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Home My WebLink About182-127-_'-~,~G=,_~,~=~- ' =~ LOC_%TION CLE~-~L~_~CE REPORT Sta~e cf Alaska ALAS~0iL & GAS C-'~SERVATION CCHMISSION .:= .~o. I g,z--/2,"7 Rev±aw "~.-a we~__ ~ ____=: ~ =, an.c~- ¢~mm~:: on pluq~q, well head . 5'0o · Well hear c"..xC o~.~: - Locac'~::~ C~_aa~ance: DaCe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D Abandoned [~] Service D 2. Name of Operator 7. Permit Number BP Exploration (Alaska), Inc. 182-127 3. Address 8. APl Number P. O. Box 196612, Anchorage, AK 99519-6612 50-029-20802 4. Location of well at surface ! ~. 9. Unit or Lease Name 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM (asp's 686026, 5941066),~3"OC~'iK31'~'. : Prudhoe Bay Unit At Top Producing Interval /~~_____j~ 10. Well Number 5249' FNL, 2379' FEL, Sec. 02, T10N, R14E, UM (asp's 684617, 5940595)~~I 06-21 At Total Depth ' 11. Field and Pool 4' FNL, 2465' FEL, Sec. 11, T10N, R14E, UM (asp's 684532, 5940559) Prudhoe Bay Field 5'. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 74 feetI ADL 28311 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, If offshore 16. No. of Completions August 27, 1982 September 5, 1982 June 5, 2000 (P&A'd)I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9452' MD / 9196' TVD 8917' MD / 8670' TVD YES [~] No [~I 2172' feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, RFT/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80 30" 1900# Poleset 13-3/8" 72# L-80 Surface 2510' 17-1/2" 2259 Sx Fondu & 400 Sx PFC 9-5/8" 47# L-80 Surface 8842' 12-1/4" 500 Sx G & 50 bbls Class C 7" 29# L-80 8519 9420' 8-1/2" 275 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) 5-1/2" 8457' 8448' 4-1/2" 8923' 8930' 3-1/2" 8957' * Plugged & Abandoned all open perforation intervals. ';~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See P&A Summary) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (cor~) Press. 24-Hour Rate · 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-403 form approved May 25, 2000 (Approval #300-137) ..... ... ........... :...,ij';.,~ L,!, ~ :.". ;:, :..; Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate 29. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone 3 Top of Zone 2 GEOLOGIC MARKERS MEAS. DEPTH 884T 8870' 8945' TRUE VERT. DEPTH 8601' 8624' 8697' 8903' 9155' 9239' 8986' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Summary of 06-21 Pre Coil Tubing Sidetrack Plug & Abandonment Operations. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed .. ~~~----__ Title Coil Tub n,q Dr n.q Supervisor Lamar L. Ganr~----'---~ INSTRUCTIONS Prepared by Paul Rauf 263-4990. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate "none". Form 10-407 06-21 DESCRIPTION OF WORK COMPLETED PRE COILED TUBING SIDETRACK PLUG & ABANDOMENT SUMMARY Date Event Summary 5/12/2000: 5/26/2000: 6/02/2000: 6/05/2000: 6/06/2000: RIH & tagged PBTD @ 9221' MD. MITOA to 2000 psi - passed. MITIA to 3000 psi - passed. A CTU Cement Plug was pumped to Plug & Abandon the lower wellbore prior to ST operations as follows: MIRU CTU. PT'd equip to 4000 psi. RIH w/CT & pumped 160° F Slickwater. Tagged PBTD @ 9170' MD. Pumped 20 bbls of 17.0 ppg Class G Cement to abandon the open perforation intervals located @: 9210' - 9216' MD (Zone 3) Reference Log: BHCS 9/06/1982. 9220'- 9226' MD (Zone 3) 9235' - 9245' MD (Zone 3/2) 9250'- 9290' MD (Zone 2) 9304' - 9314' MD (Zone 2) Attained a 500 psi press bump. Contaminated cement w/Biozan & jetted contaminated Cement f/the wellbore to the 8940' MD. POOH w/CT. FP'd well. Left 500 psi on wellhead. RD CTU. WOC. RIH & tagged TOC @ 8917' MD. PT'd tubing 1500 psi - no loss in press in 30 min. Continued w/06-21A Sidetracking Operations. Memory Multi-Finger Caliper Log Results Summary Company: PHILLIPS ALASKA Log Date: MAY 26, 2000 Log No.: 4096 Run No.: 1 Pipe1 Desc.: 5.5" 17 lb. Buttress Pipe1 Use: Tubing Pipe2 Desc: 4.5" 12.6 lb. Buttress Pipe2 Use: Tubing Pipe3 Desc: 7" 29 lb. Buttress Pipe3 Use: Liner Well: 06-21 Field: Prudhoe Bay State: Alaska APl No.: 50-029-20802-00 Top Log Intvll .: Bot. Log Intvll.: Top Log Intvl2.: Bot. Log Intvl2.: Top Log Intvl3.: Bot. Log intvl3.: Surface 8,457 Ft. (MD) 8,457 Ft. (MD) 8,923 Ft. (MD) 8,958 Fl:. (MD) 9,204 Ft. (MD) Inspection Type: Sidetrack Candidate Tubing/Liner Inspection COMMENTS: This survey was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damages. The caliper recordings indicate that the 5.5" tubing is in good to fair condition, with maximum recorded penetrations ranging from 10% to 29% wall thickness. The damage appears in the forms of general corrosion with occasional deeper isolated pits. No areas of significant cross-sectional wall loss or ID restrictions are recorded throughout the interval of 5.5" tubing logged. The 4.5" tubing also appears to be in good to fair condition, with maximum recorded penetrations ranging from 17% to 28% wall thickness. The damage appears in the form of general corrosion with a deeper line of corrosion. No areas of significant cross-sectional wall loss or ID restrictions are recorded throughout the interval of 4.5" tubing logged. The caliper recordings indicate that the 7" Liner is in fair to poor condition with respect to corrosive damage. A deep line of corrosion, with maximum recorded wall penetrations ranging from 60% to 64% wall thickness is recorded from 9,044' to the bottom of the logged interval at 9,204'. An area of what appears to be cement sheathing is recorded from 9,146' to 9,164', restricting the ID to a minimum of 5.66" @ 9,154'. No areas of substantial cross-sectional wall loss are recorded throughout the interval of 7" liner logged. The caliper was pulled through 34 ft. of 3.5" tail pipe, below the 4.5" tubing. Though the caliper can traverse the 3.5" tubing, it is unable to make accurate measurements in this pipe size. Therefore no assessment of the 3.5" tail pipe is made in this report. 5.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (29%) Jt. 70 @ Isolated Pitting (29%) Jt. 121 @ Isolated Pitting (28%) Jt. 111 @ Isolated Pitting (26%) Jt. 74 @ Isolated Pitting (26%) Jt. 119.1 @ 5.5" TUBING RECEIVED 2,786' MD 4,881' MD 4,455' MD MAY 2 6 2000 3,001' MD 4,768' MD ~,laska 011 & Gas Cons. C0mmissi0r~ Anchorage - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of circumferencial wall loss in excess of 5% are recorded throughout the 5.5" tubing inspected. 5.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant ID restrictions due to deposits or pipe deformity are recorded throughout the 5.5" tubing inspected. ProActive Diagnostic ¢o-~' ~ bdv,(.~;~, InC. / P.O. Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail' PDS(~i)rnenx)rylog.corn ~'~ Prudhoe Bay Field Off:ice Phone: (907) 4.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS ' Line Corrosion (30%) Jt. 2 @ 8,533' MD Line Corrosion (28%) Jt. 1 @ 8,507' MD Line Corrosion (28%) Jt. 6 @ 8,728' MD Line Corrosion (27%) Jt. 9 @ 8,834' MD Line of Pits (24%) Jt. 5 @ 8,662' MD 4.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No areas of circumferencial wall loss in excess of 5% are recorded throughout the 4.5" tubing inspected. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS · No significant ID restrictions due to deposits or pipe deformity are recorded throughout the 4.5" tubing inspected. 7" LINER - MAXIMUM RECORDED WALL PENETRATIONS · Line Corrosion (64%) Jt. 6 @ 9,154' MD Line Corrosion (62%) Jt. 3 @ 9,057' MD Line Corrosion (61%) Jt. 4 @ 9,077' MD Line Corrosion (60%) Jt. 5 @ 9,117' MD Line Corrosion (45%) Jt. 2 @ 8,964' MD 7" LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No areas of circumferencial wall loss in excess of 15% are recorded throughout the 7" liner inspected. 7" LINER - MAXIMUM RECORDED ID RESTRICTIONS · A minimum ID of 5.66" is recorded in an area of cement sheathing in Joint 6 @ 9,164'. RECEIVED 26 2000 Alaska 0il & Gas Cons. born.~Jssi0n Anchorage Field Engineer' J. Burton Analyst: J. Burton Witness: Larry Wade ProActive Diagnostic_ ..... qe,~,'~,~"-o~', k._o, inc. / ?.O. Box Pho,~e:.. ,, (28t~._./or (888). ~.:,6~)-~085 Fax: (,:.8:.., E-mail: PDS~:u-nemoryl()q_. _ ._ COT Pnldhoe aa', FieH Office Phone: (q07~ WeJl: 06-21 Fiek!: PRLJDH()E BAY Company: PH!LLIPS ALASKA Co~lntr¥: LiSA PDS Caliper Overview Body Region Analysis SL~ivev Pate; Mas' 16, 2000 iool T~pe: MFC40 No 99494 fool Size: 2 3/4" X~o of Fi?,ers: 40 Analysed: ] B~rton [Jubing: Size Weight G!ade & Thread Nora. OD NomlD Nom. L~pset 55 ins /7 p/ 1-$0 BTRS 5S ins ~892 ins 55 ins PeBdmtio~l a~d Met~[ Loss (% wall) 250~ 0 to 1 to 10 to 20 to 40 to abo'~e ! q~ 10% 2C)~ {, 40% 8S~,~ 85"~ Pene 0 49 167 ! 4 0 0 Loss I 0 2.~0 0 0 0 0 Damage Corl~ig~ratio~ body 200: ~r ~ N ~]berc?tj2?u da~;aged t?}a. 18}} 170 0 I 3 0 0 Damage Profile (% wall) penet!ation boc{v n/eta} loss body 0 50 0 49 100 AnalYsis Overkie~ page PD$ Ce ER. ]OINI TABULATION SI-~T Pipe: 55 ins 17 pie L-80 BI!RS VVelh Wall thickness Body: 0 304ins t/pset = 0 304ins Field: Nominal ID: 1.892 ins Company: Date: No Upset Bocls Loss jLpset iBod,, i !D Cotangents 06-21 PRUDHOE BAY PHILliPS ALASKA , penetration body USA metal Joss body M;~y i6, ?000 '---- Damage plo file 50 100 0 I 3 0 14 0 ;~ 0 ()~ 4 ~; 0 04 480 i Shallo~ pittir 05 0 48l i 2i 0 o l 0 05i 16i 3 0 179 Shallo',~ pu 18 0 ISI 3 0 0Si 483 iShallow ' 21 0 .0'I 2 j 0 04~ 4.80 ] Shallo~,~ 22 0 0S 3 J O 03 183 jShallo~, pitting. 2} i 0 04 3 0 05i 480 l%allo~ 2~ i 0 04 !31 3 0 4.80 JShatlow 25 i 0 04 i4i 2 0 0 48! Shallow i2[ 3 0 481 i Shallow ~ 26 ~ 0 .... i 4.82 Slsal~9 i27 o [ ;6Yi ~7i 3 ~ ~ L28_~0 :04] ~ 0 i 04i 4al iShallo~ 29 0 01,i 14i 3 ~ [ ~ :!,ZJ) jShaltowp~ttm~ ;, 30 Q. ~Z~, I~ 3 ;i 0 i 04 479 31 O 4 i 0 04 4 81 Sh~liox~ isittin i ~, 0 3 i 0 j ,04l 18i Sha ow ~3 0 3 i 0 03l 480 i%aliow 34 0 2 0 05i 4.79 )ittinF, o ~71 3 i o L o4i 482 36 0 2 0 i 05' 480 37 0 05 } 0 i 04i 482 }Shallox5 j ~9 o ~ osi 40 i 0 ,4! 02 4~' n 43 0 45 0 46 0 47 0 48 0 os i 16i 3 04 } 3 2 07 3 .08 4 0'/ 12', ! 0 I 0 ~ 05[ 4:~i{% Shallov~ pittinl 0 04 480 Sl~allo~ 0 482 Shallo'o, 0 i 0Si ,.81 Isolated pittiBg 0 i 0 I 482 Shallow 0 J qB0 Shallo,~ Pipe Tabulations page Aasks gl & ,',-Sas Oons 6ommissioa Ancho~'agS POS C,~ER lOlNT TABULATION S~T Pipe:5$ins iTppf LS)BTRS Wall thickness Body: 0304ins Upset - 0304ins Nominal ID: 489! ins Weii: 0,S-21 Field: PP. UDHOE BAY Con/pany: PHILLIPS Al ASKA Country: USA Date: Ma~ 16, 2000 penetration bo(Ix ioint No Lpset 49 0 50 0 Penehation ] Metali Projection Body koss Upset ]Body ID inchesj, ?~:. ~S i ~c'~es~ ch~, _gche_ 5 , (33 i 1 I 2 0 i Oi 55"~ 2 -d- i 04 .o4 05 480 [PLP 542i 0 0 ] 0} 0 0 i 0 477 ', SSSV AssN. s7 o2 0~Ti~( 0 i :o,~ 'L? sh4b,~ ~m!~s 58 02 04 j ~3 3 0 i 0ii 481 l Shailo~ oittin~ 3 i 0 i 04{ 483 iShallo~r~n~ 0 03=~ I 7 ~ ~5~ 48i Shall ......itli~ '"~ 63 O/ 2 0 [ 04} 481 Shallow O 03 ~ i} 3 65 0 04 66 0 05 3 6? 9 .os i 68 0 06 9l 3 3 29i 4 69 0 07 70 0 09 71 0 07 72 0 721 0 .03 72 2 0 0 723 0 05 73 0 06 0 481 Shalloxx pittin 0 i 03i 481 Shallow 0 041 483 St~allow 0 j 03i. 482 Shallow ]pitt!n~ 0 [ - ~[~i 483 0 06{ 481 j Isolated 0 0Si 480 i lsolated pittin8, 0 04i 4.81 Isolated 0 04j 484 l !solated 0 L o4[ 483 PUP Shallow pittin 0 0 4.81 GLM I {katch~4:30) !Si 2 { 0 05i 48/ PUP Shallow 20j 3 0 051 483 0 483 ]isolated 0 ()5i 483 [ Shallow 0 05h.$8~ [j~5:~i?~ted pitting 0 04i 494 [isolated Ls2 o o3~ 482 03~ 482 ~Sha{}o~, pi~in~. 481 ISha!low 483 Shallow 0 i i I 0 .04i 483 0 3 i 0 ()]] 482 92 0 ] /8} ; 0 .04 484 [Shallow pittin ~ 50 100 Pipe Fabulations page 2 PDS tOIX T ,BUL,,T ON Pipe: 5.5 ins 17ppf i-80BTRS Rail thickness Body:0304ins Upset 0304ins Xominal !O: 489! Well: 06~2 i Field: PRUDi tOE BAY Company: PI IILLiPS Al ASKA Country: USA Oate: May i6, 2000 penetration body metal loss body Joint Penetration Metai PJojeetion Minimum No Upset Body i Loss j tJpset Bod? iD Comments inches inches[ % % ~ inches [inches inches 0~ ~ s ~ 0 ~ ()5~ 482 iShailov~ 96 o ~ 6~-NT 3 '~ o 97 0 98 0 99 0 100 0 I03 0 07 03 07 0 03 104 [ I 07 0 108 0 .02 I !0 02 0 i115 Ol 0 i~22 01 123 02 124 0 i25 02 24! 2 02 09i 478 [isolated / os I ~6i 2 03 3 03 05 2 08 ~ ~ 06 06 2 06 2oi 3 04] '12! 3 2 2 03 3 05 2 08 26[ 2 0 .10 4 76 Shailov~ pittin 0 .09i 482 [ 051 ~8i Sh alb'~ pittin 05i 482 Shallo',~ pitting .041 0 i01 480 piltin 02j 480 i isolated 05 i 09 ~$2 [ Sh;dlov~ pittinX 0 [ 14;~ 42'6 [ Shallo',~ 0 05i 48~ 0 07 482 [ Shallow pitting O 05 483 iSl~allow 0 .10] 4Z9 06i 482 Shallow pinin~ O o~ 483 PUP isolated 0 j 48! GlM2 (Latche I:O0) 0 481 PUP Slwilow 05 2 ] 0 05i 482 Shallow .04 05l 4,84 I 0 04i 483 Shallow pittin 04 !4 3 04 i 05j 482 Si~alk i2g 0 03 ! I0 3 ' 0 i 05 4.84 i 129 01 071 479 ]Shallow p_itting 130 0 05 3 0 06{ 48i [Shallo~ 132 0 0S [1~ 2 i 0 i 07 479 Shallow ni~tinfi ll33 O 04 3 O 09~ 480 }SM 13a 0 04 0 '~80 Shx~iow 135 0 05~ 151 2 j 0 061~ 481 Shalluv, pittin 136 0 05 ~ 16~ 3 ~ 0 4.g! Shaib~ piein 13~ 0 03 i 10 3 0 05l 482 ~38 0 03 10~ 2 0 051 483 l J9 0 .05 15 4 0 i [lamage p~ofile ~ 50 Pipe Tabulations page 3 /00 PDS C~ ER IOINT TABULATION S~T Pipe: Sg ills / 7 ppf l-8() BTRS \Veil: {)6-21 Wall dqickness Bod'~: 0304ins Upset 0304ins Field: PRUDHOE BAY Nominal ID: 4892 ins Company: PHIl L lPg ALASKA Codntry: USA Date: Ma~ 16, 2000 No j Upset Body Loss lLJpse~ jBod~ i ID Comments i41 0 ~3i 3 0 i 04i 484 i Shallo~*, pittinB. 142 0 .0S 3 j 0 05 484 !Shallow [~ 13 0 05 3 [ 0 06i 48~ j Shallo~ ] 144 0 ~ .0S'~ 482 Sba!low pittiqg ~ 0 0 j )4~ 482 l ShSle*: l~!tdn~ j l47 0 0 .0Si 484 [~halJow pittiq8 0 0Si 483 iShallow 0 ~ 'i)5J 48,4 Sl~allow pittin~ 0 i ~ ;i~ I~hallow ~ttinS 0 ~ 05 182 lShallow pitdn 1542i 0 i543 0 155 0 / 56 0 157 0 158 0 159 0 160 0 ~ 62 0 163 0 16si o 04. i 66 0 03 3 ~6:- i 0 o3 8i 4 168 0 03 4 169 0 05 i 6l 2 o ~ o i 0 L 0i o i 0 05} 16] ?- i 0 04 !21 3 i 0 0 04 13' 2 i o 0 O3 2 ~ i 0 03 2 0 os i o .oG 2ol 3 o 3 0 0 0 0 0 0 0 06i 483 'Shallow 481%aJlo,,}( pitW~g 08 480 IShallo~x 483 PLP Shallow 0 482 GLM '} (Latch e 1:00} 041 482 PUP Shallow ,07i 181 i Isolated pittil 08i 481 Shallow ,05 4.82 ~!}{?]low pittin~ 04i 484 08~ 479 07 479 Sha!kx~ 08 479 Shallow 08j 481 Sha~low ' 04i 483 j Shallo~ 04i 4.84 i oi 4¢,; ~ 0Fi 480 l Shallo~, pe-~etration body metal JOSS body k170 j o 04 171 0 03 i 172 0 03 03 174 0 03 J 76 0 03 0 04 !77i 0 !77.2= 0 1773 0 O2 178 /80 181 3 3 4 3 0 o 04 0 04i 0 05i 0 0 o .osi 0 0 0 O6 0 0 0 04 0 051 o 4,84 484 i 483 Si%dlo~ 'l.86 j Shallow 483 ~ 480 Shallow 4.83 ! 482 l Shall 4 83 PLP 483 GLM 4 {Latci~ ~S 12:00) 453 PUR 402 lShallow 480 4.83 J Shallow 48S 4{34 [ Pipe fabuladons page 4 amage wall) RECEIVED A~Ohom e Ioo T BUU,:TIOX Pipe:SS(ns 17ppf L80B1RS Wall thickness. Body: 0304ins Llpset: 0304ins ~,iominal ID: 4.892 ins Well: 0G2 ! fi(eld: PRUDHOE BAY Company: PHiN IPS ALASKA Country: USA Date: May 16, 2000 No Lipset inches 184 0 18S 0 186 0 I g 7 0 ~ss o L~%j 0 189 i 0 Penetration i Metal i Body ! Loss % 3 03 ~ / ii 4 3 o ~ ~ 0! 0 02l 8i 3 Projection Mininlum Upset [Body { inches ;inches roches 0 04 L85 Line si~allow con@sion. 483 ~i Shallow pitt-'---il~ o o4i 4a4 o o5i 4.86 0 04 484 0 06 483 PUP 4.84 484 .06 4s~ GLM5 (Latch@7:00) [190. J _ 0 1903 0 03 0 03 192 0 06 [~93 0 02 i~94 0 0 0,4 196 0 0 03 i971 0 04 0 0 197.31 0 05i 198 0 02 /981 0 .02 4 0 0 0 2 05 3 0 3 0 3 0 3 0 0 3 0 0 0 3 0 4 n 04i 484 PUP Line con@sion. 0 i ,483 ) GLM 6 (! arch @ 30) 05 ,483 J PLP Shaib~x pii:til 07i 482 i 05i 484 ()5i 484 .05, 4 82 4 84 03j 484 041 485 ou 4g~ Shallo~; - !(ne shallow coil@sion PUP Shall@v, pittln GLM 7 (latch @ 3:00) 482 04 484 06 4.84 PUP Line shallow corrosion PUP 2023 2031 2032 2037i 2038{ 2O4 0 0 02 0 0 3 03 3 04 ~21 ~ 0 03 06 3 0 02 2 0 0 0 0 o o5i _~.s4 0 O~ 4.86 01 08[ !79 0 0 [ 481 PUP PLiP Shallow GIM 10 (Latch @ 5:00~ 08 05i 481 PUP 0 485 PUP Line colrosion 0 0j 483 SLIDING SLEEVE 0 0 03 4.$3 05 ,18~ 0 i 0 i82 PUP L (ne shalbw corrosion PACKER Damage p~ofile b 50 I O0 iii Pipe Tabulations page 5 PDS Caliper Sections W~ll: 06-21 Storey Date: May 16, 2000 Field: ?I~(JD) IOi BAY 7oo/ lype: MFC40 No 99494 Con~pam: Pt IIl/IPS A! ASKA Tool Size: 2 3/4" Countly; t ~SA No. oi Fin~ers: 40 55 ins I ~ LB0 B IRS Analysed: ~ Burton Cross section for joint 70 at depth 2786,31 ft ioolspeed G7 Nomn~l ID 4892 Xlomm~dOD 3300 wall alea 9~J % i::in,~el 3 I~adius = 2549 ils Isolated Pit 0088 in =: 29'~ I IiGII SLID[ =: tiP PDS Caliper Sections Well: 06-21 Storey Dale: May 16, 2000 Field: PRLJDI 1OI BAY fool /ype: MFC40 No. 99494 Company: I~ltlll IPS ALASKA lool Size: 2 3/4" (ountl~: LiSA No of I ingels: 55 ins ~], USOBIRS ,~ndysed: J~,i~u~ton Cross section for joint 111 at depth 4445~49 ft fool speed -: 65 Nomina! ID -; 4 892 Nominal OD: 5500 Ftemainin8 wall ama - 100 % Fool de¥iation :: i 7 ° Fin?,ef itt&~s 2S29ms PD' ;ALIPER JOINT TALLY SHEET Pipe: 5.5 ins 17 ppf L-80 BTRS Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Joint Depth Length Measured Type No. ID feet feet inches .1 25.04 5.14 4.878 Pup .2 30.18 3.44 4.867 Pup 1 33.62 37.97 4.873 2 71.59 39.31 4.869 3 110.90 39.29 4.871 4 150.19 39.19 4.878 5 189.38 39.21 4.874 4 228.59 39.24 4.878 7 267.83 38.16 4.876 8 305.99 39.37 4.880 9 345.36 39.32 4.880 10 384.68 39.29 4.882 11 423.97 39.10 4.870 12 463.07 39.35 4.880 13 502.42 39.29 4.881 14 541.71 39.37 nominal 15 581.08 39.35 4.882 16 620.43 39.35 4.868 1 7 659.78 39.48 4.877 18 699.26 39.27 4.897 19 738.53 39.35 4.872 20 777.88 39.40 4.872 21 817.28 39.18 4.871 22 856.46 39.29 nominal 23 895.75 39.35 4.873 24 935.10 39.21 4.871 25 974.31 39.38 4.870 26 1013.69 39.35 4.885 27 1053.04 39.21 4.886 28 1092.25 39.29 4.887 39 1131.54 37.66 4.879 0 1169.20 39.31 4.875 31 1208.51 38.86 4.881 32 1247.37 39.24 4.879 33 1286.61 39.37 4.870 34 1325.98 39.48 4.883 35 1365.46 39.43 4.887 36 1404.89 39.1 7 4.879 37 1444.06 39.28 4.882 38 1483.34 39.24 4.880 39 1522.58 39.35 4.883 40 1561.93 39.31 4.879 41 1601.24 39.42 4.888 42 1640.66 39.39 4.896 43 1680.05 39.23 4.883 44 1 719.28 39.33 4.883 45 1758.61 39.04 4.882 46 1 797.65 39.57 4.902 47 1837.22 38.41 4.875 48 1875.63 39.31 4.881 Well: 06-21 Field: PRUDHOE BAY Company: PHILLIPS ALASKA Country: USA Date: May 16, 2000 Joint Depth Length Measured Type No. ID feet feet inches 49 1914.94 39.18 nominal 50 1954.12 39.44 4.883 51 1993.56 39.33 4.880 52 2032.89 39.26 4.880 53 2072.15 39.21 4.888 54 2111.36 39.25 4.891 54.1 2150.61 12.96 4.876 Pup 54.2 2163.57 17.89 nominal Sssv 54.3 2181.46 5.04 4.859 Pup 55 2186.50 39.38 4.879 56 2225.88 39.41 4.880 57 2265.29 38.60 4.878 58 2303.89 38.76 4.881 59 2342.65 39.23 4.888 60 2381.88 38.49 nominal 61 2420.37 39.24 4.883 62 2459.61 39.21 4.883 63 2498.82 39.43 4.879 64 2538.25 39.28 4.882 65 2577.53 39.21 4.881 66 2616.74 39.41 4.886 67 2656.15 38.54 4.889 68 2694.69 39.30 4.894 69 2733.99 39.24 4.882 70 2773.23 39.38 4.898 71 2812.61 39.22 4.886 72 2851.83 39.32 4.906 72.1 2891.15 14.67 4.884 Pup 72.2 2905.82 9.20 nominal Glml 72.~'~ 2915.02 14.65 4.889 Pup 73 2929.67 38.11 4.888 74 2967.78 39.37 4.896 75 3007.15 39.30 4.897 76 3046.45 39.34 nominal 77 3085.79 39.30 nominal 78 3125.09 39.26 4.881 79 3164.35 39.41 4.891 80 3203.76 39.20 4.883 81 3242.96 38.96 4.890 82 3281.92 39.30 4.881 83 3321.22 39.35 4.887 84 3360.57 38.45 4.883 85 3399.02 39.33 4.881 86 3438.35 39.26 4.886 87 3477.61 38.70 4.891 88 3516.31 38.02 4.888 89 3554.33 39.51 4.886 90 3593.84 39.31 4.888 91 3633.15 39.31 4.890 92 3672.46 39.38 4.885 Joint Tally page 1 PD: :ALIPER JOINT TALLY SHEE-[ Pipe: 5.5 ins 17 ppf L-80 BTRS Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Joint Depth Length Measured Type No. ID feet feet inches 93 3711.84 39.31 4.884 94 3751.15 39.30 nominal 95 3790.45 39.19 4.882 96 3829.64 39.39 4.887 97 3869.03 37.88 4.882 98 3906.91 39.2 7 4.889 99 3946.18 39.44 4.877 100 3985.62 39.30 4.890 101 4024.92 39.40 4.885 102 4064.32 38.23 4.883 103 4102.55 39.61 4.877 104 4142.16 39.55 4.879 105 4181.71 39.20 4.886 106 4220.91 39.33 4.895 107 4260.24 39.54 4.883 108 4299.78 39.14 4.883 109 4338.92 39.3 7 4.899 110 4378.29 38.05 4.896 111 4416.34 38.39 4.884 112 4454.73 39.27 4.890 113 4494.00 39.50 4.899 114 4533.50 36.71 4.891 115 4570.21 39.12 4.887 116 4609.33 39.39 4.898 11 7 4648.72 38.31 4.890 118 4687.03 39.35 4.894 119 4726.38 39.62 4.890 119.1 4766.00 15.45 4.889 Pup 119.2 4781.45 8.95 nominal GIm2 119.3 4790.40 14.12 4.884 Pup 120 4804.52 39.41 4.880 121 4843.93 39.16 4.898 122 4883.09 39.36 4.884 123 4922.45 37.84 4.894 124 4960.29 39.25 4.887 125 4999.54 39.39 4.885 126 5038.93 39.24 4.889 127 5078.1 7 39.36 4.889 128 511 7.53 39.27 4.900 129 5156.80 39.29 4.878 130 5196.09 39.16 4.886 131 5235.25 38.94 4.883 132 5274.19 39.30 4.889 133 5313.49 39.29 nominal 134 5352.78 39.22 4.891 135 5392.00 39.42 4.891 136 5431.42 38.38 4.880 137 5469.80 39.39 nominal 138 5509.19 39.11 4.891 139 5548.30 39.27 4.888 Well: 06-21 Field: PRUDHOE BAY Company: PHILLIPS ALASKA Country: USA Date: May 16, 2000 Joint Depth Length Measured Type No. ID feet feet inches 140 5587.57 39.21 4.890 141 5626.78 39.34 4.901 142 5666.12 39.14 4.900 143 5705.26 39.28 4.900 144 5744.54 39.31 nominal 145 5783.85 39.29 4.890 146 5823.14 39.33 4.888 147 5862.47 37.31 4.903 148 5899.78 38.83 nominal 149 5938.61 39.26 4.895 150 5977.87 39.43 4.884 151 601 7.30 39.42 4.889 152 6056.72 39.32 4.894 153 6096.04 38.57 4.891 154 6134.61 39.34 4.894 154.1 61 73.95 14.02 4.897 Pup 154.2 6187.97 9.24 nominal Giro3 154.3 6197.21 13.75 4.883 Pup 155 6210.96 39.24 4.888 156 6250.20 39.13 4.884 157 6289.33 39.21 4.900 158 6328.54 39.31 4.889 159 6367.85 39.36 4.891 160 6407.21 39.25 4.900 161 6446.46 39.3 7 4.902 162 6485.83 39.15 4.894 163 6524.98 39.29 4.891 164 6564.2 7 39.30 4.888 165 6603.57 39.18 4.888 166 6642.75 39.16 4.895 167 6681.91 39.32 4.897 168 6721.23 39.26 4.899 169 6760.49 39.36 4.890 1 70 6799.85 39.24 4.899 1 71 6839.09 39.31 4.899 1 72 6878.40 39.39 4.896 1 73 691 7.79 39.30 4.916 1 74 6957.09 39.68 4.899 1 75 6996.77 39.23 4.899 1 76 7036.00 39.32 4.908 1 77 7075.32 39.27 4.899 1 77.1 7114.59 14.71 4.901 Pup 1 77.2 7129.30 9.39 nominal GIm4 1 77.3 7138.69 14.54 nominal Pup 178 7153.23 39.19 4.896 1 79 7192.42 38.42 4.895 180 7230.84 39.18 nominal 181 72 70.02 35.92 nominal 182 7305.94 39.42 4.902 183 7345.36 39.18 4.906 Joint Tally page 2 RECEIVED PD'. ;ALIPER Pipe: 5.5 ins 17 ppf L-80 BTRS Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Joint Depth Length Measured Type No. ID feet feet inches 184 7384.54 39.32 4.894 185 7423.86 39.37 4.899 186 7463.23 39.19 4.895 187 7502.42 39.42 4.899 188 7541.84 39.39 4.918 189 7581.23 39.19 4.900 189.1 7620.42 13.71 4.896 Pup 189.2 7634.13 8.91 nominal GIm5 189.3 7643.04 13.89 4.897 Pup 190 7656.93 37.19 4.891 190.1 7694.12 14.47 4.912 Pup 190.2 7708.59 9.42 nominal Giro6 190.3 7718.01 14.42 4.905 Pup 191 7732.43 39.28 4.899 192 7771.71 39.28 4.914 193 7810.99 39.36 4.896 194 7850.35 39.26 4.912 195 7889.61 39.27 4.913 196 7928.88 39.26 4.905 197 7968.14 39.16 4.914 197.1 8007.30 15.37 4.908 Pup 197.2 8022.67 9.05 nominal GIm7 197.3 8031.72 15.48 4.904 Pup 198 8047.20 39.27 4.901 198.1 8086.47 14.82 4.922 Pup 198.2 8101.29 9.20 nominal Giro8 198.3 8110.49 14.76 4.901 Pup 199 8125.25 39.25 4.923 200 8164.50 38.76 4.916 201 8203.26 39.35 4.914 202 8242.61 39.18 4.903 202.1 8281.79 14.28 4.914 Pup 202.2 8296.07 9.13 nominal GIm9 202.3 8305.20 14.37 4.920 Pup 203 8319.57 39.17 4.911 203.1 8358.74 10.32 4.885 Pup 203.2 8369.06 11.79 nominal Giro10 203.3 8380.85 14.04 4.896 Pup 203.4 8394.89 14.70 4.9t 4 Pup 203.5 8409.59 5.59 nominal Sidslv 203.6 8415.18 12.98 4.899 Pup 203.7 8428.16 9.86 4.897 Pup 203.8 8438.02 10.57 nominal Pbr 204 8448.59 unknown 4.878 Pkr OINT TALLY SHEE-[ Well: 06-21 Field: PRUDHOE BAY Company: PHILLIPS ALASKA Country: USA Date: May 16, 2000 Joint Depth Length Measured Type No. ID feet feet inches Joint Tally page 3 RECEIVED 2,5 200C Alaska Oil & G~s C,,):~s. Commission Anchorage Well: 06-21 Field: PRDDI IOE BAY Company: PHIl 11PS Ak ASI<.A Country: (iSA PDS Caliper Overview Bociy Region Analysis SurYex Da~e: n/ay 16, 2000 Tool]~pe: MFC40No 99494 ]ool Size: 2 3/4" No o~ Fin~ers: 40 Anal~ sed: J Bu~lon Tubing: Size Weight Grade & Thread NomOD NomlD Nom. Upsel 4:~ins 126ppf 1-80BTRS 45i~s 3958 ins 45 ins Pm~e*~rafior~ aad Me~M Loss (% wall) ;;~ ~; penetlaiion body metal loss body 2O Pene Los; Damage Configum6on ( body ) Number of oints ciamage[l (tQt~..~l 3 0 5O 0~rrfr iiiii ~ II !0 ~ottoln oi: Sulxex, = ! 2 100 Anaksis Oxel~iex~ page 2 Pipe: 43 ins 126ppf L-SOBritS Wallthickness Bo&:O27iins Upset- 0271ins Nominal ID: 3958 ins Well: 06d ! Field: PRUDHOE BAY Company: Pi I!LLiPS ALASKA Countn: USA Date: may 'l 6, 2000 No Upset j Body [ inches [inches 2 0 08 3 0 06 4 0 06 231 i ~ ; 9 06 241 07 0g j !al .os i s 03 0s 9 i O~ 07 10 03 [ 1 ! 0 05 12 0 0 Metal Ioss Projection Minimun/ J Upset ~od'~ ID Commenb~ inches 0 07i 38:5 iLine con'osian. 05 04 389 ~ Line corrosion. () .04l 389 Isolated 0 04i 386 i ~ 051 388 klsolated 2b~n~ _~ lgi i0 3 8 ilinecouosion 4 19 221 376 Li ~e corrosion 3 j 21 :97'~ 374 i tine shallow corrosion ~ j 20i 22 376 ilineconosion [Nne shallow corrosion 13 50 .22i 374 46 3 46 51 307 }X-CXe~ to 35" DamaBe Classifications Penetlation p~ojection class, in o~de~ of damage sevemx Hole -penetratxm exceeds 85% of nominal hal! t!fickness Rins- damatle a~ea exceeds 75% of ci~cunffe~ence, but depth ~ange does not exceed I * pipe ID Line - damage depth range exceeds S pipe ID. but extends less than 22% of cffcumference General ~ damage depth ange exceeds I * pipe ID and/o~ extends more than 22% ot circumference Isolated - damage depff~ range does not exceed 5 * pipe ID or extend more than 22% of circumference Damage mpo~tmg threshokl 30 thou inches deviation in bock, 50 thou in upse~ Modal !ine length 0320 feet meta! loss body Damage plofile (% wail} b 50 I O0 Pipe Tabulations page PDS Caliper Sections Weih 06-21 Sulve\ Date: may /6, 2000 Field: PRLJDIIOi BA'~ 7ool lype: MF:C40 No 99494 Company: PHIl lIPS ALASKA Tool Size: l! ~/4' Counl~V: t!SA No of Fin~er,x 40 ,13 ins 12,C~ I)~ [-f~O BFRS Am~lysec/: J Bu~ton Cross section for joint '2 at depth 8532~71 ft looi speed 67 Non!ina!ID 3938 Nominal OD 4.500 wall a~ea 95 % Iool devialion: 12 ~' RECEIVED I:in~(I 32 Penetration ::: 0081 Ins line of Coltosion 00{H in :: 3(1~; I Il('d I Sill)Ii: LP ALIPER JOINTTALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BTRS Wall thickness. Body: 0.271ins Upset: 0.271 ins Nominal ID: 3.958 ins Well: 06-21 Field: PRUDHOE BAY Company: PHILLIPS ALASKA Country: USA Date: may 16, 2000 Joint Depth Length Measured Type No. ID feet feet inches · 1 8466.64 8.95 3.975 Pup 1 8475.59 42.06 3.951 2 851 7.65 42.82 3.961 3 8560.47 42.28 nominal 4 8602.75 41.05 3.951 5 8643.80 43.95 3.960 6 8687.75 41.73 3.947 7 8729.48 43.68 3.970 8 8773.16 40.98 3.948 9 8814.14 43.73 3.971 10 8857.87 42.62 3.965 11 8900.49 36.46 3.960 12 8936.95 unknown nominal Joint Depth Length Measured Type No. ID feet feet inches Joint Tally page 1 Well: 06-21 Fieid: PRUDHOE BAY Company: PHILLIPS ALASKA PDS Caliper Overview Body Region Analysis Survey Date: M/',y 16. 2000 Too!Type: MFC40No 99494 Tool Size: 2 No o! Finsers: 40 Anak'sed: ] Burton l~ubinB: Size Weight Grade & Thread No-nOD NomlD Nora Upset Peaetration a~d Me;tJ Loss (% walt) Damage Co~figurat~on ( body ) 5yffdoer of~oints d u~Jaged {totaJ_ 7_j 0 3 i 3 0 Damage Profile (% wall) penetration body inetal loss body 0 50 lO0 Anal\,sis O~e~viexx page 2 No (pset inches 1 0¢ PDS C,~R OINT TABULATION Pipe: ? ins i!9 ppf !80 BT!{S Well: 0G-2 Wall thickness Bod~: 0 408ins UpseI - 0 408ins Field: PRUDHOE BAY qominal ID: 6.184 ins Compare,: PHILLIPS ALASKA COLIIltly; USA [)ate: ~,,/av i 6~ 2000 loss lUpset ]~Body j ID i Comments inches % I inches ~h~ches j inches ' 09~: 23 6 i /2[ 04i 6!0 jLinecouosion 18i ~3! 15 0 i ()6i 616 Damage Cbssifications Penetration/' projection class, in order of darnaae se~,erity Hole - penetration exceeds 85% oi ~ omin d ~taJl thickness Line col 'osion, C:or~osion i;~ing - dalnase area exceeds 75% of circumtLc, rence, but depth ~ange does not exceed I * pipe ID Line - dama~;e depth lange exceeds S pipe iD, but extends less than 22% of cilcumfelence Genera!-dama~edepthranseexceeds i pipe ID and/o~ extends mole than 22% o circumference Isolated - damage depth range does not exceed 3 pipe ID or extend mo~e than 22% ol ci~cumterenee Damage repotting, threshold 30 thou ind~es deviation in body' SO thou in upset. Modal line lenath 0293 feet. penelration bod~ i Damase plofile (% wall) iD Si} I O0 Pipe Tabuladolm pa~e ! PDS Caliper Sections W(]l: 06~2 I 5ulvev Da~e: May 16, 2000 FieJd: Pk~UDI{C)I BAY ]ool ]vpe: M~CI0 No 99491 Company: I'IIIII/P5 AIASIqA ~ool Size: 2 3/4" Country: USA No. of I:inge~s: 40 ___ ~ubu~ .......... 7 ir~s ~jLi ppi. i4~0 B!?,S ,~,m~l,,~ed: J, I1uaon Cross section 'for Joint 6 at depth 9153,6 ft fool speed = 70 NominallD :6 184 NominaIOD 7000 r~emailfing wall mea 93 % 1-ool deviation: 20" Finge~ 20 Penell~ti(:m=0262 C/oss-SectionsI :~e I ?DS Caliper Sections Well 06-21 Sul,~ey Date: May 16, 2000 Field: PRUDIIOE BAY [ool Fype: MIC40 No 99494 Company: I¥ !il HPS Ai ASI(A [ool Size: 2 3/4" Country: USA No oi: !::insets: 40 1-80 B i ~tS Anak sed: J. Bulton i~ool speed 70 Nominal ID 6184 Nominal OD:: 7000 I~emainin~ wall a!ea, 93 % [ool deviation ;, 20 I HGt~ SiDE Choss-Sections PH? 2 PDS Caliper Sections Well: 06..2 / Sulvex D~te: May / 6, 2000 Field: P~UDIIOE BA~ Tool l~pe: MFC40 No 99494 Compare,: Pltll LIP'_~ Al ASI(A Tool Size; 2 /4" Country: LSA No oi Fineness: 40 -- 1-80 Bi[;~S An~ti~secl: ] I~u~ton Cross section for joint 6 at depth 9153,7'I ft iool speed: 70 NomiHal ID == 6 i84 Nominal OD 7000 I<emainin~ wail a~ea 92 iool deviation ~!1 / / / Fin~,el 27 Piojeclion :: -0102 Ins CI MHN[ SI tIATi tiNG PDi ;ALIPER JOINTTALLY SHEE-I Pipe: 7 ins 29 ppf L-80 BTRS Wall thickness. Body: 0.408ins Upset = 0.408ins Nominal ID: 6.184 ins Joint Depth Length Measured Type No. ID feet feet inches 1 8955.97 34.82 6.215 2 8990.79 39.11 6.220 3 9029.90 39.29 6.215 4 9069.19 37.67 6.218 5 9106.86 39.67 6.197 6 9146.53 38.37 6.194 7 9184.90 unknown 6.187 Well: 06-21 Field: PRUDHOE BAY Company: PHILLIPS ALASKA Country: USA Date: May 16, 2000 Joint Depth Length Measured Type No. ID feet feet inches -- RECEIVED ~,~Y 26 200O Alaska Oil & Gas Cons. Com.~ission Anchorage Joint Tally page 1 STATE OF ALASKA ~'" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 74 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM (asp's 686026, 5941066) 06-21 , At top of productive interval 9. Permit number / approval number 5249' FNL, 2379' FEL, Sec. 02, T10N, R14E, UM (asp's 684617, 5940595) 182-127 At effective depth 10. APl number 50-029-20802 At total depth 11. Field / Pool 4' FNL, 2465' FEL, Sec. 11, T1 ON, R14E, UM (asp's 684532, 5940559) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9452 feet Plugs (measured) Tagged PBTD @ 9217' MD on 4/15/2000. true vertical 9196 feet Effective depth: measured 9217 feet Junk(measured) ORIGINAL true vertical 8964 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2436' 13-3/8" 2259 Sx Fondu & 400 Sx PFC 2510' 2410' Production 8768' 9-5/8" 500 sx G & 50 bbls Class C 8842' 8596' Liner 901' 7" 275 Sx Class G 9420' 9164' Perforation depth: measured 9210' - 9216'; 9220' - 9226'; 9235' - 9245'; 9250' - 9290'; 9304' - 9314'. true vertical 8957' - 8963'; 8967' - 8973'; 8982' - 8992'; 8997' - 9036'; 9050' - 9060'. Tubing (size, grade, and measured depth 5-1/2", 17#, L-80 PCT @ 8457' MD; 4-1/2", 12.6#, N-80 PCT @ 8923' MD; 3-1/2" PCT @ 8957' MD. i Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER FHL PACKER @ 8448' MD; 7" X 3-1/2" BAKER FB-1 PACKER @ 8930' MD. 5-1/2" CAMCO BAL-O SSSV NIPPLE. @ 2172' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: June 1,2000 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best o! my knowledge. Questions? Call Stephen Ward @ 265-1305. Signed ~~ "~,~ Title: Coil Tubing Drilling Supervisor Date ~'~ ~'/~)40 Lam~r L. Gantt PreDated by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity ~ BOP Test ~ Location clearance --I ,~ ~ (~) -- 1 ~' ? Mechanical Integrity Test__ Subsequent form required 10- J{Z3"~, Approved by order of the Commission D '~:~~iOr~o~s~3~'' ' iii:: i:i)i'~ Commissioner Date ~..~"~(:;~-~'"~ · Form 10-403 Rev 06/15/88 · /.~,Dprove(~ uop,J Returneci SUBMIT IN TRIPLICATE DS 6-21 Intended P&A Procedure Objective: P&A existing interval and if scheduling permits, mill window in 7" casing in preparation for CT sidetracking operations. Intended Procedure · RU slickline unit, tag bottom. · RU CT. Pump 20 bbls Class 'G', 17 ppg cement. · Clean cement top to -8940' md (KOP for CTU drilling at 9000') · WOC, Tag top of cement. If scheduling permits, mill 2.8" window in 7" casing at 9000' md with service unit. May 18, 2000 DS 6-,., A PROPOSED CT TWIN SID,.. I'RACK 5-1/2" Production Tubing SSSV @ 2172' 5-1/2" Camco MMIG GLM's Baker FHL Packer @ 8448' 9-5/8" Casing to 8842' Baker FB-1 Packer @ 8930' 3-1/2" Camco Nipple@ 8939' 3-1/2" TT @ 8958' 7" Liner & Perfs P&A'd with 17 ppg Cement 4-1/2" Production Tubing from 8457' - 8923' Top of 7" Liner @ 8519' Top of 2-3/8" Liner @ +/- 8800' Straddle Perfs 8920 - 8922' Top of P&A Cement @ TT Mill Window in 7" Casing @ 9000 - 9005'. 2-3/8" FL4S 4.6# Liner Cemented j~ & Perforated 3" Open hole TD @ ~ 9454' 7" Shoe @ 9420' ARCO ALASKA, INC. SSSVNIP Tubing-PC Casing Gas Lift MandrelNalve 3 SLS PBR PKR XO Tubing-PC STR Perf XO Tubing-PC Liner PKR (3-1/2" Camco No-Go i..N..PP!P) ............................................................. ./ NOGO ------; TTL SOSUB ISO Perf ...} ......................... Perf .-..--' ? __ ...... Perf __ Perf .....~i __ Perf ...... -- -- Prudhoe Bay APl: 500292080200 Orig Compltn: 9/15/82 SSSV Type: Last W/O: 9/14/82 06-21 Angle @ TD: 10 deg @ 9452 Rev Reason: Drift/w dummy gun; PERFS by ImO Last Update: 11/26/99 Annular Fluid: Diesel/9.6 NaCI Ref Log Date: 9/6/82 Reference Log: BHCS RKB: 74 ft Last Tag: 9258 TD: 9420 ftKB Last Tag Date: 6/13/99 Max Hole 23 deg @ 5900 Angle: Well Type: PROD Angle @ TS: 11 deg @ 8945 :. pppthiAnho~tations :. :: Depth Comment 8939 8939' Min ID=2.813" (3-1/2" Camco No-Go Nipple) Date Note FHL/TIW HBBP pkrs have reduced test pressure limits in some cases. Contact ACE (x5102) prior to pressure testing. Date Note 9/15/82 TTL ELM @ 8956: ELM Tubing Tail (Logged 04/28/83) :'~hei;:(~lUgS, ~qui~ etc~) ~ J~ELRY Depth TVD Type Description 2172 2172 SSSVNIP 5-1/2" Camco BAL-O SSSV Nipple. 8406 8167 SLS 5-1/2" Camco Sliding Sleeve 8434 8195 PBR 5-1/2" Baker PBR Assembly 8448 8209 PKR 9-5/8" x 5-1/2" Baker FHL Packer 8457 8217 XO Crossover 5-1/2" x 4-1/2" 8923 8676 XO Crossover 4-1/2" x 3-1/2" 8930 8683 PKR 7" x 3-1/2" Baker FB-1 Packer 8939 8691 NOGO 3-1/2" Camco No-Go Nipple 8957 8709 TTL 3-1/2" Tubing Tail 8958 8710 SOSUB 3-1/2" Camco Shearout Sub Btm 8457 8923 8957 Size Weight Grade Top 7.000 29.00 L-80 8519 9.625 47.00 L-80 0 13.375 72.00 L-80 0 :;Tubi~ Strihg~ ~ A!i Size Weight Grade Top 5.500 17.00 L-80 0 4.500 12.60 N-80 8457 3.500 0.00 8923 :G~si~iff Ma~dre!S/Valves Stn MD TVD Man Man V Mfr VType Btm 9420 8842 2510 ID 4.562 0.000 0.000 0.000 4.500 3.500 0.000 2.813 0.000 0.000 Mfr Type 1 2908 2908 CAMCO MMIC CAMCO R20 2 4781 4755 CAMCO MMIC HES DMY 3 6186 6054 CAMCO MMIC CAMCO OV 4 7127 6934 CAMCO MMIC HES DMY 5 7631 7414 CAMCO MMIC CAMCO DMY 6 7706 7486 CAMCO MMIC HES DMY 7 8020 7789 CAMCO MMIC CAMCO DMY 8 8099 7865 CAMCO MMIC CAMCO DMY 9 8293 8056 CAMCO MMIC CAMCO DMY 10 8369 8131 CAMCO MMIC HES DMY '1. RDO 20 7/16" Orifice Feet Description 901 Liner 8842 Casing 2510 Casing Feet Description 8457 Tubing-PC 466 Tubing-PC 34 Tubing-PC Date Vlv Run Commenl 1.5 RK 0.250 1650 6/13/99 RD 1.5 RK 0.000 0 5/11/94 D-14RP 1.5 DC 0.000 0 7124199 (1) 1.5 RK 0.000 0 3~7~94 D-14R 1.5 RK 0.000 0 1/1/60 RD 0.0 RK 0.000 0 1/16/95 D-14R 1.5 RK 0.000 0 1/1/60 RD 1.5 RK 0.000 0 1/1/60 RD 1.5 RK 0.000 0 1/1/60 RD 1.5 RK 0.000 0 9/14/94 D-14RP Status FeetSPF o 2 0 o 3 2 O 2 0 O 2 2 o 5 2 5 4 O 6 2 O 10 4 10 4 O 40 4 0 38 0 O 10 4 V OD Latch Port TRO Comment Date Type 9/20/82 IPERF 9/4/93 APERF 9/20/82 IPERF 9/4/93 RPERF 9/4/93 APERF 12/5/99 RPERF 3/18/93 APERF 3118/93 APERF 11/26/99 APERF 5/1/83 APERF 5/3/87 RPERF 2/22/92 APERF Comment Interval TVD Zone 8920 - 8922 8673 - 8675 9212 - 9215 8959 - 8962 ZONE 3 9215 - 9217 8962 - 8964 ZONE 3 9215 - 9217 8962 - 8964 ZONE 3 9217 - 9222 8964 - 8969 ZONE 3 9220 - 9225 8967 - 8972 ZONE 3 9222 - 9228 8969 - 8975 ZONE 3 9235 - 9245 8982 - 8992 ZONE 3,ZONE 2 9235 - 9245 8982 - 8992 ZONE 3,ZONE 2 9250 - 9290 8997 - 9036 ZONE 2 9250 - 9288 8997 - 9034 ZONE 2 9304 - 9314 9050 - 9060 ZONE 2 Interval Date Type 8920-8922 9/25/82 STR 9160-9235 6/18/99 ISO g210-9236 8/16/99 SQZ 9215-9217 9/25/82 SQZ 5 4 2 COILED TUBI, NI~ UNIT BOP E~U l PI, lENT I.5000 PSI '7" WELLHEAD CONNEClOR FLANGE ~.5000 PSI 4 1/1B" PiPE RAMS 5. 5000 PSI 4 1/6" HYD~LK~ SLIPS ~1.5000 PSI 4 1/~" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS B. 5000 PSI 4 1,/16" STUFFING BOX 2 ; HIREL]NE BOP EOUIPMENI* 1. 5000 PSI ?" WELLHEAD CONNECIOR IrLANC, 2. 5000 PSI WlRELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICAIOR , 4. 5000 PSI 4 1/E" FLOW TUBE PACK-OFF I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 28' FSL, 2379' FEL, Sec. 02, T10N, R14E, UM At effective depth At total depth 4' FNL, 2465' FEL, Sec. 11, T10N, R14E, UM 5. Type of Well: Development X Explorato~__ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-21 9. Permit number / approval number 82-127 10. APl number 50-029-20802 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2436' Production 8768' Liner 901' Perforation depth: 9452 feet Plugs (measured) 9196 feet 9217 feet Junk (measured) UR arms @ 9236' MD. 8964 feet Size Cemented Measured Depth 20" 19oo# Poleset 80' 13-3/8" 2259 Sx Fondu & 400 Sx PFC 2510' 9-5/8" 500 sx G & 50 bbls Class C 8842' 7" 275 Sx Class G 9420' Tagged PBTD @ 9217' MD (4/15/2000) ORIGINAL measured 9210' - 9216'; 9220' - 9226'; 9235' - 9245'; 9250' - 9290'; 9304' - 9314'. true vertical 8957' - 8963'; 8967' - 8973'; 8982' - 8992'; 8997' - 9036'; 9050' - 9060'. Tubing (size, grade, and measured depth) True vertical Depth 80' 2510' 8596' 9164' R zC;EiVED ' ,? 5 2000 Oil & Gas Cons. Commi,~ion An~or~e 5-1/2", 17#, L-80 PCT @ 8457' MD; 4-1/2", 12.6#, N-80 PCT @ 8923' MD; 3-1/2", 0#, , PCT @ 8957' MD. Packers & SSSV (type & measured depth) 7" x 3-1/2" BAKER FB-1 PACKER @ 8931' MD; 9-5/8" X 5-1/2" BAKER FHL PACKER @ 8449' MD. 5-1/2" CAMCO BAL-O SSSV NIPPLE. @ 2173' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and finaI pressure 14. OiI-Bbl Prior to well operation 0 Subsequent to operation 180 Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 672 917 810 632 Casing Pressure Tubing Pressure 217 224 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '"~ ~ c/~/~'~ Title Arco Engineering Supervisor Signed Erin Ob~ ~~ ~ ' Date Z./_ ,2. L//_ Z 00~) Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICA~~~ 06-21 DESCRIPTION OF WORK COMPLETED PERFORATION OPERATIONS Dat_=_~e Event Summa 4/15/2000: RU ELU. PT'd equip to 3000 psi. RIH w/perf guns & shot 6' of Add perforations @: 9210' - 9216' MD (Zone 3) Reference Log: BHCS 9/6/1982. Used 2-1/8" carriers and all shots @ 6 SPF, Iow side orientation, balanced press, & 0° phasing. POOH w/guns. ASF. RD. Returned well to production & obtained representative well test data. Additional work options are currently being evaluated. 2 5 2000 Anch0r~.e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate _ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development~X RKB 74 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM 06-21 At top of productive interval 9. Permit number / approval number 28' FSL, 2379' FEL, Sec. 02, T10N, R14E, UM 82-127 At effective depth 10. APl number 50-029-20802 At total depth 11. Field / Pool 4' FNL, 2465' FEL, Sec. 11, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 9452 feet Plugs (measured) Tagged PBTD @ 9252' MD (2/05/2000) true vertical 9196 feet Effective depth: measured 9252 feet Junk (measured) UR arms @ 9236' MD. true vertical 8999 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2436' 13-3/8" 2259 Sx Fondu & 400 Sx PFC 2510' 2510' Production 8768' 9-5/8" 500 Sx G & 50 bbls Class C 8842' 8596' Liner 901' 7" 275 sx C~ass G 9420' 9164' Perforation depth: measured 9220' - 9226'; 9235'-9245'; 9250'-9290'; 9304'-9314'. 0~/G/ /I ' / ...... true vertical 8967' - 8973'; 8982' - 8992'; 8997' - 9036'; 9050' - 9060'. ... Tubing (size; grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8457' MD; 4-1/2", 12.6#, N-80 PCT @ 8923' MD; 3-1/2% 0#,, PCT @ 8957' MD. " [ECEIVED Packers & SSSV (type & measured depth) 7" X 3-1/2" BAKER FB-1 PACKER @ 8931' MD; 9-5/8" X 5-1/2" BAKER FHL PACKER @ 844 5-1/2" CAMCO BAL-O SSSV NIPPLE. @ 2173' MD. 13. Stimulation or cement squeeze summary ' ~ !:i · , Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ~l~l 0il & Gas COns. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 25 1083 764 - 220 Subsequent to operation 54 1013 936 - 232 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil .__X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~(,~ 'i~, ~ Title Arco Engineering Supervisor Date /o Erin Oba Prepared by Paul Rau. f 263-,4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-21 DESCRIPTION OF WORK COMPLETED PERFORATION OPERATIONS Date Event Summary 2/05/2000: 2/8/2000: RIH & tagged PBTD @ 9252' ELM. RU ELU. PT'd equip to 3000 psi. RIH w/perf guns & shot 6' of Reperforations @: 9220' - 9226' MD (Zone 3) Reference Log: BHCS 9/6/1982. Used 2-1/8" carriers and all shots @ 6 SPF, random orientation, balanced press, & 0° phasing. POOH w/guns. ASF. RD. Returned well to production & obtained representative well test data. Additional work options are currently being evaluated to initiate flow. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate _ Pull tubing _ Alter casing _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development_X Exploratory__ Stratigraphic_ Service__ 4. Location of well at surface 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 28' FSL, 2379' FEL, Sec. 02, T10N, R14E, UM At effective depth At total depth 4' FNL, 2465' FEL, Sec. 11, T10N, R14E, UM 12. Present well condition summar Total depth: measured true vertical 9452 feet Plugs (measured) 9196 feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 2436' Production 8768' Liner 901' Plugging _ Per/orate _X Repair well _ Other_ 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-21 9. Permit number / approval number 82-127 10. APl number 50-029-20802 11. Field / Pool Prudhoe Bay Oil Pool Tagged PBTD @ 9252' MD (11/24/1999) 9252 feet Junk (measured) UR arms @ 9236' MD. 8999 feet Size Cemented Measured Depth True vertical Depth 20" 19oo# Poleset 80' 80' 13-3/8" 2259 sx Fondu & 400 Sx PFC 2510' 2510' 9-5/8" 500 Sx G & 50 bbls Class C 8842' 8596' 7" 275 Sx C~ass G 9420' 9164' Perforation depth: measured 9220' - 9226'; 9235' - 9245'; 9250' - 9290'; 9304' - 9314'. true vertical 8967' - 8973'; 8982' - 8992'; 8997' - 9036'; 9050' - 9060'. Tubing (size, grade, and measured depth) RECEIVED Naska Oil & Gas Cons. Commissi0~ Anchorage 5-1/2", 17#, L-80 PCT ~ 8457' MD; 4-1/2", 12.6~, N-80 PCT ~ 8923' MD; 3-1/2", 0~, , PCT ~ 8957' MD. Packers & SSSV (type & measured depth) 7" X 3-1/2" BAKER FB-1 PACKER @ 8931' MD; 9-5/8" X 5-1/2" BAKER FHL PACKER @ 8449' MD. 5-1/2" CAMCO BAL-O SSSV NIPPLE. @ 2173' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final Pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 0 Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl 964 723 25 1083 764 Casing Pressure Tubing Pressure 198 22O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~ ~ Title Arco Engineering Supervisor Erin Oba ' Date ! - I~- 7_.OOO Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-21 DESCRIPTION OF WORK COMPLETED PERFORATION OPERATIONS Date Event Summary 11/24/1999: 12/5/1999: RIH & tagged PBTD @ 9252 ELM. RU ELU. RIH w/perf guns & shot 6' of Reperforations @: 9220' - 9226' MD (Zone 3) Reference Log: BHCS 9/6/1982. Used 2-1/2" carriers and all shots @ 4 SPF, random orientation, & 60° phasing. POOH w/ guns. ASF. RD. Returned well to production & obtained representative well test data. RECEIVED JAN 2 2000 Nas~ 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X (resqueeze) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 74 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM 06-21 At top of productive interval 9. Permit number / approval number 28' FSL, 2379' FEL, Sec. 02, T10N, R14E, UM 82-127 At effective depth 10. APl number 50-029-20802 At total depth 11. Field / Pool 4' FNL, 2465' FEL, Sec. 11, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 9452 feet Plugs (measured) Tagged PBTD @ 9252' MD (11/24/1999) true vertical 9196 feet Effective depth: measured 9252 feet Junk (measured) UR arms @ 9236' MD. true vertical 8999 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2436' 13-3/8" 2259 Sx Fondu & 400 Sx PFC 2510' 2510' Production 8768' 9-5/8" 500 Sx G & 50 bbls Class C 8842' 8596' Liner 901' 7" 275 Sx Class G 9420' 9164' Perforation depth: measured 9235' - 9245'; 9250' - 9290'; 9304' - 9314'. ~,,- , .qS, C true vertical 8982' - 8992'; 8997' - 9036'; 9050' - 9060'. ~aska Oil a i~as Cons. "',~ ' -~, Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8457' MD; 4-1/2", 12.6#, N-80 PCT @ 8923' MD; 3-1/2", 0#,, PCT @ 8957' MD. Packers & SSSV (type & measured depth) 7" X 3-1/2" BAKER FB-1 PACKER @ 8931' MD; 9-5/8" X 5-1/2" BAKER FHL PACKER @ 8449' MD. 5-1/2" CAMCO BAL-O SSSV NIPPLE. @ 2173' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) 0RIGINAL Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation 0 964 723 198 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ....(,~'~'~/sI~ /~.~..,.,~ Title Arco Engineering Supervisor Date /l~ ~J'~r ~/ Erin OMa " Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-21 DESCRIPTION OF WORK COMPLETED CEMENT RESQUEEZE FOR GSO & PERFORATION OPERATIONS Date Event Summary 8/14/1999: 8/16/1999: 8/21/1999: 8/25/1999: 10/13/1999: 11/21/1999: 11/24/1999: 11/26/1999: MITIA to 2000 psi- passed. MIRU CTU. PT'd equip to 4000 psi. Killed well. RIH w/CT & performed a FCO to 9236' ELM. Pumped 33.6 bbls of 15.6 ppg Latex Acid Resistive Cement into the open perforations listed below: 9212' - 9228' MD (Zone 3) Reference Log: BHCS 9/6/1982. Placed 10 bbls of LARC behind pipe @ a max sqz press of 2700 psi. Contaminated Cement w/Biozan & cleaned out to 9210' MD. POOH w/CT. RD. WOC. RIH &tagged TOC @ 9217' MD. MITtbg to 1000 psi - in 30 min lost 100 psi. MITIA to 2000 psi - lost 25 psi in 15 min. RIH & tagged TOC @ 9217' MD. Milled Cement to 9246'. Broke into Sand & FCO'd to 9260' (worked past UR arms @ 9240'). Left 2500' Crude cap on Top of well. RIH & tagged BTM @ 9196' SLM. RIH & FCO'd soft fill to 9249 CTM. FP'd well w/Crude. RIH & tagged PBTD @ 9252 ELM. RU ELU. PT'd BOPE/Riser to 3000 psi. RIH w/perf guns & shot 10' of Reperforations @: 9235' - 9245' MD (Zone 2B) Reference Log: BHCS 9/6/1982. Used 2" carriers and all shots @ 4 SPF, random orientation, 60°/120° phasing, & balanced pressure. POOH w/guns. ASF. RD. Returned well to production & obtained representative well test data. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 74 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM 06-21 At top of productive interval 9. Permit number / approval number 28' FSL, 2379' FEL, Sec. 02, T10N, R14E, UM 82-127 At effective depth 10. APl number 50-029-20802 At total depth 11. Field / Pool 4' FNL, 2465' FEL, Sec. 11, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 9452 feet Plugs (measured) Tagged PBTD @ 9236' MD (6/29/1999) true vertical 9196 feet Effective depth: measured 9236 feet Junk (measured) UR arms @ 9236' MD. true vertical 8983 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2436' 13-3/8" 2259 Sx Fondu & 400 Sx PFC 2510' 2510' Production 8768' 9-5/8" 5oo Sx G & 50 bbls Class C 8842' 8596' Liner 901' 7" 275 Sx C~ass G 9420' 9164' Perforation depth: measured 9212' - 9228'; 9235' - 9245'; 9250' - 9290'; 9304' - 9314'. true vertical 8959'- 8975'; 8982'- 8992'; 8997'- 9036'; 9050'- 9060'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8457' MD; 4-1/2", 12.6#, N-80 PCT @ 8923' MD; 3-1/2", 0#,, PCT @ 8957' MD. Packers & SSSV (type & measured depth) 7" X 3-1/2" BAKER FB-1 PACKER @ 8931' MD; 9-5/8" X 5-1/2" BAKER FHL PACKER @ ~sF~B~. ' ~ ~ V ~, ~ 5-1/2" CAMCO BAL-O SSSV NIPPLE. @ 2173' MD. 13. Stimulation or cement squeeze summary ~,, Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection D,l~$t~i:t u,, Oil-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1644 42193 4794 862 Subsequent to operation (shut in) 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Erin Oba ~ ~ Title Arco Engineering Supervisor Date · Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-21 DESCRIPTION OF WORK COMPLETED ACID WASH / CEMENT SQUEEZE FOR GSO Date Event Summary 6/13/1999: 6/16/1999: 6/17/1999: 6/20/1999: 6/23/1999: 6/27/1999: 6/29/1999: 7/02/1999: RIH & tagged PBTD @ 9258' MD. PT'd IA to 3000 psi- lost 60 psi in 30 min. MIRU CTU. PT'd BOPE. Killed well. RIH w/CT & tagged PBTD @ 9235' MD. Pumped gelled sand slurry containing 2300 lbs of 20/40 mesh river sand, to place an isolation sand plug across the open perforation intervals located @: 9235' - 9245' MD (Zone 3/2) Reference Log: BHCS 9/6/1982. 9250' - 9290' MD (Zone 2) 9304' - 9314' MD (Zone 2) POOH w/CT leaving an ~ TOS @ 9230' MD. Injectivity test. RD. A CTU Acid Wash / Cement Squeeze was performed for Gas Shutoff as follows: MIRU CTU & PT'd equip. Loaded well w/hot Slick Seawater. RIH & tagged TOS @ 9235' MD, then PU & reciprocated an acid wash across the open perforation intervals located @: 9212' - 9228' MD (Zone 3) Reference Log: BHCS 9/6/1982. Pumped: (a) 15 bbls of 80% Diesel - 20% Xylene @ 2.25 bpm, followed by (b) 30 bbls of 12% HCL - 10% Xylene - 3% Acetic Acid @ 2.25 bpm, followed by (c) 60 bbls of 1% KCL Water @ 2.3 bpm, followed by (d) shutdown. No real break observed. Pumped 54 bbls of 15.6 ppg Latex Acid Resistive Cement & placed 42 bbls of LARC behind pipe @ a max sqz press of 1000 psi. Contaminated Cement w/ Biozan & cleaned out to 9160' MD. POOH w/CT. RD. WOC. MITT to 2500 psi - failed. RIH & tagged TOC @ 9141' MD. RIH & UR'd to 9230' MD. Injectivity test 0.6 bpm @ 2000 psi & 0.3 bpm @ 1140 psi. POOH. Left UR arms in hole as fish. Attempted to retrieve fish (UR arms) - unsuccessful. Ran LIB. Drifted to PBTD @ 9236' MD. Fish attempt. Attempted to retrieve fish (UR arms) - unsuccessful. Additional wellwork to include a resqueeze in near future. SchhJm_berger I GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-TN' Sherrie NO. 9958 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/2/96 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 02-'24... ~c~,.-7'~/' PRODUCTION PROFILE 951127 I 1 D.S. 3-24 r~_~- /3(~ PRODUCTION PROFILE , 951126 1 - 1 D.S. 5-17A c~_ ~l' PRODUCTION PROFILE 951125 1 1 D.S. 6-16 ~) -~_~ mDT-BORAX 951 208 1 I .... D.S. 6-19 ~- I I ~] LEAK DETECTION 951 205 I 1 p.S, 6-21 ~5- PRODUCTION PROFILE 951 208 I 1 D.S. 6-22A ~ 3 - ._~ PRODUCTION PROFILE 951 128 I 1 D.S. 15-2 E~- '~7' mDT-BORAX 951 207 I 1 ,,, __ SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Drill Site: 6 Well: 21 DOME SET PRESSURE: 510 PSIG FTP @ CLOSE (PSIG): 450 PSIG K-VALVE CLASS (A,B,C): A !t lgg4 CO~4ENTS: K-valve rmdesi~n for chanqin~ w~l! ~onditions - well to b~ choked back to limit rocks and solids Droduction. CC- ENGINEERING FILE / "~~"~m~ PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SMOEMAKE PRB 20 (WITMOUT ATTACMMENTS) FS 3 DS SuD PRB 13 (COVER ONLY) DS 06 Enq ATO .15 (WITHOUT ATTACMMENTS ) STATE OF ALASKA (COVER ONLY DESIGNED BY: MMM Drill Site: 6 Well: 21 WELL TEST DATA Mon Nov 14 14:33:29 1998 CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI SEPARATOR DATE SEL TEMP PRES 40 0 454 2624 79.8 6488 1308 13016 2300 10.70 175 266 1.1/3_3/94 Y 56 0 409 2554 80.9 649~ 1234 13438 0 0.00 176 263 82 1448 416 2619 81.1 5035 1054 13874 2382 0.00 1.76 274 ].1/10/94 82 4000 368 2543 81.9 1991 644 14053 82 3996 314 2278 83.0 2181 666 i3452 82 1604 243 684 88.8 1236 400 6109 82 1673 239 470 92.7 1609 375 6~76 90 0 329 3218 77.4 6559 1478 14273 90 0 328 3179 77.8 6195 1371 14360 85 4006 648 1423 80.8 2196 957 7448 0 0.00 177 237 11!08i94 0 0.00 180 247 1~!06/94 0 0.00 169 237 13./0~/94 0 0.00 169 23~ 11/01/94 0 0.00 175 298 10/14/9~ 0 0.00 176 297 10/13/94 0 0.00 t71 273 10/07/94 ESC=EXIT; Fi=~ELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=C~ECKL!ST; F10=ACCEPT~ SF8=RESTORE WELL TEST; CFg=CYCLE DATA; SSSV DEPTH (MEAS): 2172 FTP @ CLOSE (P~I~): 450 PRESS ADJUSTMENT: ~ TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF' USES BM TEMP AND WELL PI WPS C= ..07217e-2 N= 1.000000 NEW C= ..82360e-2 ENTERED N= 1.000000 Drill site: ~ Well: 21 K-VALVE DESIGN Mon May 30 20:37:14 1994 DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS ( A, B, C ): 245 PSIG @ 60 DEG F 255 PSIG A COMMENTS: K-valve is designed to dump in situ when. tested. Well will have to be choked to operate under normal conditions. CC: ENGINEERING FILE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.c. SMART / S.C. SHOEMAKE PRB 2O (WITHOUT ATTACHMENTS ) FS 3 DS Supervisor ( COVER ONLY ) L.A. Boughton ATO 1569 (WITHOUT ATTACHMENTS) STATE OF ALASKA. (COVER ONLY) DESIGNED BY: A.W. Brooks ~ ARCO Alaska, Inc. Date- Subject- Fro m/Locat ion: Telephone: To/Location: August 3, 1994 ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 265-6547 Distribution P.O. Box 100360, ,.,.,chorage, AK Transmittal #: 94068 99510,d~ ~' Well Log DateI Tool Type i Contractor Number (M-D-Y) 01-03 7-4-94 Leak Det 1 SCH 03-12 7-2-94 Inj Pmf I SCH 03-19 7-7-94 Prod Prof 1 SCH 03-25A [ 7-7-94 l Perf Record I SCH 04-02 i 7-3-94 Leak Det I SCH *04-07 ST1 7-8-94 Perf Record 1 SCH 05-01 7-9-94 Tubin9 Cutter 1 SCH 05-11 7-9-94 Perf Record I SCH 06-11 7-2-94 Dual Burst TDT-P I SCH 06-21 7-1-94 Prod Prof I SCH 06-22A 7-4-94 Perf Record 1 SCH 07-02 7-4-94 Prod Log I SCH 09-31A 7-8-94 GR/Collar 1 SCH 09-32 7-7-94 Dual Burst TDT-P I SCH 15-01 7-2-94 Prod Pmf I SCH 16-02 7-5-94 Inj Prof 1 SCH 16-10 7-6-94 Inj Prof 1 SCH ~¢~, _ 16-24 7-3-94 I PerfRecord 1 SCH [ 17-07 7-5-94 Leak Det I SCH *The correct APl number for 04-07 ST1 is 50-029-20189-00. Number of Records: 19 Kafla Zuspan Distribution- Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil by signing and returning ~Z~o..pY'~'~tr...ans~:~t~ ARCO Alaska, Inc. Is a Subsidiary of AlJantJcRIchfleldCompany STATE OF ALASKA _ ALASKA _AND GAS CONSERVATION CO IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 467' FSL, 960' FEL, SEC. 2, T10N, R14E, UM At top of productive interval 28' FSL, 2379' FEL, SEC. 2, T10N, R14E, UM At effective depth 3' FNL, 2453' FEL, SEC. 11, T10N, R14E, UM At total depth 4' FNL, 2466' FEL, SEC. 11, T10N, R14 E, UM 12. Present well condition summary Total depth: measured true vertical REEEIVED JUL 6. Datum of elevation(DF or KB) 74' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-21 9. Permit number/approval number 82-127 10. APl number 50 - 029-20802 11. Field/Pool Alaska 0ii & t~as C-_,,.-.=. "!~mm188'0nPrudhoe Bay Oil Pool Anchoraao ~o. ed 9452 feet Plugs(me,,o,,r ) Fill Tagged @ 9283' MD (7-1-94) 9196 feet feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 2437' Production 8768' Liner 901' 9283 feet 9029 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 1900 # Polset 80' 80 13-3/8" 2259 sx Fondu & 400 sx PFC 2511' 2511' 9-5/8" 500 sx Class G; 50 bbl Class C 8842' 8577' 7" 275 sx Class G 9420' 9164' Perforation depth: measured 9212-9228';9235-9245';9250-9290'; 9304-9314' true vertical 8959-8975'; 8982-8992'; 8997-9036'; 9050-9060' ORIGINAL Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, PCT @ 8457' MD; 4-1/2", 12.6#, N-80, PCT @ 8923' MD; 3-1/2", 9.2#, N-80, PCT @ 8957' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 8448' MD; 5-1/2", Camco BaI-O SSSV @ 2172' MD Baker FB-1 packer @ 8930' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 184 219 2012 351 ~'' 219 2136 Tubing Pressure 248 228 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X_~ Gas ...__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '~~'~ ~Rev 06/15/88 FormlSigned0.404 Title Engineering Supervisor 143/10 ce: JED_ JWP Date 7//~J/~'~ SUBMIT IN DUPLICATE ~ 6-21 DESCRIPTION OF WORK COMPLETED ROPE TREATMENT & FULLBORE ACID STIMULATION 2/24/94: MIRU CTU & PT equipment. RIH w/CT & pumped gelled Sand Slurry, containing a total of 1750 lbs of sand, to place a sand plug across the lower perforation intervals located at: 9250 - 9290' MD (Z2) Ref. Log: BHCS 9/6/82. 9304 - 9314' MD (Z2) Made final top of sandplug tag at 9255' MD. POOH w/CT. Rigged down. 3/1 I/94: RIH & set a Shear Disk in the tubing at 8377' MD, in preparation for a ROPE treatment. 3/14/94: MIRU & PT equipment. Pumped Meth Water w/0.5# XCD & pressured up on the Shear Disk to perform a ROPE Treatment of the perforations located above the sand plug (above) at: 9212 - 9228' MD (Z3) Ref. Log: BHCS 9/6/82. 9235 - 9245' MD (Z2/3) Shear disk ruptured at 5731 psi w/99 bbls of Meth Water pumped. Rigged down. 3/15/94: RIH & retrieved the ruptured Shear Disk. Rigged down. 3/19/94 - 4/2/94: Made multiple bailer runs & dumped additional sand to raise the top of the sand plug (above) in preparation for a Fracture Treatment, followed by a CT fill cleanout to remove excess sand, followed by bailer dumps to add sand & adjust the final top of the sand plug to 9250' MD. 4/3/94: A Fullbore Acid Stimulation Treatment for migrated fines removal was performed as follows: MIRU CT & PT equipment. Treated the open perforations located above the sand plug (above). Pumped: a) 50 bbls 1% NH4CI Water, followed by b) 24 bbls Xylene @ 1.6 bpm, followed by c) 50 bbls 12% HCI @ 1.4 bpm, followed by d) 47 bbls 9% HCl - 1% HF @ 1.8 bpm, followed by e) 50 bbls 12% HCl @ 1.0 - 1.7 bpm, followed by f) 300 bbls 1% NH4Cl Water Overflush w/5% Musol @ 2.0 - 7.5 bpm , followed by g) 177 bbls 1% NH4Cl Water displacement, followed by h) Shutdown. RECEIVED Flowed well back immediately to plant. Rigged down. 7/1/94: RIH & tagged top of bottom sandplug / fill at 9283' MD. JUL 1 8 1994 Aiaska Oil & Gas Cons. Commission Anchorau~ Returned well to production w/gaslift & obtained a valid production test. STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION CC_ .,VllSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing .~- Alter casing ...--, 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 467' FSL, 960' FEL, SEC. 2, T10N, R14E, UM At top of productive interval 28' FSL, 2379' FEL, SEC. 2, T10N, R14E, UM At effective depth 3' FNL, 2453' FEL, SEC. 11, T10N, R14E, UM At total depth 4' FNL, 2466' FEL, SEC.11, T10N. R14E, UM 12. Present well condition summary Total depth: measured true vertical 9452 feet 9196 feet Plugging Repair well 5. Type of Well Exploral~f ~ Stra~raphi~ ..--.. Pedorate X~ Plugs(measured) 6. Datum of elevation(DF or KB) 74' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-21 9. Permit number/approval number 82-127 10. APl number 50 - 029-20802 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 9334 feet true vertical 9080 feet Junk(measured) Casing Length Size Conductor 80' 20" Sudace 2511' 13-3/8" Production 8842' 9-5/8" Liner 901' 7" Cemented 1900# Poleset 2259sx Fondu & 400 sx PFC 500 sx Class G; 50 bbl Class C 275 sx Class G Measured depth True vertical depth 80' 80' 2511' 2511' 8842' 8577' 9420' 9164' Perforation depth: measured 9212-9222'; 9222-9228'; 9235-9245'; 9250-9290'; 9304-9314' true vertical 8959-8969'; 8969-8975'; 8982-8992'; 8997-9036'; 9050-9060' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, PCT @ 8457" MD; 4-1/2", 12.64t, N-80, PCT @ 8923' MD; 3-1/2", 9.2#, N-80, PCT @8957.' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 8448' MD; 5-1/2', Camco Bal-0 SSSV @ 2172' MD Baker FB-1 packer @ 8930' MD I'~ !~/"' r" I t I r' I"% 13. Stimulation or cement squeeze summary I\ L ~ L I V L !.~ Intervals treated(measured) N/A DEC 1 5 1995 14. Treatment description including volumes used and final pressure Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Prior to well operation 200 ~~400 2500 220 / 300 2200 16. Status of well classification as: Subsequent to operation 15. Attachments Copies of Logs and Surveys run _.. Daily Report of Well Operations X .. ,~ska uii & Gas Cons. Commission Casing Pressure Tubing Pressure --- 250 250 Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed / Form 10404 Rev 06/15/88 / 'F~le Sr. Operations Engineer , / Date SUBMIT IN DUPLICATE '"~ WELL 6-21 AD-PERFORATING SUMMARY for 09/04/93 . . . MIRU ELU and pressure tested lubricator. Perforated Zone 3 interval 9212-9222' MD at 2 spf ref. SWS BHCS 9/6/82. RD ELU and returned well to production. RECEIVED DEC 1 3 1995 Alaska u~l & Gas Cons. Commission Anchorage ARCO ~.!,~k,; Inc. P.O.Box I(X),.'.'.'.'.'.'.'.~ Anchor~fe, Alaska 99510 DATE: 10-8-93 ?7- 57 1-11 8-29-93 ~-?_~L~_L_2-6 8-29-93 ~ ~_~?_~W_L~2-12 8-29-93 _?__~~_~_~ ,4-14~ 9-7-93 ?e~ ~_~4 - 15 9-7-93 ~a~Z, 4-29 9-3-93 qwlq% 4-42 9-8-93 ?.~- g~ .~- 1 9-3-93 ~- ~_~_r_~6-17 9-4-93 E_~~:~I 9-4-93 I 9-10-93 -22A c['5- 57 ~-22A 8-38.31-931-93 v~-4~-7-8 9-2-93 ~ ** 9-9 9-10-93 ~?-~ t 11-25 8-29-93 gT'ko711-28 9-5-93 ?~ _-~:::~ _13-1 9-12-93 ~3-q[ _14-24 8-30-93 ~_~.~_,15-18 9-10-93 ~t~15-30 9-3-93 ~__~ ! 6-7 9-5-93 q~.-?5 16-31 9-7-93 ..~72.~__17-2 1 9-4-93 Prod Profile/~,ss~c~¢l~,> Run 1, 5" I~t0~~ch Prod Proflle/~l%~a~es~ Run 1, 5" Prod Profile (~I~I~?;~RR~~ 5" ~ ~Sch mj ome a 5" ~q~Sch ~j ~offie & S~c]~'o)'~ ~ B~t T~P R - ' 5" ~q~- Sch mj ome a Stati t~Sch Perf Record Perf Record ~-~ Productiong~ ~ I~l ~e~e USIT (Cement) Color USIT (Corrosion) Color Dual Burst TDTP Prod Prod IBP ~,qex~%o Run Leak Detectff~J~ Rl~n PerfRecord t~z~$-~5~zz Run GR/CCL (TCP ~e-~) R~ ~ ~/~ml~~/~ R~ Pe~ Record %~a~o R~ RECEIVED BY_~~ '~ Have A Nice Dayl Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL R-_n 1, 5" Sch Run 1, 5" Sch Run 1, l"&5" e~ schq~5 R.n 1, 5''~ tz~SchlCa~q Run 1, 5,,lzag-/msq Sch Rim 1, 5" ~~-- Schqq~ R!an 1, 5'~ Sch I~o-~5~ R~ 1, 5" ~e-~ Sch ~5 R~ 1, 5" Sch 2, 5" Sch 1, 2" t ~0- ~ Sch 1, 5" Sch 1, 5" ~'--Atlast~za° 1, l"&5" ~- Sch ~et 55 1, 1"&5" Sch 1, 5" Sch the attached copy as receipt of data. .%_ Trans# 93 !09 4,~ Co,,, o # BPX # STATE OF ALASKA The correct top logged interval for this log is 12,900 feet. The correct top logged interval for this log is 10,400 feet. Drill Site: 6 Well: 21 Sun Aug 29 09:13:32 1993 K-VALVE DESIGN CHECKLIST RECENT WELL TEST DATA IS ACCURATE AND SMAKEOUT DATA CONFIRMS WATERCUT ? y SUBJECT WELL IS PRODUCING INTO THE HIGH OR LOW PRESSURE COMMONLINE ? PAST 7 DAY AVERAGE COMMONLINE PRESSURE: -:~ AND LOW PRESSURE: SUBJECT WELL'S PAST 7 DAY AVERAGE SURFACE FLOWING TUBING PRESSURE: PAST 7 DAY LOW FTP: ~~~ REASON: clp y IS THE FTP SWINGING OR SPIKING ? y HOW MUCH ? 5 DOES THE FTP vs CML PRESSURE INDICATE A CHOKE RESTRICTION OR UNDERSIZE ? n .. CURRENT CHOKE SETTING IS AT CFR OR HIGH LIMIT (WIDE OPEN) SUBJECT WELL IS GAS LIFTED ? y GAS LIFT OPERATING SMOOTHLY ? y Printing contents of current screen - wait for message to clear Drill Site: 6 Well: 21 Sun Aug 29 09:17:16 1993 K-VALVE DESIGN DOME SET PRESSURE: 130 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 150 PSIG K-VALVE CLASS (A,B,C): B COMMENTS' · Valve designed to dump at 150 because current valve may not close until less than 130· Estimated pressure when flowing to tank is 120 so that's too close· ~ K-valve designed to ducat 165 had history of closing CC: cooper/shelden/~ (WITH ATTACH~IE~S ) J.C. SMART / M.G. SHOEMAKE (WITHOUT ATTACHMENTS ) J.E. FAUSETT / C.W. SHUMWAY PRB 20 PRB 13 L.A. Boughton ATO-1551 (WITHOUT ATTACHMENTS ) STATE OF ALASKA (COVER ONLY) DESIGNED BY :~t~ ~ Printing contmntm of current mcreen - wait for memmage to clear ARCO ,~l~_s~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 04--22-93 REFERENCE: 3-13-93 Production Log 3-15-93 Production Log 3-14-93 Spin/Temp/Gradlo/Press 3-14-93 CBT 3-14-93 USIT (Cement & Corrosion) 3-1693 Perf Record 3-12-93 Peri' Record 3-18-93 Perf Record 3-18-93 Peri Record 3-13-93 GR 3-14-93 T~,htng Cut Record 3-12-93 Production Log 3-15-93 Leak Detect 3-19-93 Production Log 3-17-93 Tie-In GR/CCL 3-17-93 Inj Prof/Spin/Temp/Press 3-17-93 Production Log 3-20-93 PITS 3-16-93 Production Log 3-11-93 Peri Record 3-12-93 Press/Temp Color Color ~nl, ~' Sch Rim 1, [~' Sch l~_m 1, ~, Sch Run 1, [~' Sch Run 1, ~' Sch Run 1, [~' Sch Run 1, ~' Sch Run 1, ~' Sch Run 1, ~' Sch Run 1, ~' Sch Run 1, Z'&~' Sch Rim 1, ~' Sch Run 1, [~' · Sch Run 1, 2~'&~' Sch Run 1, [~' Sch l~m 1, ~' Sch Run 1, ~' Sch l~_m 1, [~' Sch Run 1, ~' Sch llqm 1, ~' Sch Run 1, ~' Sch Run 1, ~' Sch Please sign and return the attached copy as receipt of data. RECEIVED BY_~_~_~~ Have A Nice Day! Sonya Wallace A P P R 0 V i D__~_~ ATO-1529 Trans# 93048 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL ~ # BPX # STATE OF ALASKA * The correct APl# for 1-5ST is 50-029-20076-00. .-- STATE OF ALASKA ___ ALASKA _ AND GAS CONSERVATION CC ]ISSION REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Other //~')~'~f ] 6. Datum of elevation(DF or KB) '~. 74' RKB 7. Unit or Property Prudhoe Bay Unit Pull tubing ~ Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic X, 4. LocatiOn of well at surface 467' FSL, 960' FEL, SEC. 2, T10N, R14E, UM RE( EIVED At top of productive interval 28' FSL, 2379' FEE, SEC. 2, T10N, R14E, ua ,~P~ At effective depth 3' FNL, 2453' FEL, SEC. 11 T1 ON, R14E, UM Alaska .0il & 6as Cons. c0mmiSs~0~ ' ~ch0rage At total depth 4' FNL, 2466' FEL, SEC.11, T10N. R14E, UM 8. Well number 6-21 9. Permit number/approval number 82-127 10. APl number 50 - 029-20802 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9452 feet 9196 feet Plugs(measured) none Effective depth: measured 9379 feet true vertical 9124 feet Junk(measured) 9350' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1900# Poleset 80' 80' Sudace 2511' 13-3/8" 2259sx Fondu & 400 sx PFC 2511' 2511' Production 8842' 9-5/8" 500 sx Class G; 50 bbl Class C 8842' 8577' Liner 901' 7" 275 sx Class G 9420' 9164' Perforation depth: measured 9222-9228', 9235-9245', 9250-9290', 9304-9314' true vertical 8969-8975', 8982-8992', 8997-9036', 9050'-9060' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, PCT @ 8457" MD; 4-1/2", 12.6~, N-80, PCT @ 8923' MD; 3-1/2", 9.2#, N-80, PCT @8957" MD Packers and SSSV (type and measured depth) Baker FHL packer @ 8448' MD; 5-1/2", Camco Bal-0 SSSV @ 2172' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 315 4322 1853 1802 573~ 2788 3136 1646 Tubing Pressure 233 222 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas ~. Suspended Service 17. I hereby certify that the fore/~ng is true and correct to the best of my knowledge. Signed ~'~~ ~- ~,~~ Title Sr. Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL 6-21 ADD-PERFORATING SUMMARY for 3/18/93 1. MIRU ELU and pressure tested lubricator. 2, Perforated zone 3/2 intervals 9222-9228' MD at 2 spf, and 9235-9245' MD at 4 spf ref. SWS BHCS 9/6/82. 3. RD ELU and returned well to production. RE: 'E VED APR 2 7' 19B,S Alaska Oil & Gas Cons. CommissioJ~ Anchorage Drill Site: 6 ~e!!: 2! Fri Mar 05 07:55:27 1993 K-VALVE DESIaN DOME SET PRESSURE FTP @ CLOSE (PSIa): K-VALVE CI~%SS (A,B,C) 120 PSIa @ 60 DEa F 127 PSIa COMMENTS: K-valve must be bench tested. It should close at current water .cut and lift .gas rates. The design will work if PI doubles and/or if lift gas rates vary by over 50%. CC: ENaINEERINa FIL COORDINATOR PRB 24 (-WITH ATTACHMENTS ) J.C. SMART / M.a. SHO~-/~%KE PRB 20 (WITHOUT ATTACHMENTS) J.E. FAUSETT / C.W. SHUMWAY PRB 13 (covER ONLY) , R.J. REINTS ATO 1560 (.WITHOUT ATTACHMENTS ) STATE OF AI~%SKA (COVER ONLY) DESIaNED BY: A.W. Brooks STATE OF ALASKA .._ ALASKA _ AND GAS CONSERVATION C( .,IlSSIOi0 R I re ! [' ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Plugging Perforate X Pull tubing Alter casing Repair well ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 467' FSL, 960' FEL, SEC. 2, T10N, R14E, UM At top of productive interval 28' FSL, 2379' FEL, SEC. 2, T10N, R14E, UM At effective depth 3' FNL, 2453' FEL, SEC. 11, T10N, R14E, UM At total depth 4' FNL, 2466' FEL, SEC.11, T10N. R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-21 9. Permit number/approval number sz-~z7 10. APl number 50 - 029-20802 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9452 feet true vertical 9196 feet Effective depth: measured 9379 feet true vertical 9124 feet Casing Length Size Conductor 80' 20" Sudace 2511' 13-3/8" Production 8842' 9-5/8" Liner 901' 7" Plugs(measured) none Junk(measured) 9350' Cemented 1900# Poleset 2259sx Fondu & 400 sx PFC 500 sx Class G; 50 bbl Class C 275 sx Class G Measured depth True vedicaldepth 80' 80' 2511' 2511' 8842' 8577' 9420' 9164' Perforation depth: measured 9250'-9290', 9304'-9314' true vertical 8997-9036', 9050'-9060' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, PCT @ 8457" MD; 4-1/2", 12.6#, N-80, PCT @ 8923' MD; 3-1/2", 9.2#, N-80, PCT @8957" MD Packers and SSSV (type and measured depth)Baker FHL packer @ 8448' MD; 5-1/2", Carr~ ~a~)~l~(~ ;~4j72' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation )~AY 1 § t992 Alaska 0il & Gas Cons. Commission Anch0ra_ae Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1400 4385 1900 -- 235 Subsequent to operation 1150' 4000 1700 -- 225 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregO~, is true and correct to the best of my knowledge. Signed ~ (~' ~,,~'~/~"~~ Title Sr. Operations Engineer Date SUBMIT IN DUPLICATE WELL 6-21 Zone 2B PERFORATING COMPLETED 2/22/92 1. Rigged up E-line unit and pressure tested lubricator. 2. RIH with perforating guns and tied in to Reference Log. o Perforated the Zone 2B interval 9304-9314' (Ref. B HCS 9/6/82) at 4 SPF. 4. RD ELU and returned well to production. * A decrease in oil rate was noted between pre- and post-perf tests. This is not believed to be associated with the above perforating. RECEIVED MAY 1 5 1992 Alaska Oil & 6as Cons. Commission Anchorago /0 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS ?~ 3-8 2-25-92 Collar R~!n 1, 5" HI~ ?I-~'~ 3-35 2-21-92 CCL/Perl Run 1, 5" HLS ?/-~ ~ 4-3 2-9-92 Perf Record Run 1, 5" HI~ 4-3 3-2-92 Perf Record Run 1, 5" HLS ?'/"- ~? 4-7ST 3-2-92 Perf Record Run 1, 5" HI~ ?~-~ ~ 5-14 2-11-92 Perf Record Run 1, 5" HLS ~z ? 6-21 2-22-92 CCL/Per~ R~_m 1, 5" HI~ ~°-/~? 9-43 2-12-92 Perf Run 1, 5" HLS ~/-t?z~. 11-3A 2-23-92 CCL/Perf Run 1, 5" HLS 3~/zz~ 14-32 2-28-92 Perf Record Run 1, 5" HI~ ~/- -~/F/17-11 2-28-92 Perf Record Run 1, 5" Please sign and return the attached copy as receipt of data.~ ~ C ~ ~ ~ 0 RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 APPROVED~ Trans# 9208~ # CENTRAL FH~S # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct APl# for 11-3A is 50-029-20666-01. ARCO A!._ska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS >~ ~ 6-21 / 11-4-91 CNTD Run 1 Job#75329 } ~ I ~ ~ 14-35 w 7-28-91 DSN Run 1 Job#L66751-3 ~/~l 15-15 ~/ 7-22-91 DSN Run 1 Job#L66619-3 Please sign and return the attached copy as receipt of data. RECEIVED BY ~___~ Have A Nice Day! Sonya Wallace AT0-1529 Sch HLS HIS APPROVED Trans# 9201~-~ .... # CENTRAL FILES (CH) CHE~ON D&M DEDE SCHWARTZ (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO RECEIVED FEB 0 3 1992 Alaska 011 & (hs Cons. Commission Anchorage ARCO ALASKA 'F'.O. BOX ANCHORAGE, ALASKA DATE: ti-22.9i 995t0 RECEIVED NOV 2 b 1991 Alaska Oil & Gas ConS. Commission - Anchorage REFERENCE: ARCO CASED HOLE FINALS -i5-9t -t7-9i -t 7-9i -t G-gt -4-9t 6-2i ,/ tt-4-9t 9-28 ./'- i t-5-9t 9-33 i2-4~~. ii i4-9i /i 3-98 / .t ,:3-24-9 ~ e).~.~Ji 3-98 ~t 0-24-9i kt 3-98 F'ERF RECORD RUN i, 5" $CH CBT (COLOR) RUN i, 5" $CH ULTRASONIC IMAGER-U$IT (COLOR) RUN t, 5' $CF! PFC RUN' i, 5' ATLAS CNL-GR/CCL _ RUN t, 51 ATLAS CNL-GR - RUN i, 51 $CH COLLAR-F'ERF RUN t, 5' ATLAS COLLAR-PERK RUN t, 5" ATLAS COLLAR-F'ERF RUN i, 5' ATLAS COLLAR-PERK RUN t, 5' ATLAS F'ERF RECORD RUN i, 5" SCH DIT-E RUN 37, 5' SCH CNL -- EPITHERMAL RUN 37, 5" $CH CNL - THERMAL . .- RUN 37, 5' $CH . " PI_EAS'E $I~N AND RETURN THE ATTACHED./COPY -AS RECEIPT OF DAI'A - .' ........... '~'.--'- ' - - ":'= ' ~ -' -.;- .2'-_ · ' · *' ~' ':::'-(:?'~':'Tk:'?~ /-'>J:;~%- .-r/. ~- ...... : ...... _ ....................... j - ._..: .~.,7~.~ ................................... ,. ...... :...~ ATO-i 529 TRANe, RECEIVE' D DISTRIBUTION · ,- _ CEN'[RAL I--II_ES ¢ F'HILLIF'.? .. -,.'"' CHEVRON F'B WEL. L. FILES D & M R & D .11. -,,. E X T E N,~ I ON. Ei X F'I_ O R A T I F)N_ -,-'"' BF'X '"' EXXON -"- · .- -~ STATE OF ALA~I<A MARAI'HON TEX AC 0 ~-'~ MOBIL · ~.~ THE CORRECT AF']:~ FOR i2--4A IS NOV 2 b 1991 Alaska 011 & Gas Cons. Commission Anchorage Drill Site: 6 Well: 21 K-VALVE DESIGN Sun Nov 17 17:42:48 1991 DOME SET PRESSURE: 170 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 165 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: K-valve designed to dump by flowing to a depressured separator with or without a/1 gas. Due to the high rate of the well it is better to bench test the valve. CC: CoP. F~_RMER / W.D. COOPER J.C. SMART / M.G. SHOEMAKE J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 K.L. MARTIN ATO 1551 STATE OF ALASKA (COVER) DESIGNED BY: W. H. Smalstig Dri!i Site: ~ >;eli: 21 K-VALVE DESIGN Jul ~2 22:15:27 1991 DOME SET PRESSURE: !35 ?SIG @ 60 DEG F FTP @ CLOSE (PSIG): '45 2SIG K-V~_LVE CLASS (A,B,C): ~ COMMENTS: does not flow w/out GL. '2onfirmed w/well nss%. CC: C.P. FARMER / W.D. COOPERC~P/~/ PRB 24 S.J. ~WYSOCKI ATO 1554 K.M. KENNEDY / W.S. WILDER PRB 20 ~sTATE 0F ~AS~ (CO.R) B.G. HARRIS / T.J. BRASSFIELD PRB 13 DESIGNED BY: A. E. Copoulos ENGINEERING WELL FILE F' ,. O~ B 0 X i (:) (') S 6 (') A N C H C R A G E:.~ A L A ,"~ K A DA i"E' 4-4-9 i F:EFEF.:ENCE ' ARCO C{qSED HOLIE FINALS ~-.:- t 9 '") .... i i - o i F' F.:O D LI C l' I 0 N i::' F;,' 0 I:: I L E '5 - 2 :5 '-' i 6 - 9 i L f=' A K D ii'] T E C T I 0 N ~'5 .... 3 i ..... i 8'" 9 i S F' I N N E R / t' I::2 i'i F' "z, 4 3 - i 7- 9 i .[ N J E. ~. I I 0 N S .... i ,::} 3 -.. i 7-.. 9 t I N J E: C T I 0 N 4- 2 6 i .... '.5 - '9 i F' I .... I ,~:" 6 .... 2i E';-6 .... 9i F'ITS Y .... t6 S .... i4-9t F'II"S '7--.. S 4 S ..... i..:':" .... c;,: t I N J E C T I [) N /i" E H F' ii-9 i .... 7....9i F'IT t i - 2 Ei i ..... i 2- 9 i F' R 0 I) U C T I 0 N I::' R 0 I:: I t.. E i 3- t 9 3- t 6-9 i I N.J E C '}" I 0 N i 3'"' 2 0 '3 ..... i '7"" c? t I N d ti:2 C l' I 0 N i L~""2:5~'.~3-i 6-9i INJECTION iS-ii 2-'i3-9t F'ERF BREAK .... I)OWN i 6 - 2 '2 - 2,5 '- 9 i S F' I N N E R / I N J r_.:' C T i 0 N i iii .... i i 3 -ILl- 9 i F' I I'S ........... . . . , ........ . . I::'I_EASE SIGN AND RETURN THE (~'I'Tt-hCHED COPY I:k lie C F.'.: I V E D B Y ...... HAVE ~q NICE ~,~.. 'T'HF CORREC 1:;: t.J N F;,' I.J N F;.'. I.J N R U N I:;.'. U i'J. I:;: U N I:;: U N I;: U N F;:LIN I:;~ I.J N R U N R U N F;: tJ N R U N. R LI H R b N RUN ........... .. . AS RECE'I'RI' OK DA F'H ILL I I::'S f:'B WELL F'ILELS R & D ~-'"'3'I"ATE OF ALASKA TEXACO ...... I"1 I:;" S C A H C 0 I"11:~: 5: C A i'i C 0 C: A i'i C 0 i..i I:;.: I I': ':." i"l l',,. ,.? C A i'i C C r:.] H C I..t R 3' !..I F;.'. 3' H I:;..' S H F;: HI';,' 3' ;' PRUDHOE BAY FIELD K-VALVE DOME-PRESSURE-SETTING DATA SHEET Drillsite-Well:l 6-21 I Comments:i. Unable to dump to depressurizecl separator. · K-valve is redesigned with a higher dome. Date:l 7/1 2/90 Previous Settings: Dome Pres. {PSIG) CloSure FTP (PSIG) Date 200 199 6/14/89 320 340 3/1 2/88 Production Data: ROR= 2000 BOPD @ CFR= 0 BOPD @ Swincj Well (very hicjh or Iow GOR)' No Oeg chOke Deg choke Choke Priority Well'No Design Rates for Hydraulics Program PH2: Test Date 6/1 7/90 Oil Rate 2080 STBO/D Watercut 37 % Formation GOR 901 SCF/STB Gas Lift Gas Rate 2219 MSCF/D Total GLR 1231 SCF/STB :lowing Tbg. Pressure 246 PSIG Flow. Wellhead Temp. 148 Deg F Choke Settin(j 74 Deg conditions at Valve: Temp. @ SSSV 1 61 Deg F Pres. @ SSSV 378 PSlG Pres. Adjustment @ SSSV 30 PSlG Notice: This adjustment is at the valve, not surface. I Calc. Dome Set Pres. 209.0 PSIG @ 60 Deg F Act~,al Dome Set pres. 21 0 PSIG (~ 60 Deg F ~ 21 0 PSIG ~ Surface B (Ap Bp or C) FTP at K-valve Closure K-valve Type cc: Ferguson / Farmer5'c'~/ Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Eng: M.M. Maguire D.S. Supv: Winters/Shumway Prep. by: M.O. Johnson ATO- 1554 PRB-13 PRB-24 .. ~ ~ i,. ,i!!i,".! 'T' {i!!i F;' ~!i ]') D,r':!i F' q" F--{ ,, t "f' ...... ~, ,: 'l"l :;;i: ]. "~,.' .:::'"" i '-':: ~ l"'lkE ~:::l:i!!; Ii) liE F::' T I'"{ :;:i'. :i. '7: ?. '4 ;: .... I ' '" I .... ":" '--q "" 'I~! ~ j t._~ .j::, c:. ~,:::. i::;, t:::' ,rz. ,:::. .................. ~ l.. ................................................. . .... ..... ~ .................................... 5 ...................................................... ! ...................................... I"'; i:':i :;;;; J:;;' J;::' j:::: j:;:' '.i:il :iiil 'j. i,::i '::" ]. ~ :'- ii. T ~iil i'q F::= J}iil F;; I:::l"J" i...i j::;; E :i. % :i. i~ :: a 'a .j., , .r .r, ~.... r., ..~..~ ~ '"" 'l ~ =~ i'.~ .... J..,~:::.c' ~ ~"'~ ,:::, :'.5 .i. ~ ! = iL ' ........ ~ "~ "~...- ~ '~ '" ""' ~" '~' ~. ~ L.. S F;: 2 ;;':?. :L ? ~:~:~ .....................................~ .................................................................. :2 ........................................................................................................................................... $'" ...................................... ~, = '~ t"l 'ii ::-' iSJ ::::', f::"l , ~ :: :: J....(3i:::: 5: i ~::;~:';: I ............... ~ ................................... t ...................................................................... -'"" :! ............................................................. ~ i t- q i '..' ::..: ....... ~ ~ , ~ c:' '! .... k.i~:::'l i:::' :'. F:' ]5 :::::~; ~:::~i'}.O ~::;;~:~ L. :~; ~ :..a.: i Lf')~ ~ : ' ' ' ~ ~ ~ .................... J::: ..... ~,.{ ~ 'i" ;:::' :::; ~" 0'.. i::'; ................................... ~ ........................... ¥c?:r;':c .............................. , .............................. ;~?-:i'i%- ........................... ~ ~ ."5 f:~i cq * 'i ::.. t..i i.::l ?::' ,:;{. :::;: {::;', ~::i "[' {~{~ ;:~; ,i ~"', ':: . ; ;........: ;.-.i ......... '""" .............. ' ........... "' .....: :-.... ..... '/": ~]z..:z: .... ' ii i . 1 I t:::'!.,.iF:' I i (iiii....l::;: I I ~T44, 6-21,12 07-12-90 2040 WELL TE3T REPORT DATE ...................................... TESTED RATE~ ................................. AU~ AV~ AUG TOTAL LIFT f'DRM TOTAL TEST TIME CHOKE SEP FTP SEP OIL WTR ~AS ~AS Z 6DR ~LR LENGTH COMP POS TEMP TEST PRES STBD BPD MSCFD MSCFD ~TR SCF/B SCF/B HOURS 06-21 06-21 06-2i 06--2! 06-17 05-17 04-.26 03-13 J,"-Zi U/.-Uo 0i"i4 01.'-05 01-03 I" 1'~ 12-0,I 1456 74 148 246 230 2080 124,-1 4092 22:[9 .'.°,7 901 1231 8.0 0911 76 144 252 235 1995 139I 3984 2148 41 920 1177 8.0 0706 71 145 242 223 1928 1491 3766+ 21:13 ,-14 8-t2 1101 6.0 0].01 70 !45 '239 220 1754 1573+ 3:341 ].752 47 792 i004 12.0 1621 85 141 23,6 221 1800 1300 S531- i'¢':E.~9 ,:t2 884- it39. o.'" 1 19il 85 140 238 221 2005 1912 4320+ 2:[98' 40 1059+ 1302 8.0 · .~.Ozl ,",oD 4":"" 2949 "38 875 1447 7.9 2016 40 ]39 292 209 i53t 35 i, 4E~ 242 224 i,.8 !295 qi:L1 2192 40 5'80 i264 8.0 1721 84 142 247 230 i966 1303 '-3858 !953 40 969 1!80 7.7 180~ 84 t41 "'~";,,o 239 ~% t.,:.~9 ?,8~8 ..11 ~95 i177 ~. 0 1,428. ,.,,% i,,1:i..,.,,.,)o9 __??0 ~,~.,.,,.'~'~ i306 7~945.. i~,4.3 39 990 ].185 7.9 F¢'~' 85 142 ,.4,.,9"" ~;¢~ .... 2057- 1319 e.'859.- ].957 39. ..°.25.-1143 8.1 ..... EXPECTED ..... FORM T T A F DRIFC OIL gOR X S V L L DIA STBD SCF/8 ~TR T P L 6 INCHES 1997 920 41 H R Y 6 4.0(} 1907 842 44 N R H ~ 3.75 1747 792 q7 E R N g 3.50 1785 885 42 E R R g 3.50 1988 1059 40 E R N 6 3.75 2013 875 38 E R R 6 3.75 1938 980 40 N R R 6 3.25 1919 995 41R R R 6 3,25 1914 995 2000 991 39 R S R ~ 3.00 2039 918 39 N R N 6 3.00 2476 1216 37 E R R O 4.00 DA'rE TIt'iE WELL SH~KE'-[IUT PERCENT PERCENT H2S PER L~C SAMPLE N~TER ~uLIDS ~ILLiON ENTERED E:Y TAKEN %.-2:L i2 I1 t0 9 5 2 05-!7-90 04.-25-90 0200 O~'-uo-~O 2000 09-23-89 2330 0,-.~I 8, 1230 0~-15..89 0710 05-05-89 0~-0~-89 0200 04-1~-89 I~0 02-i3-89I~O 42. O0 PR[1DUCTION HEADER 40. u0 6.0 PRODUCTION HEADER 42. OD ii: O0 7.0 PRODUCTION SEPARATOR ,,,..~-', riO. PRODUCTtliN HEADER i.0 PRODUCi'iLIN SEPARATOR 20.00 5.0 PRUDUi',TiON SEPARATI]R 20.00 fl_.O0 z." 0PRflDUCI'ION HEADER 5.0 PRODUCTION SJEPARATOR 15. O0 O. O0 9.0 PF,'[iDUCTII]N ~EPAi!ATllR ~. O0 O. O0 1.0 PRDDUCTiI:tN SEI"ARATDR i4.00 0.00 1.0 PRODUCTION HEADER i. O0 O. O0 6.0 PRODUCTION SEPARA'I'I]R ARCO Ai_AG~KA: INC., F'~ O~ BOX ANCI4ORAGE, AI_A~'K A 9 c' "-- DATE REFERENCE' ARCO F'RE£'$URE DATA 3--~: 9--J 3--89 BHF ....FLOWING GF;.'.ADIE. N'T' CAi'~L:O S.-J9 6-J J'-[4':;' BHF ....FI_OWiNG GRADIENT CAMCO 6--6 9-J 4-89 BI..~F .... ~"['ATIC GRADIENT CAMCO 6-14 9-7-89 BHF ....;~"FAT!C GRADIENI' CAMCO 6-2J 9-28-89 Bt"tP--FLOW ~ NG GRAD]:ENT CA~CO 9-]; i (~'-i i -89 BHF ....F-I_OWINC- GRADIENi" CAMCO 9 -- 29 9 - 23 - 89 B H P -- ~ l' A T I C G R A i) I E N T E: A H C 0 9-Sg' 9-27-89 BHF ....~TATIC GRADIENT CAHCO 9-32Z 9-3~-89 BHP--STATIE: GRADIENT CAMCO , ~- z-~"-o z BHF'--3'I'AT I C GRADIENT CAHCO '~,S-2 9-iS-89 BHF'--~;'TATIC GRADIENT CAMCO iS-ii 9'i3-89 BHP--~'I'ATiC GRADIENI' CAMCO i3-S~ 9-i3-89 BHP--S'TATIC GRADIENT CAMCO ~4-28 9-i'?-89 BHP--3~TATIC GRADIENT CAMCO t4-~8 9-2-89 R " e '- kHF--~.T~IC GRADIENT CAi'riCO i5-2i 9-S-89 BHP--~TAT!C GRADIENT CAHCO i6-2(3 i~-'4-89 BHF ....STATIC GRADIENT CAMCO ~8-~8 7-3-89 BHP--~TAT!C GRADIENT CAMCO i 8-2i 7-3-89 BI-tF'--S'TATiC GRADIENT CAMCO F'LEA~E ~IGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY! 'DALLY klOFFECKER ATO-i_,-~29 ,JAN - 8 !~0 APPF:O~ED r~ ..... Oil & Gas 1'R A N :. 9 (.) e,3, 4 DISTRIBUTION CENTRAL FILES' ~ F'FI l LL l F'5' CHEVRON F'B WELL.' F]:L.E,.'"; ~ D & M ~ R & D EXTEN.S"I ON EXPLORATION .$ BPX ~ EXXON ¢- ~.'rATE OF ALA~,"KA MARATHON ¢ TEXACO '"' M 0 B I L ARC. O ALASKA, INC~ P~O~ BOX iOOS60. ANCHORAGE, ALASKA 995i 0 DATE' · t O-i 7-89 REFERENCE: ARCO CASED HOLE FINALY i-5 t O-i i-89 COLLAR/F'ERF RLJN t , 3-2 i 0-i,S-89 PDK-t O0 RUN i , 3-28 i ~-i S-89 F'DK-i~ RUN i , ~4-S i0-6-89 GR/CCL A PERF RECORD RUN i, ~6-iS 9-27-89 F'RODUCI'ION F:'ROF'IL.E RUN i , 6-2i 9-28-89 PRODUCTION F'ROFILE RUN i, 9-i7 9'-29-89 INJECTION PROFILE RUN i , 9-26 i ~-i 4-89 F'DK-i ~0 RIJN i , ~i i -i 8 i ~-i S-89 COLLAR/PERF RUN i, t 4-i t ~-8-89 COLLAR/PERF RUN t , i4-i6 o"~ ~/89 LEAl< DETECTION RUN i i4-2i 9-~-89 INJECTION PROFILE RUN t , iT-iO 9-"S0-89 INJECI'ION PROFILE RUN t , t 7-i ~ i ~-~-89 COLLAR/PERF RUN i , i 7-i ~ t 0-~-89 COLLAR RUN i , i 8-9 9-29-89 PITS RUN t , PI_EA2E 2!6N AND RETUR RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0--i529 N THE ATTACHED COPY AS RECEIPI' OF' DAl"A Oil & Gas Cons. Comm'tssto; , ~ Anchorage 'r R A N,S ~. 8 9 ~ ~'~',~- 5." 5" .5" .5" '"5 ' 5' 5" i' 5' 5" 5" ATL. A~,' ATI_A.? A "F L.A ~' SCH C A i'-'i C 0 CAMCO C A M C 0 A 'i"l. A ~ Ai"I_AS CAMCO CAMCO CAMCO Ai't_A~ CAMCt] DISTRIBUTION CENTRAL FILES ¢ F'H ILLIF'$ CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION ~ BPX EXXON ¢ STATE OF ALASKA MARATHON ~ TEXACO MOBIL ARCO ALASKA, INC. F'.O. BOX ieO;~60 ANCHORAGE, ALASKA 995ie DATE' 9-27-89 REFERENCE: ARCO CASED HOLE FINALS 2-24 9-t 8-89 COLLAR/F'ERF 5-2 9- t 5-89 COLLAR/PERF" 4-t 9-7-.89 NOISE 5--t t '7-8'-89 SPINNER SURVEY 6-2i 9-t 4-89 CNL-GAMMA 7-2'7 7-26>-89 PERF RECORD ii-i8 7-24-89 F'ERF RE:C'ORD i t - t '2 7-27.5-89 F'ERF RECORD ti.-t7 9/ti--t:2/89 COI_LAR/F'ERF i 2-t S 9-i 7-89 COLLAR/PERF i 4-Si 9-i i-89 COLLAR/PERF ~ RUN i, 5" RtJN t , 5' RUN t, t" RUN t, 5" RUN t, 5" RtJN i , 5" RUN t , 5' RUN i , 5' RUN i, 5' RUN t , 5' RUN I , 5' PLEASE SIGN AND RETURN THE- ATTACHED COF'Y AS RECEIPT OF DATA. Al'LAS,' Al'LAS *,S' C H HLS A [LAS HLS I-tL..S H L ;.~; ATLAS AI'I_A,S' A'T'LAS SALLY Ft]F FEuKER A T O- t 5 29 COilS. OOml"61~,~ 'FRANS :~ 89 Anchorag~ DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXF'LORATION EXXON MARATHON MOBIL .,,.PHILLIPS F'B WELL FILES R & D " BF'X ~ $'T'A'I'E OF ALASKA If , TEXACO ARCO AL. AS;K A P.,C), BOX i ANCHORAC;E, ALASKA 99'.5 DATE: 9-'27-'89 R Iii: F:' Iii: R E: N C E: A R C: 0 t'1A C,; N E T I C': T A PIE ( ;~' ) W I '1" I"1 L.. 315,"T' ]: N C; ( ,5: ) 6'-",2 t 9 .... t 4'-89 C~'4L_ ( ::~ I::'A;:~J.~]; ) ,JOB:,"::sg".:'4 F:' L Iii: A .? Ei: ,!':? I ti- N A N ][) R E:'i" U R N T I'-t IE A T "t" A C I"1 Iii: D C 0 F:' Y A ~i; R E.;. C E: .'1: F:' "f' 0 F:' I) A 'f' ~':',, F:..'tii; C: IE ]: V E D B Y ii;(:i:'i' ..................... D I"tA V Ii!: A N ]; C':lii; . . ... ' :~..,-i~ ~ '~ ........... ~ Anchorage .01 ~"f' R ]: BUT ]: ON · ,-'"' C.. E N 't' R A 1._ F ;[ !... E,.,t." ( C H ) .,.'"' !::' I"1 :[ !_ L ]; F:' S C: Hli'" V R 0 N F:' B W E I... I... f:' ]: I... F,i:,S' D & id F;: & D 'f' A i"i btA.'!;' BR O Ldi'J., ~', C)l"t .~. .,.'"' .~':~ F:"x'.. '"' IE '~' '"' 0 N :~ " · ,- .... ;.~ T'A TIF O1=' A L A 5,' K A M A i::,' A "f' H 0 N T E; X A C 0 MOB]:L. PRUDHOE BAY FIELD K-VALVE DOME SE'l-rING PRESSURE DATA SHEET Drillsite-Well- 6-21 Date: 6/1 4/89 Comments: Last valve was pulled since it caused premature closure. Otis found the valve had a leak. This new design incorporates the latest design criteria for AL wells that will flow without AL. Previous K-valve Settings: Production Data: ROR = 2900 CFR = Swing Well (very high or Iow GOR) ........... Design Parameters' Design parameters are based on ,v,a,,, one of these) xxx Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. 2901 24 833 1747 1096 274 146 Set Pressure~ psig 320 340 230 BOPD @ deg. choke BOPD @ deg. choke Ne Choke Priority Well .................. Date 3/12/88 10/22/87 5/29/87 Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program... BOPD percent scf/stbo mscfpd scf/stbl psig deg. F xxx PH2 PH3 xxx PRUDHYD Other Temp. @ SSSV ............. 1 61 deg. F Pressure @ SSSV ....... 404 psig Pressure Adjustment 75 psig Calculated Dome Set Pressure -- 196.0 . psig @ 60 deg. F IActual Dome Set Press. FTP at K-valve Closure 200 199 When the well is not on AL, the K valve is expected to close at 128 FTP. psig @.60 deg. F I psig @_ surface I cc: Sennett/Farmer Wilder/Kennedy (2 copies) State of Alaska cc: D.S. Engnr. M. M. Maquire ATO 1554 D.S. Supvsr. Winters/Melton PRB13 Prepared by: M. O. Johnson AR:CO A~A~.~KA: TNC,. I)ATE: CAMf":f'l f'l T ]' :,:: fi: A M f":f"l f'l 'I'.T .% ' f'l T '1' :.;' I:;.'. F:' I': I:.i 1; ~! F:.'. I) P, Y ...................................................................................... I-'IAV.F. A NTC. I~' T':,AY! I::' I::' ('; f; Y Fl [:' N N I:!; T T A T C! .... t !~ ::! c? A t::' I::' F;.'. f') V I:' T) .............. :. .. 17:, T .?'T' I:;.' 1' F;! IT T f'l 6as cons. Commission Anchorage ~ ~:.--2 J J ~ .... 2 '? ...-~!>, '7M A (:; 'T'A P !:!: :,",: 7 2'!~.'20 C N T D ---1.4 -.. :5 t ~ f .... 2'.::-...,'.:i7 t4(.:;f:'T'AF'I::':~I:'7:;~'.5?.7~ CNI. b.J/l..l....J. F:' I... I!:: A .? E .? ]: f'; N A 1',7 ~') I:;..' Ii:' TI !!:' N Ir' 1.-!1::' A T T (::, f':: H E' I) f':: (') F:' Y f.:,.? I:i' I!:' {': E 71' F:' T ['! F:' I) A 'T A .. ( 2 ) r': ........ F' N T R A I I:: ]: I... I::: ,..:'" {::: H L.':: ¥ I? {::1N ( ~. ) l:'., I'J [.'. F' F! ['!: l!:: T F' R E X )<'. C! ~'"~ H ~-'.', K' ~-:'~ 'T' H (] N Hr)E; I !... Commission Anehomge [11::' l) ~q'T' (4., ~RCO Alaska, Inc ..... '' Prudhoe Ba., Jngineering Post Office ]~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager Oune 1, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re' DS 6-12 DS 6-21 Approval No. 7-307 Approval No. 7-306 Enclosed are the "Subsequent" Sundry Notices and Well Completion Reports detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/sd Enclosures CC' Standard Alaska Production Company File: P1(DS6-12)W1-3 PI(DS6-21)WI-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O~c. AND GAS CONSERVATION CO~v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-127 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20802 4. Location of well at surface 9. Unit or Lease Name 467' FSL, 960' FEL, Sec. 2, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 28' FSL, 2379' FEL, Sec. 2, T10N, R14E, UM 6-21 At Total Depth 11. Field and Pool 4' FNL, 2466' FEL, Sec. 11, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 74' RKBI ADL 28311 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/27/82 09/05/82 09/28/82 N/A feet MSL 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+l-VD)! 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9452'MD, 9196'TVD 9379'MD, 9124'TVD YES ~ NO [] nipple @ 2171feet MDI 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR, Cal, RFT/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91,5~ H-40 Surf. 80 ' 30" 1900~ Poleset 13-3/8" 72,0~A L-80 Surf. 2511' 17~" 2259 sx Fondu & 400 s~ PFC 9-5/8" 47,0~A L-80 Surf, 8842' 12~" 500 sx Class "G" & 50 bbls Class C 7,, 29.0~ L-80 8519' 9420' 8~,' 275 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) 5~ 8457 8457' & 4~; 3~ 8924.8957 9250' - 9290' (8997-9036')TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Ref: BHCS 9/6/82 92~5-9217 75 .~× C.~.~ 899D-Rqg~ ~DO .~w C, l n~ .,, 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 6/83I Flowing DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE GAS-OIL RATIO 5/17/81 5,3 TEST PERIOD I~ 962 799 4] ~,c~ 83~ Flow Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 345 __ 24-HOUR RATE 4358 3620 186 26 · 7 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submil in duplicate 29. GEOLOGIC MARKEt'S NAME Top Sadlerochit HOT O/W Contact Base Sadlerochit MEAS. DEPTH -[RUE VERT. DEPTH 8945 ' ,. 9314 ' 9349' Not reached 30. FORMAl IOIXl Inclucte inlerval lested, pressure (MI~:. ~11 iiu~(],.i ,i;c(~'~e~e(! ;]n(I !lr,iv~Iy, GO[~. and lime of each phase. 31 LIST OF ATTACHMENTS 8697' 9060' 9094 ' 32. ! hereby certify that the foregoing is true and correct to the best o~' my know!edge Signed ~~~~~ 'F,tie. 0per._._E~gr. Mgr. 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 measure~(;~ts given in other spaces on this form and in any attachments. item 16 and 24: If tills well is completed for separate production from more than one interval (~nultif~l~ completion), so state in item 16, and in item 24 show tine producing intervals for only the interval reporled in item 27. Submit a separate form for each additional interval to be separately i.)roduced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or ortner elevation (DF, KB, etc.). item 23' Attached supplemental records for this wel should show the details of any multiple stage lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Wat(;r I~ jection, Gas Injection, Shut-in, Other-explain. item 28: If no cores taken, indicate "none' Form 10-407 STATE OF ALASKA ALAS. , OIL AND GAS CONSERVATION COM,,,,$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other I~ Reperforation 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 467' FSL, 960' FEL, Sec. 2, TION, R14E, UM At top of productive interval 28' FSL, 2379' FEL, Sec. 2, TION, R14E, UM At effective depth 3' FNL, 2453', FEL, Sec. 11, TION, R14E, UM At total depth 4' FNL, 2466' FEL, Sec. 11, TION, R14E, UM 5. Datum elevation (DF or KB) 74' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well nu~bser6_21 8. Approval number 7-306 9. APl number 5O-- 029-20802 10. Pool Prudhoe Bay 0i1 Pool 11. Present well condition summary Total depth: measured true vertical 9452 feet 9196 feet Plugs (measured) Effective depth: measured 9379 feet true vertical 9124 feet Junk(measured) Casing Length Size 6onductor 80' 20" Surface 2511' 13-3/8" Producti on 8842' 9-5/8" Liner 901' 7" Perforation depth: measured 9250' - 9290' true vertical 8997' Tubing (size, grade and measured depth) - 9036' Cemented Measured depth 1900# Poleset 2259 sx Fondu & 400 sx PFC 500 sx Class G & 50 bbls Class C 275 sx Class G 9420' ~ue Vertical depth 80' 80' 2511' 2511' 8842' 8577' 9164' -'" 12 6# N-80 @ 8924' 5½" 17# L-80 @ 8457' 3½" 9 2# N-80 tailpipe @ 8957' 2 , · ~ , , ' ' ' ' Packers and SSSV (type and measured depth) Baker FB-1 Isolation Packer @ 8930', Baker FHL Packer @ 8457', Camco Bm]-0 @ 2172' 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 4138 2888 120 -- 329 4358 3620 186 -- 345 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~_] 15.' hereby certify that the foregoing is true and correct to the best of my knowledge ~ ¢- ~ ~'~ Signed /¢'/'¢'j'~~ Title0perations Engineering Manager Date ~/'/~. Form 10-404 Rev. 12-1-85 f SKAD~ - 263-4244 Submit in Dupli.cate Began re-perforating operation on 5/4/87. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 9265-9290'MD, (4 spf). Flowed well to cleanup, POOH, all shots fired. RIH w/gun #2, shot interval 9250-9265'MD, (4 spf). Flowed well to cleanup, POOH, all shots fired. Secured well. R.D. Ref BHCS' 9/6/82 ARCO ALaska, Inc F'.O. Box Anchorage, ALaska DATE: May t9, ~987 REFERENCE: ARCO Cased HoLe Final t-t4 5-9-87 CH CNL Run 2, 5" $ch t-~6 5-t8-87 CH CNL Run 3, 5" $ch &-2 5-te-87 CH CNL Run 5, 5' $ch 6-8 5-it-87 CH CNL Run 6, 5" $ch 6-2e 5-1i-87 CH CNL Run 2, 5" £ch 6-2i 5-4-87 Perf. Record Run i, 5' $ch PLease sign and re~urn ~he a~ached copy as receip'~ of data. Received By HAVE A NICE DAY! Rosanne Peek AT0-t529 TRAN$ ~87255 Approved ~,~,,~'s',<a Oil & Gas Cons. Commission Anchoraua 131.3TRi 8l,t'l' t ON -,. Celq~:raL Fi Les · .-'"' Chevron D & M ~."" Ex'~ension ExpLoration ~ Exxon Plata 'I'h on '"' Mob i L · '"-,- Phi llips F'B Well Fi les R & D ~- $ohio -t. .State.cf .Alaska ~ Texaco STATE OF ALASKA ALASKa-, OIL AND GAS CONSERVATION COMM.,.,SION APPLICATION FOR SUNDRY APPROVALS feet 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing © Amend order ~ Perforate~r 2. Name of Operator ARCO Alaska, Inc, 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 467' FSL, 960' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 28' FSL, 2379' FEL, Sec. 2, T10N, R14E, UM At effective depth 3' FNL, 2453', FEL, Sec. 11, T10N, R14E, UM At total depth 4' FNL, 2466' FEL, Sec. 11, T10N, R14E, UM 5. Datum elevation (DF or KB) 74' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 6-21 8. Permit number 82-127 9. APInumber 5O-- 029-20802 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 9452 feet Plugs (measured) 9196 feet Junk (measured) measured 9379 feet true vertical 9124 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2511' 13-3/8" 2259 sx Fondu & 400 sx PFC 2511' 2511' Production 8842' 9-5/8" 500 sx Class G & 8842' 8577' 50 bbls Class C 275 sx Class G Liner 901' 7" 9420' 9164' Perforation depth: measured 9250' - 9290' true vertical 8997' - 9036' Tubing (size, grade and measured depth) 4½", 12.6#, N-80 @ 8923', 5½", 17#, L-80 @ 8457', 3½" 9.2#, N-80 tailpipe @ 8957' Packers and SSSV (type and measured depth) Baker FB-1 [solation Packer @ 8930', Baker FHL Packer @ 8457', Camco Bal-0 @ 2172' 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of approver Mi ke Mi nder Date approved 4/30/87 15. I hereby,~ertify that. the foregoing is true and correct to the best of my knowledge Signed drc~~W~ Title Operations Erl g ineerirlg Manager Date ¢'/~/Z¢~7 Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity ~ BOP Test ~ Location clearance Approved by Commissioner Approval No. "~ ,"-~t~) b by order of the commission Date Form 10-403 Rev 12-1-85 SAD (263-4244) Submit in triplicate D.S. 6-21 PROPOSED REPERFORATIONS ARCO Alaska, Inc. proposes to reperforate within the Sadlerochit interval in well 6-21. The proposed perforation intervals are as follows' Existing Perforations 9250-9290 (40') Ref- BHCS of 9/6/82 Proposed Reperforations 9250-9290' (40') 4 SPF A 5000 PSI WP wireline lubricator and BOP, tested to 4000 PSI working pressure prior to the job, will be utilized for this operation. 3 ! ! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EQU I PMENT ARCO Alaska, Inc Post Office ,..,.x 360 Anchorage. Alaska 99510 Telephone 907 277 5637 October 17, 1983 Reference: Arco Pressure Data D.S. 6-4 D.S. 6-21 9-29-83 Pressure Build-up 7-30-83 Pressure Build-up 7-30/31-83 Pressure Build-up Survey Report D.$. 6-24 9-4-83 8-7-83 D.S. 17-9 8-3-83 D.S. 17-9 8-19-83 Pressure Build-up Pressure Build-up Survey Report Pressure Build-up Pressure Build-up Camco GO Sch Run 1 SS Run 2 SS se sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 546 Chevron D & M Dallas Drilling Marathon DISTRIBUTION North Geology ~.~~Oe Bay &..:!r..-:.D '. C~roZfne ~R~O .... Inc. · ,.,.-~SKa. Post Office l~c.x 360 Anchorage. ~ka 99510 Te,¢pnone 907 277 5637 September 27, 1983 Reference' Arco Cased Hole Finals D.S. 1-]9 !-.- 7-16-83 D.S. 1-22 ~/' 8-12-83 D.S. 6-3 .... 7-27-83 D.S. 6-21 ~" 7-30-83 D.S. 14-23 8-10-83 CFS CFS CFS CFS Collar Log Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" Camco sign and return the attaehed copv as receipt of data. Kelly McFarland ATO-1429F Trans. # 540 D & M Dallas Drilling Ge t t y .qarathon DiSTrIBUTION North Geology Phillips Prudhoe Bay C&rc'ine Sohio State of Alaska ARCO Alaska, Post Offic~. ex 360 Anchorage. Alaska 99510 Teie~ho'-"~ 9P7 .2-77 5537' July 20, 1983 Reference: Arco Cased Hole Finals D.S. 6-19 4 '27-83 GR 5" DA D.S. 6-21 4-28-83 GR/CCL 5" DA D.S. 13-29 5-8-83 Sonan Run 1 2" DA * D.S. 14-6 4-21-83 Production Logging Service Run 1 5" * please note that this is a corrected log and the previous · log should be discarded. Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 437 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobi I DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroling Smith Sohio State of Alaska ARCO Alaska, Inc. Prudhoe Bay E~,~lneering Post Office Box 360 i Anchorage, Alaska 99510 ~ Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 27,'1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501~ Dear Mr. Chatterton' Re: DS 6-17 DS 6-18 DS 6-19 DS 6-20 DS 6-21 DS 6-22 DS 6-23 DS 6-24 Permit No. 82-90 Permit No. 82-99 Permit No. 82-114 Permit No. 82-124 Permit No. 82-127 Permit No. 82-131 Permit No. 82-133 Permit No. 82-147 Enclosed are the Completion Repo.rts for work done on the above-mentioned wells. Very truly yours, 13. F. $cheYe Regional [n§~neer DFS/JCD/Iw Enclosures cc' Sohio Petroleum Co. ARCO At~Iska, Inc. I~ ~ $[~h'Hd[~ry of AtlenllcRichfleldCornpar~y STATE OF ALASKA ALASKA _ ,L AND GAS CONSERVATION C~ ~MISSION WELL COMItLETION OR Ri=COMPLETION REI ORT AND LOC ___ 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-127 3. Address 8. APl Number P. 0. Box 100360, Anchoraqe, AK 99510 5o- 029-20802 4. Location of well at surface 9. Unit or Lease Name 467' FSL, 960' FEL, Sec. 2, T10N, R14E, UM Prudhoe Bay Unit 'At Top Producing Interval 10. Well Number 28' FSL, 2379' FEL, Sec. 2, T10N, R14E, UN 6-21 At Total Depth 1 1. Field and Pool 4' FNL, 2466' FEL, Sec. ll, T10N, R14E, UN Prudhoe Bay Field ,5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 74'I ADL 283ll · Aband. J 15. Water Depth, if offshore 16. No. of Completions 12. Date Spudded 13 DateT.D. Reached 14. Date Comp.,Susp. or 08/27/82 09/05/82 09/28/82J N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9452'MD,9196'TVD 9379'MD,9124'TVD YES)~/( NO[]] nipple@2171feetMD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, RFT/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" 1900# Pole_set 13-3/8" 72.0# L-80 Surf 2511' 17-1/2" 2259 sx Fondu & 400 sx Permafrost fl. 9-5/8" 47.0# L-80 Surf 8842' 12-1/4" 500 sx Class G & .~.3 hhlR Fi. la~ Fi. 7" 29.0# L-80 8519' 9420' 8-1/2" 275 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) 9250-9290 MD 4 spf 4-1/2"/5-1/;" F~9R7' R457' & 8930' 8923-8962 TVDSS (isolation jacker set @ 8c~30') Ref' BHCS 9/6/82 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9215' -921 7' 75 sx Class 6 ~ 8920'-8922' 200 sx Class G 27· PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/2/83I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCr WATER-DEL CHOKE SIZE IGAS-OILRATIO 5/21/83 12.5 TEST PERIOD I~ 231:'4 1251 26 68I .680 Flow Tubing Casing Pressure CALCULATED , OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press.261 N/A 24-HouR RATE J~ 3964 2696 0 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit HOT O/W Contact Base Sadlerochi GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 31. LIST OF ATTACHMENTS 8697' 9060' 9094' 30. FORMATION TESTS Include interval lested, pressure (fala, all flub(is ~(.~cnve~e(t an(t qravi~y, GOR,and time ot each phase. 8945' 9314' 9349' Not Reached N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge _~)..~_~~ _~_~. _~_~,~,_.~ Regional Signed Title Engi neer INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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" ARCO Alaska, Inc. Prudhoe Bay L..~ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 6-17 DS 6-18 DS 6-19 DS 6-20 DS 6-21 DS 6-22 DS 6-23 DS 6-24 Permit No. 82-90 Permit No. 82-99 permit No. 82-114 Permit No. 82-124 Permit No. 82-127 Permit No. 82-131 Permit No. 82-133 Permit No. 82-147 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F..ScheVe DFS/JCD/lmi Attachments cc: Sohio Petroleum RECEIVED J!J l'l J. 5 1,q:73 ARCO Alaska, Inc, I~ a Subsidiary of AflantlcRichfleldCompany STATE OF ALASKA '-' ALASKA OIL AND GAS CONSERVATION C~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 467' FSL, 960' FEL, Sec. 2, T1 ON, R14E, UM (Surf) 28' FSL, 2379' FEL, Sec. 2, TION, R1.4E, UM (Top Prod) 41 FNL, 2466I 5. Elevation in feet (indicate KB, DF, etc.) __ 74' RKR FEL, Sec. 11: TION: R14E; UM (TD) I6. Lease Designation and Serial No. ADL 28311 7. Permit No. 82-127 8. APl Number 50- 029-20802 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 6-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stim u lat ion Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 4/28/83. RU perforating unit, pressure tested surface equipment. RIH w/ GR-CC1 tool--run log for tie-in. POOH. RIH w/ gun #1. Gun stuck in hole--pull out of rope socket. RD unit, RU slickline unit to fish gun. Recover gun--RD slickline unit, RU perforating unit. RIH w/ gun #1, shot 9270-~290' MD, 4 SPF. POOH. Flowed to/FS3 for cleanup, monitored rate and took shakeouts. RIH w/ gun #2, shot 92/50-9270' MD, 4 SPF. POOH. Perforating complete 5/2/83. All depths referenced to BHCS 9/6/83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Regi onal Engineer RECEIVED d U N 1. 5 !983 Alaska 0it & Signed D_~"~ ~"~~ ~ ~-~-~ The space below for Commission ~ ~ Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date .................... Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post ©ffice B~,~ 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 11, 1983 Reference: Arco Pressure Data D.S. 1-4~/ 4-10-83 D.S. 6-20-'~ 4-27-83 D.S. 6-21 ~' 5-4-83 · D.S. 6-22~ 4-29-83 D.So 6-24j 5-1-83 D.S 11-2~/' 4-23-83 4-23-83 D.S. 11-6/4-22-83 ~4~-22-83 D.S. 13-12 * ~-6-83 ~3-30-83 D.S. 13-22 ~3-20-83 D.S. 13-26~ 4-10-83 4-10-83 D.S. 15-1/ 3-25-83 f'3-25-83 D.S. 15-2/ 3-26-83 /3-26-83 (CONTINUED) NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON Pressure Build-up GO Pressure Build-up Survey Report Static Survey GO Static Survey Otis Static Survey GO Static Survey GO Pressure Build-up GO Pressure Build-up Survey Report Pressure Build-up GO Pressure Build-up Survey Report Pressure Build-Up DA Pressure Build-up Survey Report Fall-Off Pressure Survye DA Pressure Build=up Otis Pressure Build-up Survey Report Pressure Build-up GO Pressure ~uild-up Survey Report Pressure Build-up Camco Pressure Build-up Survey Report DISTRIBUTION EXXON MOB I L GETTY D&M STATE OF ALASKA DALLAS CHEVRON CAROLINE SMITH ARCO Alaska, Inc. Prudhoe Bay E~,~,.neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 19, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 6-19 D.S. 6-20 D.S. 6-21 D.S. 6-22 D.S. 6-23 D.S. 6-24 Permit No. 82-114 Permit No. 82-124 Permit No. 82-127 Permit No. 82-131 Permit No. 82-133 Permit No. 82-147 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/DHP/lmi Attachments cc: Sohio Petroleum ARCO AIn~kn, Inc. la a Subaldlary of AtlentlcRl,,hl'leldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C(JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLYE3 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-127 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20802 4. Location of Well 467' FSL, 960' FEL, Sec. 2, T10N, R14E, UM 28' FSL, 2379' FEL, Sec. 2, T10N, R14E, UM 4' FNL, 2466' FEL, Sec. 11, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 6-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the well, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: Ref: BHCS 9/6/82 9250-9290' MD 14. I hereby/e~rtify that the foregoing is true and correct to the best o(my knowledge. Signed ~J~t~,~~~Z~~), Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: O' IG!NA[ $1GI1£1'%, Approved by COMMISSIONER Approved Copy ~eturned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Anchorage, A ca 99510 Telephone 907 277 5637 March 1, 1983 Reference: Arco Open Hole Finals Replacement - D.S. 6-21 D.S. 13-98 9-6-82 1-1-83 1-1-83 1-1-83 1-1-83 1-1-83 1-1-83 1-1-83 1-1-83 FDC/CNL/GR (Poro) CPL/Cyberlook BHCS BHCS Waveforms DIn/SPA LDT/CNT/NGT (Raw) LDT/CNT/NGT (Poro) LDT/CNT/NGT Count Rates NGT Run 1 5" Sch Run 1 5" Sch Run 1 2" & 5" Run 1 5" Sch Run 1 2" & 5" Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Please sign and return the attached copy as receipt of data. Kelly McFarland AFA- 403 Trans. # 179 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY PHILLIPS D & M SOHIO STATE OF ALASKA MARATHON DALLAS CHEVRON CAROLI~~ SMITH AFCO Alaska. inc. is a Subsidiary of AtlenticRichfiei~C~;;r::.~" · Alaska. Oil & Gas [;ohs. ~;ommissior., AnchoFage ARCO Alaska, Inc. Post Office ~"x 360 Anchorage,..aska 99510 Telephone 907 277 5637 October 26, 1982 Reference' ARCO Open Hole Finals D.S. 6~22 9-27-82 FDC/CNL/GR D.S. 6-22 9-27-82 FDC/CNL/GR D.S. 6-22 9-27-82 BHCS D.S. 6-22 9-27-82 DIL/SFL D.S. 6-22 9-27-82 CPL/Cyberlook (Raw Data ) (Porosity) Run 1 5" SCH Run 1 5" SCH Run 1 2" & 5" SCH Run 1 2" & 5" SCH Run 1 5" SCH D.S. 18-7 9-29-82 DIL/SFL D.S. 18-7 9-29-82 BHCS-GR D.S. 18-7 9-'29-82 CPL/Cyberl ook D.S. 18-7 9m29-82 FDC/CNL/GR D.S. 18-7 9-29-82 FDC/CNL/GR (Raw Da ta ) Run 1 2" & 5" SCH Run 1 2" & 5" SCH Run 1 5" SCH Run 1 5" SCH Run 1 5" SCH J P/lease sign and return the atttached copy as receipt of data° Becky Benedict AFA - 403 Trans. #576 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DA~.L~S Nov~O ~ ]~ Alaska Oi! & Gas Cons. gommission Anchorage ARCO Alaska, Inc. ~ Post Office ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 18, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are completion reports and gyroscopic surveys for the following wells' DS 1-19 DS 6-21 DS 13-34 DS 18-6 Sincerely, P. A. Van Dusen District Drilling Engineer PAV/JG:sm EnClosures GRU2/L18 RE£EIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a subsidiary of AtlanticRichfieldCompany ' ' -~' : STATE OF ALASKA .... 0 I~ 16 IN .~ t ALASKA ,L AND GAS CONSERVATION Cf, ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Welt Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-127 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20802 4. Location of well at surface ~~~'~,~i"i 9. Unit or Lease Name 467' FSL, 960' FEL, Sec, 2, T10N, R14E, UN Prudhoe Bay Unit ~ VERIFIED i At Top Producing Interval~ ~ 10. Well Number 28' FSL, 2379' FEL, Sec. 2, T10N, R14E, UM Sur~.__'-:--~ 6-21 At Total Depth .~B. H.~.-J 11. Field and Pool 4' FNL, 2466' FEL, Sec. 11, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 74' RKB ADL 28311 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 08/27/82 09/05/82 09/28/82 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9452'MD,9196'TVD 9379'MD,9124'TVD YES IX1 NO [] nipple @ 217~eet MDI 1900' (approx) 22. Type Electric or Other Logs Run D I L/SP/BHCS/GR, FDC/CNL/GR/Cal, RFT/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE! ~'E~NTING RECORD AMOUNT PULLED 2U" 91.5# H-40 Surf 80' 30"~",_:~1~900~ Poleset i3-3/8" 72.0# L-80 Surf 2511' 17-1/2" 2259 sx Fondu & 400 sx Permafrost C 9-5/8" 47.0# L-80 Surf 8842' 12-1/4" 500 sx Class G & 50 bbls Class C 7" 29.0# L-80 8519' 9420' 8-1/2" 275 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) None 4-1/2"/5-1/2" 8957 ' 8457 ' & 8930' (isolation pa~;ker set Ca~ 8930'.) 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9215'-9217' 75 sx Class G 8920'-8922' 200 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ . Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~4/..:. ,?..¢ /, --..: i:,".,;~.,, ,. ,. ,~'¢,'. ,',: /;~-, . ",.,,,',./'.~ , ,. ,,.. Form 10-407 Submit in duplicate Rev. 7-1-80 6RU2/~C9 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORI NAME Include interval tested, pressure MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Sadl erochi t 8945' 8697' N/A HOT 9314 ' 9060 ' O/W Contact 9349' 9094 ' Base Sadlerochit Not Reach, d 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey--(2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge )RMATION TESTS data, all fluids recovered and gravity, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification. of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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". DS 6-21 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0100 hrs, 08/27/82. Drld 17-1/2" hole to 2515'. Ran 61 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2511'. Cmtd 13-3/8" csg w/2259 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8850'. Ran 210 jts 9-5/8" 47#/ft, L-80, BTC csg. w/shoe @ 8842'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC and cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9452' TD (09/05/82). Ran DIL/SP/BHCS/GR f/9452'-8841'. FDC/CNL/GR/Cal f/9452'-8841' & RFT/GR. Arctic packed 9-5/8" x 13-3/8" ann. Ran 23 jts 7" 29#/ft, L-80, BTC csg f/8519'-9420'. Cmtd 7" lnr w/275 sx Class G. Drld cmt to 9379' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/9376'-8400'. (poor bond) TIH & perforated 9215' -9217' & 8920' -8922' w/4 spf. TIH w/gauge ring & junk basket to 9376'-no recovery. TIH & set cmt retainer @ 9192'. TIH & tagged retainer @ 9192'-tested valve-held 1000 psi - ok. Squeezed 75 sx Class G cmt into perfs. TIH w/gauge ring w/CCL and junk basket to 8950'-no recovery. TIH w/cmt retainer & set @ 8868'. Stung into retainer & squeezed 200 sx Class G cmt. Drld cmt to 8867' & tagged retainer. Drld retainer. TIH to 9049', tagged cmt, drld cmt to 9192' & tagged retainer. Tstd upper perfs ~ ..... 8_9_2~..!__-8.922'; would not hold. Drld retainer @ 9192'. Drld cmt to 9379' PBTD. Tstd lower perfs - ok. Ran CBL/VDL f/9379'-8400'. Ran & set isolation packer on wireline to 8930'. Ran 4-1/2"/5-1/2" completion asSy w/tail @ 8957' & pkr @ 8457'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Press. up to 1000 psi on ann - ok. Press. tbg to 3000 psi & set packer. Press tbg to 3000 psi & ann to 250 psi - ok. Tstd w/2000 psi on ann & 250 psi on tbg - ok. Installed BPV. Nipple for SSSV @ 2171'. Instld tree cap & tstd to 5000 psi - ok. Put VR plug on 13-3/8" ann. Secured well & released rig @ 0200 hrs, 09/15/82. Gyroscopic survey ran 09/28/82. JG'sm 10/18/82 GRU2/DH6 Eastman Whipstock A PETROLANE REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA ~ INC o COMPANY DS 6r Well Number: 21 WELL NAME Pr~dhoe Bay. North Slope. Alaska LOCATION JOB NUMBER SURVEY BY Controlled Drilling Consultants TYPE OF SURVEY Directional Single Shot~,~ OFFICE DATE 27-Aug-82 ARCO ALASKA~ IRC, · [mS 6, WELL NOt 21 DSS .... F'RUDHOE-BAY~'-NORTH'SL-OF'E-~--AE~SKA (CDC) DSS,, 0-9440 HD,, DRILLERI DALE HENDRIX DATE RUNt 27-AUG-B2 SURVEY PROVIDED BY CONTROLLED DRILLING CONSULTANTS RECORD OF SURVEY J RAD I US'''~ OF-CURVATURE-ME THO[I ARCO ALASKA, INC. COMPUTATION PAGE' N0o 1" DS 6, WELL NOt 21 DSS (CDC) TIME DATE PRUDHOE BAY, NORTH SLOPE, ALASKA !4149150 16-SEF'-82 , TRUE HEASURED DRIFT riRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U.L A R C L 0 S U R E DOGLEI --DEPTH ANGLE DIRECTION' LENGTH ..... [IEF'TH---SECTION---:'-TVD---C-O-O-R-']I:I--I-N-A--T-E'-S--D-I-STA-NCE D-IRECTION-SEVERI' FEET. D M D M FEET FEET FEET FEET FEET FEET D H DG/1OOI ...... .0, 0 0 ......0"-0 Oo 0;'00 :. 0';0'0~:74';-00 0700 0";00' 3970. 0 0 0 0 3970. 3970.00 0.00 3896.00 0,00 0.00 4090. 5 48 S 30 0 W 120. 4089.80 4.41 4015.80 5.26 S 3.03 W " 4212, 11 0'8'44 0'W 122; ..... 4210;44 --18;'73---4136'F44~l'?g~5--S~l'3-;-73-W a352.. 13 42 S 62 0 W 140. 4347,19 46.69 4273,19 37,39 S 37,54-W O;DO .............. 0 .... 0 ........... 0,'o0 0,00 0 0 0o00 6.07 S 30 0 W 4.83 '23¥8-r--S-35'-I3-W ....... 4'55 52.99 S 45 7 W 3.34 ...... 4508. 17 6 S'66 .... O"W ....... 156; ....... 4497'757 ....... 87;55-'--~423'~57 ..... 55';55:S .... 74¥76--W 937.1'4 S-"53'-23-'W ........ 2.28 4662. 19 30 S 70 0 W 154. 4643,77 135.69 4569.77 73,66 S 119.59 W 140.45 $ 58 22 W 1.76 4755. 21 42 S 72 0 W' 93.. 4730,82 168.38 4656.82 84.31'8 150.52 W 172.52 $ 60 45 W 2.48 ...... 5242, 22 36 8-75 ........ 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DISTANCE: .............. 1555-;"39-FEET .............................. F;: E.:. C.:: OF:;~D C.)F' S 6, WIE!.._I_ I',-I(]: 2: ;[ GI"iE; ._lf"tB NO: AC, 9 :J: 2 R ':) :3 ,:-:' ::.3 - .')G T I I;!E !}A'I"!S :d_IEIHF)[E ~;~AY: N('-IF,'-FH '.F.:L.E~F'E=., AL.A'.'_:i:KA 15: 5; 1: 56 1 ! -r'u::::T--',:=.'.::? TI?UE EAS':URIEP f)RIF'T I)RIFT C:OURSE VER'['ICAL VERTIC:AL '.-];LIBSEA R E C: T A N G IJ L A R C: L. 0 '.F.: LI R E DC,S!.._Fr3 DE]F'TH ' ANE LE D ! REC:T I OF.I - LENC¢t=H ..... DEPT-H ...... SPE:q: I ON .........-TVD ....... ].f3--O-Ct-R t-..'EFFf.',,N(SE-- [) ! R_~-E.'-¥-t ON--SEVER !-T FEIE]' D I"1 D Pl F'EET FEET FEET FEET FEE'[' FEE:]' D I"1 ...... 300: 0 400, 0 ...... '.:5 0 0 ,, 0 600, () 700, 0 0 0 0 100. 100. C~c) O. O0 2."6. ('x'~ O, O0 O. O0 O. O0 0 0 O. ()() 15 S 24 0 IS lO,:1~. 200.00 -'0, 0:.']', 126. OC) 0,20 3 0.0'.:.~ E O, ;if::::.' E: 24 0 E O, :?5 1 .'=i :.-.-:: 15(] ................. 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C ().'(..;) E .................... P'I fi:_.- A S I_1R EE D 15: 52:: ,"l.'.q ~..t.......[')C'r'.-..'. r2 T R I_1 [~ :..1;; I..l ]-q ?._; E VERTIr-:AL I'!.'D-,.TVD 'v'l/ii;l::;t'TIL:A[_ R [:_-' (": T A I',.I G I..I I_ A R C .... I_-) 'iii; I...t l:'< NAHE .... DEF'TH .............. DEF'TPt ............. [..~ ! F:F ......... DEPTH ............ C: f:! r~- R-.---_D- t .... N-A -'F--E - '._:; !} t ',ii.:'FA!'-.K.::[i. - !] !. i :;: IE C: -!' '): (.)hi · F E:' l-:: 'T F: E:' E'F t:::' IS E T F E ES T F E E; 'l' t: :' C...' !' '0 H ......... Tt]P .'S,":-:',f'~ R I ~,,~E'R .......... A:"';4:::h,--,FP:"~. ....... 8/:,('.~2,-.':[;'.1 ........ 24,':..,, 0 ...... :i.:5':.-:;8,0 !- ............ .:,--,, L:i; 140,:':' /'_', ! I.,,1 TOP :i!i;HUBL ][ K A ',E',S7CI ,, (-)0 8/:,2:.]~, ,'!:,0 :2-'..':!,.,_'.:,. -'~.~ :!!i',.~J;.,':l.'i.:/, ,:'.:,0 Zl.:'ji:!5,, :';ft'.-'.:' '.S 1404, 70 T r'l p '.S I-.-I I...I B I.... I K B 8',q ? 4., o 0 F,' ....../-, 4 7. 1/-, '-:'... .,').,. ,":.-.. ,. 8 '"",.:,":'.:_, '""/'-,..:,, ..... 1/-, ,.1 :'q 6 :]:', 2 fi; 14 ,:.:~'i:.-,' ,, 1/-,_ H. '-" 2 ''? -" r.:.- ._ ':',t ":' TOF' S;HUBL. t l< I;": :::'..-} 1 1 ,, ,('~0 ........ -8/_-, 6 :3 -, :.:.34 .,::; :t-,.--,, .2 ,-t :::J-.-:ii:;.-.--:t:4--t---:;:_'-, :36 W ............ _ .... ...... ::: ...... ::, :: . 84 .......... 4-S: ... 'T' 0 F:' '.-2: A D l.._ Ii:-'; R 0 C t--I ;[ T 8'P 4 5, ("~ 0 :E,, 6'P 7. 1. 7 ':2: '".l. 7. ::i', ','ii', ,/_-, '7.:.:' :3 ,, ! 7 .'.1. :3':'.? ,, ():3 '.:-:; 1_ 4 ! :~'__:': ,, 80 W .... ;"_':'::' ...... / ...::,.' ..... J:'~t' c.~'7";,' :'1.. 4 .... l:l ..... f'OP "~C i".t!E :3 o .t. 5!5,~ (')(:~ .......... --~27.;"C:':3 ~, ':;.:':,'~ ........ ,.- , :t. ,,'8 ~;::~::: '?':.'~ ,, 24 ......... 4-15 .i.-,~ -'"'-'" ........ '- .. 'TC~F' Z(}N[~.': 2 'P:,--:::.:.:5.0'::) 8'.:.:'8:1., 'P':) :;::.5:"~ ,, 1_ ',::iv?07,, ?0 4.5,:5,, '-.-/?::; ¢i: :1.470,, '7? W · '"~ I::; ~ "~ C77 ~-'" r.- r::- ! ,"'~ HOT 'P31Zl.. C:,O '.? (.) !:5 'P . ,':-,f:";_ ._ .,:.'.._. 4.4 ,'::, :: ,::,.::, ,, ./- ........ 'l- ,:;, ., : :. , (".','7... S ]. 4- :iii: ::::': ,, ';"'if.' W ......... O/W' C 0 f',rt': A ~':: T ?'!F.:4 E,' ;' 0 () ............. PO'F.' zt. ~--':.t.-:3 ............. 2 ~!:~ 4 ,~ ~" ............ ?0 ~. 0-~ -.!. :3 .1,/.', 4 2-7--E;' ' :i_-,4..EI'F'. ,.-(.:: :7 · W !::' B 'T' ......... Ti ':.:, :'::'79 (i')~, '~:~':'~.~I (') ':'::' .1. :::it 3 ,, ~.¢..:.~:~(") :;.: ....... .'-'- :'"'; ~,:;":, .................... ::-,',:") 4 ":.-~ 7 (") 4/',,':', ,:-t 9 ~:; 14 9 Zl. 12 I/..l f"D :7.,, Zl..,:-~2 /. /1 t::'I!¢"r/:;'7.:}z ANE ,:';%)?;,CF.:, NY Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ,~, ~O~.~_ator, ~ · DJ ~-~/ ' - 'Well N~me and Number Reports and Materials to be received by: /~-~·~--~ ' Date Required Date Received· Remarks C°mPletion Report Yes /~ --~"-- ~).. ~ ~ _ Wel. 1 History Yes. · · · Samples ' :, , ,.x/~ - p I . -Pt ;- ,, , , ,,, · · : . ,,; .[ . . , .,, ' . , ~ , , ' , , ~re' ~iPS ::. /'//~F'''~'~--'' '- " O~ ' i~ , . " · , Core' Description., //~/~-~ . . Registered Survey 'Plat y' ,~.J ~,, , · ..~ · Inclination Survey .. ~/~,. Id -' Directional Survey Y~ -PI · Drill Stun Test Reports //~ ~-- ' d~ , , ' .w . production Test Reports ~/~ ~~ ..... d' ~'~ · , , , , ~s ~n.. ~es .id .2o- ~ ;~. · ,...., u , Digitized Data y~. ARCO Alaska, Inc. Post Office Bo,~ ~ Anchorage, Ala~,~, 99510 Telephone 907 277 5637 October 14, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil &Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for September on these drill sites' 1-19 18-6 1-20 18-7 6-21 1E-28 6-22 1E-29 13-16 1E-30 13-34 1F-6 1G-2 1G-3 WSW-3 WSW-4 Also enclosed are well completion reports for' 2-26 1G-1 6-20 14-15 (completion report & subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:Ilm Enclosures GRU2/L15 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany - STATE OF ALASKA .... - ALASKA~ .AND GAS CONSERVATION CC vIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well k~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-127 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20802 9. Unit or Lease Name 467' FSL, 960' FEL, Sec. 2, TION, R14E, UM Prudhoe Bay Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 6. Lease Designation and Serial No. ADL 28311 10. Well No. DS 6-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of. September , 19 82 -- 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0100 hfs, 08/27/82. Drld 17-1/2" hole to 2515'; ran cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 8850'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 9452' TD; ran open hole logs; ran & cmtd 7" lnr. Ran CBL-squeezed cmt. Ran CBL/VDL. Ran 4-1/2"/5-1/2" compl, assy. Secured well & released rig @ 0200 hfs, 09/15/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld, conductor set (~ 80'. 13-3/8 Permaf 9 -5/8" 7" , 29 SEE DR Installed w/1900# Poleset. ", 72.0#/ft, L-80, BTC, csg w/shoe @ 2511'. Cmtd w/2259 sx Fondu & 400 sx rost C. , 47.0#/ft, L-80, BTC csg w/shoe @ 8842'. Cmtd w/500 sx Class G. #/ft, L-80, BTC csg f/8519'-9420'. Cmtd w/275 sx Class G. ILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BHCS/GR f/9452'-8841' FDC/CNL/GR/Cal f/9452'-8841' RFT/GR 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foCegoing is true and correct to the best of my knowledge. ~'~'~~ ~~.A.//~ Area Drilling Engineer SIGNED .... , . ,_ ..... ITLE DATE NoTE--Report on this f~'~required for each cJendar month, regardless of the status of operations, and must be iile/d ~n duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 G R U 2 / M R 6 Submit in duplicate DS 6-21 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0100 hrs, 08/27/82. Drld 17-1/2" hole to 2515'. Ran 61 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2511'. Cmtd 13-3/8" csg w/2259 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8850'. Ran 210 jts 9-5/8" 47#/ft, L-80, BTC csg. w/shoe @ 8842'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC and cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9452' TD (09/05/82). Ran DIL/SP/BHCS/GR f/9452'-8841'~ FDC/CNL/GR/Cal f/9452'-8841' & RFT/GR. Arctic packed 9-5/8" x 13-3/8" ann. Ran 23 jts 7" 29#/ft, L-80, BTC csg f/8519'-9420'. Cmtd 7" lnr w/275 sx Class G. Drld cmt to 9379' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/9376'-8400'. (poor bond) TIH & perforated 9215'-9217' & 8920'-8922' w/4 spf. TIH w/gauge ring & junk basket to 9376'-no recovery. TIH & set cmt retainer @ 9192'. TIH & tagged retainer @ 9192'-tested valve-held 1000 psi - ok. Squeezed 75 sx Class G cmt into perfs. TIH w/gauge ring w/CCL and junk basket to 8950'-no recovery. TIH w/cmt retainer & set @ 8868'. Stung into retainer & squeezed 200 sx Class G cmt. Drld cmt to 8867' & tagged retainer. Drld retainer. TIH to 9049', tagged cmt, drld cmt to 9192' & tagged retainer. Tstd upper perfs @ 8920'-8922'; would not hold. Drld retainer @ 9192'. Drld cmt to 9379' PBTD. Tstd lower perfs - ok. Ran CBL/VDL f/9379'-8400'. Ran & set isolation packer on wireline to 8930'. Ran 4-1/2"/5-1/2" completion assy w/tail @ 8957' & pkr @ 8457'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Press. up to 1000 psi on ann - ok. Press. tbg to 3000 psi & set packer. Press tbg to 3000 psi & ann to 250 psi - ok. Tstd w/2000 psi on ann & 250 psi on tbg - ok. Installed BPV. Nipple for SSSV @ 2171'. Instld tree cap & tstd to 5000 psi - ok. Put VR plug on 13-3/8" ann. Secured well & released rig @ 0200 hrs, 09/15/82. JG-sm 10/05/82 GRU2/DH6 ARCO Alaska, Inc, Post Offi~e.~Box 360 Anchor; Alaska 99510 Telephone 907 277 5637 October 15, 1982 Reference: ARCO Directional Surveys D.S. 1-19 /8-27-82 D.S. 1-20% 9-11-82 D.S. 6-21~ 8-27-82 Directional Single Shot 'Directional Single Shot Directional Single Shot D.S. 6 22~ 9-15-82 D.S. 18-6 ~ 8-17-82 Directional Single Shot Directional Single Shot E/w E/W E/W / ~. 18-7f 9-13-82 Directional Single Shot E/W Please sign and return the attached copy as receipt of data Becky Benedict AFA - 403 Trans. #547 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL ~ .. ~ P,L~.~ t~ L Anchorage STATE OF A~S~ DALLAS Post Office Box 360 Anchorage, /'~'~ka 99510 Telephone 9~ 277 5637 October 15, 1982 Reference: ARCO Case Hole Finals D.S. 6-21~''~ 9-9-82 CCL/Perforating Record D.S. 6-21/r- 9-12-82 CBL/VD D.So 6-21/~ 9-9-82 CBL/VD Run 1 SCH Run 1 SCH Run 1 SCH D.S. 13-1:1~ 6-20-82 Differential Temp. Survey . 'D.S. 12-2 ~:~" 6-21-82 Differential Temp. Survey D.S. 4-14 ~-'~' 10-7-82 Spinner Survey Run 1 D.S. 13-17~ 9-26-82 Spinner Survey Run 1 D.S. 3-6 ~ 9-13-82 Engineered Production Log Run 1 /lease and return the attached receipt of data. sign copy as Becky Benedict AFA- 403 - Run 1,2,&3 CAMCO Run 1,2,&3 CAMCO OTIS OTIS SCH Trans. #550 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS S0HIO MARATHON CHEVRON EXXON MOBIL ARCO Alaska, Inc. Post Office !~,~x 360 Anchorage, ska 99510 Telephone 907 277 5637 October 15, Reference: 1982 ARCO Open Hole Finals D.S. 6-21 9-6-82 FDC/CNL/GR (Porosity) Run 1 5" D.S. 6-21 9-6-82 FDC/CNL/GR (Raw Data) Run 1 5" D.S. 6-21 9-6-82 DIL/SFL/GR Run 1 2"&5" D.S. 6-21 9-6-82 BHCS/GR Run 1 2"&5" D.S. 6-21 9-6-82 CPL/Cyberlook Run 1 5" D.S. 6-21 9-6-82 RFT Run 1 5" D.S. 13-34 9-8-82 RFT Run 1 5" D.So 13-34 9-8-82 CPL/Cyberlook Run 1 5" D.S. 13-34 9-8-82 FDC/CNL/GR (Raw) Run 1 2"&5" D.S. 13-34 9-8-82 FDC/CNL/GR (Porosity) Run 1 2"&5" D.S. 13-34 9-8-82' BHCS/GR Run 1 2"&5" D.So 13-34 9-8-82 DIL/SFL/GR Run 1 2"&5" Please sign and return the attached copy as receipt of data. - Becky Benedict AFA - 403 Trans o #551 SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH $CH DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA /"7 Post Office Box 360 Anchorage. ~"-ska 99510 Telephone 9, ;77 5637 September 21, 1982 Reference: Arco Magnetic Tapes and Listings D.S. 18-6 9-7-82 D.S. 13-34 9-8-82 .... p~: ..~ 6.._g!. 9'6'82 D.S. 1-19 9-7-82 D.S. 6-4 7-28-82 OH tape and list (ACC 65554) OH tape and list (ACC 65556) OH tape and list (ACC 65553) OH tape and list (ACC 65552) C/O log (8 passes)(ECC 1389) Run 1 & 2 Run 1 Run 1 Run 1 · ~~Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 479 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE O~ ALASKA CHEVRON DALLAS ARcO Alaska, Inc. Post Office [~ Anchorage, Alaska 99510 Telephone 907 277 5637 September 10, i982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas ConServation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for August on these drill sites' 1-19 13-32 1E-30 2-23 13-34 1G-1 2-26 14-21 1G-2 6-19 18-3 1F-5 6-20 18-6 WSW-2 6-2I 1E-17 'Also enclosed is a well completion report for Kuparuk 1E-16. Surveys for 2-22 and 6-18 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:llm Enclosures GRU1/L93 ARCO Alaska. Inc. is a subsidiary of Atl,'~nticR.ichfieldCor~'~pany '- ~ STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C~. ,,.,IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellX[~ Workover operation [] 2. NAr~td o rato 7. Permit No. ~ as[<a, Inc. 82-127 8' APl ~b_e~0802 3. A~d. res(~. BOX 360, Anchorage, AK 99510 5o- 9. Unit or Lease Name FSL, 960' FEL, Sec. 2, T10N, R14E, UM Prudhoe Bay Unit 4. Location of We~7 , at surface 74- RKB ADL 28311 10. Well No. DS 6-21 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool For the Month of. August ,1982 12. Depth at end of month, footage drilled, fishing jobsLdirectional drilling problems, spud date, remarks Spudded well @ 0100 hrs, 08/27/82. Drld 17-1/2" hole to 2515'; ran, cmtd & tstd 13-3/8" csg. Dr!d 12-1/4" hole to 6520' as of 08/31/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld, conductor set @ 80'. Installed w/1900# Poleset. 13-3/8",72#/ft, L-80, BTC, csg w/shoe @ 2511'. Cmtd w/2259 sx Fondu & 400 sx Permafrost C. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run None to date 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~'~./~~~'~.--.._ Area Dr il ling Engineer SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ¢_DII1 /MDg~ DS 6-21 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0100 hrs, 08/27/82. Drld 17-1/2" hole to 2515'. Ran 61 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2511'. Cmtd 13-3/8" csg w/2259 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 6520' as of 08/31/82. JG'sm 09/03/82 GRU1/DH40 MEMORANDUM State of Alaska TO: T~IRU ' · FROM: ALASKA OIL AND C-~%S CO~$ERVATION COM~ISSIO~,'~ .~-.~~ September 7, DATE: C. rton Ch i~/~n FILE NO: Lonnie C. Ri th ~.~c., ~ Commi s si one r Doug Amos P~troleum Inspoctor TELEPHONE NO: 108A/c SUBJECT: 1982 Witness the BOPE %'est on. ARCO's DS 6-21 Well Sec. 2, T10~, R14E, Pern-dt No. 82-127 on Rowan P, ig No. 26 ..S, Pnday, ~Au.gust .2.9~.,~ 1982 - The DOPE test cor~n~nced at 12:00 a.m. and~ v,~s concluded at 2:00 a.m. The rotary hose used as the choke line failed and was replaced and retested during this test. I filled out an A.O,G.C.C. BOPE test report which is attached. In sum~ry, I witnessed the BOPE test on ARCO's DS 6-21 well. The choke line failed and %~s replaced and retesteQ. I filled out an A.O.G.C.C. BOPE test report which is attached. O&G #4 .4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report .37' /Z:s~ 'Inspector Operator Well D, Representative Permit # 8Z Location: Sec 2 T I~R 1~ 6 M ~,/~, ~aslng Set @ ~t~9 ft. Drilling Contractnr .~.~b~/~A~ Rig # Location, General Well Sign General Housekeep Reserve pit "Annular Preventer Pipe Rams 'L &~. ~ Blind Rams ;_ '.~ ' Choke Line ValvesOO H.C.R. Valve ~ Kill Line Valves~L: Check Valve // Test Pres sure ~ooo /! It /i ACCUMULATOR SYSTEM Full Charge Pressure ~_~9~_~ psig Pressure After Closure _~ ~_/9 psig 200 psig Above Precharge Attained: min.~ sec. Full Charge Pressure Attained: _- min · . /~?~,,. ,??~, ~a ~ Il sec Controls: Master ~/~ Remote '~F~_~ Blinds switch cover Kelly and Floor safety Valve's " Upper Kelly.. / ~est Pressure Lower Kelly.. / .~~t Pressure /; Ball Type / Test Pressure /! Inside BOP / Test Pressure Choke Manifold ! Test Pressure · No. Valves /~ No. flanges ~ Adjustable Chokes / Hydrauically operated choke / /! Test Results: Failures / Test Time ~ hrs. Repair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. Remarks: /~,~;';~yf../.~&;~.~ /r~/Z~D' E;A/ ~.w~/~ /_/,~/~ / · - . t~1 I Ill I Ii I Distribution orig. - AO&GCC cc - Operator co - Supervisor Inspector ARCO Alaska, Inc,'~ Post Office. x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 9, 1982 Ms. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats Dear Elaine' Enclosed are as-built location plats for the following wells' Drill Si Wells 1 , 22, 23, 24 Drill Site Wells 6 If you have any questions, please call me at 263-4944. Sincerely, doAnn Gruber Associate Engineer JG'sm Enclosures GRU1/L62 ARCO AI,3ska, Inc. is ,3 subsidiary of AtlanlicRichfieldCompanY iO~5' S "l,.. CA,c-f LOCR T i 0i'4 !-.i i,.,.i ]' F_, ~' L <. L_ L A'. ;~' ~, .... 22: Y=5., ':'~a i i ::_',S. T';6 -- . -- : ¢ i':, · ,,:..; = 6 E,,5., ,:,c, 7 RF, LRT= 7A i 4. 3'9..~',47, 6 .... 2.3 h"=?;, 94 ! , 2'_:¢.'~. i £ ""-- 6 ¢j $., ':.' ~ q ~:', ~] LFtT= ,.""'~-.3 .i. 4. 4¢:..i. 4.'~S Hi.4 F_: r3 ~: A E ;_ u ~'::'- EL.E~,,,= L iIl ~'~l] = 14 F-: 2 ,:4 S .i :997 i:-:; = 6 ¢; F.,., 9 4. 2 . ~-,'i :.:' LRT= ,.-"Fr; i4 4~ .6~73 L'" N G = '~ a ',E: :2'. ':' 5 ;2 ;.-' 23 COND Cfo A4- u l-"r D..4. ARCO Alas'l a, inc. Subsid~ar~ of ~tlcntic Richfield Comt)~ny NORTH' SLOPE DRtLLING-PRU~HOE ........... .......... ....... I I SHEET t ___ OF I Auk~at 10, 1982 Area Driltin~~ Engineer ARCI) Alaska, Inc. P. O, Bo~ 36~ a~ca Anchorage, At ~' Prudhoe Bay · Un i t D~; 8-21 ARC(_} Aiaaka, !ne, ~em:i t ~0. 82-127 Sur. Loc. 959'¥~L, 46fi'NSL, Sec. i.;t~:~oie Loc. 37'S!~L, 2643'~i~L, Sec. 11, T16h, C14~, U~.:. anclo~ec~ ia ihe approved application for per~-;~it to drill the referenced well. '~{eil sa~;~plea and a n~u~ lo{7 are not required. A conti~mous 2irectional s~rvey is required as per 20 AAC available, a tape containing the diL~iiized log information ai~all be aub~;;itted on ail iogs for copyink~-cxce!;.t experimental io~-' velocity surveys and di~ ~=, . ~-~me ter surveys. }dany riYera in Alaska aha their draina{{e a;ysten;s i;ave been classified aa in~portant for t~,e sI.;.awning or ~. ~t.~ration of anadroi:'~ous fisB. Operation~ in these areaa are subject to A~ I~ 0~.. 870 and the re~,'ulations r~romulTated thereunder (Tilia 5, Alaska Adminiatrative Code). operatiena you may be contacted by the !iabitat Coordinator's Off ice, Department of Fiah and {;ar;:e. Pollution of any waters of the State is prohibited by AS 46, C~apter 3, Article 7 and the ~e[~ulationa promulgated thereuncier (Title I~, Alaska A~::inistrative Code, Chapter 70) and by the Peoeral }rater Pollution Control Act, as amen(~ed. }riot to ccca:~encing c:peratio.n~ you r;~a.r bo contacted ;.' -- oy a rel:~rescntative ,~f the ~epart~?;ent of ~nvironmentaI Co:nservatio~'~. aid us i~ schedulin~~_ field r~ork, ~:;e would a~'-'~-'~;.~:rcciate your. notifyins' this office within ,t8 hours after thc ~..:cll i~ apu~de~J. ;~e ~oula ala~ like to be notified so that a repreaentative of the Con:~d ssio~_~ -",.~ay.- '~e present, to v:i tness Mark A. Major Prudhoe Bay Unit DS 6-21 -2- Aug~aot 10, 1982 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment° please give this office adequate advance notification so that we may have a witness present. Very truly yours, C, V. Chatterton Chai~an of 8Y OH-D~a O~ THE COMI~i~::;;O~ Alaska Oil and Gas Conservation Cor~ission Eric l o sure cc: Department of Fish & Game, Habitat Section w/o encl. Depa tment of Environmental Conservation w/o encl C~fC: be ARCO Alaska, Inc. Post Office B¢~ Te~ephor~e ~cj? 2:%? 5537 July 28, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 6-21, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 6-21 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled.; and a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Sincerely, Area Drilling Engineer HAM/J G' bc Enclosures Alaska 0it & Gas Cons, CoinmissJorl Anchorage ARCO A!askg:, Inc. is ~ subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '-' ALASKA L,,b AND GAS CONSERVATION CO,,,MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE I~ MULTIPLE ZONE [] Name of operator 2. ARCO Alaska, Inc. 3. Address P 0 Box 360, Anchorage, Alaska 99510 959~ WEL & ~66~ NSL~ Sec, 2~ T10N~ RI~E~ At top of proposed producing interval 19' NSL & 2~55 ~EL, Sec. 2, T10N, R18E, At total depth 37' SNL & 2643' WEL, Sec. 11, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 74' PAD 37' I ADL 28311 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number DS 6-21 11. Field and pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool Amount $500,000 I15. Distance to nearest drilling or completed -20 well 120' (~ surface feet 18. Approximate spud date 09/08/82 13. Distance and direction from nearest town Deadhorse 3 NW miles 16. Proposed depth (MD & TVD) 9527' MD, 9225'TV• 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 4000 feet. 21 14. Distance to nearest property or lease line 37' from ADL 28308 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 20 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program _ ~44R . psig@ ...... Surface _.4~-- ._psig@_92_.2~ft. TD (TVD) SIZE Hole Casing Weight 0"~~ 20" 91 5# 7-1/2" 13-3/8" 72# I2-1/4"9-5/8" 47# 182-21./D2~ic r ib~'~ roposed 2pgrro~gram.' :ASING AND LINER Grade Coupling H-40 Welded L-80 IBUTT 2464' L-80& /BUTT 7805' S00-95 /BUTT 1000' L-80 /BUTT 987' Length MD 80' 37' 36' 35' 7840' 8540' SE I'TING DEPTH TOP TVD t 37' 117'1 I I 117' 36' t 35' 7640' 8298' MD BOTTOM TVL) 2500'12500' 7840'17640' 8840'18580' 9527'19225' QUANTITY OF CEMENT (include stage data) 2205lbs est. Poleset 2300sx Fondu + 400 sx PF 500sx G 1st Stage 300sx PFI 2nd Stage 400sx Class G Cmt ARCO Alaska, Inc., proposes to directionally drill this well to 9527' MD (9225' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and gas lift mandrels will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud and at least daily thereafter. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED~.~, /f,~ ~ ~./.~,~ TITLEArea Drilling Engineer The spac~ ~el~v~ fo~ E~ommi~n/e CONDITIONS OF APPROVAL Samples required []YES Permit number APPROVED BY Form 10401 Mud log required []YES ~NO Approval date GRU1/PD14 DATE SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 10, 1982 '-" by order of the Commission Submit in triplicate Directional Survey required I APl number ~.Y ES •NO , ~,,. ! ~ . J ti ~ i J l._i_ ~ J J ~ J J I J i J J ~ !l- j it! ~ ' ~ ' ~ J SURFACE HOLE. D Z VERTER ARCO ALASKA .....-----IO" HYD. OPR. BALL VALVE f ~ WELL BORE (SEE DETAIL) /"' ~'~----IO" HYD. OPR. BALL VALVE // //" I ALL EKD° TURNS ARE "TEE" WELL ( ~) BORE - I RESERVE PIT AREA NOTE' SYSTEM INC'. FLOWL INE "'-I0" D IVERTER LINE SCHEMATIC ,, DR ILL lNG R I SER Valves on diverter lines open automati- cally when the annular preventer is closed. F 20" 2O0O PSI WP ANNULAR PREVENTOR lNG SPOOL I O" HYDRAULIC OPERATED BALL VALVES 20" CONDUCTOR PIPE "DETAIL" 2O26010 ANNULAR PREVENTER L i ,i BL IND RAMS ,,~ 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test l. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining · after all units are closed with charging pump off. 4. Record on [ADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill 80P stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a,250 psi low pressure test for a minimum of 3, minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum o~ 3 minutes. B~eed pressure to zero. _ 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes° Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe r ams. 11o Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. i2. Bleed pressure off all equipment° Open blind rams° Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate 8OPE daily. Rev. 5/13/81 .- CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE · 3. 4. 5. 6. 7. 8. (3) Admin ~C~u,~ f'~'iIfx' 9. ~ thru 11) 10. 11. (4) Ca sg _~<.,~.~, ~o..~,,~,~-- 1 (12 thru 20) 1 1 1 me 3. 4. 5. 16. 17. 18. 19. 20. YES NO Is the permit fee attached ........................................ Is well to be located in a defined pool ............................. Is well located proper distance from property line ................. Is well located proper distance from other wells ................... Is sufficient .undedicated acreage available in this pool ........... Is well to be deviated and is well bore plat included .............. Is operator the only affected party ................................ Can permit be approved before ten-day wait ......................... Is conductor string provided ..... ' 'Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst Iff this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included, on 10-403 .......... Is adequate well bore separation proposed ......................... REMARKS (5) BOPE (2i ' ~hrU 24) 21. 22. 23. 24. 25. Is a diverter system required ....................................... ~/ Are necessary diagrams'Of 'diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating -Test to ~ psig .. 4~ Does the choke manifold comply w/A_PI RP-53 (Feb.78) .................. , /1/,~ .~-~,A~w,~k-~-~ Additional requirements Additional Remarks: Geology: Enginger, ing: HWK ~ LCS y~_~" BEW (! / rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 WELL NAME FIBLD NAME BOROUGH S TA T E API NUMBER REFERENCE NO ARCO ALASKA INC. DS 6-21 PRUDHOE BAY NORTH SLOPE ALASKA 500292080200 98395 RECEIVED LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN : FLIC REEL NAME : 98395 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA, DS 6-21, PRUDHOE BAY, API #50-029-20802-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN · FLIC TAPE NAME : 98395 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, DS 6-21, PRUDHOE BAY, API #50-029-20802-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 6-21 API NUMBER: 500292080200 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 12-AUG-98 JOB NUMBER: 98395 LOGGING ENGINEER: R STEPHENSON OPERATOR WITNESS: S SCHUDEL SURFACE LOCATION SECTION: 2 TOWNSHIP: ION RANGE: 14E FNL: FSL: 467 FEL: 960 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 74.00 DERRICK FLOOR: 73.00 GROUArDLEVEL: 37.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 7. 000 9420.0 29. O0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA ~ ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 06- SEP- 82 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9225.0 9218.5 9216.5 9213.5 9209.5 9207.5 9188.0 9180.5 9176.0 9174 0 9172 5 9171 5 9163 5 9157 5 9154 0 9153 0 9149 0 9145 0 9141 0 9135 5 9134 0 9131 5 9129 0 9128 0 9125 5 9124 5 9122 0 9116.0 9115 0 9114 0 9113 5 9113 0 9108 5 9108 0 9102 0 9101 0 9097 0 9096.5 9091 0 9090 0 9085 5 9083 5 9081 5 9080 5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH RST 88886.5 88892.0 9206.0 9186.5 9175.0 9173.0 9154.0 9149.5 9145.0 9135.5 9132.5 9129.5 9125.5 9122.0 9116.0 9114.5 9112.5 9108.5 9103.0 9098.0 9091.0 9086.0 9081.5 9229.0 9221.5 9218.0 9215.5 9212.0 9181.5 9175.0 9173.0 9163.0 9158.5 9154.0 9142.0 9135.0 9129.5 9125.5 9116.0 9115.0 9109.0 9103.0 9098.0 9091.0 9086.0 9081.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 9076.0 9074.5 9073.0 9065.0 9064.0 9063.0 9059.5 9049.0 9044.0 9042.5 9042.0 9039 5 9038 0 9037 0 9035 0 9032 0 9027 5 9024 0 9023 5 9018 0 9016.5 9013 5 9012 5 9011 0 9005 0 9001 0 8997 5 8997 0 8991 5 100 0 $ REMARKS: 9074.5 9073.0 9065.5 9062.0 9058.0 9050.5 9042.5 9040.0 9038.5 9032.0 9028.0 9024.5 9017.0 9013.5 9012.0 9005.0 9001.0 8996.0 8992.5 101.0 9077.5 9065.0 9050.0 9044.5 9042.5 9038.5 9035.5 9028.0 9024.5 9017.0 9013.5 8999.5 102.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S DS 6-21 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GA~9~A RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GA~LA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMPUkRY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9224.5 8991.0 RST 9241.0 8992.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ REMARKS: .......... EQUI,VALENT UNSHIFTED DEPTH GRCH RST THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT I1 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NOWB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 NBAC RST CPS 1208475 FBAC RST CPS 1208475 SBNA FIL CU 1208475 SFNA FIL CU 1208475 SBFA FIL CU 1208475 SFFA FIL CU 1208475 TRAT FIL 1208475 IRAT FIL 1208475 CIRNFIL 1208475 CIRF FIL 1208475 BSALRST PPK 1208475 SIBF RST CU 1208475 TPHI RST PU-S 1208475 SFFC RST CU 1208475 SFNC RST CU 1208475 SIGM RST CU 1208475 DSIG RST CU 1208475 GRCH RST GAPI 1208475 TENS RST LB 1208475 CCL RST V 1208475 FBEF RST UA 1208475 CRRA RST 1208475 GR BCS GAPI 1208475 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9424.000 SFNA.FIL -999.250 IRAT.FIL -999.250 SIBF.RST -999.250 SIGM. RST -999.250 CCL.RST -999.250 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST DSIG.RST -999.250 GRCH.RST -999.250 TENS.RST FBEF. RST -999.250 CRRA.RST -999.250 GR.BCS DEPT. 8843.000 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST CCL.RST -999.250 FBEF.RST -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 FBAC. RST SFFA. FIL CIRF. FIL SFFC. RST GRCH. RST CRRA. RST -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC. RST -999.250 TENS.RST -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 22.578 -999.250 -999.250 ~999.250 -999.250 -999.250 84.375 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N~IMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~4FIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9224.5 8991.0 RST 9241.0 8992.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88886.5 88892.0 9230.0 9234.0 9226.0 9230.5 9221.5 9220.0 9225.0 9218.5 9221.5 9215.5 9214.0 9213.0 9215.5 9205.5 9204.5 9202.0 9204.0 9201.0 9200.0 9194.5 9196.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 9187 5 9185 0 9180 5 9174 0 9171 5 9164 5 9162 5 9160 5 9157.5 9153.5 9152.5 9149.0 9145.5 9144.5 9140.5 9139.5 9135.0 9129.0 9128.0 9124.5 9120.5 9115.5 9115.0 9114.0 9113.0 9111.5 9108.0 9107.5 9104.5 9104.0 9102.5 9100.5 9099.5 9098.0 9096.5 9094.5 9091.5 9090.5 9089.5 9087.0 9084.5 9083.5 9081.0 9080.0 9074.0 9073.5 9068.5 9068.0 9064.5 9064.0 9062.0 9059.5 9057.5 9055.0 9049.0 9186.5 9175.0 9165.0 9154.0 9144.5 9140.0 9135.5 9129.5 9125.5 9116.0 9114.5 9112.5 9108.5 9104.5 9102.5 9100.0 9098.5 9095.0 9092.5 9090.5 9088.5 9085.5 9081.0 9075.0 9068.0 9065.0 9062.0 9054.5 9189.0 9181.5 9173.0 9163.0 9161.0 9159.0 9154.0 9150.0 9147.0 9141.5 9129.5 9122.0 9116.0 9115.0 9113.0 9109.0 9106.0 9103.0 9098.0 9091.0 9086.0 9081.5 9075.0 9070.0 9065.0 9061.0 9058.5 9050.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 9044 5 9042 0 9041 5 9039 5 9038 0 9037 0 9035.0 9034 5 9031 5 9028 0 9023 5 9016 5 9015 5 9013 5 9012 5 9011 0 9003.0 9001.5 9000.0 8999.5 8994.5 100.0 9045.5 9042.5 9040.0 9038.5 9036.0 9032.5 9028.0 9017.0 9013.5 9012.0 9005.0 9000.5 101.0 9042.5 9038.5 9035.5 9032.0 9024.5 9017.5 9013.5 9003.5 9002.0 8997.0 102.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 9 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 2 1 1 4 NBAC RST CPS 1208475 O0 000 O0 0 2 1 1 4 FBAC RST CPS 1208475 O0 000 O0 0 2 1 1 4 SBNA FIL CU 1208475 O0 000 O0 0 2 1 1 4 SFNA FIL CU 1208475 O0 000 O0 0 2 1 1 4 SBFA FIL CU 1208475 O0 000 O0 0 2 1 1 4 SFFA FIL CU 1208475 O0 000 O0 0 2 1 1 4 TRAT FIL 1208475 O0 000 O0 0 2 1 1 4 IRAT FIL 1208475 O0 000 O0 0 2 1 1 4 CIRNFIL 1208475 O0 000 O0 0 2 1 1 4 CIRF FIL 1208475 O0 000 O0 0 2 1 1 4 BSALRST PPK 1208475 O0 000 O0 0 2 1 1 4 SIBF RST CU 1208475 O0 000 O0 0 2 1 1 4 TPHI RST PU-S 1208475 O0 000 O0 0 2 1 1 4 SFFC RST CU 1208475 O0 000 O0 0 2 1 1 4 SFNC RST CU 1208475 O0 000 O0 0 2 1 1 4 SIGM RST CU 1208475 O0 000 O0 0 2 1 1 4 DSIG RST CU 1208475 O0 000 O0 0 2 1 1 4 GRCH RST GAPI 1208475 O0 000 O0 0 2 1 1 4 TENS RST LB 1208475 O0 000 O0 0 2 1 1 4 CCL RST V 1208475 O0 000 O0 0 2 1 1 4 CRRA RST 1208475 O0 000 O0 0 2 1 1 4 FBEF RST UA 1208475 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9241.000 NBAC.RST 2648.545 FBAC.RST SFNA.FIL 20.649 SBFA.FIL 32.805 SFFA.FIL IRAT. FIL 0.582 CIRN. FIL 1.448 CIRF. FIL SIBF.RST 9.126 TPHI.RST 20.493 SFFC.RST SIGM. RST 17.132 DSIG.RST 1.409 GRCH.RST CCL.RST 0.001 CRRA.RST 1.702 FBEF.RST DEPT. SFNA.FIL IRAT.FIL SIBF.RST SIGM. RST CCL.RST 8991 000 NBAC.RST -999 250 SBFA.FIL -999 250 CIRN. FIL -999 250 TPHI.RST -999 250 DSIG.RST -999 250 CRRA.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 GRCH.RST -999.250 FBEF.RST 3429 781 SBNA.FIL 18 426 TRAT. FIL 2 564 BSAL.RST 16 948 SFNC.RST -999 250 TENS.RST 58 826 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST 46.306 TENS.RST -999.250 41.000 0.964 -39.318 18.528 1212.000 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 10 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~WNkRY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9225.5 8991.0 RST 9237.0 8992.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH RST 88888.0 88887.5 88888.0 9230.0 9230.0 9222.5 9225.0 9215.5 9215.0 9213.0 9215.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE 9207.0 9206.0 9206.0 9204.5 9200.5 9199.5 9199.5 9201.0 9194.0 9196.5 9176.5 9175.0 9172.0 9173.5 9168.0 9168.5 9167.0 9168.0 9163 . 5 9164.5 9160.5 9161 . 0 9154.0 9154.0 9153.0 9154.0 9149.0 9149.0 9141.5 9142.0 9134.5 9135.0 9129.0 9129.5 9128.0 9129.0 9125.0 9125.5 9121.5 9122.0 9116.0 9116.0 9115.0 9116.0 9114.0 9114.5 9113.5 9115.0 9112.5 9112.5 9111.5 9113.0 9107.5 9108.5 9106.0 9106.0 9103.5 9105.0 9103.0 9103.0 9097.0 9098.5 9096.5 9098.0 9095.0 9095.5 9090.5 9090.5 9090.0 9091.0 9084.0 9085.5 9082.0 9081.5 9080.5 9081.5 9077.0 9077.0 9076.0 9077.5 9068.5 9070.0 9065.0 9065.0 9064.0 9065.0 9061.0 9062.0 9059.5 9061.0 9057.5 9058.5 9056.0 9056.5 9051.5 9052.5 9048.5 9050.0 9046.5 9047.5 9045.0 9046.0 9044.5 9045.5 9042°5 9042.5 9041.0 9041.0 9039.5 9040.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 12 9038.0 9038.5 9037.5 9038.5 9035.5 9036.0 9035.0 9035.5 9032.5 9032.5 9028.5 9028.5 9027.5 9028.0 9023.5 9024.5 9021.5 9022.0 9022.0 9018.0 9017.0 9016.5 9017.5 9014o0 9013.5 9012.5 9013.5 9011.0 9012.0 9009.5 9010.5 9004.5 9005.0 9004.0 9006.5 9000.5 9002.0 9000.0 9001.0 8997.5 8999.5 100.0 101.0 102.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORJLY PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 13 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APi API API API FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 1208475 O0 000 O0 0 $ 1 1 4 68 0000000000 FBEF RST UA 1208475 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9237.000 NBAC.RST 2449.630 FBAC.RST 3411.606 SBNA.FIL SFNA.FIL 26.543 SBFA.FIL 85.984 SFFA.FIL 24.082 TRAT. FIL IRAT. FIL 0.575 CIRN. FIL 0.273 CIRF. FIL 0.708 BSAL.RST SIBF. RST 136.787 TPHI.RST 19.873 SFFC.RST 25.615 SFNC. RST SIGM. RST 25.477 DSIG.RST -0.943 GRCH.RST -999.250 TENS.RST CCL.RST 0.004 CRRA.RST 1.703 FBEF.RST 57.532 105. 722 O. 692 278. 561 27. 817 1207. 000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 14 * * * * FILE TRAILER * * * * FILE NAME '. EDIT .003 SERVICE . FLIC VERSION . O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE '. LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE - 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SU~k~&RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9224 . 0 8990.0 RST 9237.5 8991 . 5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH RST 88888.0 88886.0 88888.5 9230.0 9230.5 9220.5 9218.5 9213.0 9216.0 9207.0 9206.0 9209.5 9201.0 9203.5 9200.5 9200.0 9199.5 9201.0 9191.0 9194.0 9187.0 9187.0 9184.5 9187.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 15 9183.0 9178.0 9174.0 9171.5 9163.0 9160.5 9159.5 9154.0 9152.5 9148.5 9144.5 9144.0 9141.0 9139.5 9138.5 9135.0 9134.5 9130.0 9128.5 9128.0 9125.5 9124.5 9121.5 9115.5 9115.0 9112.0 9111.0 9108.5 9107.5 9105.5 9105 0 91 O1 0 9098 0 9096 5 9091 0 9089 5 9088 0 9084 5 9084 0 9080 5 9076.0 9071.0 9068.0 9064.5 9064.0 9062.0 9059.5 9057.5 9049.0 9046.0 9044.5 9042.5 9041.5 9038.0 9037.0 9175.0 9162.5 9160.0 9154.0 9149.5 9145.0 9140.5 9135.5 9129.5 9125.5 9122.0 9116.0 9112.5 9108.5 9106.0 9098.0 9091.0 9089.0 9084.5 9077.0 9072.5 9065.0 9059.5 9047.5 9045.0 9043.0 9038.5 9185.0 9180.0 9173.0 9161.0 9154.0 9145.0 9141.5 9139.5 9135.5 9131.5 9129.0 9125.5 9116.0 9113.0 9109.0 9106.0 9103.0 9098.0 9091.0 9086.0 9081.5 9077.5 9069.5 9065.0 9063.5 9061.0 9058.5 9050.0 9042.5 9038.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 16 9035.5 9036.0 9034.5 9035.5 9032.0 9032.5 9029.0 9030.0 9028.0 9028.0 9027.0 9028.0 9025.0 9025.0 9023.0 9024.0 9021.0 9022.0 9022.0 9017.0 9017.5 9016.0 9017.0 9013.5 9013.5 9012.0 9013.5 9009.0 9010.5 9000.5 9000.5 9000.0 9002.0 8997.5 8996.5 8995.5 8997.0 8992.5 8992.5 100.0 100.0 101.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 17 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRST PPK 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RST CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST CU 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARST 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1208475 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9237.500 NBAC.RST 2654.370 FBAC.RST 3507.004 SBNA.FIL SFNA.FIL 26.138 SBFA.FIL 87.291 SFFA.FIL 24.052 TRAT. FIL IRAT.FIL 0.580 CIRN. FIL 0.297 CIRF. FIL 0.749 BSAL.RST SIBF.RST 128.490 TPHI.RST 19.105 SFFC. RST 25.346 SFNC.RST SIGM.RST 25.117 DSIG.RST 1.687 GRCH. RST -999.250 TENS.RST CCL.RST 0.000 CRRA.RST 1.708 FBEF.RST 57.955 DEPT. 8990.000 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBFoRST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST CCL.RST -999.250 CRRA.RST -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 101.504 0.685 262.067 27.040 1157.000 FBAC.RST -999.250 SBNA.FIL -999.250 SFFA.FIL -999.250 TRAT.FIL -999.250 CIRF. FIL -999.250 BSAL.RST -999.250 SFFC.RST -999.250 SFNC.RST -999.250 GRCH.RST 59.596 TENS.RST -999.250 FBEF.RST -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 18 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9225.0 8992.0 RST 9237.5 8991.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH RST 88888.0 88887.0 88888.5 9233.0 9233.5 9226.5 9228.0 9222.0 9224.5 9220.0 9219.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 19 9218.5 9213.0 9209.5 9207.0 9206.5 9205.0 9201.0 9200.0 9199.5 9193.5 9191.0 9186.0 9182.5 9175 5 9171 5 9170 0 9164 5 9153 5 9152 5 9151 5 9144 0 9138 0 9135 0 9134 0 9131 5 9128 5 9127 5 9125 0 9124 0 9123.5 9118.5 9115.5 9115.0 9113.0 9112.5 9108.0 9107.0 9104.0 9102.0 9101.0 9097.0 9096.5 9094.5 9090.5 9089.5 9087.5 9081.0 9O8O. 0 9076.5 9075.5 9073.0 9067.5 9064.5 9063.5 9057.0 9206.0 9200.0 9196.0 9187.0 9175.0 9171.0 9164.5 9154.0 9152.5 9145.0 9139.0 9135.5 9132.5 9129.5 9125.5 9123.5 9119.5 9116.0 9112.5 9108.5 9105.0 9103.0 9098.5 9095.5 9091.0 9088.5 9081.0 9077.0 9068.0 9065.0 9221.5 9216.0 9212.0 9209.5 9208.0 9203.5 9201.5 9194.0 9185.0 9173.0 9153.5 9135.0 9129.5 9125.5 9116.0 9115.0 9109.0 9103.5 9098.0 9091.0 9081.5 9077.5 9075.0 9065.0 9058.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 2O 9055.5 9049.0 9048.0 9046.0 9041.5 9037.5 9037.0 9034 5 9033 0 9030 5 9028 5 9027 0 9023 0 9021 5 9013 0 9012 0 9011 0 9003 0 9000 5 8994 0 100 0 $ 9054.5 9050.0 9047.5 9038.5 9034.5 9032.0 9028.0 9022.0 9013.5 9012.0 9005.0 9001.0 8996.0 102.0 9050.0 9042.5 9039.0 9035.5 9028.0 9024.5 9013.5 101.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 21 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1208475 NBAC RST CPS 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 BSALRST PPK 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RST CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RST PU-S 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RST CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RST CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM RST CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RST CU 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 TENS RST LB 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 CCL RST V 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA RST 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RST UA 1208475 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9237.500 NBAC.RST 2726.868 FBAC. RST 3418.539 SBNA.FIL SFNA.FIL 23.744 SBFA.FIL 83.240 SFFA.FIL 22.935 TRAT. FIL IRAT. FIL 0.574 CIRN. FIL 0.292 CIRF. FIL 0.748 BSAL.RST SIBF.RST 124.377 TPHI.RST 18.142 SFFC.RST 23.950 SFNC. RST SIGM. RST 23.892 DSIG.RST 1.944 GRCH.RST -999.250 TENS.RST CCL.RST 0.008 CRRA.RST 1.686 FBEF.RST 58.390 DEPT. 8991.500 NBAC.RST 2539.711 FBAC.RST 3451.382 SBNA.FIL SFNA.FIL 13.664 SBFA.FIL 69.056 SFFA.FIL 13.627 TRAT. FIL IRAT. FIL 0.523 CIRN. FIL 0.749 CIRF. FIL 2.155 BSAL.RST SIBF. RST 103.195 TPHI.RST 15.917 SFFC. RST 13.699 SFNC.RST SIGM. RST 13.666 DSIG.RST 0.027 GRCH.RST -999.250 TENS.RST CCL.RST 0.003 CRRA.RST 1.936 FBEF. RST 55.811 100.315 0.674 253.677 24.449 1150.000 101.210 0.666 208.204 13.748 1090.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 22 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE - FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE · 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, RST $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC RST CPS 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC RST CPS 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT RSAV 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT RSAV 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNRSAV 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF RSAV 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL RSAV PPK 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI RSAV PU-S 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG RSAV CU 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF RSAV UA 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA RSAV 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH RST GAPI 1208475 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 24 DEPT. 9241. 000 NBAC. RST 2458. 933 FBAC. RST 3346. 063 SBNA. RSAV SFNA.RSAV 20. 789 SBFA.RSAV 31. 633 SFFA.RSAV 18. 422 TRAT.RSAV IRAT. RSAV O. 589 CIRN. RSAV 1 . 481 CIRF. RSAV 2. 608 BSAL. RSAV SIBF. RSAV 9.235 TPHI.RSAV 20.565 SFFC.RSAV 16.942 SFNC.RSAV SIGM. RSAV 17.125 DSIG. RSAV 1 . 566 FBEF. RSAV 58.538 CRRA. RSAV GRCH. RST -999. 250 41. 238 O. 965 -38. 980 18. 711 1. 705 DEPT. 8991.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 I~T.RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CRRA.RSAV -999.250 GRCH.RST 20.468 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE . FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH RST 9270.5 8935.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 25 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 25-MAY-98 8Cl-205 2159 25-MAY-98 9255.0 9260.0 8990.0 9237.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~A RAY RST RESERVOIR SATURATION TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 7.000 9420.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OI.L ZONE TOP NORMALIZING WINDOW (FT) .. BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN SCHLUMBERGER BHC LOG OF SEPT. 6,1982 SEAWATER PASSES #1 & #2 DID NOT REPEAT SEAWATER PASSES #3 & #4 REPEATED WELL LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 26 Ail SEAWATER PASSES WERE WITH FLOWRATE OF 1 BPM BORAX PASSES #1, #2, #3 WERE RUN WITH A FLOWRATE OF 1 BPM NOTE: ONLY BO~ PASS #3 WAS LOGGED TO 8900' SINCE WE HAD TROUBLE GETTING PAST THE GO-NO GO NIPPLE. PUMPING SUMMARY: 470 BBL OF SEAWATER WERE PUMPED 140 BBL OF BORAX WERE PUMPED CHASED BY 150 BBL OF CRUDE FOLLOWED BY 100 BBL OF DIELSEL FOR CLEANUP. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS1 F/HR 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS1 LB 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 NPHV PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PSl V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS1 S 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CHV PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PSl V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 FPHV PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS1 S 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS1 PSIG 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS1 UA 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS1 MA 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PSi UA 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS1 UA 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS1 UA 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS1 V 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 Ri&LC PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PSl MA 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS1 PPK 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS1 CU 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS1 CPS 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS1 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS1 CPS 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS1 CU 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS1 CU 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS1 CU 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS1 CU 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1208475 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center I2-AUG-1998 13:07 PAGE: 28 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFFA SIG CU 1208475 O0 SBNA SIG CU 1208475 O0 SBFA SIG CU 1208475 O0 SFNA FIL CU 1208475 O0 SFFA FIL CU 1208475 SBNA FIL CU 1208475 SBFA FIL CU 1208475 SIBF PS1 CU 1208475 SFNC PS1 CU 1208475 SFFC PS1 CU 1208475 SIGM PS1 CU 1208475 SIBF SIG CU 1208475 SIGM SIG CU 1208475 TRAT PS1 1208475 TRAT SIG 1208475 TRAT FIL 1208475 GR PS1 GAPI 1208475 RDIX PS1 1208475 CRNI PS1 KHZ 1208475 CRFI PS1 KHZ 1208475 RSCS PS1 1208475 CTM PS1 DEGC 1208475 XTM PS1 DEGC 1208475 TAV PS1 KV 1208475 FICU PS1 AMP 1208475 CACU PS1 AMP 1208475 BUST PS1 1208475 BUSP PSI 1208475 RSXS PS1 1208475 TPHI PSI PU 1208475 TPHI SIG PU 1208475 CCLC PS1 V 1208475 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 I I 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 i 1 4 68 0000000000 ** DATA ** DEPT. 9270.500 NPDE. PS1 1452.027 AQTM. PS1 0.661 CM2V. PS1 -12.231 RCAK. PS1 0.000 FSCE. PS1 2.013 HVPV. PSt 159.668 NBEF. PS1 33.536 BSTR.PS1 32.305 XPSV. PS1 5.089 RXLC. PS1 0.000 BSAL.PS1 -999.250 CIRN. FIL -999.250 IRAT. PS1 -999.250 CS.PS1 1764.706 TENS.PS1 921.000 NPHV. PS1 NSCE. PS1 2.851 CRRA.PS1 1.682 NSCR.PS1 CHV. PS1 200.854 CPSV. PS1 5.069 CP2V. PS1 RCFR.PS1 0.000 RCLC. PSl 0.000 RCRC. PS1 RTDF. PS1 0.000 FPHV. PS1 1389.161 FPDE. PS1 FSCR.PS1 0.032 AQTF. PS1 0.661 SF6P. PS1 BMCU. PS1 38.086 GDCU. PSl 60.996 EXCU. PS1 FBEF. PS1 56.404 NPGF. PS1 0.991 FPGF. PS1 BSPR.PS1 1.100 MARC. PSi 0.000 XHV. PS1 XP2V. PS1 12.129 Aff42V. PS1 -12.387 RXFR.PS1 RXRC. PSI 0.000 ~.PS1 0.000 SHCU. PS1 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRF. FIL -999.250 DSIG.PS1 -999.250 FBAC. PS1 IRAT. FIL -999.250 NBAC. PS1 -999.250 SFNA. PS1 1477.052 0.063 12.173 0.000 1370.813 149.050 4.340 1.000 200.370 0.000 25.365 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 29 SFFA.PS1 -999.250 SBNA.PS1 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS1 -999.250 SFFC. PS1 SIGM. SIG -999.250 TRAT.PS1 GR.PS1 13.561 RDIX. PS1 RSCS.PS1 8459.000 CTM. PS1 FICU. PSi 2.417 CACU. PS1 RSXS.PS1 8878.000 TPHI.PS1 DEPT. 8935.500 CS. PS1 NPDE. PS1 1455.613 NSCE. PS1 AQTM. PS1 1.322 CHV. PS1 CM2V. PS1 -12.240 RCFR.PS1 RCAK. PS1 2.000 RTDF. PS1 FSCE. PS1 2.001 FSCR.PS1 HVPV. PS1 159.749 BMCU. PS1 NBEF. PS1 28.976 FBEF. PS1 BSTR.PS1 42.216 BSPR.PS1 XPSV. PS1 5.075 XP2V. PS1 RXLC. PS1 0.000 RXRC. PS1 BSAL.PS1 4.341 BSAL.SIG CIRN. FIL 1.300 CIRF. FIL IRAT. PS1 0.525 IRAT. FIL SFFA.PS1 15.208 SBNA. PSi SFFA.SIG 0.203 SBNA.SIG SFFA.FIL 15.073 SBNA.FIL SFNC. PS1 12.824 SFFC. PS1 SIGM. SIG 0.156 TRAT. PS1 GR.PS1 27.034 RDIX. PS1 RSCS.PS1 8463.000 CTM. PS1 FICU. PS1 2.405 CACU. PS1 RSXS. PS1 8878.000 TPHI.PS1 -999.250 SBFA.PS1 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS1 -999.250 TRAT.SIG 384796.000 CRNI.PS1 66.406 XTM. PS1 2.515 BUST. PSi -999.250 TPHI.SIG 1779.243 TENS.PSi 2.876 CRRA.PS1 200.370 CPSV. PS1 0.000 RCLC. PS1 0.000 FPHV. PS1 -0.144 AQTF. PS1 35.429 GDCU. PS1 56.536 NPGF. PS1 1.107 MARC. PSi 12.123 XM2V. PS1 0.000 RXAK.PS1 2.674 CIRN. PS1 3.043 DSIG.PS1 0.528 NBAC. PS1 51.186 SBFA.PSl 2.847 SBFA.SIG 50.624 SBFA.FIL 12.822 SIGM. PS1 0.814 TRAT. SIG 393918.000 CRNI.PS1 68.848 XT~.PS1 2.508 BUST. PSI 15.491 TPHI.SIG -999.250 -999.250 -999.250 -999.250 -999.250 447.605 66.406 3.000 -999.250 1198 1 5 0 1396 1 59 1 0 -12 1 1 0 2430 45 3 42 12 0 450 66 3 0 000 951 069 000 485 322 859 001 000 374 000 295 318 044 039 468 951 816 010 471 927 000 413 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 TAV. PS1 BUSP. PS1 CCLC. PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 TAV. PS1 BUSP.PS1 CCLC. PS1 -999.250 -999.250 -999.250 -999.250 -999.250 266.133 94.888 3.000 0.029 1480.714 0.071 12.165 0.000 1372.720 150.073 6. 365 O. 996 200. 127 0.000 27.642 3.005 3248.053 17.631 0.266 17.494 23.643 0.917 0.811 230.879 95.060 3.000 -999.250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 3O **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 9267.5 $ LOG HEADER DATA STOP DEPTH 8937.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 25-MAY-98 8Cl -205 2159 25-MAY-98 9255.0 9260.0 8990.0 9237.0 TOOL NUMBER CGRS-A RST-A 7.000 9420.0 PRODUCED FLUIDS 9.00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 31 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN SCHLUMBERGER BHC LOG OF SEPT. 6, 1982 SEAWATER PASSES #1 & #2 DID NOT REPEAT SEAWATER PASSES #3 & #4 REPEATED WELL Ail SEAWATER PASSES WERE WITH F~OWRATE OF 1 BPM BORAX PASSES #1,#2,#3 WERE RUN WITH A FLOWRATE OF 1 BPM NOTE: ONLY BORA~ PASS #3 WAS LOGGED TO 8900' SINCE WE HAD TROUBLE GETTING PAST THE GO-NO GO NIPPLE. PUMPING SUMMARY: 470 BBL OF SEAWATER WERE PUMPED 140 BBL OF BORAX WERE PUMPED CHASED BY 150 BBL OF CRUDE FOLLOWED BY 100 BBL OF DIELSEL .FOR CLEANUP. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE 32 TYPE REPR CODE VALUE 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS2 F/HR 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS2 LB 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS2 S 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RCAK PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS2 S 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS2 PSIG 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS2 UA 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS2 MA 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS2 UA 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS2 UA 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS2 UA 1208475 O0 000 O0 0 8 '1 1 4 68 0000000000 NPGF PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 33 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) XPSV PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 X~2V PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS2 MA 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS2 PPK 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CIRN PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CIRN FIL 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS2 CPS 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS2 CPS 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA FIL CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA FIL CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFNC PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS2 CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF SIG CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM SIG CU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 TR_AT SIG 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT FIL 1208475 O0 000 O0 0 8 1 I 4 68 0000000000 GR PS2 GAPI 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RDIX PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS2 KHZ 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS2 KHZ 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RSCS PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS2 DEGC 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS2 DEGC 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 TAV PS2 KV 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS2 AMP 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CACU PS2 AMP 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 34 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BUSP PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS2 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS2 PU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS2 V 1208475 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 9267.500 CS.PS2 1734.104 TENS.PS2 812.000 NPHV. PS2 NPDE. PS2 1455.766 NSCE. PS2 2.888 CRRA.PS2 1.626 NSCR.PS2 AQTM. PS2 0.661 CHV. PS2 201.096 CPSV. PS2 5.040 CP2V. PS2 CM2V. PS2 -12.250 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 1398.927 FPDE. PS2 FSCE. PS2 1.970 FSCR.PS2 0.192 AQTF. PS2 0.661 SF6P. PS2 HVPV. PS2 160.156 BMCU. PS2 40.429 GDCU. PS2 59.028 EXCU. PS2 NBEF. PS2 34.213 FBEF. PS2 55.630 NPGF. PS2 0.999 FPGF. PS2 BSTR.PS2 33.977 BSPR.PS2 1.095 MARC. PS2 0.000 XHV. PS2 XPSV. PS2 5.079 XP2V. PS2 12.129 X~2V. PS2 -12.368 RXFR.PS2 RXLC. PS2 0.000 RXRC. PS2 0.000 RXAK. PS2 0.000 SHCU. PS2 BSAL.PS2 -999.250 BSAL. SIG -999.250 CIRN. PS2 -999.250 CIRF. PS2 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS2 -999.250 FBAC. PS2 IRAT. PS2 -999.250 IRAT.FIL -999.250 NBAC. PS2 -999.250 SFNA.PS2 SFFA.PS2 -999.250 SBNA.PS2 -999.250 SBFA.PS2 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS2 SFNC. PS2 -999.250 SFFC. PS2 -999.250 SIGM. PS2 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. PS2 -999.250 TRAT. SIG -999.250 TRAT. FIL GR.PS2 144.779 RDIX. PS2 395728.000 CRNI.PS2 460.440 CRFI.PS2 RSCS. PS2 8463.000 CTM. PS2 69.824 XTM. PS2 67.383 TAV. PS2 FICU. PS2 2.388 CACU. PS2 2.515 BUST. PS2 3.000 BUSP. PS2 RSXS. PS2 8878.000 TPHI.PS2 -999.250 TPHI.SIG -999.250 CCLC. PS2 DEPT. 8937.000 CS.PS2 1824.144 TENS.PS2 1153.000 NPHV. PS2 NPDE. PS2 1456.834 NSCE. PS2 2.870 CRRA.PS2 1.967 NSCR.PS2 AQTM. PS2 1.102 CHV. PS2 200.854 CP5V. PS2 5.055 CP2V. PS2 CM2V. PS2 -12.201 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 1394.044 FPDE. PS2 FSCE. PS2 2.044 FSCR.PS2 0.053 AQTF. PS2 1.102 SF6P. PS2 HVPV. PS2 159.945 BMCU. PS2 35.859 GDCU. PS2 60.077 EXCU. PS2 NBEF. PS2 29.100 FBEF. PS2 57.245 NPGF. PS2 1.000 FPGF. PS2 BSTR.PS2 45.237 BSPR.PS2 1.094 MARC. PS2 0.000 XHV. PS2 XPSV. PS2 5.078 XP2V. PS2 12.129 XM2V. PS2 -12.372 RXFR.PS2 RXLC. PS2 0.000 RXRC. PS2 0.000 RXAK. PS2 0.000 SHCU. PS2 BSAL.PS2 3.562 BSAL.SIG 2.717 CIRN. PS2 1.323 CIRF. PS2 CIRN. FIL 1.342 CIRF. FIL 3.101 DSIG. PS2 0.568 FBAC. PS2 IRAT. PS2 0.548 IRAT. FIL 0.546 NBAC. PS2 2677.362 SFNA.PS2 SFFA.PS2 13.557 SBNA.PS2 53.923 SBFA. PS2 42.640 SFNA.SIG SFFA.SIG 0.163 SBNA.SIG 4.078 SBFA.SIG 3.241 SFNA.FIL SFFA.FIL 13.741 SBNA.FIL 52.930 SBFA.FIL 41.144 SIBF. PS2 1481 0 12 0 1373 150 5 l 200 0 25 -999. -999. -999. -999. -999 -999 -999 -999 283 94 3 0 1485 0 12 0 1374 150 6. .'1 200 0 28 3 3379 16 0 16 23 935 143 143 000 101 329 129 005 127 000 040 250 250 250 25O 25O 250 250 250 173 888 000 019 597 231 187 000 017 739 786 004 256 000 617 124 002 277 348 612 376 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 35 SFNC. PS2 11.578 SFFC. PS2 SIGM. SIG 0.150 TRAT. PS2 GR.PS2 24.179 RDIX. PS2 RSCS.PS2 8463.000 CTM. PS2 FICU. PS2 2.359 CACU. PS2 RSXS.PS2 8878.000 TPHI.PS2 11 283 0 792 404491 000 68 604 2 508 14 238 SIGM. PS2 TRAT. SIG CRNI.PS2 XTM. PS2 BUST. PS2 TPHI.SIG 11.439 SIBF. SIG 0.010 TRAT. FIL 452.446 CRFI.PS2 66.895 TAV. PS2 3.000 BUSP. PS2 0.397 CCLC. PS2 0.931 0.786 230.000 94.993 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUI~ViARY VENDOR TOOL CODE START DEPTH RST 9269.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 8936.5 25-MAY-98 8Cl -205 2159 25-MAY-98 9255.0 9260.0 8990.0 9237.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 36 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAiV~IA RAY RST RESERVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 7.000 9420.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN SCHLUMBERGER BHC LOG OF SEPT. 6, 1982 SEAWATER PASSES #1 & #2 DID NOT REPEAT SEAWATER PASSES #3 & #4 REPEATED WELL All SEAWATER PASSES WERE WITH FLOWRATE OF 1 BPM BORAX PASSES #1,#2,#3 WERE RUN WITH A FLOWRATE OF 1 BPM NOTE: ONLY BORAX PASS #3 WAS LOGGED TO 8900' SINCE WE HAD TROUBLE GETTING PAST THE GO-NO GO NIPPLE. PUMPING 470 BBL OF SEAWATER WERE PUMPED 140 BBL OF BORAX WERE PUMPED CHASED BY 150 BBL OF CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 37 FOLLOWED BY 100 BBL OF DIELSEL .FOR CLEANUP. THIS FILE CONTAINS THE RAW DATA FOR BORJLY PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CS BX1 F/HR 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 TENS BX1 LB 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVBX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMBX1 S 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CHV BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RCAK BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 38 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) RTDF BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVBX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF BX1 S 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P BX1 PSIG 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU BX1 UA 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU BX1 MA 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU BX1 UA 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF BX1 UA 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF BX1 UA 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 MARC BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 XHV BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV BXI V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 X~2V BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKBX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU BX1 MA 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL BX1 PPK 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CIR1VBX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC BX1 CPS 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT BX1 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC BX1 CPS 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13~07 PAGE: 39 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFNC BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 SFFC BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 SIGM BX1 CU 1208475 O0 000 O0 0 9 1 1 4 68 SIBF SIG CU 1208475 O0 000 O0 0 9 1 1 4 68 SIGM SIG CU 1208475 O0 000 O0 0 9 1 1 4 68 TRAT BX1 1208475 O0 000 O0 0 9 1 1 4 68 TRAT SIG 1208475 O0 000 O0 0 9 1 1 4 68 TRAT FIL 1208475 O0 000 O0 0 9 1 1 4 68 GR BX1 GAPI 1208475 O0 000 O0 0 9 1 1 4 68 RDIX BX1 1208475 O0 000 O0 0 9 1 1 4 68 CRNI BX1 KHZ 1208475 O0 000 O0 0 9 1 1 4 68 CRFI BX1 KHZ 1208475 O0 000 O0 0 9 1 1 4 68 RSCS BX1 1208475 O0 000 O0 0 9 1 1 4 68 CTM BX1 DEGC 1208475 O0 000 O0 0 9 1 1 4 68 XTM BX1 DEGC 1208475 O0 000 O0 0 9 1 1 4 68 TAV BX1 KV 1208475 O0 000 O0 0 9 1 1 4 68 FICU BX1 AMP 1208475 O0 000 O0 0 9 1 1 4 68 CACU BX1 AMP 1208475 O0 000 O0 0 9 1 1 4 68 BUST BX1 1208475 O0 000 O0 0 9 1 1 4 68 BUSP BX1 1208475 O0 000 O0 0 9 1 1 4 68 RSXS BX1 1208475 O0 000 O0 0 9 1 1 4 68 TPHI BX1 PU 1208475 O0 000 O0 0 9 1 1 4 68 TPHI SIG PU 1208475 O0 000 O0 0 9 1 1 4 68 CCLC BX1 V 1208475 O0 000 O0 0 9 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9269.000 CS.BX1 NPDE. BX1 1447.259 NSCE.BX1 AQTM. BX1 0.661 CHV. BX1 CM2V. BX1 -12.250 RCFR.BX1 RCAK. BX1 0.000 RTDF.BX1 FSCE.BX1 2.024 FSCR.BX1 HVPV. BX1 159.424 BMCU. BX1 NBEF. BX1 32.827 FBEF.BX1 BSTR.BX1 28.177 BSPR.BX1 XPSV. BX1 5.069 XP2V. BX1 RXLC.BX1 0.000 RXRC.BX1 BSAL.BX1 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF.FIL IRAT. BX1 -999.250 IRAT.FIL SFFA.BX1 -999.250 SBNA.BX1 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC.BX1 -999.250 SFFC.BX1 SIGM. SIG -999.250 TRAT. BX1 GR.BX1 32.904 RDIX.BX1 RSCS.BX1 8463.000 CTM. BX1 FICU. BX1 2.427 CACU. BX1 1829.268 2.771 201.096 0.000 0.000 -0.771 37 500 56 206 0 931 12 129 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999250 424567000 62012 2.520 TENS.BX1 CRRA.BX1 CPSV. BX1 RCLC.BX1 FPHV. BX1 AQTF. BX1 GDCU. BX1 NPGF. BX1 MARC. BX1 X~2 V. BX1 RXAK. BX1 CIRN. BX1 DSIG.BX1 NBAC. BX1 SBFA.BX1 SBFA.SIG SBFA.FIL SIGM. BX1 TRAT. SIG CRNI. BX1 XTM. BXI BUST. BX1 860.000 1.712 5.060 0.000 1389.161 0.661 59.684 0.988 0.000 -12.368 0.000 -999.250 -999.250 -999.250 -999.250 ~999 250 -999 250 -999 250 ~999 250 452 115 59 570 3 000 NPHV. BX1 NSCR.BX1 CP2V. BX1 RCRC. BX1 FPDE. BX1 SF6P. BX1 EXCU. BX1 FPGF. BX1 XHV. BX1 RXFR.BX1 SHCU. BX1 CIRF. BX1 FBAC. BX1 SFNA.BX1 SFNA.SIG SFNA.FIL SIBF. BX1 SIBF. SIG TRAT. FIL CRFI.BX1 TAV. BX1 BUSP.BX1 1472 169 0 861 12 173 0 000 1369 210 147 003 4 734 1 005 200.127 0.000 33.820 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 264.058 95.031 3.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE 4O RSXS.BX1 8878.000 TPHI.BX1 DEPT. 8936.500 CS.BX1 NPDE.BX1 1452.294 NSCE. BX1 AQTM. BX1 0.661 CHV. BX1 CM2V. BX1 -12.250 RCFR.BX1 RCAK.BX1 0.000 RTDF. BX1 FSCE.BX1 2.068 FSCR.BX1 HVPV. BX1 159.636 BMCU. BX1 NBEF.BX1 28.544 FBEF. BX1 BSTR.BX1 40.102 BSPR.BX1 XPSV. BX1 5.075 XP2V. BX1 RXLC.BX1 0.000 RXRC. BX1 BSAL.BX1 210.155 BSAL.SIG CIRN. FIL 0.779 CIRF. FIL IRAT.BX1 0.538 IRAT. FIL SFFA.BX1 12.363 SBNA.BX1 SFFA.SIG 0.268 SBNA.SIG SFFA.FIL 12.382 SBNA.FIL SFNC. BX1 12.747 SFFC. BX1 SIGM. SIG 0.164 TRAT. BX1 GR.BX1 19.504 RDIX.BX1 RSCS.BX1 8463.000 CTM. BX1 FICU. BX1 2.352 CACU. BX1 RSXS.BX1 8878.000 TPHI.BX1 -999.250 TPHI.SIG 1774 889 2 889 200 612 0 000 0 000 -0 117 35 468 56.217 0 977 12 111 0 000 3 288 2 265 0 535 94 4OO 4 095 96.820 12 454 0 634 433531 000 61 523 2 513 14 479 TENS.BX1 CRRA.BX1 CPSV. BX1 RCLC.BX1 FPHV. BX1 AQTF.BX1 GDCU. BX1 NPGF. BX1 MARC.BX1 X~I2V. BX1 RXAK. BX1 CIRN. BX1 DSIG.BX1 NBAC.BX1 SBFA.BX1 SBFA.SIG SBFA.FIL SIGM. BX1 TRAT. SIG CRNI.BX1 XTM. BX1 BUST.BX1 TPHI.SIG -999.250 1142.000 1.969 5.060 0.000 1389.161 0.661 60.077 1.003 0.000 -12.381 0.000 0.774 0.274 2654.011 66.933 5.836 67.394 12.501 0.011 453.098 60.059 3.000 0.337 CCLC. BX1 NPHV. BX1 NSCR.BX1 CP2V. BX1 RCRC. BX1 FPDE. BX1 SF6P. BX1 EXCU. BX1 FPGF. BX1 XHV. BX1 RXFR.BX1 SHCU. BX1 CIRF. BX1 FBAC.BX1 SFNA.BX1 SFNA.SIG SFNA.FIL SIBF. BX1 SIBF. SIG TRAT. FIL CRFI.BX1 TAV. BX1 BUSP. BX1 CCLC. BX1 O. 019 1477. 052 -0. 010 12. 173 O. 000 1370. 813 146. 867 6.549 1. 000 200. 127 O. 000 35. 555 2.217 3412. 188 12.296 O. 309 12. 609 104. 069 1. 475 O. 641 230. 063 94. 945 3. 000 - 999. 250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE · 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION · O01CO1 DATE · 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 41 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 9271.0 $ LOG HEADER DATA STOP DEPTH 8938.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) '. LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : 25-MAY-98 8Cl -205 2159 25-MAY-98 9255.0 9260.0 8990.0 9237.0 TOOL NUMBER CGRS-A RST-A 7.000 9420.0 PRODUCED FLUIDS 9.00 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 42 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS) '. TOOL STA1VDOFF (IN): REMARKS: TIED IN SCHLUMBERGER BHC LOG OF SEPT. 6,1982 SEAWATER PASSES #1 & #2 DID NOT REPEAT SEAWATER PASSES #3 & #4 REPEATED WELL Ail SEAWATER PASSES WERE WITH FLOWRATE OF 1 BPM BORAX PASSES #1, #2,#3 WERE RUN WITH A FLOWRATE OF 1 BPM NOTE: ONLY BORAX PASS #3 WAS LOGGED TO 8900' SINCE WE HAD TROUBLE GETTING PAST THE GO-NO GO NIPPLE. PUMPING SU~9~RY: 470 BBL OF SEAWATER WERE PUMPED 140 BBL OF BORAX WERE PUMPED CHASED BY 150 BBL OF CRUDE FOLLOWED BY 100 BBL OF DIELSEL FOR CLEANUP. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 43 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CS BX2 F/HR 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 TENS BX2 LB 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 NPHV BX2 V 1208475 O0 000 O0 0 10 1 I 4 68 0000000000 NPDE BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 NSCE BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CRRA BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 NSCR BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 AQTMBX2 S 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CHV BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CPSV BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CP2V BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CM2V BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RCFR BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RCLC BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RCRC BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RCAKBX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RTDF BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FPHVBX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FPDE BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FSCE BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FSCR BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 AQTF BX2 S 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SF6P BX2 PSIG 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 HVPV BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 BMCU BX2 UA 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 GDCU BX2 MA 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 EXCU BX2 UA 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 NBEF BX2 UA 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FBEF BX2 UA 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 NPGF BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FPGF BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 BSTR BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 BSPR BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 MARC BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 XHV BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 XPSV BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 XP2V BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 i~12VBX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RXFR BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RXLC BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RXRC BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RXAK BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SHCU BX2 MA 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 BSAL BX2 PPK 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 BSAL SIG PPK 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNBX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CIRF BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNFIL 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 44 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SgMP ELF_~ CODE (HEX) DSIG BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC BX2 CPS 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 IR~T FIL 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 NBAC BX2 CPS 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA SIG CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA SIG CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA SIG CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA SIG CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA FIL CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA FIL CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA FIL CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA FIL CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFNC BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SFFC BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM BX2 CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF SIG CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM SIG CU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 TROT SIG 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 TROT FIL 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 GR BX2 GAPI 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RDIX BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CRNI BX2 KHZ 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CRFI BX2 KHZ 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RSCS BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CTM BX2 DEGC 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 XTM BX2 DEGC 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 TAV BX2 KV 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 FICU BX2 AMP 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CACU BX2 AMP 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 BUST BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 BUSP BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 RSXS BX2 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI BX2 PU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI SIG PU 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 CCLC BX2 V 1208475 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 9271.000 CS.BX2 1796.407 TENS.BX2 852.000 NPHV. BX2 NPDE.BX2 1451.951 NSCE. BX2 2.877 CRRA.BX2 1.726 NSCR.BX2 AQTM. BX2 0.661 CHV. BX2 200.370 CPSV. BX2 5.079 CP2V. BX2 CM2V. BX2 -12.211 RCFR.BX2 0.000 RCLC.BX2 0.000 RCRC. BX2 1474.610 0.049 12.158 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE 45 RCAK. BX2 0.000 RTDF. BX2 FSCE. BX2 2.059 FSCR.BX2 HVPV. BX2 159.668 BMCU. BX2 NBEF. BX2 33.084 FBEF. BX2 BSTR.BX2 46.102 BSPR.BX2 XPSV. BX2 5.079 XP2V. BX2 RXLC.BX2 0.000 RXRC.BX2 BSAL.BX2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. BX2 -999.250 IRAT. FIL SFFA.BX2 -999.250 SBNA.BX2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. BX2 -999.250 SFFC.BX2 SIGM. SIG -999.250 TRAT. BX2 GR.BX2 155.947 RDIX. BX2 RSCS.BX2 8463.000 CTM. BX2 FICU. BX2 2.417 CACU. BX2 RSXS.BX2 8878.000 TPHI.BX2 DEPT. 8938.500 CS.BX2 NPDE.BX2 1453.706 NSCE.BX2 AQTM. BX2 1.102 CHV. BX2 CM2V. BX2 -12.240 RCFR.BX2 RCAK.BX2 0.000 RTDF. BX2 FSCE.BX2 2.002 FSCR.BX2 HVPV. BX2 159.831 BMCU. BX2 NBEF.BX2 28.834 FBEF. BX2 BSTR.BX2 42.693 BSPR.BX2 XP5V. BX2 5.077 XP2V. BX2 RXLC.BX2 0.000 RXRC.BX2 BSAL.BX2 206.309 BSAL.SIG CIRN. FIL 0.776 CIRF. FIL IRAT. BX2 0.531 IRAT. FIL SFFA.BX2 13.447 SBNA.BX2 SFFA.SIG 0.226 SBNA.SIG SFFA.FIL 12.999 SBNA.FIL SFNC.BX2 13.109 SFFC.BX2 SIGM. SIG 0.173 TRAT.BX2 GR.BX2 21.655 RDIX. BX2 RSCS.BX2 8463.000 CTM. BX2 FICU. BX2 2.378 CACU. BX2 RSXS.BX2 8878.000 TPHI.BX2 0.000 FPHV. BX2 -0.282 AQTF.BX2 40.722 GDCU. BX2 57.104 NPGF.BX2 0.982 MARC.BX2 12.129 X~2V. BX2 0.000 RXAK.BX2 -999.250 CIRN. BX2 -999.250 DSIG.BX2 -999.250 NBAC.BX2 -999.250 SBFA.BX2 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. BX2 -999.250 TRAT. SIG 434866.000 CRNI.BX2 61.523 XTM. BX2 2.520 BUST.BX2 -999.250 TPHI.SIG 1823.623 TENS.BX2 2.862 CRRA.BX2 200.612 CPSV. BX2 0.000 RCLC.BX2 0.000 FPHV. BX2 -0.388 AQTF.BX2 35.820 GDCU. BX2 54.327 NPGF.BX2 1.088 MARC.BX2 12.121 XM2V. BX2 0.000 RXAK.BX2 3.392 CIRN. BX2 2.277 DSIG.BX2 0.535 NBAC.BX2 96.467 SBFA.BX2 4.120 SBFA.SIG 95.509 SBFA.FIL 12.982 SIGM. BX2 0.642 TRAT. SIG 443702.000 CRNI.BX2 61.768 XTM. BX2 2.511 BUST. BX2 14.688 TPHI.SIG 1391.603 0.661 60.668 1.002 0.000 -12.368 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 445.555 59.570 3.000 -999.250 1128.000 1.884 5.074 0.000 1389.161 1.102 59.968 1.002 0.000 -12.373 0.000 0.757 -0.053 2603.130 71.375 4.478 78.120 12.949 0.011 451.667 60.872 3.000 0.353 FPDE. BX2 SF6P.BX2 EXCU. BX2 FPGF. BX2 XHV. BX2 RXFR. BX2 SHCU. BX2 CIRF.BX2 FBAC.BX2 SFNA.BX2 SFNA.SIG SFNA.FIL SIBF. BX2 SIBF. SIG TRAT. FIL CRFI.BX2 TAV. BX2 BUSP.BX2 CCLC.BX2 NPHV. BX2 NSCR.BX2 CP2V. BX2 RCRC. BX2 FPDE. BX2 SF6P.BX2 EXCU. BX2 FPGF. BX2 XHV. BX2 RXFR.BX2 SHCU. BX2 CIRF.BX2 FBAC.BX2 SFNA.BX2 SFNA.SIG SFNA.FIL SIBF. BX2 SIBF. SIG TRAT. FIL CRFI. BX2 TAV. BX2 BUSP.BX2 CCLC. BX2 1371.194 147.003 5.129 0.999 200.127 0.000 31.219 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 258.140 95.031 3.000 0.038 1474.610 0.185 12.165 0.000 1370.660 147.378 6.707 1.002 200.127 0.000 34.449 2.183 3303.933 13.868 0.352 13.141 102.349 1.512 0.645 239.725 95.031 3.000 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 46 **** FILE TRAILER **** FILE NAME : EDIT . O10 SERVICE - FLIC VERSION - O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE . FLIC VERSION . O01CO1 DATE . 98/08/12 MA3fREC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUB~4ARY VENDOR TOOL CODE START DEPTH RST 9265.0 $ LOG HEADER DATA STOP DEPTH 8824.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 25-MAY-98 8Cl -205 2159 25-MAY-98 9255.0 9260.0 8990.0 9237.0 TOOL NUMBER CGRS-A RST-A 7. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 47 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9420.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN SCHLUMBERGER BHC LOG OF SEPT. 6, 1982 SEAWATER PASSES #1 & #2 DID NOT REPEAT SEAWATER PASSES #3 & #4 REPEATED WELL All SEAWATER PASSES WERE WITH FLOWRATE OF 1 BPM BORAX PASSES #1, #2, #3 WERE RUN WITH A FLOWRATE OF 1 BPM NOTE: ONLY BORAX PASS #3 WAS LOGGED TO 8900' SINCE WE HAD TROUBLE GETTING PAST THE GO-NO GO NIPPLE. PUMPING SUMMARY: 470 BBL OF SEAWATER WERE PUMPED 140 BBL OF BORAX WERE PUMPED CHASED BY 150 BBL OF CRUDE FOLLOWED BY 100 BBL OF DIELSEL FOR CLEANUP. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13:07 PAGE: 48 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CS BX3 F/HR 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX3 LB 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 NPHVBX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 NPDE BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 NSCE BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CRRABX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 NSCR BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 AQTMBX3 S 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CHV BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CPSV BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CP2V BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CM2V BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RCFR BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RCLC BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RCRC BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RCAK BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RTDF BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FPHV BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FPDE BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FSCE BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FSCR BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 AQTF BX3 S 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SF6P BX3 PSIG 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 HVPV BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 BMCU BX3 UA 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 49 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GDCU BX3 MA 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 EXCU BX3 UA 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 NBEF BX3 UA 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FBEF BX3 UA 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 NPGF BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FPGF BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 BSTR BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 BSPR BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 MARC BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 XHV BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 XPSV BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 XP2V BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 X~2V BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 Ri~FR BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RXLC BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RXRC BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RXAK BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SHCU BX3 MA 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 BSAL BX3 PPK 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 BSAL SIG PPK 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNBX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CIRF BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNFIL 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CIRF FIL 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 DSIG BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX3 CPS 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT FIL 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 NBAC BX3 CPS 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA SIG CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA SIG CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA SIG CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA SIG CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA FIL CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA FIL CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA FIL CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA FIL CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFNC BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SFFC BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM BX3 CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF SIG CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM SIG CU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT SIG 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT FIL 1208475 O0 000 O0 0 1I 1 1 4 68 0000000000 GR BX3 GAPI 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 50 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RDIX BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CRNI BX3 KHZ 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CRFI BX3 KHZ 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RSCS BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CTM BX3 DEGC 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 XTM BX3 DEGC 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 TAV BX3 KV 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 FICU BX3 AMP 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CACU BX3 AMP 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 BUST BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 BUSP BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 RSXS BX3 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX3 PU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI SIG PU 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 CCLC BX3 V 1208475 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE.BX3 AQTM. BX3 CM2 V. BX3 RCAK. BX3 FSCE.BX3 HVPV. BX3 NBEF. BX3 BSTR.BX3 XPSV. BX3 RXLC.BX3 BSAL.BX3 CIRN. FIL IRAT.BX3 SFFA.BX3 SFFA.SIG SFFA.FIL SFNC.BX3 SIGM. SIG GR.BX3 RSCS.BX3 FICU. BX3 RSXS.BX3 DEPT. NPDE.BX3 AQTM. BX3 CM2V. BX3 RCAK.BX3 FSCE.BX3 HVPV. BX3 9265.000 1452.714 0.441 -12.231 0.000 1.962 160.156 35.587 59.596 5.069 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 332 235 8463 000 2 412 8878 000 8824 000 1452 562 1 322 -12 250 2 000 2 086 159 554 CS.BX3 1796.407 TENS.BX3 NSCE.BX3 2.871 CRRA.BX3 CHV. BX3 200.854 CPSV. BX3 RCFR.BX3 0.000 RCLC.BX3 RTDF. BX3 0.000 FPHV. BX3 FSCR.BX3 -0.450 AQTF. BX3 BMCU. BX3 39.550 GDCU. BX3 FBEF.BX3 61.821 NPGF. BX3 BSPR.BX3 1.057 MARC. BX3 XP2V. BX3 12.114 XN2V. BX3 RXRC.BX3 0.000 RXAK. BX3 BSAL.SIG -999.250 CIRN. BX3 CIRF. FIL -999.250 DSIG.BX3 IRAT. FIL -999.250 NBAC.BX3 SBNA.BX3 -999.250 SBFA.BX3 SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL SFFC.BX3 -999.250 SIGM. BX3 TRAT. BX3 -999.250 TRAT. SIG RDIX.BX3 445267.000 CRNI.BX3 CTM. BX3 61.523 XTM. BX3 CACU. BX3 2.510 BUST. BX3 TPHI.BX3 -999.250 TPHI.SIG CS.BX3 1757.307 TENS.BX3 NSCE.BX3 2.867 CRRA.BX3 CHV. BX3 200.854 CP5V. BX3 RCFR.BX3 0.000 RCLC.BX3 RTDF. BX3 0.000 FPHV. BX3 FSCR.BX3 0.304 AQTF. BX3 BMCU. BX3 33.691 GDCU. BX3 931 000 1 737 5 050 0 000 1389 161 0 441 59 684 1 000 0 000 -12 407 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 388.099 60.547 3.000 -999.250 1117.000 2.266 5.055 0.000 1391.603 1.322 60.034 NPHV. BX3 NSCR.BX3 CP2V. BX3 RCRC.BX3 FPDE. BX3 SF6P. BX3 EXCU. BX3 FPGF. BX3 XHV. BX3 RXFR.BX3 SHCU. BX3 CIRF. BX3 FBAC. BX3 SFNA.BX3 SFNA.SIG SFNA.FIL SIBF. BX3 SIBF. SIG TRAT. FIL CRFI.BX3 TAV. BX3 BUSP. BX3 CCLC.BX3 NPHV. BX3 NSCR.BX3 CP2V. BX3 RCRC. BX3 FPDE. BX3 SF6P.BX3 EXCU. BX3 1467.286 -0.050 12.143 0.000 1370.011 147.515 5.129 1.000 200.127 0.000 32.194 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 223.406 95.031 3.000 0.019 1474 610 0 114 12 158 0 000 1371 308 147 532 7 996 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 13: 07 PAGE: 51 NBEF. BX3 BSTR . BX3 XP5 V. BX3 RXLC. BX3 BSAL. BX3 CIRN. FIL IRA T. BX3 SFFA. BX3 SFFA. SIG SFFA. FIL SFNC. BX3 SIGM. SIG GR. BX3 RSCS. BX3 FICU. BX3 RSXS. BX3 26.112 66. 506 5. 078 O. 000 205. 643 O. 440 O. 432 16. 980 0 415 17 291 18 899 0 355 28 249 8463 000 2 347 8878. 000 FBEF. BX3 59.177 NPGF. BX3 BSPR. BX3 1 . 174 MARC. BX3 XP2V. BX3 12.119 J~I2V. BX3 RXRC. BX3 O. 000 RXAK. BX3 BSAL. SIG 7. 533 CIRN. BX3 CIRF. FIL 1. 522 DSIG. BX3 IRAT. FIL O. 433 NBAC. BX3 SBNA.BX3 91. 600 SBFA.BX3 SBNA. SIG 3. 577 SBFA. SIG SBNA. FIL 93. 063 SBFA. FIL SFFC.BX3 17.311 SIGM. BX3 TRAT. BX3 O. 660 TRAT. SIG RDIX. BX3 457289.000 CRNI.BX3 CTM. BX3 61 . 768 XTM. BX3 CACU. BX3 2. 508 BUST. BX3 TPHI.BX3 16.211 TPHI.SIG 1.005 FPGF. BX3 0.000 XHV. BX3 -12.365 RXFR.BX3 0.000 SHCU. BX3 0.432 CIRF. BX3 1.690 FBAC.BX3 2707.456 SFNA.BX3 73.070 SFNA.SIG 4.032 SFNA.FIL 73.570 SIBF. BX3 17.314 SIBF. SIG 0.015 TRAT. FIL 451.357 CRFI.BX3 61.165 TAV. BX3 3.000 BUSP. BX3 0.520 CCLC. BX3 1 200 0 37 1 3337 18 0 19 102 3 0 199. 94. 3. -999. 004 321 000 918 486 365 943 647 316 052 355 667 164 974 000 25O ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION . 001C01 DATE · 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN : FLIC TAPE NAME : 98395 CONTINUATION # : 1 PREVIOUS TAPE : COIv~ENT : ARCO ALASKA, DS 6-21, PRUDHOE BAY, API #50-029-20802-00 * * * * REEL TRAILER * * * * SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN : FLIC REEL NAME : 98395 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA, DS 6-21, PRUDHOE BAY, API #50-029-20802-00 ***************************** , .... -...-.------,--., LVP 010,f{02 VER][FtCATION LISTING PhGE SEPVlCE NA~E :EDIT' O~IO!h : REEL ~A~E g'72520 CONTI~.{~ATION ~ :C1 PREVIOU& REEL C{)~MF!~TS :EDIT L15,ARCO PRODHOE MAY P.$. ~-21,A{~I 5o-02g-208o2 ** TAPE HEADER SERVICE NA~E ;EDIT DATE :87/12/ 6 ORIGIN :7252 TAPE NAME CONTI~,ib ATION ~ PREVIO{}$ TAPE CO~ENTS :MDIT OI~,ARCU PRU[~HI]M MAY D.8. 5-21,APl 50-029-20802 * BIhE.HEADER ** FILE ~'~At~'P~ :EOIT ,00l SERVICE NAME : # : bENGT~! : 102,4 TYPE 1 PREVIOUS F'ILE ; ** INFORMATION RECORDS ** C~ % ARCO TOW!~ SECT.: 2 CO{..;~: ~ORTH ShOPE 000 00(} 018 065 000 00.0 O.i'O 06.5 000 000 012 0'65 000 O0-O..'004'. :0~'5 ouO o00 004 065 000~: 0'0.0 0...0..1 0.6.5 0 O0 00'0 012 065 ... 000. 000 0.06 · 065 000 00() 004 065 .. .... ...00.0. 0.00. 001 065. .. '( CO~PA~Y = ARCO ALASKA, APl ~ = 50-029-20802 FIELD : PRUDHOE BAY COUNTY : NORTH 8hOPE S'~ A'I' E : ALASKA dOB NI;~BER A3' AKCC: 7252o {{UN {~1 DATE L()GGED: [.,tOP: R ','[ C K CASIr,fG : 9,625" f~' 8H42 CASING = 7.0i' ~a 9420' 1UB.IN~ = 3.5" (a 8957' TYPE FLUIi) - PRODUC. kD FLU MATRIX: SANDS~,NE NOTE{ 1.) FILE I%. I2.001 CONTAINS C S{~,O HOhg Ci3MPENSATED NEUTRON DATA OF PASS 1 (P$1 PASS 2 (P$2), PASS 3 (PM3) AND HO[GES bEH~ANN 2.) FT[,F'; EDIT.O02 CONTAINS CASING COhLAR bOCAT~R DATA OF PASS 1, PASS 2, ******************************************************************************** , · SCHLUMBER(;,~R LOGS I~',~Ci, UDE{.) W1TH THIS MAGNET1C TAPE: · COb~P~NSATEt_) NEUTRON LOG - CASED HObE {3 PASSES) · PASS I (PSI) DATA AVAILABbE: 9350~ TO 8795' · PASS 2 (FS2) DATA AVAII~A~L,E: 9349' TO 8794' · PASS 3 (PS3) DATA AVAILABbE: 9349' TO 8965' R~]CORD ** TYPE SIZE REPR CODE ENTRY 2 1: 06 0 bVP Ola,H02 VgRiF.).CATiON [,[STii,iG PAGE 4 H 4 73 6 () l o i b6 1 0 t 66 0 DATU~ SPECIFICATION ~LOCKS ID OROER ~ bOG TYPE CLASS OEPT FT O0 000 O0 GR PS1 GAPI O0 310 ol ~PHI FS~ PU Ou ~90 O0 NRAT PSt O0 420 Ol R N N A P S ) 0 o u 00 ~CNL PS 1 CPS O0 3 ]o 3 FC~L PS1 CPS oo 330 3() TE~S PSI LB 0,) 635 GR PS2 GAP1 OD 3JO ~PHI PS2 PU O0 890 O0 RNRA P82 OD 000 O0 NC~L PS2 CPS O0 33o 31 FCNL PS2 CPM O0 330 30 TE~8 PS2 Lt~ 00 635 21 GR PS3 G~PI 00 31 0 0i ~PHI PSI FU oO 8g0 O0 NRAT PS3 O0 420 Ol 00 000 00 CP~ : O0 ~30' FC~L PS3 CPS O0 330 30 TENS PS:3 bB O0 635 21 NPMI HLA PU DO 8qO O0 REPR CODE 68 68 68 68 68 68 68 68 68 68 PROCESS ¢OCTAh) 00000000000000 00000000000000 00000o00000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 o000o000000000 00000000000000 0000o000000000 00000000000000 00000000000000 68 000000000000:00 b6 00000000000000 68:00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 000o0o00000000 6@ oo0ooooo000000 68 0o000000000000 ~8 O0000uO0000000 RNRA ' q9.9.25O0 NCNb ".GR '-:999',.2500 ~PMi '99.2500 FCNL <."~'"..NPH! : FCNL. -999,2500 TENS ... .. ... -999.2500 N. 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C:.Cb · · .... 0...0o00 CCh. · . ..:'.o...0o0o COb -999.250'0 CCh. ... · ":"FILE.~!A.M.E .:EDIT. ,0.02 SE~V1CE N A i~tE : 0,0000 0,0000 0,'0000 · .: .0.,0000 '..'999,2.5'.00 -.999,.2.500. -.999,2500 FI LE T¥ NEXT FILE ********** EDF *********.* ** TAPE TRAILER ** 5ERVICE NAmE :EDIT ¢ATE :8'1/12/ n ORIGIN :7252 TAPy '~NE CONTINUATION # :01 COMMENTS :EDIT bIS,ARCO PRUOHGE BAY D,$, 6-21,AP! 50-029-20802 REEL TRa, IIS}<R ** ORI(,It,~ ~/1 / ~S~:I.~_~f, ~172520 ~jEXT RE~;b ~A~E : CO'~MEi~:TS: :EDi~ bI~,ARCO PRUDBO. E BAY D,S,': 6:"21 5:0~029':2:0802 ' :' L'~ I~ l! I Ijl iI:] J! [~ i~ ~ LVP 010.H01 ¥}~RIFICSTIO~~ I,ISTTF~G ** REEL MFADER ** SERVICE NAME JSERVIC DATE :B2/09/13 ORIGIN ~ R~EL ~E :REEL ID CONTINUATION ~ :01 PREVIOUS REEL : COMMENTS :REEL CO~MEi~T$ ** TAPE HEADER SERVICE NAME DATE ORIG1N ~6555 CONTINUATION PREVIOUS TAPE : COMMENTS :TAPE COMMENTS EOF ** FILE HEADER Flbg NA~E :.SER¥IC,OOi SERVICE NAME VERSION # MAXIMUM L~N.GTH .: .102.4 FTL~ TYP~ PR~¥ I'OUS .. 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GR 68 i API 2 SPD 68 ! F/MM 3 TEN 68 ! LB 4 TTEN 68 ! LB 5 CLSN 68 1 CTS 6 CSSN 68 ! CTS 7 CN 68 1 PCT 8 CNC 68 1 PCT 9 CNRA 68 1 C/C !0 LSN 68 ! CTS t! SSN 68 ! CTS 12 CCL 68 ! VOLT BYTES 4 4 4 4 4 4 4 4 4 4 4 4 DATA P~CORD DEPTH CLSN' LSN 9346,000 0. 0000000E+00 0. 0000000E+00 (TYPE# 0) ~R CSSN~ SSN 0. 0000000E+00 50.00000 50.00000 994 BYTES * SPD CN CCL 0. 0000000E+00 0.0000000E+00 150,0000 9296. 000 53.61734 23.99760 11 ~ 84034 175. 7466 34. 88062 47 . 36134 175.7466 0 . 0000000E+00 9246,000 94.80266 17,21458 219.6873 68,85834 219.6873 9196.000 20.46033 23.14558 241.5506 92.58229 24!.5506 9146,000 29.39264 22.61313 239.1835 90.45251 239.!835 23.96190 27.76927 O.O000000E+00 23.99760 20.44826 0. 0000000E+O0 22.99770 20.88493 0.0000000E+00 9096~000 22.51103 23.40390 '28.64832 265,8931 !6.88625 114.5933 265.8931 0.0000000E+00 9046°000 36.20966 23,99760 25.51451 255,7034 19.16815 102.0581 255.7034 0.0000000E+00 8996~ 000 20. 32529 23. 99760 27. 10880 254o 1367 17. 17368 108 . 4352 254 . 1367 1 . 000000 TEN CNC -100.0000 0.0000000E+00 -12.10301 38.88062 -9.137192 31.76927 -13.90129 24,44826 -2.143541 24.88493 -29.76648 20.88625 -5,022131 23.168!5 -23.30200 21.17368 TTEN CNRA 0,0000000E+00 0.0000000E+00 10!7.012 O. 6737161E-01 1014.596 0.7835948E-01 1020.585 0.9582084E-01 1012.943 0.9454304E-0! 963.8489 0.1077437 1005.194 0.9978!69E-0! 976.5991 0.1066701 TOTAL. DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** 41 9346.00 ENDING TAPE DEPTH = 8962.00 FILE # 3 PASS 3.003 FILE HEADER 1024 * FORMAT-I~iECORD (TYPE# 64) ONE DEPTH PER PR.A_ME TAPE DEPTH UNIT : FT 12 CURVES : NAME CODE SAMPLE# UNIT BYTES ! GR 68 i API 4 2 SPD 68 ! F/~M 4 '3 TEN 68 1 LB 4 4 TTEN 68 1 LB 4 5 CLSN 68 1 CTS 4 6 CSSN 68 1 CTS 4 7 CN 68 1 PCT 4 8 CNC 68 ! PCT 4 9 CNRA 68 I C/C 4 !0 LSN 68 1 CTS 4 '' !! SSN 68 1 CTS 4 12 CCL 68 1 VOLT 4 DATA ~CORD (TYPE# O) 994 BYTES * DEPTH GR SPD CLSN CSSN CN LSN SSN CCL 9346.000 0.0000000E+00 0 0000000E+00 0.0000000E+00 50.00000 0.0000000E+00 O.O000000E+00 50.00000 150.0000 9296.000 52.64812 22.99770 11.37210 176.7689 37.52025 45.48840 176.7689 0.0000000E+00 9246.000 18.39398 73,57590 9196.000 23.64734 94.58934 9!46.000 21.70914 86.83655 9096.000 29. 02003 116.0802 95.82414 218~6448 218.6448 23.76!80 24.97400 ,0000000E+00 25.86778 244°4397 244.4397 23.99760 20.14124 0.0000000E+00 28.61729 244.8406 244.8406 23.99760 23.06419 4.000000 241.05411 267.81!5 267.8115 23.99760 16.72388 0.0000000E+00 TEN CNC -100.0000 O.O000000E+O0 -9.890846 41.52025 1.985551 28.97400 -39.90956 24.14124 -9.077717 27.06419 -23.77293 20.72388 TTEN CNRA 0.0000000E+00 0.0000000E+00 1002.542 0. 6433314E-01 1011.984 0.84!2725E-01 982.1709 0.9674!02E-01 1008.573 0.8866638E-01 965.4971 0.1083599 8996.000 - 19o54726 27.90166 253.5231 111.6066 253.5231 23~99760 16.28667 0.0000000E+00 -17.26697 20.28667 988.4331 0.!100557 TOTAL DATA RECORDS : STARTING TAPE DEPTH'= **** FILE TRAILER 41 9346.00 ENDING TAPE DEPTH = 8962.00 **** TAPE TPA%ILER **** LIS 89/09/14 3974 01 TOTAL RECORDS iN THIS LOGICAL TAPE : 135 **** REEL TRAILER LIS' g!091 ATLAS O1 TOTAL RECORDS IN'THIS LOGICAL REEL : 136 TOTAL RECORDS IN THIS PHYSIC.~L .REEL:' 136 End of execution~ Wed 20 SEP 89 2:36p Elapsed _xecutlon time = 28.72 seconds. SYSTEM .RETURN CODE = 0 * AbASKA CO~PL,ITING C~!]~,!TMR * * ****************************** * ..... -- $CMI, U~BERGER ...... -* ****************************** C[]~PANY NAME : ,~RC[~ AL~SKA INC, FIE[~,D NA~E : PRUDHOE BAY BOROUG}~ : NORTH 8hOPE STATE : A b,~$ K,a, API NUM~)ER : 5002920802 REF'E~EMCE NO ~ 75329 RECEIVED FEB 0 :~ 199~ 011 & G~ ¢~s. Oomml~io~ Anchorage LIS $chlU~>er<]er Alas~,a Co~rF;.utJ. ng Center 992 ! 1: 59 **** TAPE NEADER **** SERVICE {',iAi',!,E : EDIT DATE : 92/0!/ 3 OR ~C,I ~ : FLIC TAP~ ~A~E : 7~329 COt~TI~.~U~TIO~ ~ : ~ PREVI []~.~S TAPE : CON~ENT : ARCO ALASKA IL~C,PRUD~OE BAY,P.S. 6-21,500292080200 TAPE HEADER PPUD}-iOE BAY UNIT CASrP !,tOLE WiRELINE LOGS APl ~,~UNBER: OPERATOR: LOGGING CO~A~,~Y: T~P~ CREATION DAT~: JOB ~,.~L)~3gR: OPERATOR WIT~,~EMS: SURFACE LOCaTIO~ SECT'[ON: TOWNSHIP: RANGE: ~SL: WEL: EI,~EVATION(FT FRCJ~ ~SL O) K~LLY BUSHING: DERRICK FLOOR: GROI. IND LEVEL: W~LL CASING RECORD SURFACE LOCATIOn3 1ST STRIMG PRODUCTION STR!~G P.S, 6'2 ~ 5.0Z920802 ARCO ALASKA INC, SCHLD~BERGER ~JELL SERVICES 3-JAN-9~ 75329 G, $CM~ARTZ ALLEN 2O 960 467 74.00 73.00 37 · O0 OPE~'~ HOL~.~ CASING DRILLERS CASING BIT SIZE (IN) SIZE ¢I{~!) DEPTH fFT) ~VEIGHT (LB/MT) ''''''''''''' ';''~''''.. ,6 5 '';'''''''8 42.0 "':~'''''''''',7 7.000 9420,0 29,00 PAGE: LIS Ta~e verificatlor, Listlnq Scblu~erqer Alaska Cor~!~utir~ Cent~,r ~hSEL!~E C~RVE FO~~ SHIFTS L(]GGI~G CO~'~PANY: ~AKRI,,I ~E DEPTH GRCt~ ~ . 8.0 ~898 ~8887.0 9286,5 9285,5 g~77,5 9277,O 9258.5 9258,0 9250.5 9249.5 9228.5 Q227.5 9204,0 9203,0 9!80.0 9179,5 9~54.0 9~53,5 9~5],0 9~52,5 91.0~.5 9108.0 9~07.5 9040.5 9040.0 9038.5 9038.0 897~,5 8909 g909,0 I00,0 9g,5 g9.5 .......... F'{~UIVALE~IT tJ;;:!SnlFTED DEPTH .......... THE OPE~:{ HOLE DATA SUPPLIED BY THE CLIENT DTD NOT INCLUDE SUCH I~iF'OT~ATION AS: TOOl, CODE, R~.tt~ NUMBER, PASS ~,'1 u"{- ~,;G .. , , . ~J-.t.~]R, ~,OGGI DATA, Af~.;D LOGGI~G CO~'~PA~,~Y THE OPEN HOLE TAPF SUPPLIED BY THE CLIENT REFLECTED TWO TOOL 8~IRING8 I~qCLUDIN. G A SONIC, [)UA~ I~DUCTION, LOT AND CNL, THE C~JRVE5 INCLUDED THREE GA~-~A RAYS, AND ~'O NPHI CURVES. AFTER CONF~RRI~G ~ITH SUE WINFIELD THE GAM~A RAY FRO~ FILE 5 %~A6 SELECTED AS TNE BASE CURVE FOR TME SHIFTS. THE NP~I FRO~ ~NAT APPEARED TO BE THE MAiN C~L PASS k~AS {)SED TO SHIFT THE CASED HOLE NPHI. ~A'.IN CNL PASS wAS USED TO SHIFT THE CA~EO ~OLE NPHI. FIELD ENGINEEP CO~4NE~TS: TIED lgTO SWS BHCS DATED 6 SEP'82 ~g.[,~I,~ $~{UT-I~ PRIOR TO LOGG~,~G t~T 60:00 t, 1-4-91. 8IW~P : 2000 PSI. FL~JlD bEVEL FOU{'~D AT 5750' N(3R~,~AL!ZED C{][J~,~T RATkS OVE~ THf3 I~.~I.E~xV.Ai, 9084' 9092 PAGE: bis 'rave verification Listtnq Schlumberger Alask8 Corcputlnq Center S~:~V 1CE ~ PLIC D,~TE : 9210,1/ 3 l,~X RFC S~%~ : 1024 FILE; TYPE : bO PAGE: FTbF HEADEk FILE NUi4BER: ED!TE;D CURVES Depth Shifted and cllpmed curves ~or each pass in separate ~iles. P~Sg NUMBER: l DEPTH INCRE;4ENT 0.5000 FILE 8t,J~ARY PBI.! TOO[, CODE START DEPTH STOP DEPTH ..... ......... GRCH ,0 92 0 C~!TD 9~16.0 8892.0 $ CURVE SHIFT DATA - PASS TO PASS{MEASURED DEPTH) ~ASELINE CURVE FOR SHIFTS PBU CURYE CODE: PASS ----------EOUIVA[,ENT UNSMIFTED DEPTH---------' GRCH Ci~TD ~A. SELINE OEPTH RE~4ARKS: THIS FILE coNTAINS THE FIRST PASS OF THE CNTD' NO PaSS TO PASS SHIFTS !~ERE ~PPLIED TO THIS DATA. S bis FORMAT DATA TYPE : CONS TONI VALU DEFI TYPE CN ~RCO ALASKA INC, Company Name FN PRUDHOE BAY Field Name W~ D.S 6-21. Well Name API~ 500~920R02 API Serial Number FL 960' FEI.., & 467' FSL Field Location SECT ~ Section TOwN !0N TowDsh~p RANG 14E Range Schlu~bercler Alasks Co~Dut;~.~q Center 3-JA~-.1992 11:59 T [! ~; I ~ ~ L U ~ E F ! T ¥ P E CO~ ~'~[~TH SLOPE County STAT ~I.~ASKA State or Province LIT"I Lat it ude LO ~,~ C Lonq i tude WIT~; AI.,LE~ }~itness Name SO~ 413a06 Service Order Number PQ,~T ,~Sb Per~anent datum ~PD FT 0. ElevatloD o~ Permanen L~F RKB ~o~ ~east]red From APO FT 74. Above Permanent Datum E~B FT 74. Elevation of Kelly Bu EOF wT 73. Elevation of Derric~ EGL FT 37. Elevation of Ground L TOD FT 9308. Total DePth - Driller TDL FT 9307. Total Depth - Logger 8[,I FT 9303. [~otto,~ boq Interval T5I FT ~g00. Top I,o~ Interval OFT PR[]DUC~i:D FLUIDS Drlllin~ Fl~lld Type DFD G/C3 Drilling Fluid Denslt ZONE DFP~ Drilling Fltltd Ph ZONE DFV CP Drilling Fluid Vlscos ZONE DFL ~3 Drilling Fluid 5oss ZO~4E R~{S OH~N ReSiStivity Of ~Ud Sa ZONE ~ST DEGF ~ud Sample TemPeratur ZONE R~FS OM~ Resistivity Of ~ud FI ZONE ~FST DEGF ~ud Filtrate Sample T ZONE R~!CS OH~ Resistivity of ~ud Ca ZONE ~CST DEGF ~l~ld Cake Sample Tempe ZONE STE~ DEGF -999.25 St,~r face Temperature B~T I3EGF Bottom Hole Temperatu ZONE TYPE: ZONE TUNI BDEP TDEP DFD DFP~ DFV DFL ~ST R~FS ~FS? ~CS ~CST BHT FT O. O. O, 0. 0:. 0. 0, 0. O. 0. bls Ta[',e verification },istic, o Schlu~,~,.berger ~las~a Co,~,'~]ti, nq Ceoter 3-d~N-1992 11 DEPT NPHT Com~ensate~ ~eutron Porosity, SS ~atrix cal!& dead time corr. NRAT ~,{eutron Ration ~,~on-Dead time corrected ~CNT Raw {~ear [>etector Count Rate, Dead Ti,~,e Corrected FCNT Raw Far Detector Count rate, oead Time Corrected C~TC Corrected ~ear Detector Count Rate CWTC Corrected Kar Detector Count Rate G~CH Gammo RaVIn Casir~ TF~S Surface Tension PAGE: ** DATA F~]R~,~AT SPECI~'ICATION R~ .... dR[~ ** ** SEt~ TYPE - 64EB ** ....... .... ........ E REPR CODE V tie 2 66 0 3 73 40 4 66 ! 5 66 6 73 7 65 8 68 0~5 9 65 !1 66 25 12 68 13 66 o 14 65 FT 15 66 16 66 0 66 o mmmmm~mmmmmmm#mmmmm~mm~m~mm~mm ** SET TYPE - CHAN ** NAMFSERVUNIT. SERVICE APi API API. AP1 FILE NUMB NUmB SIZE REPR PROCESS ID ORDEP # bOG TYPE CbA$S MOD ~UMB SAMP ELEM CODE CHEX) '~;; ............. FT 413406''''' ..... 0; ........ 000 ;; ............. 0 I :'''' ....... 1 X ..... ''''''~68 000000~;' NPHT CNTD PU-S 413406 O0 000 O0 () 1 1 1 4 68 0000000000 NRAT CNT~ 413406 O0 000 00 0 1 1 1 4 68 0000000000 C~AT CNTD 413406 00 000 00 o I 1 I 4 68 0000000000 NEST C~TD CPS 413406 00 000 00 o I { 1 4 68 0000000000 FCNT C:~TD CPS 413406 00 000 0(~ 0 I i 1 4 68 0000000000 C~TC C~TD CPS 413406 0o 000 O0 0 I I I 4 68 0000000000 LIS Tare veriflcatlon Listinq Sc.~]..umberqer AlasKa Computlno center 3-j~i~q-1992 ]1:59 PAGE: Na~,'~5~ . v Ut;IT .ICE APl AP1 APl FILE ~.~ . ~MB SIZE REPR PRO TO OR{>E',R ~ bfJG ~'!'~PE CLASS ~OD NI.~B Sf~'~P ELE~ CODE (HEX) CFTC. ~ ~[I~ D CPS 41 6 O0 SO O0 o 1 4 6 0000000 0 G~C" Cc,~TD GAPI 413406 <)0 00o O0 (? 1 1 1 4 68 0000000000 TENS C~'~ T [~ LB 413406 O0 000 O0 O 1 1. 1 4 68 0000000000 .~EP3. 931e.000 NPHI,CNTD 22.825 ~,CC,~T. CNTD 2827.157 FC~!T.CNTD 711.503 .... NS C~ TD 1095.000 GRCH,C~TD -999,250 TE D~PT g00U.O00 r,{PHI, CNTD 20.398 NC?T:CNTO 5066,132 FCNT. C~';TD ~265.205 GRC~{.CNTD. 24. 703 .7'ENS,... ,CNTD.. 1275. 000 DEPT. 8890,500 NPHI,Cr<TD 34.330 NCNT,C,ITD 2516 854 ~CNT Ci'~TD 440.8~6 GRC~. C~T ...... ~ 43,000 TEMS,C~'~'n lz65.000 ** E~O OW DATA ** NRAT,C 4~IO CNTC, CNTD NR~T.CNTD CNTC.CNTD ~:~', t~ T cNr~ ,'., C.CNTD 4 057 CRAT CNTD 2757:881 CFTC;CNTD 3,671 CRAT.CNTD 4809.785 CFTC.CNTD 5 ~56 CRAT CNTD 2414:51 CFTC:CNTD 4,132 665,660 ~,806 1204,580 5 557 428:262 **** FILE TRAILER **** FILF NAME : EDIT ,001 SERVICE : FbIC VEPSIO~ : O01A07 DAT~ : 92/01/ MAX REC SIZE : 1024 FILE TYPE bAST FILE : **** FILE HEADER **** FILE NA~E : EDIT ,002 SERVICE : FLIC VERSIOM : 001A07 D~TE : 92/01/ 3 ~X REC SIZE : 1024 FILE TYPE : LO L~ST FILE : F I L E N ~..1 ~ B E P: 2 EDITE~ CURVES DeDtn shifted aF~d clipped curves for each DaSS ]~n separate files, LIS Tare ?erification Listinq PAGE: DEPTH !NCREqEi~T 0.5000 F!LF' SiJ ~ :'~ARY ' ' ~308 0 GRCH ~ . C~c?O 931~.0 ..... .o g892.0 CURVE SHIFT DAT~ - PASS TO PASS(MEASU~EB DEPTM) ~ASE[,I,~E CURVE FOR SHIFTS PBU CURVE CODE: PASS NJ~BER: ----------EGUIVALENT !)N8HIFTED OEPTH .... - ..... GRCH C~TD ~SEbliqE DEPTH RE~RKS: THIS FI[,E CO!qTA!i~S THE SEC~f~O P~SS OF THE C~JTD. NO PASS TO PASS SHIFTS WERE APPLIED ~O THIS DATA AS IT WAS OM DEPT~ ~ITH PAS& $ LIS FORMAT D~TA TAB!~E TYPE TUMI VhLU DMFI TYPE C~ APIN SECT TOWN COON STAT ~TI LO~G PDAT b~F EDF EG L TOD .ARCO ALASKA iNC, PRODaOE BAY D,S, 6'21 5002920802 960' FEL & 467' FSL 2 iON i4E ALASKA USA ALLE~ 413406 0, ~T 74. MT 74, FT 73. VT 37, FT 9308. Compan~ Name Field ~.ame ~ell Name API Serial Number Field bocation Section Township Ranqe COunt~ State. or Province Nation Latitude Longitude Witness Name Service Order Number Permanent datum Elevation of Permanen ~o~ ~easured From ADore Permanent Datum Elevation of Kelly Bu Elevation of Derrick Elevat on of Ground L Total Depth - Driller Schll]~berc~er Alaska Co~tltin~ Ce~'~ter 3-J~%N-19q2 :l~:59 PAGE: 8 TUWI VALU DE~I TYPE TD~ ~T 9307 ~otal Depth - 5og~er BLI FT 9303. ~ot. to~ Lo~ Interval TLI rT 8900. ~oP Log Interval DFT P~ODUCED FLUIDS Drillin~ Fluid Type DFD G/C3 Drillin~ Fluid Denslt ZONE DFP~ Drillln~ Flu~.d Ph ZONE DFv CP Drilling Fluid Visco$ ZON~] DFL F3 Drlllin~ Fluid Loss ZONE R~S OH~ ~esistlVity of ~,ud Sa ZONE ~$T PELF ~ud Sample Temoeratur ZONE R~FS OHN~ ResistiVity of ~ud Fi ZONE ~FST OEGF ~ud Filtrate Sample T ZONE R~C~ OHN~ Resistivity of ~ud Ca ZONE ~CST DEGF ~ud Cake Sample Tempe ZONE S~'E}~ OEGF -999.25 Surface Temperature B~T DEGF Bottom Hole Tem~eratu ZONE TYPE : ZONE TUN! BDEP TDEP DFD DFPH DFV DFL RMS MST RNFS NFST RMC$ ~CST BHT I FT 0, O. O. O. 0. 0. O, 0. 0. O. O, O, TABLE TYPE DEFI DMPT De~th NPHI Compensated Neutron Porosity, SS Matrix, call & dead time corr, MR.~T Neutron Ratio[~ Non-Dead time corrected. (N/F) CR~T Neutron Ratio,~Dead Time Corrected (RN/RF) NCNT ~aw Near Detector Count Rate, Dead Ti~e Corrected FCNT Raw Far Oetector Count rate, Dead Time Corrected GRCH Gam~a Ray in Casing CNTC Corrected wear Detector Count Rate CFTC Corrected Far Oetector Count Rate TENS Surface Tension LI.$ ?ape verification [,J, stino Schlumhercer Alaska Con~putiDc (,eDter 3-JAN-t99~ 11:5q PAGE: 1 66 0 2 66 3 73 40 4 66 5 66 6 73 7 65 6 68 0,5 g 65 FT 11 66 25 12 6~ 13 66 !4 65 15 66 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 APl APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT ~ .:~ 1 406 ~ 000 O0 2 I 68 0000 0000 014 O0 NP~I CNTD PU'$ 413406 O0 000 O0 0 2 1 1 4 68 0000000000 N~AT CNTD 413406 O0 000 O0 0 2 1 I 4 68 CRAw CNTD 413406 00 000 O0 0 2 t 1 4 68 NCNT CNTO CPS 4i3~06 O0 000 O0 0 2 1 1 4 68 FCNT CNTD CPS 413406 O0 000 O0 0 2 1 1 4 68 GRCH CNTD GAPI 413406 O0 000 O0 0 .2 I 4 68 CNTC CNTD CPS 413406 O0 000 O0 0 2 I 1 4 68 CFTC CNTD CPS 413406 O0 000 O0 0 2 1 I 4 68 TE~S CNTD LB 413406 O0 000 O0 0 2 I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** D a T A ** .... . , , . ' '~1' ' CNTD 4,176 CRAT CNTD DEP? 9318 0(~0 NPHI CN[CD 23 750 ~RAr, NCNT'CNTD 2750,605 FCNT,CNTD 658:596 G~CH,CNTD -999,250 CNTC:CNTO CFTC,CNTD 620,252 ,'"'r~'..~.,~., CN~ 1090,000 4, ~ 55 2642 ,,265 DEPT. 9000.000 NPNI,CNTD I9.850 CNTD 3.823 CRAT,CNTD ~.733 ~, NRAT'cNT.D 25 828 CMTC CNTD 4848,8~2 NC. NT.CNTD 5034.067 FCNT'~C{NI,~':i ~65.265 GRCH. . CWTC.C~TD 1.234.975 TENS....¢TD .250.000 LIS Tare Veri..~,ication I..,istlnq Schl.mberger Alaska Cor~puti~q Cea. tar 3-JAN-1992 11159 PAGE: l0 DEPT. 8892.000 ~PH I. C,~TD 37.533 ~.IR AT. C ~ITD ~.iC:.}T,C~TI'1 2500,o00 FCNT,C~'iTD 392,~37 CFTC, C:~;T9 3~5,2~2 TENS,C?~TD 1270,00(~ 6.250 CRAT.CNTD 43.813 CNTC.CNTD 5 921 2398~276 **** FILE TRAILER FILE NAaE : EDIT ,002 SMRVICE : FLIC VERSIOn! : 001A07 DATE I 92/01/ ~AX. BEC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE iqAaE : EDIT .003 SERVICE : FLIC VERSION : O01A07 DATE : 92/01/ ~AX REC SIZE : 10~4 FILE TYPE : LO LAST CURVES Uept~ shifted and clipped curves ~or each Dass in separate 0.50oo PASS NUMBER: [)MPTi-t !NCREME~T # F?Lr SUmmARY DBU TOOL CODE GRCH C~TD START DEPTM .... 9318,0 STOP DEPT~ 8883.0 8883.0 CURVE SHIFT DATA - PASS TO PhSS(~FASURED DEPTH) BASELINE CURVE FOR SHIFTS PPi! CURYE CODE: Gl]CH PASS NUMBER~ 1 --- ....... EOUIVALENT U~]SHIFTED ~ASELINE DEPTF! GRCH CNTD ................... ~88~.0 88~87.5 q2a6.5 9286.5 I, IS Ta~e Cer~,£ication I,istinq SchlUmberger r,,lasKa Co~outinq Center 3-dA~-1992 92,78.0 9277.5 9~59.0 925~ . 5 923~.0 9237.5 922o. 5 922r~. 5 915.,~,. 0 9125,5 9125.5 9108.5 nIO~.5 9075.5 9075.0 9068.0 9067.5 043 0 9043.0 .038:5 9014 0 9013,5 ~94~:5 8941.5 ~939.5 ~939.5 8909.5 8909.5 1 (>0.0 ] 00.0 100.0 RE~KS: THIS FILE CO~TAI~S THE THIRD PASS OF D[lPTH ADOUST?'~F).~TS SMOW;~,: ABOVF REFLECT ~ GR A[~,~D PASS 3 NPHI TU PASS ] NPHI, DIS FOR~T' DATA PAGE: 11 THE C!qTO. THE PASS 3 GR TO PASS T~BI,E TYPE : CONS N ARC[') ALASKA I~,~:C, Company Name ~N P~UDHOE BAY Field ~ame WN D,S, 6-21 Well Name API~! 5002920802 AP% Serial Number FL 960' FEL & 467' FSL Field [~ocatlon SECT 2 Sec~lo~ TOW~ 10N Township RA~ 14E Range COU~i NORTH SLOPE County STAT AI~ASK~.~ Stateor Province NATI USA ~iat, lon LATI Latitude LONd Longitude WITN ALL~N ~ltness Name SON 413406 Service Order Number PDAT ~,~SB Permanent datum EPD FT 0 El. evation of ~er~aDen L~iF ~B Loq Measured~rom APD FT 74, Above Permanent Datum EKB FT 74, Elevation of Kelly Bu EDF WT 73. Elevation of ~erricK EGL ~_ 37 Elevation O~ Ground L TDD FT 93 8. Total Depth -Driller TDL FT 9307, Total DePth - Log~er BL! FT 9303, Bottom Log IDterval TU~! VALU DEF! TYPE LIS Tape Yeri~ication Listir~q SchlUl?,berqer Alaska Comput'tn~ Center 3-JAN-lq92 1.1:.59 PAGE: 12 TUi:I YAI.,U DEFI TYPE TbI FT Rg()~. ToP I,oo Interval OFT PRODUCED Fbi]liDS Drlll in~ Fluid Type DFD G/C3 Drlllin~ Fluid oensit ZONE DFPP Orillin~ Fluid en ZONE DFV CP Drillinq Fluid Vtscos ZONE DFL F3 Drillinq Fluid boss ZONE R~S OH~,'~i ReslstiPity ot i~ud Sa ZONE ~ST DC¢;F M~dS~mRle Tem~er~tur ZOnE ~F'$ OH~ Reslstivlt~ of Mud Fi ZONE ~FST OEGF ~Ud Filtrate Sample T ZONE RMCS OH~ ReslstivltY of ~Ud Ca ZONE MCST OEGF ~ud Cake Sample Tempe ZONE ST£U DEGF -999.25 Surface Temperature B~T OEGF Bottom Hole TemDeratu ZONE TABI~E TYPE : ZOP.iE ?UNI [~I)EP TDEP DFD DFPN DP~V DFb MST R~FS ~FST RMCS ~CST BHT 1 FT fl, 0'. 0 0. 0. 0. 0, 0. O. ©. O. ~. D E F ~ DEPT Oe~th N. HI Compensated Neutron Poroslt , SS ~atrix call & dead 'SPAT Neutron Ratio~ ~!on-Dead tim= Corrected iN/F) CRAT Neutron Ratlo, Dead Time Corrected (RN/RF) NCNT Raw Near Detector Count Rate, Dead Tlm~e Corrected FC~T Raw Far Detector Count rate, Dead Time Corrected GRCM Gamma Ray in Casing CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate TEbtS Surface Tension time torT, blS Tat~e Verification l, istinq Scblumber(~er Alaska Comc~utin~ (Tenter 3-dAi"~-lgq2 171, :59 ** ~ATA F(1RMAT SPECIFICATIUN RECO~D ** ** SET TYP< - 64EB ** TYPg REPR CCJ[>g VAbUE ** SET TYPE- CHAM ** N A ~IV~ SERVICE APi API I P! FILE SIZE REPR PROCESS It') ORDER # l,,gG TYPE CbA$S ~OD MUMB SA,~P ELEM CODE (HEX) '"'"'" ....... ";";' .... ; .... " ........ ..... T'"'""'";' ...... DEPT ~.'T .13 06 0 000 O0 3 1 , 68 000 000000 NPi41 C~TD PU-S 413406 O0 OliO O0 0 3 I I 4 68 0000000000 N~AT CNTD 413406 O0 000 O0 0 3 I I 4 68 CRAT CNTD 413406 O0 000 O0 0 3 1 1 4 68 NCNT C~TD CPS 413406 O0 000 O0 0 3 I ! 4 68 FCNT CNTD CPS 413406 O0 000 O0 0 3 1 1 4 68 GRCH CNTD GAPI 41~406 O0 000 00 0 3 1 1 4 68 C~TC CNTD CPS 413406 O0 000 O0 0 3 ! 1 4 68 CFTC CNTD CPS 413406 O0 OOO O0 0 3 1 1 4 68 TENS CNTD LB 413406 O0 000 O0 0 3 ! 1 4 68 0000000000 0000000000 0000()00000 0000000000 0000000000 0000000000 0000000000 0000000000 13 ** DATA ** C.~ID '~ ' '. 931B.000 NPHI.ct. lq, D [..EP? CNTD 2761, 038 FCNT NCNT, . . ,.~..... ,-.. ~ · . ' CFTC C~,ITD 652 9~.7 TENS.C.~.ID DEPT, NCNT,CMTD CF. TC.CI~TD 9000,000 5130.260 1259.969 NPHI. ~. ....... FCNT' '~ D TEN~. C !',i T D 22,396 NRAT,CNTD 694,7'~ GRCH, CiS~TD 1.065 , OUO 19.991, NRAT CNTD 1 3 6 0,0 0 0 d R C H ', C ~.i... T D 1 255. 000 4 000 CRAT.CNTD -999:250 CNTC.CNTD 3 600 CRAT.CNTD 25:805 CNTC,CNTD 3.752 4878,238 bis Tape v'erificatlon I,lstinq Schlumberaer AlasKa Computinq (]enter 3-jAN-,:Igg~ ",1:59 PAGE: 14 4 897 CRAT.CNTD 50:625 CNTC.CNTD 4 713 2363~511 ** F,',![.~ OF OATa, ** **** FTbF~ TRA ILE~ **** FII.,F NA~4E : EDIT .003 SERVICE : FL!C VER$1-F!N : 00lA07 DaTF : 92/01. t 3 ~AX ~FC SIZE FIhK TYPE : h~s'r WILE : **** FTL~ H E*,DF.R **** FI,t,F NA~qE : EDIT ,004 S~:RVICE : FLIC VERSION : O01A07 D~TF : 92/01/ 3 M~X R~':C SIZ..K : I02<1 FIL~ TYPE : 1,0 bAST FILE : FILE HEADER AVERAGED CURVES Compensated Neutron: Arithmetic average o~ edited passes for all curves, PulsedNeutron: Unavera~ed edited PaSs 1 ~ammaray and: bacKround counts; arithmetic average of edited statlc baseline passes for all other curves, DEPT}t INCREMENT 0,5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS MUaBERS -----.----.-- C N T P ~ RE,ARKS: THE ARITF~METiC AVERAGE OF TME THREE PASSES PERFORMED AFTE:R ALL DEPT[~ ADJUSTfqENT$ ~4ERE APPb!ED, $ # LIS FORMAT DATA bis Tape Verification [,istinq $chlt.lm+'er~]er AlasKa Compt,ltinq Cepter 992 I ~t: 59 PAGE: 15 STAT N~TT PDA? APD EDF E~L TDD TDL DFT DFP~ DFL R~$ ~ST MFST RNCS MCST B~T T~g},K TYPE : CO~,iS I ~!I VAI,U DE.~I TYPE ..................................... ........ ....... ....................... ' .... '"""" CN ~' CO ~any ~ ~ K , m N me F~ P~UDHO~ ~A~ Field ~ame D.S~ 6-~1 mell Name 5002920802 APl Serial Number g{>0' FEL & 467' ~'SL Field Location 2 Section 10N Township I, 4E Range kORTH SLOPE Count~ ALASKA State or province U S A h~ a t i o n batitude Longitude AbLF~ witnes~ Name 413406 Service Order Number :'qSb Permanent datum FT O. Elevation of Permanen RKB Loo Measured From FT 74. AbOve Permanent Datum FT 74. E'levat~on of Kell~ Bu FT 73, Elevation of Derrick FT 37. Elevation of Ground b FT 9308, Total Depth - Driller FT 9307, Total DePth - Logger FT 9303. Bottom Log IDterval .. r 8900. Top LOg Interval PRf3DUCED FLUIDS Drilling Fluid Type G/C3 Drilling Fluid Denslt ZONE Drlllin~ Fluid Ph ZONE CP Drtllin~ Fluid Vlscos ZONE F3 Dr~llin6 Fluld 5oss ZONE OH~IM Re:sistlgitY Of ~ud Sa ZONE DEGF Mud Sample Temperatur ZONE OH~ Resistivity of Mud F1 ZONE DEGF Mud Filtrate sample T ZONE OH~q ~esist~vit~ of ~ud Ca ZONE DEGF ~ud Cake Sample Tempe ZONE ~EGF -999,25 Surface Temperature DEGF Bottom Hole Temperatu ZONE bis Ta~e Yerificatlom ListInq $chlumberq~er AlasKa ComDutino Cent~¥ PAGE: 16 D~PT DePth ,',~PNI Compensated ,~etltron Poros}ty, SS Matrix, cal, i & dead time corr, NRAT Neutron Ration r'i!on-Oead t~me Corrected CRAT Meutron Ratio, Dead Time Corrected hC¢:T Raw Meat Detector Count Rate, Dead Time Corrected FC~{T ~aw Far Detector Count rate, Dead Time Corrected CNTC Corrected Mear Detector Count ~ate CFTC Corrected Far Detector Coumt Rate GRCH Gamma Ray in Casing TENS §urface Tens ion ** DATA ~OR!4AT SPECIFICATIOh? RECOR~~ ** SET TYP£ -64ES . M YALUE TYPE R .... PR CDDE I 6'6 0 2 66 0 3 73 4O 4 66 5 66 6 73 7 65 9 65 11 66 25 !2 68 ~3 66 !4 65 FT t5 66 68 !6 g6 0 66 I I-,IS 'rape v~rl~.ication ',~,1stlnc SChlU~,~herc~er ~!asK~ Co~'~puting Center PAGE: 17 CRAT CNTC CFTC GRCH T E ~ S ** SET TYPE - C~{AK! ** U. IT SERV ~' AP1 A PI AP1 FI ~. N~,g~,, U~3. P..OCESSR ' ~:]~D~R ~ [,0(.3 TYPE ChASS YOD ~(.!~B SA~....P Ebg~ CODE (HEX) 413 ~0 0 o00 0 4 I 68 0000000 Cr~V plJ-$ 413406 O0 000 O0 0 4 l ! 4 68 0000000000 Ch,~V 4,13406 O0 000 OO 0 4 I 1 4 68 0000000000 C~AV 413406 O0 000 O0 0 4 1 1 4 68 0000000000 C~,~V CPS 413406 0O 000 OO C 4 1 1 4 68 0000000000 C~AV CPS 413406 O0 0o0 0O O 4 ~ I 4 68 0000000000 Ct,,~V CPS 413406 O0 000 O0 0 4 1 I 4 68 0000000000 CNAV CPS 4134(36 00 0CO 0C o 4 1 1 4 68 0000000000 C~AV GAP! 41.3406 O0 0C0 00 O 4 1 1 ~ 68 0000000000 C~V bE 413~06 O0 000 O0 O 4 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmm~mmmmmmmm~m~m~mm~mmm#m~mm~mmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmm#mmmm ** DATA ** DEPT. 9316.000 NPHI.CNAV 22.685 NRAT.CNAV 3 928 CRAT.CNAV NCNT'C!4~V 2774.646 FCNT.CNA¥ 712.734 CNTC.CNAV 2665: 9,31. cFTC.CNAV GRCH.CNAV 653.8!1 TENS. C[~AV !069.893 D...Pq gO00,O00 NPHI,CNAV 20,078 NRAT CNAV 3 .698 CRAT CNAV NC!q'T. Ci:'~ A V 5076.313 FCNx.CNAV 1296, 4 CN ,rE.. CNIV 4845:1]1 CFTC:CNAV GRCH C'. . TEi'~S N . ~,~AV 25 443 .C AV 1259. 4 ~P'r. 8892,000 NPHI.CNAV 36.232 ~'~!~:~ A T. CN .~¥ 5 783 CRAT.CNAV ~CNT CN~V 2455.679 FCNT CN~ 419.284 CNTC CNAV 2354~695 CFTC CNAV GRCH, C~AV 47,954 TENS,C~AV 1238,209 ** END OF DATA ** 4.114 653'811 3 76 3 5.774 398'461 **** FILE TRAILER **** FILE NA~E g EO!T ,004 SERVICE : FLIC VERSIO~ : O01A07 DATM : 92/01/ 3 ~AX AEC SIZE : 1024 FILE TYPE : bO LAST FILE : LIS Ta.~e verification bistlng Schlttmber~er A].as<,~ Com~jtjna Center 18 VFRSIO~ : 001. DATE : g2tt, l/ ~X ~EC SIZ~ : 1024 FILE TYPE : baST FILE : F!L~ H~DE~ FIbF ~UMBER 5 RaW C!J~VE$ ~urves and lo0 ~)ea~er data for each pass in separate files: raw background pass in last file P~SS !,~U~BER: 1 DEPTH I~CREMENT: -.5000 F~LV SUMmArY VE~DO~ TOOt, CODE START DEPTH ?N''~''''''''~ ..... ''''T;9316 ,. .... LOG HEA~ER DATA DATE LOGGED: T!M~ LOGGER ON 80TTD~: TI) DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL BOTTOM LOG INTERVA[~ (FT): LOGGING SPEED DEPTH CONTROL USED (YES/NO): 'roob STRING (TOP TO BOTTOM) VEMDOR TOOL CODE TOOL TYPE ................ i;i ...... CNTD P. NEUTRON' C~RT. CNTD E EMET~Y CARTRIDGE CNTD TELEMETRY ~ODULE BOREHOLE A~D CASING DATA OPEM gObE BIT SIZE ~RII.,LERS CASING DEPT't ( 7 bOGGERS CASI~G OEPTH (FT) BO~EHODE CONDITIO~$ FLUID TYPE: FLOID DENSITY (LB/G): SURFACE TEN~PERAT[JRE (DEGF): gOTTO~ HOLF, 'r~T~PERATURE (bEGF): FLUID SAblN!TY (PPM) STOP DEPTH o 04-NOV-91 CP 32.4 1 ~50 04-NOV-9 ] 9]08.0 9307.0 8900 · o 9303.o 1800.0 N 0 TOOL NUMBER CMC-DA 146 ATC-CB 644 ATM 283 8842.0 PRODUCED FLUIDS bis wane verlftcatlom l,istinq Schlumberger A!ask. a Com~:t]tinq Centor 3-JAN-:!992 !.1:59 FLUTF) bEVI<b (FT): FLUID RAFF AT ~'~EbLHEAD (~%P¢~): WATER CUTS (PCT): ~/OTL RATIO: CJ~OKE (DCG): t~ ELi T R 0 ~',~ TOOL TOOL TYPE (.EPITHEP,~,~AL ~)~ q'HE~,AL): ~4.~TR I X: LATRIX DENSITY: ~,tOLM CORRECTION (IN): SANDSTON~_~ 2.65 ~[!RiqA L I Z ~T,?. Orl START DEPTH STOP DEPTH ahS SCALING FACTOR FOR J',,IEAa AND FAR COUi~TS: MJI, TIPLIER." ~.EMARKS: TIED iNTO ~':,t'.uS DATED 6'SEP'82 ¢~E[.,.L SHUT IN PRIOR T'O LOGGING AT 60:00 11-4-91, SIWHP : 2000 PSI. FLUID LEVEL ~OLINb AT 5750', NORM~L, IZE[) COLiiqT RATES'OVER TNE INTERVAL 9084-9092, bis [vOR~AT DATA PAGE: TASL~ TYPE : CONS TONI VALU OEFI TYPE . , CN a~CO ALASK~ ~NC. ~ompan[ ~ame FN PRUDHOE BAY ieid ~ame APl M SECT TOw~ COLIN STAT NhTI bATI LONC PDAT APD FT FT D.S.~ 6-21 5002920802 960' FE[~ & 467' FSL ~ORTH SLOPE ALASKA A b [.., E N 413406 MS [, O. Well Name API Serial Number Field Location Section Township Ran Cou~e t¥ State or Province Nation Latitude Longitude Witness ~ame Service Order Number Permanent datum Elevation of Permanen Log Measured From Above Per~anent Datum LIS Tape 'Verification Listln~ Schlu~.~,er~er ~lasKa Com~.utinq Center 3-JAN-1992 11:59 PAGE: 20 TU~I VALU DEFI TYPE EK ~' E1 ation of ~ ~ 74. ,ev e Mu K llY EOF ~T 73. Elevation of Perric~ EGL FT ,~7. Elevation of Ground b TD~ FT 9308. Total Depth - Driller TDL FT 9307. Total Dept~ - Logger ELI FT 9303. Bottom Log Interval TLI FT 8900. Top bog Interval DFT PRODUCED FLUIDS Drilling Fluid TYpe DFD G/C3 Drilling Fluid Densit ZONE DFPg~ Fluld Ph ZONE Drilling Fluid Vi co ZONE DFV CP Drillln_~ s s DWL F3 Drillina Fluid Loss ZONE R~S ON~ Resistivity of i~ud Sa ZONE ~ST DEGF Mud Sample Temperatur ZONE R~FS OH~ Resistivity of ~ud Fi ZONE ~FST DEGF ~ud Filtrate Sample T ZONE R~CS OH~ ~esistivitY of Mud Ca ZONE ~CST DEGF Mud Ca~e Sample Tempe ZONE STE~ DEGF -999.25 Surface Temperature BHT DEGF Botto~ Hole Temperatu ZONE TYPE : ZONE TABLE TYPE : CURV DEFI D~PT Depth NPHI Compensated ~I . ~,,eutron Porositv, SS t~iatrix, calI & dead time corr, RTNR Raw Thermal Neutron Ratio T~RA Thermal ~!eutron Ratio Calibrated RENT RENT RCFT RCFT C~TC Corrected ~ear ~etector Count Rate CFTC Corr.cted ~ar Detector Count Rate GR ~PI-Corrected Gamma TE~S Surface Tension CCL ECL Amplitude LIS TaPe %~erif. icatlon t.,istir~g Schl',~berger 21asKa Co~ut:i.r~:] Cer, t:er 3-JAN-19q~ 11:59 PAGE: 21 1 66 2 66 O 3 73 44 4 66 1 5 66 6 73 7 65 8 6~ 9 65 FT i1 66 23 13 66 0 14 65 FT 15 66 16 66 i 0 66 1 mmmm~mm~mmmm~mmmmm~mmm#mmmmmmm ** SET ~.~P~, CH~N ** ';;;~i ......... SERV ~I'~;''''''~~ SERVI ............ API API ;';P ................... API FIL~ NLi~q8 N~;;'''''SIZE ....... REPR''';;~;;;''' ID ORDER ~ LOG TYP~ CbASS M[)D NU~4B SA~P ELEM CODE (HEX) D~PT FT 413406 oi) ~100 00 0 5 ~ 1 4 68 0000000000 aPaI PSi PU 413406 O0 000 O0 0 5 1 I 4 68 0000000000 RTN~ PSi 413406 O0 000 00 0 5 1 1 4 68 0000000000 TNR~ PSI 413406 O0 000 O0 0 5 1 I 4 68 0000000000 RCNT PS1 CPS 413406 O0 000 O0 0 5 1 I 4 68 0000000000 RCFT PS1 CPS 413406 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PSi CPS 413406 O0 000 O0 0 5 1 I 4 68 0000000000 CFTC PSI CPS 413406 00 0O0 O0 0 5 1 i 4 68 0000000000 G~ PSI GAPI 413406 O0 GOO O0 0 5 i 1 4 68 0000000000 TENS PSl LB 4i3406 O0 000 00 0 5 1 I 4 68 0000000000 CCL PS1 ¥ 413406 00 000 O0 0 5 1 I 4 68 0000000000 DEPT 9320.000 '~PHi Pei 22 i~32 RTNR.PS! 4057 RCNT'PS1 2886,912 RCFT.~$1 711.563 CNTC.PS! 2769.898 GR. P$.~ 27.609 TE~.IS, F,S I 975.000 CCL,PS! 0.000 DEPT. 9000.000 NPHI.PSi 19.494 RTNR.PS1 3 aCNT.PSI 5327.:886 RCFT.PS1 1.378.757 Ci~!!C'~''o PSi 5004 '2674431 G~oPSi 2;~.!)3i TE~S..PSi 1255.000 CCL.PS1 0°000 {~ PSi ~133 T~.RA, CFTC,PS1 67 T~.PS1 '~ ~ T CF~.C PS1 1307,192 LIS TaDe verification Scblu~,berger Alaska ComputJ..nQ Center 3'"JAi'~-1992 !.1:59 PAGE: 22 DEPT. ~891.000 ?~P!!i.PS1 PC~w. PS1 2516.~54 aC~T.PS1 G~'.P$1 ~3.0o0 IE~$.PS1 34.330 440.8!6 C~TC.PS1 12°5.000 CC~,,eS1 5.550 TNRA.PS1 2414.151 CFTC.PSi 0.000 5.557 428,262 ** END OF DATA **** FILE TRA I bk'.R **** FILE bIA':qE : EOIT .005 SFRVICE : FLIC VERSION : OOl.~t~07 DATI~7 : 92101/ 3 Y,~X ~EC SIZE : 1024 FILE TYPm : L~ST rILE **** FILE ~EADER **** FIL~ NAME : EDIT ,006 SERVICE : FLIC VERSIO~ : O01A07 DATF : 9~/01/ 3 MAX REC SIZE : 1024 FILE TYPE L~ST FILE FILE HEADER FIL~ NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUgBER: 2 DEPTH INCREMENT: -,5000 FILE S!J~MARY VENDOR TOOL CODE START DEPTH C N T D $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOm: TI3 DRILLER (FT): TD LOGGER(FT): TOP LOG BOTTOM bOG INTERVAL (FT): bCGGING SPEED (FPHR): ~EPTH CONTROL USED (YES/NO); STOP DEPTH 8892,0 04-t~!OV-91 CP 32.4 1850 04-Nov-g1 9308,0 9307.;0 8900,0 9303,0 !~oo.0 LIS 7'ame ver.ifi, catio~ L~stinq. Sch].u~berqer ~lasko Co~,~putina Center 3-J&i'.~-1992 !1..:59 PAGE: 2] Tf30L STRING (TOP TO EUTRO~ CART. CNTD TELE ~:~F.'~' R Y C~TFIDGK CNTD TELE~ET~Y ¢ORE~OLE AND CASI~'~G DATA [3PEN NOLE BIT SIZE fiN}: DRILLERS CASI~,~G DEPT~ LOGGERS CASING DE;PTH ~CREHO[,E CONDITIOPS FLUID TYPE: FLUID DE~SITY (LB/G) SCRFACE T~P~;~ATURE {DEGF): 8OTTOH MOIRE TE~,PERATURE (DEGF): FLUID SALINITY {PPg): FLUID RAT~.~ ~.T ?~EbLHEAD ~TER CUTS {PCT) (;AS/OIL, RATIO: CHOKE (DEG): ~'EUTR[IN TOOL TOOL TYPE (EPITHER~,~AL OR THERMAL): .{qATRIX: ~q~TRIX DE~SITY: HOLE CORRECTIO~.~ fiN) START DEPT}..i (FT): STOP DEPTH (FT): AMOUNT: GAS SCALING FACTOR FOR NEAR A~,~D FAR COUNTS: MULTIPLIER: TOOL STANDOf'F (IN) ~ ,~ ~. L;~ 4 ATC-C8 64.4 Am!',~, 283 P?ODUCED FLUIDS SANDSTONE 2.65 ~'E;~ARKS: TI~;D I~.!~rO SwS ~;~,HC"S DATED 6-SGP-82, WELL S~L!T !M P[{!rlR TO LOGGING AT 00100 11-4-91. SI~'HP : 2000 PS!, FLUID LEVEL, FOUf,,iD AT 5750'. ~OR~.{ALIZED COU?~7 RATES OVER TH~ INT[~RVAL 90~4-9092. LIS FOR~'AT DATA L, IS ~'~aoe ~'eriflcation Listi. m~ Sc~,lU~erqer ~las~a Com[>utinq Center !1:59 PaGE: 24 :Ft.~ {',} ! ~ A I., !! DEF I TYPE C~'> RCO Abr~ . a,~an~. Na F~~ PeUOHOE ~ Field Name W~,~ O.S 6-2! Well ~ame 500~92n~02 AP1 Serial ~umber 960' FEL & ~67' FSb Field Location 2 Section I 0~ Towns~i p 14E Range :~ORTH SI, OPE County ALASKA State or province ~SA Nation Latitude Longitude AbLEN Witness Name 413406 Service Order Number ~.~Sb Permanent datum FT 0 Elevation of Permanen R~B [,og Measured From FT 74, ADore Permanent Datum PT 73, Elevation of Derr FT 37, Elevation of Ground L FT 9308, Total Depth - Driller FT 9307, Total DePth - Logger FT 9303, Bottom Log Interval ~T 8900 Top bog Interval PRODOCED FLUIDS Drt.llin~ Fluid TYpe G/C3 Drllltn~ Fluid Densit ZONE 0rlllin~ Fluid Ph ZONE CP Drlllina [l~lId Viscos ZONE F3 Drillln~ fluid Loss ZONE Oa~ ResistiVitY of Mud Sa ZONE OEGF .Mud Sample Temperatur ZONE OH~M Resistivity of ~4ud F1 ZONE 9~Gf ~ud Filtra e Sample T ZONE OHM~:~ Resistivity of MUd Ca ZONE DEGF Mud CaMe Sample Tempe ZONE OEGF -999.25 Surface Temperature DEGF Bottom) Hole Te~peratu ZONE LIS ~aDe qertfication [.,lstinq Schlumberger AlasKa Com~utin~ ('.enter 3-d~i~-1.992 !.1:59 PAGE: 25 T~B[,E ':~YPE : CURV DEPT Oe~th ~P~ Compensated ~eutron Porosity, SS ~atrix, call & dead time corr. RT~R Raw Thermal. Neutrom Ratio TNR~ Thermal Neutron Ratio Calibrated RCNT RCNT RCFT RCFT CNTC Corrected Near Detector Count ~ate CFTC Corrected Far Detector CouDt Rate GR API-Corrected Gamma Ray T~NS Surface Tension CCL CCL Amplitude DATA FOR~Af SPECIFI AT IO}~ RECORD 2 66 0 3 73 4 66 5 66 6 73 7 65 8 6~ 0,5 9 65 PT 1]. 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 LIS Tare verlf, lcatlon bistina $chlt]~-ber~er Alaska Com~::ut..inq Center 3.-JAN-!992 !! :59 PAGE: 26 0 66 ** SET ID D~PT FT NPH! PS2 PU R~N~ PS2 TNRa RCNT PS2 CPS RCF'~ PS2 CPS C~!C ~82 CPS CFTC PS2 CPS GR PS2 GAPI TENS PS2 CCL PS2 V TYPE - CHAN * SEPVIC~ A ORDER # bOG a!3406 O0 413406 00 413406 O0 413~o6 O0 413406 4.1]~06 00 413406 00 4]]406 0O 4.13406 00 413606 O0 , API TYPE CLASS O 00 00 0 000 O0 0 000 00 0 000 00 0 000 00 0 000 00 0 000 O0 0 000 00 0 000 O0 0 000 00 0 0 0 0 0 0 0 FILE B NJ.IN $IZ REPR ROCESS OD ~.it.tMB SAMP ELEM CODE (HEX) 6 1 1 4 68 0000000000 6 1 1 4 68 0000000000 6 1 1 4 68 0000000000 6 ! 1 4 68 0000000000 6 I 1 4 68 0000000000 6 1 1 4 68 0000000000 6 1 I 4 68 0000000000 6 1 1 4 68 0000000000 6 1 1 4 68 0000000000 6 I 1 4 68 0000000000 6 1 ! 4 68 0000000000 DEPT. 9321 RC~!iT.PS2 2750 ,500 NPHI,PS2 F' ,~05 RC. f,PS2 .281 TEN$,:PS2 EPT'. 9000 ~CNT,PS2 5289 G~.P82 21 ,000 NPHI.P$2 ,7~6 RCFT,PS2 ,469 TE!~o,P82 DEPT 8892,500 RC~T:P82 25O0,00O g~,P$2 43,81.3 NPHi,P$2 RCFT,PS2 TENS.,PS2 23 658 1035 19 1442 1255 37 392 1270 .750 RTNR,P$2 4,1.76 TNRA,PS2 596 CNTC,PS2 2639,11.6 CFTC,PS2 :000 CCI.,,PS2 ' 0,000 ,080 RTNR,PS2 3 489 TNRA,PS2 ,886 C~;7'C,P$2 5024:704 CFTC,PS2 ,000 COb,PS2 0,000 ~3_~ RTNR.:PS2 6,250 TNRA.PS2 237 CNTC'.PS2 2398'276 CFTC,PS2 000 ~;[ , ' CC,.~,, PS2 O, 000 4,255 620,252 3,629 1342,2t4 5,9 2 ! ] 95 ' 232 **** FILE FILE NA~E $~RVlCE VERSIO~ DaTE F!L~ TYPE bAST FILE TRAILER **** : EOIT .006 : ~bIC : 001A07 : 92101/ 3 : 1,024 LIS Tape veriitcation [,]$tinq Schlut~berger Al, asEa Comput.~m~ Cer~ter FIB[' ¢,~;E : ~.£~I~I .O07 SF~vICE .' FLIC DATE : 921011 3 FILE 'tYPE : LAST F~LE : 3-dh~-lgq2 11:59 PAGE: 27 FILE HE~{)ER FILF NUMBER 7 RI~ CURVES Curves and lo~ ~eoder data ~or each ~ass ~n separate ~iles; raw bacKqround pass In last ~lle PgS$ NI!gBER: 3 DEP~!i INC~EgE~i'r: -.5000 # F!bF SiJ~NARY VENDOR TOOL CODE START DEPTt~ C~,iTO 9163 .0 $ # LOG ?lEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGGER O~'! 'rD DRILLER (FT)I TD LOGGER(ET): TOP bO~ I~TERVAb ~OTTOM LOG INTERVAL LOGGING SPEED nEPTM CONTROL USED ~oor, ST~I~G C~'oP TO ~O~TO~) VENDOR TOOL CODE: TOOL TYPE CNTD CO~ , NEUTR05! C~RT. CNTD' TELEMETRY CARTRIDGE CNTD TELEMETRY ~ODULE $ BOREHOLE AND CASING DATA OPEN ~tOLE BIT SIZE (IN): DRILLERS CASI~G DEPTH LOGGERS CASING DEPTH (F~): BCRE~OLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) BOTTOm4 [.tO[.,E TE~4PERATURE (DEGF): FLUID SAb!NITY (PP~): STOP DEPT~ ~89~ 0 04-~V-9~ CP 32.4 1850 04-NOV-91 9308.0 93O70 9oo:o 3~3.0 1800.0 TOOL NUMBER CNC-DA ~46 ATC-CB 644 PRODUCED FLUIDS [,IS Ta~e verification ti~ti.n.q Scblumt>er~er AlasKa Co{~r?~]tlr, Ocerter 992 i ~ : 5g 2.65 START DEPTH STOP AMOUNT: SCALING FACTOR FOR ~,~EAP A!,IP FA~ C{JIJ~TS: TOOL STANOOFF (iN): RM~ARKS: TIE[) lf~TO SWS BHCS DATED 6-SEP-82, WELL S~[;T IN PRIOR TO bOGGING AT 00:00 ~1-4-9~, $IW~P = 2000 PSI. FLUID LEVEL FOUND AT 5750', NO~AtlZED COUNT PATES OVER THE INTERVAL 9084-9092. $ bls FORMAT DATA PAGE: 28 TABLE TYPE : CO~,~S 'I~ t.,I ~ I V AI, O DEFI TYPE CN ARCO ALASKA INC, Company Name FN PRUDHOE BAY FI. eld ~tame WN D S ~-21 Well Name API~-~ 5~9~0802 AP1 Serial Nut, bet Fl,, 960' FEb & 467' FSL Field Location SECT 2 Section TO ~ ~,'~ 1 ON Township RANC 14E Range COtJ~,~ ~ORTH SI,[)PE~ County STAT A[~ASK~A State or Province ~3~TI USA ~ation LATI Latitude LO~G Longitude SO~,} 413~06 Service order ~lumber PDAT ~Sb Permanent datum EP[) ?T O. Elevation o! Permanen D;~F RKB [~Og ~easure~ From APb ~T 74. Above Permanent Datum LIS war)e verificatlon Listing Schlu.:~berger Alaska Co,~p(]tino Center 3-jAt~-19~2 ti :59 PAGE: 29 E~2 ,4 eva Kel y EDF ~T 73. Elevation of Derrick EGb FT 37 [l].evation of Grot]nd 1, TOD FT 93~8. Total Depth - Driller TD5 FT 9307. Total Depth - Logger BLI FT 9303. ~ottom Log Interval TLI FT g900. TOD Log Interval DFT PPODUCED FLbID6 Drilling Fluid Ty~e DFD G/C3 Drillin~ Fluid Densit ZONE D~pN DrilllDg Fluid Ph ZONE DWV CP DrilliDg FlUid ~iscos ZONE DFL w3 Drillinq Fluid ~oss ZONE R~S OH~l EesistivitY of ~ud Sa ZONE ~ST OEGF ~'~]d sample Temperatur ZONE P~FS OH~M Nesist~vity of [,Iud Fi ZONE ~FST OEGF ~ud Viltrate Sample T ZONE R~CS OH~,! Resistivity of ~ud Ca ZONE ~CS~ OEGF ~<ud Ca~e Sample Tempe ZONE STE~,~ OEGF -999.25 S~lr face Temperature BMT DEGF Bottom Hole TemDeratu ZONE T~BI[.,F TYP~ : ZONE T~R[.,~: TYPE : CURV OEFI D~PT~Dept. NPH! Compensated Neutron Porositv, SS ~atrlx, cali& dead time tort, RTNR Raw Thermal ~eutron Ratio T~RA T~ermal ~eutrop Ratio Calibrated RCNT ~CNT RCFT ~CFT C~TC Corrected ~3ear Detector Count Rate CFTC Corrected Far Detector Count ~ate GR APl-Corrected Gamma ~ay TENS Surface TepsIon CCI,, CCL A~Pl~tude LIS Tar~e Verificatlor~ l,istln¢~ SchluF,.ber[ler Alaska Cemputlt~o Center PAGE: 3O ** DATA F'~qRr~aT SPECIFICATION ** SET TYPE - 64EB TYP[ REPR C VALD 2 66 3 73 4 5 66 6 73 7 9 65 11 66 1~ 13 66 14 65 15 66 16 66 0 66 mmmmmmmmmmmmmmm 0 0 4~ 0.5 FT 23 0 FT 6~ 1 - ' N ** SET TYPE CHA * NA~ SERV UNIT S~VICE APl ID ORDER # LOG DEPT FT 413406 O0 NPHI PS3 PU 413~06 O0 RTN~ PS3 413406 O0 TNRa ~$3 413406 O0 RCNT PS3 CPS 413406 O0 RCFT PS3 CPS 413406 O0 CNTC PS3 CPS 413406 O0 C~TC PS3 CPS 413406 00 g~ PS3 GAPI 413406 O0 T~N$ PS3 LB 413406 O0 , AP TYP 000 O0 0 000 O0 0 000 00 0 o 00 00 0 000 O0 0 000 O0 0 000 00 0 0 O0 O0 0 000 O0 0 000 0 O 0 0 00 0 CCL PS3 V 413406 O0 AP1 lPI FILE NUmB NUNB SiZE REPR PROCESS CLASS i~OD NUmB SA~[' ELEM CODE (HEX) 7 1, 1 4 68 0000000000 7 1 1 4 68 0000000000 7 I 1 4 68 0000000000 7 I 1 4 68 0000000000 7 I 1 4 68 0000000000' 7 I 1 4 68 0000000000 7 1 I 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 I 4 6B 0000000000 7 1 1 4 68 0000000000 ** DATA ** '~q . 32 . . D...PT 9 2 ,00(} NP~I PS3 RC~,~T.PS3 ~797 .156 RCFT.PS3 G~,PS3 31109 TEh,>. PS3 DE~PT, 9000.000 ~JPHI ,P53 RCNT,PS3 5226.45~ ~CFT,PS3 ~.PS3 23 75(1 'Ii.,'~$ PS3 22 ~6 RT~R.PS] 4.000 TNRA..PS3 694~.~9 CNTC.PS3 2666.510 CFTC,PS3 950.000 CCS.PS3 0,000 18 829 RTNR.Pe , o3 3 556 TNRI.PS3 1449.8ca6 CNTC.PS3 50651964 CFTC.PS3 ~250.000 CCL.PS3 0.000 4,075 654,339 3,595 1358'043 [,IS Ta~e verilication l,i. stimq Schlum>er¢~er AlasKa Computing Center 3-JA,~-1992 1]:59 PAGE: 31 D~PT, GP,PS3 aaR3.50o i,!P~I.P53 27.312 ~TNP.PS3 4.897 TNRA.P$3 4.713 2,i16.326 RCFT.PS~ 474.4..38 C?.~TC. PS3 2363.511 CFTC.PS3 484.469 50.62,5 TENS.PSI 1255.©00 CCL.PS3 0.000 FII.,~ NA~E : EDIT ,007 SFRVICE : FLIC VFR$ION : 001A07 DATE : 92/0!/ 3 ~X R~C SIZE : 1924 FILF TYPE : bO LIST **** TAP~ TRAILER **** SERVICE ~AME :MDIT [)ATE ~ 92/01/ 3 ORIGIN : FLIC TAPE NAME : 74329 CONTINUATION ~ : ~ PREVIOUS TAPE : CO,gENT : .ARCO ALASKA INC,PRUDHOE BA¥,D.S. 6-21,500292080200 **** RBEb TRAIt, ER **** SERVICE MANE : EDIT OAT~: : 92101/ 3 ORIGIN : FLIC RME[,, NA~E : 7~329 CONTINUATION# PREV'IOUS REEL CO,WENT : ARCO ALASKA I~iC,PRUDMOE BAY,D.S. 6-21,500292080200