORE FROM 4400 - 4427'. MONITOR WELL AND POH SLOW. L/D CORE #5. RECOVERED 27' OF 27'. SERVICE WEAR RING CHECK BIT AND RIH WITH CORE BBL #6. CIRC AND COND MUD. DROP BALL. CORE FROM 4427 - 4454'. MONITOR WELL AND POH SLOW WITH CORE #6'. RIH WITH CORE BBL #8 MW: 0.0 VIS: 0 FINISH POH WITH CORE #6. RECOVERED 25' OF 27' CORED. CHECK BIT AND RIH WITH CORE BBL #7. CIRC AND COND MUD. DROP BALL. CORE FROM 4452 - 4484' MONITOR WELL AND POH SLOW. RECOVERED 17 - 30' CORED. CHECK BIT AND RIH WITH CORE BBL #8 TO 1015'. SLIP AND CUT DRILL LINE. WORKING ON CROWN O MATIC. WOULD NOT RELEASE. POH W/ CORE BBL #9 MW: 0.0 VIS: 0 REPAIR CROWN 0 MATIC. FINISH RIH WITH CORE BBL #8. CIRC AND COND MUD. DROP BALL. CORE FROM 4484 - 4506' MONITOR WELL. POH SLOW W/ CORE BBL #8. RECOVERED 22' OF 22' CORED. CHECK BIT AND RIH WITH CORE BBL #9. CIRC AND COND MUD. DROP BALL. CORE FROM 4506 - 4530' MONITOR WELL AND POH SLOW WITH CORE #9. P/U BHA #5 MW: 0.0 VIS: 0 FINISH POH W/ CORE BBL #9. RECOVERED 31' OF 24' CORED. CHECK BIT AND RIH WITH CORE BBL #10. CIRC AND COND MUD. DROP BALL. CORE FROM 4530 - 4560'. MONITOR WELL. POH SLOW. RECOVERED 22' OF 30' CORED. TOTAL RECOVERY 92% FROM 4295 - 4560' PULL WEAR RING AND INSTALL TEST PLUG. TEST BOPE. PULL TEST PLUG AND INSTALL WEAR RING. MU BHA #5. CIRC MW: 0.0 VIS: 0 FINISH RIH TO 4260'_ REAM FROM 4260 - 4560' DRILL 9 7/8" HOLE FROM 4560 - 4700' CIRC BOTTOMS UP. MONITOR WELL AND SHORT TRIP TO CASING SHOE @ 2587'_ NO PROBLEMS. CIRC BOTTOMS UP. MONITOR WELL. DROP EMS. PUMP DRY JOB. POH. LD BHA AND RETRIEVE EMS. CLEAR RIG FLOOR. RU ATLAS W/L AND RUN DLL/MLL/ZDL/CN/RG/CHT. RD ATLAS. RU SCHLUMBERGER MDT TOOL ON DP AND TEST SAME. RIH WITH MDT TOCL TO 4200' CIRC AND COND MUD BEFORE INSTALLING SIDE ENTRY SUB. WELL ' MPU E-20 OPERATION: RIG · NABORS 22E PAGE: 4 06/08/95 (16) TD: 4700' ( 0) 06/09/95 (17) TD: 4700' ( 0) 06/10/95 (18) TD: 4700' ( 0) 06/11/95 (19) TD: 4700' ( 0) 08/24/95 (20) TD: 4681 PB: 4637 MU BHA 96 AND RIH MW: 0.0 VIS: 0 RU SIDE ENTRY SUB AND PUMP DOWN WET CONNECT. MADE 5 SETS @ 4446, 4324, 4513, 4363, AND 4335' POH TO SIDE ENTRY SUB AND RD SAME. POH WITH WIRELINE. POH WITH MDT TOOL AND RECOVER SAMPLES. CLEAR FLOOR. MU BHA #6 AND RIH TO OPEN HOLE FROM 4200 - 4700'. RUN 9-5/8 CSG MW: 0.0 VIS: 0 TIH T/4200. OPEN HOLE T/4700. CBU & MONITOR WELL. TRIP T/CASING SHOE. OK. CBU. MONITOR WELL. POOH & LD BHA. PULL WEAR RING. CHANGE TOP RAMS T/9-5/8" TEST SEALS T/3000. RU T/RUN CASG. DISPLACE WELL W/ SOURCE WATER MW: 0.0 VIS: 0 FINISH RUNNING 115 JTS 9 5/8" L-80 BTC/NSCC CASING. SHOE @ 4681'. MU HANGER AND LANDING JT. RU CEMENT HEAD. CIRC AND COND MUD. NO LOSSES. PUMP 700 BBLS. TEST LINES. PUMP 20 BBL WATER, 70 BBLS SPACER, 375 SXS "G" @ 15.8 PPG. DISPLACE WITH RIG PUMP AND BUMP PLUG. FLOATS HELD. TEST CASING. LD CEMENT HEAD, LANDING JT, CASING EQUIP AND CHANGE OUT ELEVATORS. RU RUNNING TOOL AND INSTALL PACK OFF BUSHING AND TEST SAME, OK. CHANGE TOP RAMS TO 5" AND TEST SEALS. PULL TEST PLUG. INSTALL WEAR RING AND CHANGE OUT MASTER BUSHING. SERVICE TOP DRIVE. SLIP AND CUT DRILLING LINE. MU BIT AND SCRAPER AND RIH TO FC @ 4637'. TAKE ON FILTERED SOURCE WATER. DISPLACE WELL WITH FILTERED SOURCE WATER WITH CORRISION INHIBITOR - CORREXIT 7726. RELEASE RIG MW: 0.0 VIS: 0 POH TO 2000'. FREEZE PROTECT 9 5/8" CASING WITH 120 BBLS DIESEL. FINISH POH. RU ATLAS WL. MAKE GAUGE RING/JUNK BASKET RUN TO 4635'. RIH WITH HOWCO SUMP PACKER AND SET @ 4537', TUBING TAIL @ 4555'. ND BOPE. REMOVE 13 3/8" 5M X 13 3/8" 5M TUBING SPOOL. INSTALL 13 3/8" 5M X 11" 5M TUBING SPOOL AND FRAC TREE. TEST PACKOFF AND TREE, OK. FREEZE PROTECT MP E-11 W/ 80 BBLS DIESEL AND MP E-20 W/ 100 BBLS DIESEL. RELEASE RIG @ 2100 HRS ON 06/10/95. NU BOPE MW: 0.0 SCOPE & LD DERRICK. MOVE RIG F/MPU E-23I T/E-20. SPOT & BERM RIG. RAISE & SCOPE UP DERRICK. FINISH CLEANING PITS. RIG ACCEPTED @ 0200 HRS.,08~24~95. ND DRY HOLE TREE. TAKE ON BRINE IN PITS. NU BOPE. CHANGE OUT KILL LINE HOSE & HYDRAULIC CONTROL HOSE ON KILL LINE HCR. R£CEIV£1) ~,¥ 2 0 1996 Alaska Oil & Gas Cons. commissior~ Anchorage WELL : MPU E-20 OPERATION: RIG : NABORS 4ES PAGE: 5 08/25/95 (21) TD: 4681 PB: 4637 08/26/95 (22) TD: 4681 PB: 4637 08/27/95 (23) TD: 4681 PB: 4637 REVERSE CARBOLITE F/J-PLUG MW: 0.0 CHANGE OUT KILL LINE HOSE & HYDRAULIC CONTROL HOSE ON KILL LINE HCR. TEST BOPE 250-5000 PSI, ANNULAR 250-3000 PSI. WITNESSING WAIVED BY BOBBY FOSTER, AOGCC FIELD INSPECTOR. LD TEST JT. PULL TEST PLUG. SET WEAR RING. STRAP & MU BHA #1(BAKER RET HEAD). RIH ON 3.5" DP, SLM & DRIFT T/500'. DISPLACE OUT 50/50 METHANOL W/10.3# BRINE. RIH WITH DP, SLM & DRIFT. SLIP 42' & CUT 84' DRILLING LINE. CONT RIH T/4379'. CBU @ 2.5 BPM W/1400 PSI. TAG IBP @ 4393'. LATCH, EQUALIZE & RELEASE IBP. MONITOR WELL. LOSS RATE 6 BPH. POOH SLOW & WET. LD IBP. PULL WEAR RING. MU BHA #2. RIH T/4400'. TAG CEMENT @ 4469'. DRILL CEMENT F/4469' T/4475'. WASH THRU CARBOLITE F/4475' T/4481'. TAG JP PLUG @ 4481'. RU TO REV CIRC. REV 40 BBLS XANVIS SWEEP W/BREAKER. NU LUBRICATOR F/DATA FRAC MW: 0.0 FINISH REV XANVIS SWEEP AROUND. CONT REV UNTIL CLEAN RETURNS. FL 18 BPH WHILE REVERSING. OK. POOH. LD 8.5" BIT. SERVICE RIG. SKIM CRUDE OIL OF PIT #3 & CLEAN. STRAP & MU BHA #3 (JP PLUG RETRIEVING TOOL & 9-5/8" SCRAPER). RIH T/4478'. CIRC & FILTER BRINE. WASH THRU BRIDGE TO JP PLUG @ 4525'. REV TOP OF PLUG. LATCH PLUG & PULL FREE. MONITOR WELL. POOH. LD BHA #3 & JP PLUG. RU ATLAS WIRELINE. RUN #1 (8.5" GR/JB T/4537' WLM). RECOVERED RUBBER, METAL & SAND. RUN #2. RERUN SAME T/4537'. NO RECOVERY. RD ATLAS LUBRICATOR. ND FLOW NIPPLE. NU 13-5/8" X 7-1/16" APAPTER. MU GRAVEL PACK ASSY MW: 0.0 NU 13-5/8" APAPTER FLANGE ON ANNULUR. CHANGE RAMS. PIPE TO TOP & BLIND TO BOTTOM FOR LUBRICATOR DRAIN. TEST 250-5000. OK. RU ADAPTERS & ATLAS LUBRICATOR. TEST AGAINST BLINDS T/1200 PSI. OK. RIH WITH NFL/CCL/SPINNER. TIE IN TO ATLAS DIL DATED 6/6/95. SET @ 4500'. PERFORM DATA FRAC AS PER WELL PLAN W/ 1916 TOTAL BBLS OF FLUID. MAX PRESS 1340 PSI @ 40 BPM. ISIP: 572 PSI. SPINNER PASSES AS REQUIRED. CONFIRMED +- 25%-75% FLUID SPLIT BETWEEN OA & OB SANDS. POOH W/ WIRELINE. ND LUB & ADAPTER FLANGE. NU RISER & FLOWLINE. MONITOR PRESSURE DECLINE F/500-0 PSI. NO FLOW. SET TEST PLUG. ND RAMS. NU BLINDS IN TOP & 4.5" IN BOTTOM. TEST 250-5000 PSI. OK. PULL TEST PLUG. MU GRAVEL PACK ASSY. RECEIVED ~a¥ ~ 0 ~996 AlasKa Oil & G3s Cons. GommissioD Anchorage WELL : MPU E-20 OPERATION: RIG : NABORS 4ES PAGE: 6 08/28/95 (24) TD: 4681 PB: 4637 08/29/95 (25) TD: 4681 PB: 4637 TESTING FRAC LINES MW: 0.0 FINISH MU GRAVEL PACK ASSY. REPAIR GEARBOX ON PIPE SKATE. RIH W/ GRAVEL PACK ASSY ON 4.5",12.6#,BTC-MOD WORK STRING TO 4530'. DRIFT. WORK ON MUD PUMP. CBU @ 4 BPM W/150 PSI. PU WT:63K. SO WT:57K. STING INTO SUMP PACKER @ 4543'. SPACE OUT FOR FLOOR CONNECTION WITH BURIED PUPS. RU FRAC VALVE. DROP 2.75" PACKER SETTING BALL. CHANGE STUDS IN BJ ADAPTER FLANGE. TEST LINE T/3500 PSI. OK. CIRC BALL DOWN. SET PACKER @ 4365' W/3000)PSI. BLEED OFF. TEST ANNULUS @ 2000 PSI. OK. SHEAR BALL W/3200 PSI. RELEASE F/PACKER W/37K OVER. REVERSE OUT & CATCH BALL @ 5 BPM W/500 PSI. STING INTO PACKER & SET DOWN 30K. RU BJ, 4" FRAC LINE & 2" REVERSE LINE. TESTING LINES. SETTING PLUG/MONITOR WELL MW: 0.0 TEST LINES @ 6000 PSI. OK. PICKLE WORK STRING W/12 BBLS ACID. DISPLACE TO GP TOOLS. REVERSE ACID TO TANK TILL CLEAN RETURNS. SLACK BACK TO FRAC POSITION. FRAC AS PER REVISED TS0,8/26/95. SCREENED OUT T/5100 PSI W/30 BBLS,12~ BEHIND PIPE (126 BBLS SHORT OF DESIGN). AVERAGE RATE 40 BPM. MAX PRESSURE PRIOR TO SCREENOUT 1670 PSI. ATTEMPT TO REESTABLISH INJECTION. NO GOOD. OPEN TOOL TO REVERSE POSITION & BREAK REVERSE CIRC. ATTEMPT TO CLOSE TOOL. NO GOOD. REVERSE SAND FROM TUBING. CLOSE TOOL. TEST SCREEN. OK. ATTEMPT TO CIRC TO CHECK PACK. PRESSURE UP TO 2200. BLED OFF T/1750 PSI TO FORMATION. RESTRESS T/2500 PSI. SCREENS APPEAR TO BE PACKED. REVERSE OUT TUBING. LTR F/FRAC:315 BBLS 73M# 16/20 CARBOLITE BEHIND PIPE. SHUT IN & MONITOR PRESSURE DECLINE F/130 PSI T/15 PSI WHILE WO GEL TO BREAK. BLEED PRESSURE. RD FRAC LINES. RU TO PULL TBG. LD 4.5" WORK STRING, PACKER RUNNING TOOL & SEAL ASSY. RD TBG EQUIP. RU FOR 3.5" DP. SET TEST PLUG. CHANGE RAMS T/3.5". TEST 3.5" RAMS 250-5000 PSI. PULL TEST PLUG. WELL : MPU E-20 OPERATION: RIG : NABORS 4ES PAGE: 7 08/30/95 (26) TD: 4681 PB: 4637 08/31/95 (27) TD: 4681 PB: 4637 09/01/95 (28) TD: 4681 PB: 4637 SPOT XANVIS PILL MW: 0.0 STRAP & MU BHA #5. RIH W/JP PLUG ON 3.5" DP T/4537'. PU WT:78K. SO WT:68K. SET JP PLUG. RELEASE SETTING TOOL. TEST PLUG @ 500 PSI. OK. DUMP 100# SAND DOWN DP. CIRC SAND DOWN 1 DP VOLUME @ 3 BPM W/ 290 PSI. POOH. LD SCRAPER & JP SETTING TOOL. INSTALL WEAR RING. CHANGE RAMS,TOP TO BOTTOM. TEST RAMS 250-5000 PSI. OK. ND FLOWLINE & RISER. NU PERF FLANGE. RU ATLAS. TEST LUBRICATOR AGAINST BLINDS T/ll00 PSI. OK. RIH W/4.5"JUMBO JET CASING GUNS LOADED 12 SPF, 135/45 DEGREE PHASE,B~GHOLE CHARGE. TIE INTO ATLAS DLL, DATED 6/6/95. TAG SAND @ 4362'. RUN #1 PREF'D 4332'-57'. POOH. ASF. FL STEADY. RUN #2 PERF'D 4312'-32'. POOH ASF. FL STEADY.RUN #3 LOG TEMP F/4359' T/4200' TIES INTO ATLAS PRISM LOG DATED 6/14/95. RU BJ TO DATA FRAC. RUN #4. RERUN TEMP LOG. POOH. CLOSE BLINDS. TEST LINES @ 6000 PSI. DATA FRAC. SITP:300 PSI. RIH W/TEMP TOOLS. MADE INITIAL & 2-.5 HR TEMP PASSES F/4200' T/4358'. LIMIT OF FRAC HT @ 4290'.ND PERF FLANGE & NU FLOW NIPPLE. WELL O PSI & STATIC. PULL WEAR RING. SET TEST PLUG. CHANGE RAMS TO BLINDS ON TOP,PIPE ON BOTTOM. TEST RAMS 250-5000 PSI. PULL TEST PLUG. SET WEAR RING. MU BHA #5RR. RIH TO 5 STDS OFF BOTTOM. SPOT 20 BBL XANVIS PILL W/BREAKER ON BOTTOM. RU TO SET PACKER MW: 0.0 FINISH RIH T/4347'. WASH TO JP PLUS @ 4357'. RU & REV CIRC @ 4 BPM W/600 PSI. RELEASE PLUG. MONITOR, 45 BPH FLUID LOSS. RESET PLUG. MIX 40 BBL XANVIS PILL WITH BREAKER. SPOT DOWN @ 4357'. RELEASE JP PLUG. MONITOR, 6 BPH LOSS. ALLOW FLUID TO BALANCE. POOH. LD SCRAPER & JP RUNNING TOOL. SET TEST PLUG. CHANGE PIPE RAMS T/4.5". TEST 250-5000 PSI. OK. PULL TEST PLUG. RU FLOOR TO RUN 4.5" WOR_K STRING. MU GRAVEL PACK ASSY. RIH W/ GRAVEL PACK ASSY ON 4.5" WORK STRING TO 4317'. DRIFT. CBU @ 3 BPM W/50 PSI. CIRC XANVIS PILL OFF BOTTOM. FINISH RIH. PU WT:60K. SO WT: 55K. STING INTO PACKER @ 4365' SPACE OUT. MU FRAC VALVE & LINES. DROP BALL. STING INTO PACKER. SET DOWN 20K. RU TO P?MP DOWN. LD 4.5" WORK STRING MW: 0.0 SET PACKER AT 4249' W/2000 PSZ. DISPLACE TUBING W/SOURCE WATER. FRAC 'N SAND AS PER TS0 DATED 8/29/95. MADE TWO ATTEMPTS TO RE-ESTABLISH INJECTION, NO GO. PULL OFF PACKER AND REVERSE SAND FROM TUBING. RESTRESS GP TWICE. PACK DOESN'T APPEAR IDEAL, BUT TIGHT ENOUGH TO PREVENT PUMPING ADDITIONAL SAND. CIRC FILTERED BRI~. RD FRAC LINES AND VALVE. RU TO LD 4.5" WORK STRING. Lq~STING F/PACKER. MONITOR WELL, LOSING +/- 32 BPH. CUT BRINE WEIGHT BACK W/SOURCE WATER. RECEIVED MAY ?. 0 1996 Alaska Oil & Gas Cons. Commission Anchorage WELL : MPU E-20 OPERATION: RIG · NABORS 4ES PAGE: 8 09/02/95 (29) TD: 4681 PB: 4637 09/03/95 (30) TD: 4681 PB: 4637 09/04/95 (31) TD: 4681 PB: 4637 RUNNING ESP COMPLETION MW: 0.0 FINISH LD 4-1/2" WORK STRING AND RUNNING TOOLS. SET TEST PLUG. CHANGE PIPE RAMS TO 3-1/2". TEST BOPE. STATE WITNESSING WAIVED BY JERRY HERRING, AOGCC. RIH W/MULESHOE AND CASING SCRAPER ON 3-1/2" DP TO 4242'. REVERSE CIRC. MONITOR WELL, OK. LD DP. INSTALL TEST PLUG. CHANGE PIPE RAMS TO 2-7/8". RU FLOOR TO RUN 2-7/8" ESP COMPLETION. MU ESP ASSEMBLY AND LOGGING BYPASS TOOL. MAKE MOTOR LEAD SPLICE. RUNNING COMPLETION ON 2-7/8" TUBING. ND BOPE MW: 0.0 RIH W/2-7/8" ESP COMPLETION STRING. RU TO RUN HEAT TRACING LINE. RIH W 2-7/8" ESP COMPLETION STRING, INSTALLING HTL. SPACE OUT HEAT TRACE, MU HANGER, SPLICE ESP CABLE F/HANGER. LND TUBING AND RILDS. ND BOPE, SPLIT BOP F/SHEAR RAMS INSTALLATION. RELEASE RIG 09/03/95 1400 HRS MW: 0.0 ND BOP AND NU XMAS TREE. TEST TREE AN HEAT TRACE I AND ESP LINES. PULL TWC, FREEZE PROTECT . INSTALL BPV, SECURE XMAS TREE. RELEASED RIG AT 1400 HRS 09/03/95. SIGNATURE: (drilling %uperintendent) SPERRY-SUN DRILLING SERVICES ANCHOPJtGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPE-20 500292256100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/16/95 DATE OF SURVEY: 060695 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50051 KELLY BUSHING ELEV. = 53.80 FT. OPERATOR: BP EXPLORATION TRUE SUB - SEA COD-RS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RE CTANGUT_~AR COORDINATES NORTH/SOUTZq EAST/WEST VERT. SECT. 2608 2581.27 2527.47 12 13 N 38.22 W .00 109.86N 236.60W 2658 2630.15 2576.35 12 19 N 39.76 W .69 118.12N 243.29W 2753 2723.03 2669.23 12 43 N 44.30 W 1.12 133.43N 257.11W 2849 2816.89 2763.09 12 18 N 45.88 W .56 148.14N 271.86W 2945 2910.67 2856.87 10 0 N 51.50 W 2.66 160.41N 285.67W 235.58 246.21 266.81 287.55 305.81 3039 3004.26 2950.46 8 28 N 54.98 W 1.72 169.54N 297.84W 3134 3098.48 3044.68 6 12 N 59.39 W 2.45 176.17N 307.99W 3228 3191.45 3137.65 4 52 N 60.29 W 1.44 180.70N 315.78W 3322 3285.00 3231.20 2 23 N 55.14 W 2.67 183.79N 320.83W 3417 3380.00 3326.20 0 57 N 89.90 W 1.78 184.92N 323.24W 320.61 332.19 340.65 346.26 348.67 3512 3475.55 3421.75 0 44 S 80.44 W .26 184.82N 324.65W 3607 3570.14 3516.34 0 24 S 6.57 W .78 184.38N 325.29W 3700 3663.50 3609.70 0 28 S 2.60 W .08 183.67N 325.34W 3794 3757.67 3703.87 0 31 S 18.53 E .20 182.87N 325.22W 3889 3852.47 3798.67 0 31 S 20.64 E .03 182.05N 324.93W 349.48 349.56 349.04 348.35 347.53 3981 3944.37 3890.57 0 28 S 13.81 E .09 181.29N 324.70W 4074 4037.14 3983.34 0 21 S 9.80 E .12 180.64N 324.56W 4168 4131.59 4077.79 0 12 S 11.96 W .19 180.18N 324.54W 4263 4226.49 4172.619 0 22 S 74.81 W .35 179.92N 324.88W 4358 4321.57 4267.5'7 0 26 S 58.29 W .14 179.65N 325.48W · 4453 4415.98 4362.18 0 21 S 43.21 W .14 179.25N 325.99W 4547 4510.54 4456.74 0 18 S 34.35 W .07 178.82N 326.34W 4639 4602.07 4548.27 0 22 S 50.42 W .13 178.42N 326.71W 4700 4662.84 4609.04 0 22 S 50.42 W .00 178.16N 327.03W 346.80 .- 346.21 .'. ' 345.84 345.86 346.04 346.05 345.94 345.87 345.88 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 372.41 FEET AT NORTH 61 DEG. 25 MIN. WEST AT MD = 4700 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 320.34 DEG. RECEIVED 0 1996 AlaSka Oil & ~ Con~. commissio~ Anchomge SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MILNE POINT / MPE-20 500292256100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/16/95 DATE OF SURVEY: 060695 JOB NUMBER: AK-EI-50051 KELLY BUSHING ELEV. = 53.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 2608 2581.27 3608 3571.00 4608 4570.97 4700 4662.84 2527.47 109.86 N 236.60 W 26.86 3517.20 184.38 N 325.29 W 37.13 10.27 4517.17 178.55 N 326.55 W 37.16 .03 4609.04 178.16 N 327.03 W 37.16 .00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPE-20 500292256100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/16/95 DATE OF SURVEY: 060695 JOB NUMBER: AK-EI-50051 KELLY BUSHING ELEV. = 53.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 2608 2581.27 2527.47 109.86 N 236.60 W 26.86 2682 2653.80 2600.00 122.10 N 246.60 W 28.56 1.70 2784 2753.80 2700.00 138.40 N 261.96 W 31.04 2.48 2887 2853.80 2800.00 153.75 N 277.64 W 33.42 2.38 2988 2953.80 2900.00 165.13 N 291.62 W 35.04 1.62 3089 3053.80 3000.00 173.69 N 303.81 W 36.15 1.11 3190 3153.80 3100.00 179.12 N 312.99 W 36.72 .57 3290 3253.80 3200.00 183.05 N 319.77 W 37.04 .32 3390 3353.80 3300.00 184.92 N 322.81 W 37.11 .07 3490 3453.80 3400.00 184.87 N 324.37 W 37.12 .01 3590 3553.80 3500.00 184.50 N 325.27 W 37.13 .01 3690 3653.80 3600.00 183.75 N 325.34 W 37.13 .00 3790 3753.80 3700.00 182.90 N 325.23 W 37.14 .00 3890 3853.80 3800.00 182.04 N 324.93 W 37.14 .00 3990 3953.80 3900.00 181.22 N 324.68 W 37.14 .00 4090 4053.80 4000.00 180.54 N 324.54 W 37.15 .00 4190 4153.80 4100.00 180.10 N 324.56 W 37.15 .00 4290 4253.80 4200.00 179.88 N 325.05 W 37.15 .00 4390 4353.80 4300.00 179.52 N 325.69 W 37.15 .00 4490 4453.80 4400.00 179.08 N 326.15 W 37.15 .00 4590 4553.80 4500.00 178.63 N 326.48 W 37.15 .00 4700 4662.84 4609.04 178.16 N 327.03 W 37.16 .00 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS *****~** ANADRILL ********* SCHLL~BERGE~ ******************************************************* JOB ~ 36177 APl ~ 50-029-22561-(~ *********~ .SUR:Y~Y F$:OGRAM *********** COEPA~NY BF' WELL NAME MPE-20 LOCATION 1 MILNE POINT L~ATION 2 ALASI<A MAGNETIC D~LI~TION 28,?3 GRID CONVERGENCE ANGLE DATE: ~LL NUMBER 0 WELL HB~D ~CATION: LmT.~-~ 0.00 DEP(E/-W) AZIMUTH FROM ~TARY TABLE TO TARGET IS 320,34 TIE IN'POINT(TIP) : ~ASURED DEPTH lt2orf) TRUE YT-_f~T DEPTH 1!2,00 INCLINATION 0~00 AZIMUTH 0,00 LATI~JDE(N/-S) DEPAR~E(~-W) 0,00 RECEIVED MAY ZO 199(~ Ala~k~ Oil & Ga,~ Cons. Commission Anchoroge PAGE NO, MEASURED INTERVAL VERTICAL DEPTH DEPTB 1i2.00 0,~ -.~ ^n 178,03 &5,0 178,03 267,83 89,8 267,82 .~o.~ 90 443.54 ******~****** ANADRILh ************** SURVEY CA~CULATIC~S **.*****~***** CIRO]LAR AE~ ME~,OD*****~** %ARGET STA%tON AZIMU~ LA%ITUDE SECTION D.~LN. N/-S f~ ~eg ~eg ft 0,00 0,00 0,00 0,00 -0,23 0,43 162.37 -0.24 -0.85 0,54 162,99 -0,98 -1.72 0,% 170J6 -2.04 -2,61 0,50 168,31 -3,14 RECEIVED MAY 2 0 1995 Alaska 0tl & G~ Cons. Commission Anchomge DE'AR'CURE D!SF%ACEM£NT ~t ~,/-W ft ft 0,00 0.00 0,08, 0,25 0,!6 0,'.;.'9 0,24 0,30 3,15 AZIMJ]TH DLS deg/ deg l~.~ft 0,00 0,00 162,37 0.65 '170.98 0.22 173,22 0,47 i74,54 0,50 534,52 624,72 716,11 806,65 896.70 90,2 624,70 91,4 7!6,07 90,5 . 806,60 %,i 896.62 -2,96 0.42 214,86 -3,81 -3,24 0,73 211,71 -4,57 -4,03 0,84 165,09 -S.72 -4,67 0,94 ~27.57 -5,86 -4.'~ 2,i8 ~c~,~.~? -8,63 ~,~1 179,26 0,25 0,05 ~ ~ . -0,44 4,59 185,56 0,34 -0,58 5,75 185,79 0,69 -0.gA ~ '''~ 18. ,~ 1,03 · .. ,.,,7~ 7 "'~ -2,66. 9,03 197,12 1,38 987,56 108i.98 !176,3i 1270,19 1366,16 90,9 987,40 94,4 1081,6.9 94,3 1175,/¥~" '~,? 1269,19 96,0 ~' ~ 1~o4,4~ -5,17 2,73 230,99 -1t.27 -4,90 3.25 25~.60 -14.20 -3,40 4,69 249,32 -17,07 0.63 6,91 259,88 -19,42 7.52 7,41 271,11 -20,32 -5.~u 12,55 -9,46 17.07 -t5.27 22,91 -24,42 31,20 -36,29 41,..~ 206,02 0,73 213,67 0,61 221,51 1,81 231.51 2,62 240,76 1,54 14~0,20 t650.'~ 1745 ~ 1840.75 94,0 1457,~ 93,6 1549,86 97,2 !645,28 94,4 ~.4 1831,71 17,12 8,57 ~q~,, ~i,. -18.51 29,96 10,29 290,23 -13,94 4,,Y~ 11,52 291,54 -7,38 61,76 t0.37 292,65 -0,64 77,34 10,99 ~?1.69 6.02 -49,15 52,52 -63,76 65,26 -80,92 81.26 -97,54 97.54 -113,91 114,07 249,36 2,26 257,67 2,14 264,79 1.30 269,62 1,24 573,03 0,67 2030,05 2126,76 2223.~ 23!9,i7 yo,, 1923,76 ~,4 2017,22 96,7 2111,83 96,6 2206,09 95,8 2299,40 ¢0,o~ tl,60 294,!5 13,19 111,01 11,74 294,53 21,15 129,59 12,19 302,56 D,73 150.15 13.05 314,71 43,89 172,00 13,37 322,23 60,26 ~% oR 131,49 W5,76 0.83 -148,42 149,92 278,11 0,17 -165.98 165,80 280,49 1,78 182,32 187,53 ~.a,j4 2,88 -1'96,80 205,82 287,02 1,82 2414,43 ?..509,58 2523,60 2608,13 2702,45 2~02,16 95,2 ~ " ~484,~y t4,0 2498,67 84,5 2581,27 94.3 !93,67 t2.94 321,40 .77.31 214,56 12,42 320,47 93,53 217,57 12,38 32~,38 -95.,8~ 235.58 12,22 321,78 109,86 256,13 12,98 316,48 125,39 -210.20 223,97 290,19 0,~9 -223.36 24~,!5 292,72 0,59 -225,28 244,82 293,05 0,32 -23A,60. 260 . ~,., "~ 294,91 0,40 -Z50,07 279,75 296,63 1,47 2797,70 2893,91 29g9.12 3084,72 3179,42 95.3 27~.I6 96,2 266.0,34 95.2 2954.16 95,6 3048,66. 94,7 3143,04 277,40 12,87 316,61 140,86 296,83 10,6~ 310,01 1~,36 312,72 9,03 o0o,..,~° 164,46 g25,19 6,58 301,40 171,78 334,56 5,40 302,17 176,98 -264,73 299,87 298,02 0,12 -278,89 318,75 298,96 2,72 -291,62 ~34,7'? 2?9,42 1,79 -302.31 347.71 299,61 2,67 -310,72 357,59 27~.67 1,24 3272,41 ooo6,09 3460,58 3649,88 93.0 ~-~: 7~ ?3,7 94.5 3423,67 ~5,i 3516,94 94,2 3613,1~ 341,12 3,01 310,48 180,90 344,12 0,90 261,78 182,64 345,07 0,64 274.06 182.83 345,26 0,23 163,19 182,69 344,79 0,~ 141.73 162,27 -316,~c'o 364,36 299,77 2,64 -3!6,87 367,48 299,80 2.42 -320.13 368,66 299,73 0,29 -~20,60 .%9,00 ~¢?,~ 0,79 5 ~O ,. . -320,36 ~68,., 2~9,^4 0,17 **.***.******** ANAl)RILL ************** SURVEY CALCULATIO~S ************* CIF.~I]LAR ARC METHOD******** MEASUR~ tN?EE~ALVERTICAL TARG~ STATION AZIMUTH LATITUDE ~'TH DP'TH S£CTION INCLN. ~/-S ft ft ft ft d~ Oeg. ft 3743.88 94,0 3707,18 344.21 0.35 143.55 181,81 3837.33 93,5 3800,63 343.66 0,34 114,21 181,47 3~2.t7 94,8 3~95.¢~ 343,02 0,50 130.16 181,09 4024.71 92,5 3988.00 342,3 0,33 145,29 180,61 4134,95 110,2 4098,23 342,16 0,16 354,51 160,50 D~ARTUR£ DISPLACBI~T at AZIMUTH DLS E/-W deg/ ft ft deg. lOOft -320,01 36B,05 2~,60 0,04 -319.59 ~,7.52 29'~.59 0.18 -319.02 366.83 ~-79.58 0,21 -318,56 3~,19 29~,55 0.22 -318,39 366,00 299,55 0.42 4187.05 52.1 4150,33 342,21 0,10 65,08 180,59 4265,73 7~,7 4~9.02 342.39 0,34 286,12 160.66 TH~ SUE%'EY BELOW tS PRCkiEC~D TO .~ 4295,00 29.3 - 42~8.29 342,53 0.34 266.,12 · 160.73 · *********** **************** -318,36 366,01 27B,5~ 0.29 -318,52 366,20 299,56 0,54 -318.69 366.37 299,~ 0,10 Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) September 11, 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 St *~ /~ka Oil & Gas Conservation Attn: Larry Grant 3001 Porcupine Drive ' "'~An~ge, Alaska 99501 1 OH LIS Tape 3 Bluelines I Film 1 Depth Shift Display 1 OH LIS I Blueline each 1 RF Sepia each OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail P 905 127 900 PLEASE AOI~NOWLEDGE RECEIPT B LY~p~I~?~ .~,1~1~ BETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. QEP "i i i995 SCHLUMBERGER GEOQUEST PETROTECHNICAL DATA CENTER, MB3-3 ' .... ' ' 500 WEST INTERNATIONAL AIRPORT ROAD 900 EAST BENSON BLVD. - -- ANCHORAGE, ALASKA 99518-1199 ANCHORAGE, ALASKA 99519-6612 Alaska 0il & Gas 0ohs, Commission Anchorage Schlumberger Courier: Date Delivered: Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 8 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as d~scribed below: WELL ' : # DESCRIPTION ' - : ECC No. MPE-15 ' 1 SBT/GR FINAL BL+RF Run MPE' 0 i 1 TEMP LOG FINL BL+RF Run ~ 1 Received by: Please sign and return to: Attn.'Rodney D. Paulson __ Atlas Wireline Services ~%~ ~ V~D . · 5600 B Street . Suite 201 Anchorage, AK 99518 SEP 1 .~ Or F~ to (907) 563-7803 A(~ska Oi/& Gas C~-s LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 31 August 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PLS FINAL BL+RF Please sign and return to: Attn. Rodney D. Paulson . Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: .//A'~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: Enclosed, please find the data as described below: Prints/Films: 1 1 Date: RE: 26 June 1995 Transmittal of Data ECC #: 6441.04 MPE-20 ~ //0 NORTH SLOPE, AK ~ ~ PRISM FINAL BL+RF PFC/PERF FINAL BL+RF \. Run # 1 ~'~~ ~' ~ Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wirelin~q~"~ o Received b to: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 20 June 1995 Transmittal of Data ECC #: 6441.03 Sent by: PRIORITY MAIL Data: PRISM Dear Sir/Madam, Reference: BP MPE-20 MILNE POINT / SBP NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PRISM FINAL BL+RF Run # 1 Please sign and return to: ~ttn. Rodn_e.y D~~ RECEIVED Atlas Wi~e Services 5600~reet~~ /'~ //Anchorage,or.~t~X (907)AK 99518S~lte 201 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION . 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 June 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below:~'~//~ WELL # DESCRIPTION ~'l MPE-20 2 PFC/PERF FINAL BL+RF Run # 1 1 GR/CCL FINAL BL+RF Run # 1 ECC No. 6441.02 Please sign and return~to: Attn. ~y D. P~ ./5600 B-- ~ r.~-e,?t. / // ~rage, AK 9951 ~~Or ~AX to (907) 563-780~ve~m_ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 15 June 1995 Transmittal of Data ECC #: 6441.01 Sent by: PRIORITY MAIL Data: PRISM Dear Sir/Madam, Reference: BP MPE-20 MILNE POINT / SBP NPRTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PRISM FINAL BL+RF Run # 1 Please sign and return to i~-.,Attn. Rodney D. ~las Wi~rvices 56~~et S u/i~fe 201 ? _ · /~n h ~ AK 9 5]~ / ~c~?~ra~, (~_~7;9~_7803 Received b~~ ~ 2 ~- ".~~~ Date-. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, -"~ Reference: BP MPE-20 MILNE POINT / SBP NPRTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 1 DLL/MLL/GR FNL BL+RF ZDL/CN/GR FNL BL+RF SSVD/MWD FNL BL+RF BHP FINAL BL+RF Date: RE: 12 June 1995 Transmittal of Data ECC #: 6441.00 Sent by: PRIORITY MAIL Data: OH-LDWG Run # 1 Run # 1 Run # 1 Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201- Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s i;n and z~e~-u~*n tO; Petrotechnics_% Data Cen~e~ BP .Exploration (Alaska) 900 East Benson Boulevar~ ~ch~ge, ~aska ~0~ ............ E'C E D JUN "! G 1995 Alaska Oil & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPE-20 MILNE POINT / SBP NPRTH SLOPE, AK . Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Date: RE: 13 June 1995 Transmittal of Data ECC #: 6441.00 Sent by: PRIORITY MAIL Data: OH-LDWG Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and r. eturn ~: Petrotec~hnical Data Cente~ BP Exploration (Alaska) In~ 90~East Benson Boulevard _ ~~~e, ~aska 99508 .. AlaSKA OIL AND GAS · CONSERVATION COM~HSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3! 92 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 19, 1995 Adrian Clark Drilling Engineer.supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .' Hilne Point Unit MPE-2?0 BP Exploration (Alaska), Inc. Permit No~ i 95-71 Sur. Loc. 3637'NSL, 1955'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc. 3822'NSL, 226%'WEL, Sec. 25, T13N, R10E, UM Dear Mr. Clark~ 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 b_~_~Q ~y contacting the Commission petroleum field ~t~lop. pager at 659-3607. David~W. Johnston% Chair~ · BY ORDER dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION P£R IT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill r'-Illb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFlI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 55' f e et Milne Point Unit - Schrader Blufl 3. Address 6. Property Designation P. O. Box 196612, Anchoraae. Alaska 99519-6612 ADL 25518 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 2S.025) 3637' NSL, 1955' WEL, SEC. 25, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 3822' NSL, 2269' WEL, SEC. 25, T13N, RIOE MPE-20 2S100302630-277 At total depth .... 9. Approximate spud date Amount 3822' NSL, 2269' WEL, SEC. 25, T13N, RIOE 5/21/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(MDa, d'rVD) property line ADL 28231-2269' feet No close approach feet 2560 5124' MD/5095' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 i Kickoff depth 800 feet Maximum hole angle , o Maximum surface//-~OO 333~ psig At total depth (TVD) 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 1250 sx Arcticset I (Approx.) 16" 13-3/8" 54.5# K-55 BTRC 2486' 31' 31' 2517' 2500' 738 sx PF 'E'/250 sx 'G'/250 sx PF'E' 12-1/4' 9-5/8' 47/40# L-80 BTRC 5094' 30' 30' 5124' 5095' 501 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production MAY ] 6 1995 Liner AIP~$k~ Oil & Gas Cons. Commission Perforation depth: measured Nl~0ra? true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid prograr~ [] Time vs dept.,h plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify_~_.~!)ajt/tt~e/Coregoi~jt~./~/.,,////.,.,_///(~.j.//~/~//, is true and correct to the best of my knowledge Date,~"//~///~' '~' Signed ,~,/~ ~..-."-..~--~/ ,~,.. Title Drilling Engineer Supervisor Number~I ' Commission Use Only Permit IAPI number Appr.9.ov~! date ISee cover letter ¢/J--,¢7! 15o- 02?-~;z,~-G;-Oo I ~.~/"~.~'"~ Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Io9/¢'eCl'UlrCd [] Yes [] No Hydrogen sulfide measures/E~'Yes ~No Direc~.tional survey required ~ Yes [] No Required working pressure for BOPE []2M; I.d'3M; []5M; I'-ll0M; I-'115M; Other: Original Signee By by order of Approved by David W. Johnston Commissioner ,ne commission Date'~5~'/~//~'5 Form 10-401 Rev. 12-1-85 Submit j~ I :ate I Well Name: I MPE-20 Well Plan Summary Type of Well (producer or injector): [Schrader Producer I Surface Location: Target Location: Bottom Hole LOcation: 3637 NSL 1955 WEL Sec 25 T13N R10E UM., AK. 3822 NSL 2269 WEL Sec 25 T13N R10E UM., AK. 3822 NSL 2269 WEL Sec 25 T13N R10E UM., AK. [AFE Number: [330128 Estimated Start Date: [ 5/21/95 [Rig: [Nabors 22-E ! Operating days to complete: [ 1 1 !mr : !5124 I I TVD: 15095 bkb I I I }C: I SS' [ Well Design (conventional, slimhole, etc.): ] Milne Point Big Bore 13-3/8"/9-5/8" Longstring Formation Markers: Formation Tops MD TVD (bkb) base permafrost '17 63 1755 NA 4294 4265 Top of Schrader Bluff Sands (8.3 ppg) OA 4443 4414 (8.3 ppg) OB 4497 446 8 (8.3 ppg) OB Base 4525 4496 Base of the Schrader Bluff Sands I\L LI V L Total Depth 5124 5095 ~uasha 0il & Gas Gons. Commission Casing/Tubing Program: Ancflom-:~ Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.t # H-40 Weld 80 32/32 112/112 16" 13-3/8" 54.5 # K-55 btrc 2486 31/31 2517/2500 12.25" 9-5/8" 47/40 # L-80 btrc 5094 30/30 5124/5095 Internal yield pressure of the 9-5/8" 40g casing is 5750 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 4200 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 1800 psi is 1400 psi, well below the internal yield pressure rating of the 9-5/8" casing. Logging Program: lOpen Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional Only NONE MWD LWD GR Only & Wireline Logs RES/GR/NEU/DENSITY (RFT's) GR/CCL will be run in 9-5/8" casing to coincide with Perforation Operations. Mud Program: Special design considerations I None- Surface Mud Properties: Spud I Density Marsh Yield i0 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.5 90 35 15 30 10 15 Intermediate Mud Properties: N/A'" [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: KCL ! None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: {KOP: 1800 Maximum Hole Angle: Close Approach Well: 9 degrees None Disposal: Cuttings Handling: CC2A iRECEIVED 1 Ft 199,5 '] Gas Cons. Commission ~ohor~,,'-~' Fluid Handling: All drilling and completion fluids can be annular injected. Annular Injection: The MPE-20 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 3.5,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) Milne Point MPE-IO 2500 35,000 6/1/94 to 12/31/94 Milne Point MPE-11 2500 35,000 6/1/94 to 12/31/94 Milne Point M PE-20 0 35,000 Submitted FREEZE PROTECTION: Pay close attention to annuli being used for disposal so to avoid freezing. Sometimes the annuli are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. MPE-11 Well Plan PAGE 2 JDP 1/3/95 MPE-20 Proposed Summary of Operations . . o . o Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. MU 16" bit and MWD (Dir), drill surface hole, and run and cement 13-3/8" casing. 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. . RIH w/ Insert bit on a motor with DLS (Dir/GR), Test 13-3/8" casing to 2000 psig for 30 minutes, Drill out float equipment and 10 feet of new formation, Perform a FIT -- 12.5 ppg. o Drill 12.25" hole through the Schrader formation into the Seabee (Colville) Shale. Wiper Trip, POOH and LD BHA. 9. Run Wireline Logs and RFT's as per logging program. 10. MU Rotary Assembly and perform conditioning trip. 11. Change Top Rams to 9-5/8", and Run and Cement 9-5/8" casing, Bump the plug, check the floats, and pressure test the casing to 4000 psig for 30 minutes. 12. RIH with 8.5" bit and scraper to clean out to the Float Collar. Displace drilling mud with source water and perform a casing wash -- filter source water. 13. POOH and MU the 9-5/8" Gravel Pack Sump Packer and set 50' md below the OB Sand Base. 14. Freeze Protect Well with 2000' of deisel while POOH. 15. ND BOPE & NU the 7-1/16" Dry Hole Tree with (6-3/8" thru bore) in preparation for Nabors 4-ES to perform the frac pack. 16. RDMO Nabors 22E drilling rig to drill next well. Drilling Hazards and Risks: 1. There was evidence of shallow gas/hydrates in the E-Pad area (E-7, 8, 9, 10, and 11 wells); therefore, the MW schedule requires 9.5 ppg by 2000' tvd. This practice was applied on the MPE-09 well and there was no evidence of hydrate problems while drilling the surface hole. , No other drilling hazzards or risks have been identified for this well. RECEIVED MA'( 1 6 1995 ~aska Oil & Gas Cons. 00mmi~i0n MPE-11 Well Plan PAGE 3 JDP 1/3/95 MPE-20 WELL 13-3/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 13-3/8" CIRC. TEMP 75 deg F at 4500' TVDSS. SPACER' 75 bbls fresh water. LEAD CEMENT TYPE' ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 738 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE' Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaCI2 WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx APPROX #SACKS: 250 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 15.6 ppg YIELD: 0.96 cu ft/sk. APPROX NO SACKS: 250 MIX WATER: 3.7 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint on bottom 10 joints of 13-3/8" casing. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 14 - 16bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 392' md above the 13-3/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 13-3/8", 54.5# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. R E 6 ~ IV E 0 M/ 'f 6 1995 ~att~ roil & Gas Cons. Commission MPE-11 Well Plan PAGE 4 JDP 1/3/95 MPE-20 9-5/8" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON CIRC. TEMP: 140°F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 501 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 9-5/8" x 12" Straight Blade Rigid Centralizers-- two per joint on the bottom of 9-5/8" Casing (20 total). 2. Run one 9-5/8" x 12"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 3. Total 9-5/8" x 12"Straight Blade Rigid Centralizers needed is 21. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Sand with 30% excess. RECEIVED Al~ka Oil & Gas Cons. Conmllssioll MPE-11 Well Plan PAGE 5 JDP 1/3/95 P.-P~-:2'?-:1995 89:4:1 FR~I-~J: RNADRILL TO .... PEri:) ENGINEERS 1 SH'ARED SERVICES DRTLI"": NG - P. IB4 I · i ii I PE-20 (PC) , VERTICAL .SECTION VIEW i · i :Section a't: 3~7.66: TVD Sca]e.' ~: ~nch. = 800 feet ' Dep 5c81e.' :1 ~nch'- B00 feet <KB> o- x ,,. · I Dra~n ' 04/~5/95 I i · 400 ....... : ...... ,,: /nadrl ]] 5chJumberger. ~ i i -I I II I ~ i Harker Identification MD BKB SECTN INCLN B00--- 8~ ~ .. ~ , ~~ ' A) KB 0 0 0 0.00 ~ 8) KOP/BUILD 2/~00 800 800 0 0.00 C) END 2/~00 BUILD ~200 ~99 5 8.00 ~200 ............ C ............ D) CURVE B/JO0 J3DO t298 8 8.DO ' D--,I E) END 6/~00 CURVE ~32 ~8. ~9 8.96 E ~- I F] DROP 6/~00 22J0 2197 J31 8.96 ~J G) CURVE 2/J00 2213 2~00 13t 8.60 ~600--- ,,'i ....I¢ H) END 6/100 DROP '2~13 ~200 131 8.B0 ' ~ [ I t) END 2/100 CURVE 2392 · 2377 t58 8.9~ i~ ~ ~ J) DROP 2/~00 3398 337~ 3~4' 8.gl B ~00o ......... ' .. ~ ......... K) END 2/100 DROP 3844 38~5 348 : 0.00 : L) ....... T~ET ....... ~29~ 4265 348 0.00 K ' ~,.~~ M) TD 5,2, 5095 348 0.00 2400--- ~ . i ..... ~,~ .......... AK~-DPC ........ ~ :EASIBIL ~ P~hl ~oo. , 'NOT APPF ;, o~- I EXECLJTION .I I i K-- : I ' i ' -- ' ~ooo- : !. , ,. ~400 ...... : ..... ;~ " : · ' · I ...... i .... ' .... ' ' .i i ' Comm~ion I - ~~as cms. ..~Z: ,~ '~ ....... 5~00 ........ [ ~ .... ~ ............ ~ ~0~" 5600 . , : ~ : ~ ' i . 6000 ........ , -.. ~_ ._ I . _ .... ~ . . -8oo -4oo o ~oo ~oo 12oo ~6oo 2ooo 2zoo 28oo 3200 3600 4000 44bo ~eoo -- ' · ~ SecU. on Departure 00; ~ 0 · 00~ oo~ o6~ OOk O0§ OO9 " ' ' ) · d~,~ i~.~'~'~;-i~ ~,o~,~i':~ i :. ! OOZ OOB ~ 006 000; 00~ 00~ ! 00~ ......... r mil JaJJaq~un[q~S [[ FJPeUK · ...... ~m m I m I §6/G~/~O ........ NM~WO laat 00~ = 43u! ~ : ....... 3q¥OS ~ ~96'B~: :'NO~IVNIlO30 9~'00£ qln~zv le laa~ ~9£' : ..... ~RSO~3 .... N-3~A NYqd (gd) ._. ' ~ , ','.7- ' ~6~ ~6§1 : 9~ .~ ~6£~ ~9~ '9~ ~ £[22 .82 0 OOB 0 0 o Ol [~ ....... i39BV/. dOuO OOl/g ON3 001;/~ ~1:)0 [P .tA~D3 00[72 ON3 (I ~OUQ 00~/9 ON3 (H 00;/~ 3ABF13 (9 OO;/g dOUO (J 3Ai:IKI3 OO1;/§ ON3 (3 00;/9 :JA)~3 (O O0]/g O~l:nB/eO~ (8 ua (. le3.~ ~[. :~u~p! ,Ja~aeN 9NI99I 0 S331AI:::I.3S. 03WYHS S0' d S~33N 19N3 (lEd 01 WELL PERMIT CHECKLIST WELL NAME GEOL AREA der ~ redrll [] serv [] oNXoF ADMINISTRATION APPR DATE ENGINEERING 1. Permit fee attached ................... 2. Lease number appropriate ............... ~ N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... .~ N '7. Sufficient acreage available in drilling unit ..... .~ N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservationorder .... ~ N 12. Permit can be issued without administrative approval..~ N 13. Can permit be approved before 15-day wait ....... ~ 'N APPR DATE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~;~O,, ..p~i~.~ N 27. Choke manifold complies w/API RP-53 (May 84). 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones/~... Y N 32. Seismic analysis 9f shallow gas zones..J ...... Y N 33. Seabed condition survey (if off-shore~-C... ...... ~ ~ 34. Contact name/phone for weekly pr~3~ss ~e~orts ..... Y N [exp~toryonly] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:~FORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : MPE-20 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292256100 REFERENCE NO : 95273 ~S Tape Verification Listing Schlumoerger Alaska Computing Center 7-SEP-1995 18:11 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/09/ 7 ORIGIN : FLIC REEL NAME : 95273 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT MPE-20, APi #50-029-22561-00 PAGE: **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/09/ 7 ORIGIN : FLIC TAPE NAME : 95273 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT MPE-20, API #50-029-22561-00 TAPE HEADER MILNE POINT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD BIT RUN 1 95273 OPEN HOLE 1ST STRING 2ND STRING MPE-20 500292256100 BP EXPLORATION SCHLUMBERGER WELL SERVICES 7-SEP-95 BIT RUN 2 BIT RUN 3 25 13N IOE 3637 1955 53.80 53.80 24.60 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 24.000 20.000 112.0 16.000 13.375 2607.0 .,S Tape Verification Listing Schlumberger Alaska Computing Center 7-SEP-1995 18:11 3RD STRING 12.250 4200.0 4TH STRING 9.875 4295.0 PRODUCTION STRING REMARKS: WELL DRILLED 28-MAY-95 TO 8-JUN-95. REAL-TIME MWD GAMMA RAY INTERVAL IS 2587' TO 4294'. $ **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: 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 2584.0 4290.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH MWD 88888.0 88884.0 4275.0 4271.0 4266.0 4262.5 4257.5 4253.5 4249.0 4245.5 4244.0 4241.0 4240.0 4236.0 4234.0 4230.0 4230.5 4226.5 4227.0 4223.5 4220.0 4216.5 4217.0 4214.0 4213.0 4209.5 4208.0 4204.5 4205.5 4202.5 100.0 97.0 $ MERGED DATA SOURCE _~S Tape Verification Listing Schlumberger Alaska Computing Center 7-SEP-1995 18:11 LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE $ REMARKS: THIS FILE CONTAINS THE DEPTH CORRECTED RAW MWD GAMMA RAY, INTERPOLATED MWD GAMMA RAY, AND INTERPOLATED RATE OF PENATRATION. THE BASE GAMMA RA¥.(.PDC) ONLY COVERS THE LOWER SECTION OF MWD DATA ACQUIRED, FOR THAT REASON ALL MWD CURVES IN THIS FILE HAVE A CONSTANT BLOCKSHIFT OF -3' ABOVE 4205.5'. $ LIS FORMAT DATA PAGE: 3 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name FN MILNE POINT Field Name WN MPE-20 Well Name APIN 500292256100 API Serial Number FL 3637' FSL & 1955' FEL Field Location SECT 25 Section TOWN 13N Township RANG iOE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN XXXX Witness Name PDAT SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 53.8 Above Permanent Datum EKB FT 53.8 Elevation of Kelly Bushing EDF FT 53.8 Elevation of Derrick Floor EGL FT 24.6 Elevation of Ground Level TDD FT 4705. Total Depth - Driller TDL FT 4705. Total Depth - Logger BLI FT 4294. Bottom Log Interval TLI FT 2587. Top Log Interval DFT LSND Drilling Fluid Type TABLE TYPE : CURV DEFI DEPT Depth GRRW Gamma Ray GRIN Gamma Ray ROP RATE OF PENETRATION GR Gamma Ray ~S Tape Verification Listing 7-SEP-1995 18:11 Schlumberger Alaska Computing Center PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYP~-- REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ~A~ S~V UN~ S~V~C~ A~ AP~ A~ A~ r~ ~U~ ~U~ S~Z~ ~ ~$~- ~ 0~ ~ ~0~ ~¥~ C~^SS ~0~ ~U~ S^~ ~ CO~ o~ ~ oo ooo ooo ~ ~ ~ ~ -~ .... GRRW MWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000 GRIN MWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 I 1 4 68 0000000000 GR PDC GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ....................................................................................... 4617.500 GRRW.MWD -999.250 GRIN.MWD -999.250 ROP.MWD 83.949 2584.000 GRRW.MWD 48.000 GRIN.MWD 48.000 ROP.MWD -999.250 ** DATA DEPT. GR. PDC DEPT. GR.PDC ** END OF DATA ** -999.250 444.700 ~IS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 7-SEP-1995 18:11 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 7 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 MWD 2587.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): . BOTTOM LOG INTERVAL (FT}: BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 'VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA STOP DEPTH 4294.0 8-jUN-g5 REAL-TIME 47O5.0 2587.0 4294.0 0.0 13.4 TOOL NUMBER ~lS Tape Verification Listing Schlumberger Alaska Computing Center 7-SEP-1995 18:11 OPEN HOLE BIT SIZE (IN~: DRILLERS CASING DEPTH ~FT~: BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (k~/~): MUD VISCOSITY (S}: MUD PH: MUD CHLORIDES ~PPM): FLUID LOSS (C3): RESISTIVITY (OHHH) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX C!RCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF EWR FREQUENCY REMARKS: DIRECTIONAL SURVEY SERVICE (DSS) WAS PICKED UP ON 24-HAY-95 AT 112' TO DRILL TO THE 13.375" CASING POINT AT 2607' BY 26-MAY-95. DIRECTIONAL LOGGING SERVICE (DLS) WAS THEN PICKED UP ON 28-MAY-95 TO DRILL THE 12.25" SECTION FROM THE CASING SHOE TO 4200' ON 29-MAY-95. AT THIS POINT, DLS WAS USED TO DRILL THE 9.875" SECTION FROM 4200' TO 4295' ON 30-MAY-95. CORING BEGAN ON 31-MAY-95 FROM 4295' AND WAS COMPLETED ON 05-JUN-05 AT A DEPTH OF 4560'. $ LIS FORMAT DATA PAGE: 6 TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION Company Name Field Name FN MILNE POINT WN MPE-20 Well Name APIN 500292256100 API Serial Number FL 3637' FSL & 1955' FEL Field Location SECT 25 Section TOWN 13N Township RANG ' IOE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN XXXX Witness Name ~S Tape Verification 'Listing Schlumberger Alaska Computing Center 7-SEP-1995 18:11 PAGE: 7 TUNI VALU DEFI SEA LEVEL Permanent datum PDAT EPD FT O. LMF DF APD FT 53.8 EKB FT 53.8 EDF FT 53.8 EGL FT 24.6 TDD FT 4705. TDL FT 4705. BLI FT 4294. TLI FT 2587. DFT LSND Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type TABLE TYPE : CURV DEFI DEPT Depth GR Gamma Ray GR Gamma Ray GR Gamma Ray ROP RATE OF PENETRATION ROP5 RATE OF PENETRATION ROP RATE OF PENETRATION VDEP True Vertical Depth as channel <TVTCPI> ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** =____ 1 66 0 2 66 0 3 73 32 4 66 1 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 .~S Tape Verification-Listing Schlumberger Alaska Computing Center 7-SEP-1995 18:11 PAGE: TYPE REPR CODE VALUE 0 66 I ** SET TYPE - CHAN ** uNiT ID ORDER # LOG TYPE CLASS MOO NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 I 1 4 68 0000000000 GR RAW CPS O0 000 O0 0 2 1 i 4 68 0000000000 GR MWD AAPI O0 000 O0 0 2 i I 4 68 0000000000 GR INT AAPI O0 000 O0 0 2 i I 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 MWD F/HR O0 000 O0 0 2 1 i 4 68 0000000000 ROP INT F/HR O0 000 O0 0 2 I i 4 68 0000000000 VDEP MWD FT O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA DEPT. ROP.MWD DEPT. ROP.MWD 4294.000 GR. RAW -999.250 GR.MWD -999.250 GR. INT 28.400 ROP5.MWD 23.600 ROP. INT 28.400 VDEP.MWD 2587.000 GR.RAW 14.100 GR.MWD 48.000 GR. INT 444.700 ROP5.MWD 438.800 ROP. INT 444.700 VDEP.MWD -999.250 4257.300 48.000 2560.600 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/09/ 7 ORIGIN : FLIC TAPE NAME : 95273 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT MPE-20, API #50-029-22561-00 _~S Tape Verification Listing Schlumberger Alaska Computing Center 7-SEP-1995 18:11 PAGE: **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/09/ 7 ORIGIN : FLIC REEL NAME : 95273 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT MPE-20, APi #50-029-22561-00 MPE - 20 MI~NE POINT M C OFIL Run 1' 06 - June - 1995 DLL/MLL/ZDIJCN/GR 42OO RECEIVED ,JUN 1 5 1996 Alaska Oil & Gas Cons. Comrp/s.~inn nn,norage Logging Services WESTERN ATLAS Tape Subfil~ 2 is typ~. LIS TAPE HEADER MILNE POINT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6441.00 J. DAHL COOK/PYRON MPE - 20 500292256100 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 12-JUN-95 RUN 2 RUN 3 25 13N 10E 3637 1955 53.80 0.00 24.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 13.375 2587.0 PRODUCTION STRING 9.875 4700.0 REMARKS: DLL/MLL/ZDL/CN/GR. CIRCULATION STOPPED AT 15:30, 06-JUN-95. MLL & ZDL CALIPER AFTER LOG VERIFICATION DONE IN CASING (12.6" I.D.). BARITE PRESENT IN MUD SYSTEM (1%). AS PER CLIENTS REQUEST, ENVIRONMENTAL & TORNADO CHART CORRECTIONS WERE APPLIED TO DLL/MLL DATA. THE MLL WAS CORRECTED FOR THE EFFECTS OF MUD CAKE & AN "RXO" CURVE WAS OUTPUT. THE DLL DATA WAS CORRECTED FOR BOREHOLE EFFECTS. THE CORRECTED DLL DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RXO = RESISTIVITY OF FLUSHED ZONE RT = TRUE FORMATION RESISTIVITY DI = DEPTH OF INVASION~ NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4200.0 4618.0 DLL 4200.0 4694.0 SDN 4200.0 4642.0 2435 4200.0 4621.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH MLL 4202.5 4204.0 4204.5 4209.5 4217.0 4218.5 4224.0 4226.5 4230.0 4230.5 4236.5 4237.0 4240.5 4241.0 4242.5 4246.5 4253.5 4268.5 4273.5 4280.0 4281.0 4292.0 4295.0 4295.5 4296.0 4300.5 4305.5 4307.5 4308.0 4312.5 4316.5 4317.0 4322.0 4334.0 4335.5 4342.0 4346.0 4350.0 4359.0 4363.5 EQUIVALENT UNSHIFTED DEPTH LLD RHOB NPHI 4202.5 4204.0 4204.5 4205.0 4209.5 all runs merged; no case 4217.0 4218.0 4223.5 4226.0 4230.0 4230.5 4230.0 4236.5 4236.0 4240.0 4241.0 4242.0 4246.5 4253.5 4253.5 4253.5 4268.0 4269.0 4273.0 4273.5 4273.5 4279.5 4281.0 4291.5 4292.0 4291.5 4295.0 4295.5 4295.5 4299.5 4305.5 4307.0 4307.5 4311.5 4316.0 4315.5 4316.0 4321.5 4321.5 4321.5 4321.5 4334.0 4334.5 4335.0 4335.5 4342.0 4345.0 4346.0 4345.5 4349.5 4358.0 4358.5 4359.0 4359.0 4363.0 43 43 43 43 43 43 44 44 44 44 44 44 44 66.0 66.5 70.0 70.5 87.0 93.0 05.5 07.5 10.0 13.0 13.5 20.5 28.5 4430.5 4431.5 4432.0 4433.0 4433.5 4442.0 4442.5 4457.0 4459.0 4461.5 4463.5 4466.5 4467.0 4468.0 4477.5 4480.5 4482.0 4483.0 4485.5 4488.5 4492.5 4493.0 4493.5 4511.5 4516.5 4517.0 4532.5 4548.5 4577.5 4578.0 4584.5 4594.0 4605.0 4610.0 4610.5 4659.5 4666.0 4670.5 $ MERGED DATA SOURCE PBU TOOL CODE GR DLL SDN 2435 $ 4370.0 4410.0 4413.5 4420.0 4428.5 4432.5 4442.0 4462.0 4467.0 4482.0 4492.0 4516.0 4532.5 4604.5 RUN NO. 1 1 1 1 4365.5 4370.0 4413.0 4430.5 4433.0 4441.5 4457.0 4459.5 4461.5 4467.0 4492.5 4511.0 4516.0 4577.5 4593.5 4609.5 4659.5 4665.5 4670.0 PASS NO. 2 2 2 2 4370.5 4387.5 4408.0 4412.5 4434.0 4442.0 4457.5 4461.0 4463.5 4466.0 4478.0 4489.0 4493.0 4516.5 4578.5 4611.0 4366.5 4371.0 4393.0 4405.0 4413.0 4431.5 4442.5 4463.0 4468.0 4480.5 4483.0 4486.0 4488.5 4494.0 4517.5 4548.5 4584.0 4604.5 4609.5 MERGE TOP 4200.0 4200.0 4200.0 4200.0 MERGE BASE 4618.0 4694.0 4642.0 4621.0 REMARKS: MAIN PASS. RXO & CALl (from MLL tool) WERE SHIFTED WITH MLL CURVE. LL3, RT, DI, SP, MTEM, TEND, & TENS WERE SHIFTED WITH LLD. DRHO, PEF, & CALl (from ZDL tool) WERE SHIFTED WITH RHOBo FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT /??MATCH1.OUT /??MATCH2.OUT /??MATCH3.OUT /??MATCH4.OUT $ : BP EXPLORATION (ALASKA) : MPE - 20 : MILNE POINT / SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool COde Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 LL3 DLL 68 1 OHMM 4 3 LLD DLL 68 1 OHMM 4 4 RT DLL 68 1 OHMM 4 5 DI DLL 68 1 IN 4 6 SP DLL 68 1 MV 4 7 MTEM DLL 68 1 DEGF 4 8 TEND DLL 68 1 LB 4 9 TENS DLL 68 1 LB 4 10 MLL DLL 68 1 OHMM 4 11 RXO DLL 68 1 OHMM 4 12 CALl DLL 68 1 IN 4 13 RHOB SDN 68 1 G/C3 4 14 DRHO SDN 68 1 G/C3 4 15 PEF SDN 68 1 BN/E 4 16 CALl SDN 68 1 IN 4 17 NPHI 2435 68 1 PU-S 4 18 FUCT 2435 68 1 CPS 4 19 NUCT 2435 68 1 CPS 4 4 17 310 01 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 76 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 86 TaPe File Start Depth = 4704.000000 Tape File End Depth = 4192.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20501 datums Tape Subfile: 2 289 records... Minimum record length: ~ 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4200.0 4620.0 DLL 4200.0 4674.0 MLL 4200.0 4696.5 ZDL 4200.0 4643.5 2435 4200.0 4622.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL KNJT KNJT TEMP PCM MIS DLL FTS MIS MLL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB MICRO LATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 06-JUN-95 FSYS REV. J001 VER. 1.1 1530 06-JUN-95 2039 06-JUN-95 4700.0 4697.0 4200.0 4694.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222EA/2222MA 3923NA 3923NA 2806XA 3506XA 3967XA 1229EA/1229MA 3967XA 3104XA 9.875 2587.0 .0 KCL POLYMER 9.30 MUD VISCOSITY (~,: MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE - 20 : MILNE POINT / SBP : NORTH SLOPE : ALASKA ,8.0 8.0 5.0 82.0 .168 .142 .152 .000 .234 .000 THERMAL SANDSTONE 2.65 .000 2.0 68.0 82.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units 1 GR DLL 68 1 2 RS DLL 68 1 3 RD DLL 68 1 4 RT DLL 68 1 5 DI DLL 68 1 6 SP DLL 68 1 7 TEMP DLL 68 1 8 CHT DLL 68 1 9 TTEN DLL 68 1 10 SPD DLL 68 1 11 RMLL MLL 68 1 12 RXO MLL 68 1 13 C24 MLL 68 1 14 ZDEN ZDL 68 1 15 ZCOR ZDL 68 1 16 PE ZDL 68 1 17 C13 ZDL 68 1 18 CNC 2435 68 1 19 CNCF 2435 68 1 GAPI OHMM OHMM OHMM IN MV DEGF LB LB F/MN OHMM OHMM IN G/C3 G/C3 BN/E IN PU-S PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 17 310 01 1 4 17 220 09 1 4 17 220 10 1 4 17 120 46 1 4 17 120 44 1 4 17 010 01 1 4 17 660 99 1 4 17 635 99 1 4 17 635 99 1 4 17 636 99 1 4 20 270 03 1 4 20 935 02 1 4 20 280 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 995 99 1 4 43 995 99 1 4 43 995 99 1 20 CN 2435 ~ 1 21 LSN 2435 68 1 22 SSN 2435 68 1 * DATA RECORD (TYPE# 0) Total Data Records: 187 PU-L 4 CPS 4 CPS 4 1018 BYTES * 88 4 43 890 01 4 43 334 31 4 43 334 30 Tape File Start Depth = 4704.000000 Tape File End Depth = 4192.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 47128 datums Tape Subfile: 3 272 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE REPEAT PASS Composite of all curves and log header data from all tool strings for a single run; Multiple repeat passes for individual tool strings, if they exist, follow in a separate file. Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 1 1 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4439.0 4620.0 DLL 4439.0 4674.0 MLL 4439.0 4696.5 ZDL 4439.0 4643.5 2435 4439.0 4622.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 06-JUN-95 FSYS REV. J001 VER. 1.1 1530 06-JUN-95 2023 06-JUN-95 4700.0 4697.0 4200.0 4694.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL KNJT KNJT TEMP PCM MIS DLL FTS MIS MLL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB MICRO LATEROLOG TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222EA/2222MA 3923NA 3923NA 2806XA 3506XA 3967XA 1229EA/1229MA 3967XA 3104XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 2587.0 .0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/~): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE - 20 : MILNE POINT / SBP : NORTH SLOPE : ALASKA 9.30 78.0 8.0 5.0 82.0 .168 .142 · 152 .000 .234 .000 THERMAL SANDSTONE 2.65 .000 2.0 68.0 82.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR DLL 68 i GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM RT DLL 68 1 OHMM DI DLL 68 1 IN SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN RMLL MLL 68 1 OHMM RXO MLL 68 1 OHMM C24 MLL 68 1 IN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E C13 ZDL 68 1 IN CNC 2435 68 1 PU-S 4 4 17 310 01 1 4 4 17 220 09 1 4 4 17 220 10 1 4 4 17 120 46 1 4 4 17 120 44 1 4 4 17 010 01 1 4 4 17 660 99 1 4 4 17 635 99 1 4 4 17 635 99 1 4 4 17 636 99 1 4 4 20 270 03 1 4 4 20 935 02 1 4 4 20 280 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 995 99 1 4 4 43 995 99 1 20 CN 2435 68 1 21 LSN 2435 68 1 22 SSN 2435 68 1 * DATA RECORD (TYPE# 0) Total Data Records: 99 PU-S 4 PU-L 4 CPS 4 CPS 4 1018 BYTES * 4 43 995 99 4 43 890 01 4 43 334 31 4 43 334 30 88 Tape File Start Depth = 4704.000000 Tape File End Depth = 4432.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45549 datums Tape Subfile: 4 Minimum record length: Maximum record length: 185 records... 62 bytes 1018 bytes Tape Subfile 5 is type: LIS 95/ 6/12 01 **** REEL TRAILER **** 95/ 6/12 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 12 JUN 95 3:36p Elapsed execution time = 6.76 seconds. SYSTEM RETURN CODE = 0