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Home My WebLink About197-062 k1ECHANICAL INTEGRITY REPC } ,k¡¡:; --'. ....., II" '~'.'" " J. .,é!, J,... ~- b '~:.::., ¡ "L .I,r ~ ~. 'n~¡1 !:3~;"" 6;, () SPUD DATE: ,4' {. c::;..,I;Ç;.. '~\ ~'")'. ii, (/' I. \;.""," ~> OPER & FIELD /::./¿:(c.l:.) I <¡~-O~Jt (::'L ~1i) ,;t("'c..t.. \:..... I G£~ ~~" /:; RIG "RELEASE: :2..f9' 7t \-tELL NUMBER ~1: - \~ L1- WELL DATA TD: ... .- . ~ MD ,I" ~-;: ,,,,",,, TVD ~i"<~ 7'?- Ct. "I ~. ~ J 19 PBTD :1(.f£8' MD ¿) lice!, TVD C·. ~7")'¡f~ ~ ii Shoe .. '..-1 !iõi_t;"""" MD as 1ng. h'¡, ~.:::.} ..:..j, II .-..... L .::/-, S5~): MD 1ner: '1';~, Shoe: . '¿)~n~' ,:)' ....p .~ ?,( ~;'fµ;Î' ~ s-.9-;¡4-12:.~"f\ ~ Tubing:.'t. 4§~'~?8!Packer MU TVDJ DV: MD OTVD Hole Size 8~s- and TVD J TOP: .~-78;sMD 'r'¢' a '3 TVDJ Set at (2) Ó'õ§' J Perfs 1/2~i:.:, TVD " ' ,,- s~ ~~ J.~ c: to ~jf';?':;? ,~- t/ ¿J..r. ofI'«JiJ ~: MECHANICAL INTEGRITY - PART #1 Annulus Press Test: IP 15 min J 30 min Comments: MECHANICAL INTEGRITY - PART #2 r~ ~. ,_ " .\?": \/ C. ~"èr. . '. \' '. ""':'Lrl'-'i \L'~"~ t r'· tt"-"..j()C; ....:.. \ '-.. ' ,: . " .....\\) ':. . SO'· ,. < A £"'1'-' ~\.(:,t.;.",", ,~ '- , \,..\ Q>.~'" r'" l "t: c~.ç1-? Cement Volumes: Amt. Liner J CsgS1~:;r;<f'" J DV ~)..- . " !I.~~' ._ ;E:~..eQ í1!.;i~)-û~ Cmt vol to cover perfs (-1'R.) <$í~-' 1'4{~ f e) d/ Cß:ff( f (7_$''''"1'2 - ~r~"(~~S:-)i " 3 ;? ~,a 1 ,17' - ~.' '-. 7P o:ro .r;;;-~. í;'? ~G. )) , {t-i IQ; s -:. i:'; r.... ~:¿, S ~~'"1 b (~, ~o' ---- ~ ---., ;~eo~et~:i'l ·~o; ~-¡ n:"- ~I; '>~ )~ - ç:-~~~''-\~Cél<'' ù,~~~~ç;) \.".., '''1 'I/:;;-¡', e -¡¿V;,-.:¡;;,~7.- (' I" \, ..¡;, ~ "o)(J""l. 7 :: ?.¡¡:;.,-~~\ ø (' Çc;.ç \\'\1-(.(-- -\-ôD ¿~1J'Î (, " i [. .¡;:;,.;)) (;.-.:> l\"';¡¡ "'~ ~ \r~; k", ;. ... ï V'\.#......J-l '''''''.J,.?/0 \ L~4 ~.'~ : ('".. ......--.-- ..... ... - «.. 'v'J' ~ '-:--..:-- Cement Bond Log (Yes or No>........id~Cµ '. ",,1:.J In ADGCC Ftl-e~~·:;~~z::=T=-~ , . ~).z. <>~;? ~ S ~;,~ if ~~ ~:~ ~ t D'~:;" 'S, ~'~" () t (ft' ~~J.', G~ GEL Evaluation, zone above perfs '/¿ld~;:Æ(~.d~ ",< (":\, ~ r-'" .." , ,"" ". ('\, \ (\, \ 1 C·\. /J . )C,~'t..\ \U~'~ \-.r0 \.::..J:~ ~~~c~ \)0 (''C'';; CtL ',," '-N)\ ,~-;-((:\. '.~) ",., ,'. (~,.A;¿':~r~~~jÞ(Ji !:;~~ ¿ :)'£") ':}<~~ 50:') Produc.tion Log: Type Evaluation 1"'. ,''\. 1'\ I'" ~ 1"\,, rr.= iJì _ t\ D \ > ,) ,~I ') (H I h ~no 'ð~ 'A~rL_7 !,,! h t~ t [0. CONCLUSIONS: Par t # 1 : -------".......~_..,..........._..~....~.......,-....... rev. OS/20/87 ,~ t61 ~(~("1...w. ,~.~..._ / \' ' ,./<' (52\'- C..:.:' ° i . ~ . ~ . ,~ . " t C~¡, ,1~~L"l 'v~"i¡ :~ ~;\.>:; ) ¿/1l,.,/ \ ~, ,J ...,......"_1' ,,",,,--1 " L_ -....." ,_ ........_~- .- ~J..05- \~/tQ )91 C.028 .~----- Par t 12: fV\ f T ON OR BEFORE ARY 03 2001 c=LO~n~w~D°c AOGCC Geological Materials Inventory PERMIT 9 7-062 ARCO Log Data Sent Recieved 7852 T SCHLUM PDC/GR 10/27/1997 10/30/1997 8167 D SPERRY MPT/GR/EWR4 10/29/1997 10/30/1997 CBL L 5550-6120 11/19/1997 11/21/1997 DGR/EWR4-MD L 5826-8485 10/29/1997 10/30/1997 DGR/EWR4-TVD L 5140-6381 10/29/1997 10/30/1997 MWD SRVY R SPERRY 5699.-8485. 11/5/1997 11/10/1997 10-407 Completion Date Daily well ops Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis _description recieved? --, yes Aretests required? yes no Received? :-- yes no Well is in compliance Initial Comments Box no Friday, October 08, 1999 Page 1 of 1 AOGCC Geological Materials Inventory PERMIT 97-062 Log Data 97-062 ~-~ 5550-6120 ('~ ~'~ ~ 97-062 ~"'~-~PERRY 5~99.-8485: 97-062 ~ SPERRY MPT/GR/EWR4 ~ [~.~ ~? 97-062 ~ SCHLUM PDC/GR ~ 2 ~':)~ 97-062 t~/ 5826-8485 ~'~ ~)~ C,~) }~-~( 97-062 ~Jff? 5140-6381 (?'1~ ,~ ~- ~-~ ~t ~[ ~-~07 Completion Date / 0//~/~/¢ Daily well ops ARCO Sent 11/19/1997 11/5/1997 10/29/1997 10/27/1997 10/29/1997 10/29/1997 Recieved /21/1997 /10/1997 /30/1997 /3O/1997 /30/l 997 /30/1997 Are dry ditch samples required? Was the well cored? Are tests required? Well is in compliance Comments yes ~- no And received? ~._--...~.s-...~-~ no yes ~ no Analysis description recieved? yes ~ no Received? Initial Box ~y. es-~.:5...no Thursday, October 07, 1999 Page 1 of l ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 31-12L1 (Permit No. 97-62) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the multilateral operation on the existing well KRU 31- 12. This completion report details the completion run in the newly constructed lateral leg, 31-12L1. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Development WSI/skad RECEIVED DEC - 5r glash3 0ii & Gas Cons. comm~lon Anohorago ORIGINAL 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 [] GAS [~ SUSPENDED [~ ABANDONED~ SERVICE ~'~ INJECTOR 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-62 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~., :. ...... '~., . ...:': 50-029-21565-60 131' FSL, 66' FEL, Sec. 36, T13N, R8E, UM " Kuparuk River Unit At Top Producing Inte~al [ ': . - ........ 10 Well Number 1403' FSL, 1437' ~L, Sec. 36, T13N, RSE, UM 31-12L1 At Total Depth ~ ......... . ~.~.[~ 11 Field and Pool 1552' FSL, 981' ~L, Sec. 36, T13N, R8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease D~ignation and Sedal No. Kuparuk River Oil Pool RKB 72', Pad 40' ADL 25523 ALK 2559 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. [ 15 Water Depth, if offshore 16 No. of Completions 13-Sep-97 16-Sep-97 12-O~-97 ~'~ NA feet MSL 1 17 Tot~ Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey ~20 Depth where SSSV set [ 21 Thickness of permafrost I 8488' MD & 6382' ~D 8392' MD & 6337' ~D YES ~ NO ~ NA feet MD 1465' APPROX 22 Type Electric or Other Logs Run G~CCURes/CBL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD [ CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5~ H-40 SURF. 110' 24' 259 sx Cold Set II 9.625" 36.0~ J-55 SURF. 3448' 12.25' 1150 sx CS III & 285 sx Class G 7' 26.0~ J-55 SURF. 5800' 8.5' 400 sx Class G & 175 sx CS I 4.5" 12.6~ L-80 5800' 8488' 6.125' 458 sx Class G 24 Pe~orations open to Production (MD+~D of Top and BoRom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8230'-8~70' MD 62~'~238' ~D 2.375 x 3.5' 7160' 5684' & 5870' 8155'-8120' MD 6231'-6217'~D 8095'-8075' MD 6206'-6198' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8028'-8008' MD 6178'-6169' ~D DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6 spf 27 PRODUCTION TEST Date First Production [Method of Operation (Flowing, gas lift, etc.) Inje~or Date of T~t Hours T~ted PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [ GAS-QIL RATIO I TEST PERIOl: Flow Tubing Casing Pre~ure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Pr~s. 24-HOUR RATE: 28 CORE DATA Bdef d~cdption of lithology, porosity, fracture, apparent dips and pr~ence of oil, gas or water. Submit core chips. ORIGINAL ECE VED ;~aska 0il a ~as Cons. Commission Anchora~,~ Form 10-407 Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE :29. 3[}. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7951' 6146' Top Kuparuk A 8068' 6195' 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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". Form 10-407 Date: 11/26/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:31-12L RIG:NORDIC WELL_ID: AK8821 TYPE: AFC: AK8821 AFC EST/UL:$ 1840M/ 2415M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:09/12/97 START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21565-60 09/06/97 (D1) TD: 7398' (7398) SUPV:DLW DAILY:$ 09/07/97 (D2) TD: 7398'( SUPV:DLW 0) DAILY:$ 09/08/97 (D3) TD: 7398' ( 0) SUPV:DLW DAILY:$ 09/09/97 (D4) TD: 7398'( SUPV:DLW 0) DAILY:$ 09/10/97 (D5) TD: 5841'( SUPV:DLW 0) DAILY:$ 09/11/97 (D6) TD: 5800'( 0) SUPV:DLW DAILY:$ 09/12/97 (D7) TD: 5826'( 26) MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 MONITOR WELL & WEIGHT UP CLEAR Turn key rig move from 3A pad to 3I pad. Move rig from 3A to 3I turn off. Accept rig for operation @ 1900 hrs. 9/7/97. 26,545 CUM:$ 26,545 ETD:$ 0 EFC:$ 1,866,545 MW: 11.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PULL & L/D 2-7/8" TBG Displace well w/seawater. Shut in well. Raise weight to 11.0 ppg. Displace seawater w/ll.0 ppg clear brine. N/D tree. N/U BOPE. Test BOPE 250/3500 psi. Pull and lay down 2-7/8" tubing. 40,115 CUM:$ 66,660 ETD:$ 0 EFC:$ 1,906,660 MW: 11.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 WEIGHT UP MUD Continue to pull 2-7/8" tubing. RIH w/BHA #1. 43,108 CUM:$ 109,768 ETD:$ 0 EFC:$ 1,949,768 - MW: 11.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TESTING 7" CSG TO 2000 PSI Work over OEJ slick stick @ 7080', packer came free. CBU, flowing light 10 psi on annulus gauge. Monitor well. Hole take fluid about 5 to 7 bbls per/hr. POOH. Recover packer assembly. RIH with 5.95" gauge ring junk basket to 7213' 53,325 CUM:$ 163,093 ETD:$ 0 EFC:$ 2,003,093 MW: 11.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MIXING HIGH VIS PILL RIH with permanent packer assembly. Set packer @ 7113-7160'. Test 7" casing to 2500 psi for 15 min. RIH w/ 2-7/8" tubing.. 50,679 CUM:$ 213,772 ETD:$ 0 EFC:$ 2,053,772 MW: 9.6 VISC: 48 PV/YP: 11/14 APIWL: 8.0 START MILLING OF WHIPSTOCK FAC RIH w/ orientation BHA assembly. Spot brine pill from 5841' to 5700'. RIH with Whipstock assembly. 45,884 CUM:$ 259,656 ETD:$ 0 EFC:$ 2,099,656 MW: 9.5 VISC: 71 PV/YP: 15/42 RIH W/WINDOW MILL APIWL: 6.0 Date: 11/26/97 SUPV:DLW DAILY:$ 09/13/97 (DS) TD: 5826' ( 0) SUPV:DLW DAILY:$ 09/14/97 (D9) TD: 6529'(703) SUPV:DLW DAILY:$ 09/15/97 (D10) TD: 7832'(1303) SUPV:DLW DAILY:$ 09/16/97 (Dll) TD: 8485'(653) SUPV:RLM DAILY:$ 09/17/97 (D12) TD: 8485'( 0) SUPV:RLM DAILY:$ 09/18/97 (D13) TD: 8485'( 0) SUPV:RLM ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 Sidetrack off Baker 'ML' whipstock from 5800' to 5802' Mill window from 5800' to 5814' Mill open hole from 5814' to 5826' 126,456 CUM:$ 386,112 ETD:$ 0 EFC:$ 2,226,112 MW: 9.6 VISC: 60 PV/YP: 12/36 APIWL: 5.8 RIH W/BHA #8 RIH with watermellon mill on window mill BHA #7. Performed LOT, 12.3 ppg EMW. Work 6.125" mill and watermellon through window from 5800' to 5814'. Test BOPE to 300/3500 psi. 56,751 CUM:$ 442,863 ETD:$ 0 EFC:$ 2,282,863 MW: 9.5 VISC: 48 PV/YP: 48/ 0 APIWL: 5.4 DRILLING @ 6975' P/U kelly fill pipe work through window @ 5800' to 5814' with bit 5818' started mud motor, ream out to 5826' continue to slide out for build and direction from 5826' to 6529' 63,961 CUM:$ 506,824 ETD:$ 0 EFC:$ 2,346,824 MW: 9.9 VISC: 50 PV/YP: 11/22 APIWL: 4.4 DRILLING AHEAD @ 8085' Continue drilling 6.125" hole w/BHA #8 for direction and angle from 6529' to 7704' Short trip from 7704' up 30' below window 5856'. One tight spot @ 6536'. Continue drilling ahead w/6.125" hole from 7704' to 7832' 58,883 CUM:$ 565,707 ETD:$ 0 EFC:$ 2,405,707 MW: 10.1 VISC: 55 PV/YP: 15/25 APIWL: 4.5 POOH Directional drill and survey with MWD from 7831' to 8467' Wipe hole from 8467' to 7769' work through tight hole at 7769' Continue to pull to window at 5800'. Had intermittent tight spots from 7092' to 6547', able to work through. Performed open hole LOT 12.5 EMW. Circulated, hole packed off. Regained and lost returns several times. Directional drill and survey w/MWD from 8467' to 8485' 56,150 CUM:$ 621,857 ETD:$ 0 EFC:$ 2,461,857 MW: 10.4 VISC: 55 PV/YP: 15/25 APIWL: 4.5 CIRCULATE LINER AT WINDOW Pump hi-vis sweep. Hole not cleaning up as well as it should, continued silt and shale across shakers. Increase mud weight to 10.3 ppg. POOH, had intermittent tight hole from 7092' to 6547' CBU, good cuttings recovery on bottoms up. Minor increase in cuttings with sweep, hole cleaning up. No packing off problems while circulating. Held pre-job safety meeting. Run 4.5" liner. 51,082 CUM:$ 672,939 ETD:$ 0 EFC:$ 2,512,939 MW: 10.3 VISC: 48 PV/YP: 15/20 __ ~PIWL: 4~8 DRILLING HARD CEMENT ~'%ECE/V~ Continue to run 4 1/2" liner to 8588'. Cement 4 1/2" A~aska Oil & Gas Cons. Commission Anchorage Date: 11/26/97 DAILY:$ 09/19/97 (D14) TD: 8488' ( 3) SUPV:RLM DAILY:$ 09/20/97 (D15) TD: 8488' ( 0) SUPV:RLM DAILY:$ 09/21/97 (D16) TD: 8488' ( 0) SUPV:RLM DAILY:$ 09/22/97 (D17) TD: 8488' ( 0) SUPV:RLM DAILY:$ 09/23/97 (D18) TD: 8488' ( 0) SUPV:RLM DAILY:$ 09/24/97 (m19) TD: 8488' ( 0) SUPV:RLM ARCO ALASKA INC. WELL SI/MMARY REPORT Page: 3 liner. Cement did not u-tube up drill pipedue to thick mud used for displacement of cement. 103,398 CUM:$ 776,337 ETD:$ 0 EFC:$ 2,616,337 MW: 10.2 VISC: 44 PV/YP: 12/15 APIWL: 6.0 TEST STACK Clean out hard cement from 5551' to top of 4.5" liner at 5788'. Clean out cement sheath on low side of 4.5" liner from 5788' to 5815' 36,228 CUM:$ 812,565 ETD:$ 0 EFC:$ 2,652,565 MW: 9.8 VISC: 35 PV/YP: 7/ 6 APIWL: 0.0 SWAP TO BRINE Test BOPE to 400/4000 psi. Held safety meeting on trapped pressure. RIH to top of liner. CBU. 32,643 CUM:$ 845,208 ETD:$ 0 EFC:$ 2,685,208 MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 POOH W/SCRAPER Clean mud pits. Flush all surface lines and equipment. Mix hi-vis and safe clean sweeps. Change over to brine. Run CBT/CCL/GR. 3 pieces of cement and a piece of rubber were caught in bottom centralizer on run #1. 48,750 CUM:$ 893,958 ETD:$ 0 EFC:$ 2,733,958 MW: 10.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RUN LOG INTO LINER Pump hi vis sweep and circulate hole clean. Recovered 5-10 gallons cement fines and 3 pieces of rubber from drill pipe dart. Clean out 12' soft fill in liner top. Continue to clean out. 35,687 CUM:$ 929,645 ETD:$ 0 EFC:$ 2,769,645 MW: 10.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PERFORATING WELL RIH w/CBT/CCL/GR, ran tool to 8147', stopped. RIH tool stopped at 6100' log to top of liner at 5788', made repeat run. Good cement to top of liner. Ran 3-3/8" CCL/GR to 8030' tool stopped, could not work tool to bottom. Build 1-11/16" CCL/GR with rollers. Ran to bottom CCL failed. POOH. Change out CCL run to bottom tool failed. Wireline not compatible with CCL tools on runs 1 and 2 with 1-11/16" tools. 35,820 CUM:$ 965,465 ETD:$ 0 EFC:$ 2,805,465 MW: 10.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RUN PACKER ON WL Continue run CCL/GR tool failed. Run CCL/GR. Run perf gun #1 perf from 8230' to 8210'. Run perf gun #2, first run failed. Rerun gun ~2 perf from 8210' to 8190'. Run perf gun #3 perf from 8190' to 8170'. Run gun #4, first run failed, rerun and perf from 8155' to 8135'. Run gun #5 perf from 8135' to 8120'. Run gun #6 perf from 8095' to 8075'. Run Date: 11/26/97 DAILY:$ 09/25/97 (D20) TD: 8488'( 0) SUPV:RLM DAILY:$ 09/26/97 (D21) TD: 8488'( 0) SUPV:RLM DAILY:$ 09/27/97 (D22) TD: 8488' ( 0) SUPV:RLM DAILY:$ 09/28/97 (D23) TD: 8488'( 0) SUPV:RLM DAILY:$ 09/29/97 (D24) TD: 8488'( 0) SUPV:RLM DAILY:$ 09/30/97 (D25) TD: 8488'( 0) SUPV:DLW DAILY:$ 10/01/97 (D26) TD: 8488' ( 0) SUPV:DLW DAILY:$ ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 gun ~7 perf from 8028' to 8008' 81,415 CUM:$ 1,046,880 ETD:$ 0 EFC:$ 2,886,880 MW: 10.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PUMP HPBD Run packer and set packer top at 5870'. Held pre-job safety meeting. Run HPBD assembly. 139,606 CUM:$ 1,186,486 ETD:$ 0 EFC:$ 3,026,486 MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PU 4.5" RETRIEVAMATIC PACKER Attempted test on tubing and seals, would not test. Attempted annular test, would not test. Tested surface equipment and determined had minor leak. Conducted HPBD. Opened well to manifold and monitored pressure decline. 130,170 CUM:$ 1,316,656 ETD:$ 0 EFC:$ 3,156,656 MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIH W/PILOT MILLING BHA RIH w/3.5" DP to top of packer @ 5870'. Set 'SB' plug in Model 'D' packer and set retrievamatic packer. Test BOPE. 60,905 CUM:$ 1,377,561 ETD:$ 0 EFC:$ 3,217,561 MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MU WASHOVER BNA RIH with pilot milling BNA to 5758' Milling 4.5" liner top w/Baker pilot mill. Remove pilot mill and shorten bullnose by 2' (suspect bullnose holding mill off bottom due to length). Resume pilot milling operation to 5793' 31,415 CUM:$ 1,408,976 ETD:$ 0 EFC:$ 3,248,976 MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIH W/SPEAR TO RETRIEVE 4.5" Continue pilot milling from 5793' to 5794'. Wash down and tag top of 4.5" @ 5793' Mill over 4.5" from 5793' to 5809'. Stuck washpipe @ 5809' Work stuck pipe and circulate. 33,604 CUM:$ 1,442,580 ETD:$ 0 EFC:$ 3,282,580 MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CIRC @ BAKER ML PKR 5841.5' RIH on 3.5" DP to 5797'. Stab in fish @ 5797'. RIH w/Whipstock assembly. 82,745 CUM:$ 1,525,325 ETD:$ 0 EFC:$ 3,365,325 MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 L/D GUIDESTOCK RUNNING TOOL RIH w/2-7/8" mule shoe joint and junk basket clean out assy to clean out ML packer @ 5841'. Circulate and work pipe @ 5841' top of ML packer. Had to rotate to clean out inside ML packer to 5847'. POOH. RIH with Baker Guidestock assy. 41,763 CUM:$ 1,567,088 ETD:$ 0 EFC:$ 3,407,088 Date: 11/26/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 10/02/97 (D27) TD: 8488'( 0) SUPV:DLW DAILY:$ MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MONITOR WELL @ 0600 W/150 PSI Continue to orient Guidestock. Slide into Baker ML packer 5841' Slide thru 4.5" liner window to 5862'. RIH with 3.125" overshot assy to retrieve SB plug from Model 'D' Baker packer @ 5870'. Work overshot at window trying get past guidestock. Rotate pipe slowly while lowering thru window, sliding on in hole to 5868' 34,015 CUM:$ 1,601,103 ETD:$ 0 EFC:$ 3,441,103 10/03/97 (D28) TD: 8488'( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 M/U GUIDESTOCK OVERSHOT ASSY. Continue circulating sand off top of 'SB' plug set in Baker model 'D' packer @ 5870'. Wash over 'SB' plug bar and latch on pull plug. Well flowing. Shut-in well. Started getting crude oil as opened well, continue getting oil til completely around. Weight up to 10.6+ ppg. Started pumping kill fluid. Oil at surface when annulus opened. Shut well in. Pump high vis FLO-PRO. Bullhead Flo-Pro below Model 'D' pkr and to perfs controlling annulus pressure. Shut down, well dead. 31,415 CUM:$ 1,632,518 ETD:$ 0 EFC:$ 3,472,518 10/04/97 (D29) TD: 8488' ( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIH W/SCOOPHEAD ASSY No gas or oil. RIH to recover guidestock. Work over guidestock @ 5803'. POOH with Guidestock. RIH to recover debris. 50,427 CUM:$ 1,682,945 ETD:$ 0 EFC:$ 3,522,945 10/05/97 (D30) TD: 8488' ( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TEST DUMMU SEAL IN 'ML' PKR Recovered debris catcher w/10 pieces of junk. RIH with Baker scoophead diverter w/anchor assy. Slide seal assy into 'ML' packer @ 5841' to 5853' POOH. 31,415 CUM:$ 1,714,360 ETD:$ 0 EFC:$ 3,554,360 10/06/97 (D31) TD: 8488' ( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 POOH RIh with dummy-seal assembly to top of 'ML' packer @ 5841' stab-in 'ML' packer w/seal assembly to 5857'. RIH with scoophead/diverter w/anchor assembly to top of 'ML' packer @ 5841' 33,265 CUM:$ 1,747,625 ETD:$ 0 EFC:$ 3,587,625 10/07/97 (D32) TD: 8488'( 0) SUPV:DLW MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 LOST MULE SHOE & LOWER SEAL AS RIH with fishing tools. Tag fish @ 5793'. RIH with seal assembly. Pass through scoop head and attempt entry into lateral w/seal assy. Encountered restriction @ 5807' (diverter block) preventing seal assy from entering top of lateral. RU foster tongs and attempt to rotate BHA through window. Unable to enter window. RIH with flexible BHA to Date: 11/26/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 DAILY:$ 5807', unable to pass through window w/new BHA. Spot high vis pill to fight fluid loss. 32,920 CUM:$ 1,780,545 ETD:$ 0 EFC:$ 3,620,545 10/08/97 (D33) TD: 8488' ( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 BOPE RIH with BHA #35. Latch into scoop head and attempt to release from ML packer. Pulled free. POOH, no fish. RIH. POOH with fish. Retrieved scoop head diverter anchor assembly. Test BOPE. 31,415 CUM:$ 1,811,960 ETD:$ 0 EFC:$ 3,651,960 10/09/97 (D34) TD: 8488'( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MU ML PACKER Test BOPE. RIH w/ muleshoe, boot basket, bit sub, bumper jar to check for obstructions through seal bore extension. RIH w/seal assembly, locator. Tag top of ML packer @ 5841' Sting into seal bore extension and test. MU ML packer and setting tool. 37,315 CUM:$ 1,849,275 ETD:$ 0 EFC:$ 3,689,275 10/10/97 (D35) TD: 8488' ( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 SETTING/ORIENTING SCOOPHEAD DI RIH with ML packer and setting tool. Tagged top of 1st ML packer @ 5841'. Set packer. Top of ML packer set @ 5834.5' 31,415 CUM:$ 1,880,690 ETD:$ 0 EFC:$ 3,720,690 10/11/97 (D36) TD: 8488' ( 0) SUPV: DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 POOH Continue RIH w/ scoophead diverter assembly to 5828'. Top of scoophead @ 5796' 51,165 CUM:$ 1,931,855 ETD:$ 0 EFC:$ 3,771,855 10/12/97 (D37) TD: 8488' ( 0) SUPV:DLW DAILY:$ MW: 10.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PULL LANDING JOINT RIH w/completion assembly. Sting into scoophead and verify latch. Test tubing and set packer. 165,038 CUM:$ 2,096,893 ETD:$ 0 EFC:$ 3,936,893 10/13/97 (D38) TD: 8488' ( 0) SUPV: DLW DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 STARTING 3Q-08A ND BOPE, NU production tree, test packoff @ 5000 psi. Test tree @ 250/5000 psi. Freeze protect well. Move off well. Release rig at 12:00 hrs. 10/13/97. 56,296 CUM:$ 2,153,189 ETD:$ 0 EFC:$ 3,993,189 End of WellSummary for Well:AK8821 S~ ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KRU / 31-12L1 500292156560 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 DATE OF SURVEY: 091697 MWD SURVEY JOB NUMBER: AK-MM-70266 KELLY BUSHING ELEV. = 72.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5699.00 5043.63 4971.63 39 55 N 78.76 W .00 717.43N 1911.91W 2038.60 5800.00 5121.26 5049.26 39 37 N 79.84 W .75 729.43N 1975.39W 2102.79 5986.43 5250.14 5178.14 52 42 N 75.95 W 7.17 758.04N 2106.43W 2236.42 6082.53 5304.87 5232.87 57 50 N 75.85 W 5.35 777.28N 2183.00W 2315.26 6177.59 5352.73 5280.73 61 41 N 73.46 W 4.60 799.04N 2262.17W 2397.32 6272.27 5397.81 5325.81 61 27 N 73.55 W .27 822.68N 2342.01W 2480.58 6367.88 5442.09 5370.09 63 20 N 72.95 W 2.06 847.10N 2423.13W 2565.29 6463.05 5484.14 5412.14 64 12 N 72.56 W .98 872.41N 2504.67W 2650.66 6557.14 5525.58 5453.58 63 31 N 72.96 W .82 897.45N 2585.34W 2735~14 6652.66 5568.78 5496.78 62 41 N 74.42 W 1.62 921.37N 2667.10W 2820.31 6748.36 5610.65 5538.65 65 25 N 72.78 W 3.24 945.68N 2749.63W 2906.34 6842.69 5650.06 5578.06 65 10 N 72.44 W .41 971.29N 2831.42W 2992.04 6938.31 5690.65 5618.65 64 35 N 72.55 W .63 997.33N 2913.98W 3078.62 7033.61 5732.36 5660.36 63 30 N 72.61 W 1.15 1022.99N 2995.74W 3164.30 7129.64 5776.03 5704.03 62 24 N 73.54 W 1.43 1047.89N 3077.55W 3249.82 7225.16 5820.47 5748.47 62 8 N 74.01 W .51 1071.51N 3158.73W 3334.35 7320.10 5863.95 5791.95 63 20 N 72.49 W 1.90 1095.83N 3239.54W 3418.74 7415.55 5907.37 5835.37 62 32 N 72.51 W .83 1121.40N 3320.60W 3503.74 7510.98 5950.76 5878.76 63 21 N 72.86 W .91 1146.69N 3401.74W 3588.73 7605.55 5993.79 5921.79 62 30 N 72.97 W .90 1171.43N 3482.24W 3672.94 7701.50 6038.75 5966.75 61 35 N 74.00 W 1.34 1195.53N 3563.50W 3757.69 7797.42 6081.60 6009.60 65 20 N 70.69 W 4.97 1221.58N 3645.23W 3843.48 7891.30 6120.62 6048.62 65 31 N 70.80 W .23 1249.74N 3725.84W 3928.80 7986.39 6160.34 6088.34 65 5 N 71.23 W .61 1277.85N 3807.54W 4015.16 8082.56 6201.03 6129.03 64 49 N 71.22 W .28 1305.89N 3890.04W 4102.26 8178.48 6241.37 6169.37 65 26 N 71.73 W .80 1333.54N 3972.55W 4189.27 8274.20 6282.62 6210.62 63 29 N 71.09 W 2.12 1361.07N 4054.41W 4275.60 8369.29 6326.37 6254.37 61 43 N 70.66 W 1.90 1388.72N 4134.16W 4359.97 8417.16 6349.07 6277.07 61 39 N 71.22 W 1.04 1402.48N 4173.99W 4402.09 8485.00 6381.29 6309.29 61 39 N 71.22 W .00 1421.71N 4230.52W 4461.77 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. NA[ HORIZONTAL DISPLACEMENT = 4463.02 FEET 0RIG! ~ AT NORTH 71 DEG. 25 MIN. WEST AT MD = 8485 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 287.22 DEG. RECE Vbu TIE-IN SURVEY AT 5,699.00' MD WINDOW POINT AT 5,800.00' MD PROJECTED SURVEY AT 8,485.00' MD NOV 10 199T Oil A Gas Cons, Com~ior~ Anchorage S! RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC KRU / 31-12L1 500292156560 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 DATE OF SURVEY: 091697 JOB NI3MBER: AK-MM-70266 KELLY BUSHING ELEV. = 72.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5699.00 5043.63 4971.63 6699.00 5589.56 5517.56 7699.00 6037.56 5965.56 8485.00 6381.29 6309.29 717.43 N 1911.91 W 655.37 932.78 N 2706.91 W 1109.44 454.06 1194.92 N 3561.38 W 1661.44 552.00 1421.71 N 4230.52 W 2103.71 442.27 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KRU / 31-12L1 500292156560 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 DATE OF SURVEY: 091697 JOB NUMBER: AK-MM-70266 KELLY BUSHING ELEV. = 72.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5699.00 5043.63 4971.63 717.43 N 1911.91 W 655.37 5735.99 5072.00 5000.00 722.06 N 1935.19 W 663.99 8.62 5868.36 5172.00 5100.00 738.19 N 2020.33 W 696.36 32.37 6023.40 5272.00 5200.00 765.29 N 2135.34 W 751.40 55.03 6218.22 5372.00 5300.00 809.22 N 2296.47 W 846.22 94.83 6435.14 5472.00 5400.00 864.88 N 2480.69 W 963.14 116.92 6659.71 5572.00 5500.00 923.06 N 2673.13 W 1087.71 124.57 6894.80 5672.00 5600.00 985.54 N 2876.48 W 1222.80 135.09 7120.95 5772.00 5700.00 1045.70 N 3070.17 W 1348.95 126.15 7338.03 5872.00 5800.00 1100.66 N 3254.82 W 1466.03 117.08 7558.33 5972.00 5900.00 1159.16 N 3442.19 W 1586.33 120.30 7774.85 6072.00 6000.00 1214.97 N 3625.90 W 1702.85 116.52 8014.09 6172.00 6100.00 1285.93 N 3831.33 W 1842.09 139.24 8250.41 6272.00 6200.00 1354.17 N 4034.26 W 1978.41 136.31 8465.44 6372.00 6300.00 1416.16 N 4214.22 W 2093.44 115.04 8485.00 6381.29 6309.29 1421.70 N 4230.52 W 2103.71 10.27 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11575 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 1/1 9/97 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk ,,, 1 C- 11 . ~1L~' !-~ ~, PRODUCTION PROFILE LOG 9709 06 I 1 1E-31 c~'l · I~)~[ CBT 970905 I 1 1 E-31 ,4, CET 970905 I 1 '~'Y-2 ~>' O5~ J,k,i ~ INJECTION PROFILE/WFL/(TDT-P) 970810 I 1 2A-14 ~,.~. I~1~ GAS LIFT SURVEY & FBHP 970917 I 1 2 A- 16 ~ · 14 '7' FLOWING PRESSURE sURVEY 9709 09 I 1 3C-02 ~,~. J~ 1.4,{ ~ WATER INJECTION PROFILE 970901 I 1 3C-02 q,," ',,[,/ INJECTION PROFILE 970904 I 1 31-12L1 4:~'-j ~ ~(~7._. ~ CBT 970923 I 1 . , Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 F! I I_1_11M G November 5, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re' MWD Survey 31-12L1 . ob L- Dear Sir/Madam, Enclosed is two hard copy of the above mentioned file(s). Well 31-12L1 MWD survey tie-in point at 5,699.00', window point at 5,800.00' to projected survey at 8,485.00'. Please call me at 563-3256 if you have any questions or concerns. Sincerely, William T. Allen Operations Support Engineer Attachments. k~OV ?0 1997 AJ~ka 0~1 & Gas Cons. Comr~ssbn gnct~ora.qe 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 10/27/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11490 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia LIS ~-~.--~- ~)~~ Tape 31-12L1 ~ '~'~'~ g7480 PDCGAMMARAY-COMPOSITE 970924 !1 · · Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: REOEtVbu ~q~"T ~0 199~' '~v ! ,,~Jaska Oil & Gas Cons. Commissior, Anchorage ri !=! i I_1_ I [M G S ~:: F! ~./I C ~:: S LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cormn. Atm.-Lori Taylor 3001 Porcupine Dr. . Anchorage, Alaska 99501 October 29, 1997 RE: MWD Formation Evaluation Logs 31-12 L1, AK-MM-70266 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 $1-12 LI: 2" x 5" MD Resistivity & Cranuna Ray Logs: 50-029-21565-60 2" x 5" TVD Resistivity &Garnrna Ray Logs: 50-029-21565-60 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia · . OCT ;50 1997 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company C! F! I (-!_1 IM G SGFIVII~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3 001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 31-12L1, October 29, 1997 AK-MM-70266 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention off Ytm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ICG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APIIC: 50-029-21565-60 OCT 30 t997 0il & Gas C~ns, . . . 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASi~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 11, 1997 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kupamk River Unit 31-12L1 ARCO Alaska, Inc. Permit No 97-62 Sur. Loc.: 131'FSL, 66'FEL. Sec. 36. TI3N. R8E. UM Btmhole Loc: 1536'FSL, 1008'FWL. Sec. 36, TI3N, RSE, UM Dear Mr. Zanghi: Enclosed is thc approved application for permit to drill thc above rcfcrcnced well. The permit to drill does not excmpt you from obtaining additional permits required bx, laxv from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new segment from existing well 31-12, Permit No. 86-60, APl No. 50-029- 21565. Production should continue to be reported as a function of thc original well identifier. Blowout prevention cquipmcnt (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed bcfore drilling beloxv the surface casing shoe must be given so that a representative of thc Commission may witness thc test. Notice mav be given bv contacting thc Commission petroleum field inspector on the North Slope David W.J~~ ~ Chairman ~ BY ORDER OF THE COMMISSION dl£'enclosures cc: Dcparlmcnl el' Fish & Game. I iabitat Section w/o encl. Department of E~lVh]onltll¢llt Conscn'ation w/o encl. STATE OF ALASKA Al_ASK,. OIL AND GAS CONSERVATION COMMISSIC~,I PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill [~ Redrill [] lb. Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Add Lateral X Re-Entry ['"1 Deepen [] Service [] Development Gas [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 72', Pad 40' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25523, ALK 2559 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 131' FSL, 66' FEL, Sec. 36, T13N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1405' FSL, 1432' FWL, Sec. 36, T13N, R8E, UM 31-12L1 #U-630610 At total depth 9. Approximate spud date Amount 1536' FSI, 1008' FWL, Sec. 36, T13N, RSE, UM 4/1 1/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3 I- 1 1 8458' MD 1405' @ Target feet 24'@ surface' feet 2560 6377' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAO 25.035(e)(2)) Kickoff depth 5800' feet Maximum hole angle 63.3° Maximum surface 2520 psig At total depth (TVD) 3200 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD {include stage dataI 6-1/8" 4-1/2" 12.6# L-80 NSCT 2658' 5800' 5121' 8458' 6377' 387 sxs Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. :~ Present well condition summary .i ~., c.O 1997 Total depth: measured 7 57 2 feet Plugs (measured) true vertical 6532 feet 41aska 0il & 6a.s Effective depth: measured 7 41 8 feet Junk (measured) true vertica 6408 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 8 O' I 6" 259 Sx CS II 11 0' 11 0' Surface 341 9' 9-5/8" 1150 sx CSlll, 285 sx Class G 3448' 3263' Intermediate Production 7477' 7" 175 sx CS 1, 400 sx Class G 7505' 6478' Liner Perforation depth: measured 7248'-7264', 7270'-7294', 7304'-7334' MD true vertical 6271'-6284', 6289'-6310', 6316'-6341' TVD 20. Attachments Filing fee X Property plat Fl .BOP Sketch X Diverter Sketch El Drilling program X Drilling fluid program X Time vs depth plot El Refraction analysis [] Seabed report [] 20 AAC 25.050 require, ments X 21. I hereby certify that t~e foregoing] is true and correct to the best of my knowledge Signed Title Drill Site Develop. Supv. Date ! "-- Commission Use Only I~ermit Number I APJ.~mber I Approval date .~ "~1 .,~'."' ~ ~ 50- O .2., ~'.,' ~ ~/..~ ~ ..~'-- ~'(::~ '~//'"'-- ¢ otherSee coVerrequirementsletter for Conditions of approval Samples required [] Yes i~ No Mud Icg required I'--I Yes J~ No Hydrogen sulfidemeasures '~ Yes E~ No Directional survey required ~ Yes [--I No Required working pressure forBOPE r"] 2M ~]. 3M I'-I 5M [~] 10M I--I 15M Other: by order of Approved by. _ ,~a-vi~ Johnston Commissioner tho commission Date ~/Z)~/// ~,,~7 Form 10-401 Rev. 7-24-89 Submit in triplicate MULTI-LATERAL PLAN SUMMARY Well 31-12L1 Type of well (producer/injector): Surface Location- Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date' Operation Days to Complete: Injector 131' FSL, 66' FEL, SEC 36, T13N, RSE, UM 1405' FSL, 1432' FWL, SEC 36, T13N, R8E, UM 1536' FSL, 1008' FWL, SEC 36, T13N, R8E, UM 8458' 6377' Nordic Rig 2 4-11-97 32 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Window in 7" casing 9.5 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to weight up 9.5-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9,5-10 <12% Drilling Fluid System- Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: ,;,,.. ,,.- .. ~,,a,~.:a ou & ~,-~2.$ Coils. Drilling fluid practices will be in accordance with the appropriate regulations stated in 2~rt~.~, .033. Page 1 Casing/Tubing Program: Hole size CsoJ'rba 6-1/8" 4-1/2", 12.6#, L-@0, NSCT Length Top (MD/TVD) Btm (MD/TVD 2658' 5800'/5121' 8458'/6377' Tubing 3-1/2", 9.3#, L-80, EUE 8rd 5711' 2-3/8", 4.7#, L-80, Hydril CS 160' 29'/29' 5740'/5074' 5740?5074' 5900'/5194' Cement Calculations: Casing to be cemented: 4-1/2" in 6-1/8" open hole Volume = 387 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 66%, & 20' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,520 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 13.0 ppg EMW. With an expected formation pressure in the Kuparuk of 3200 psi and a gas gradient of 0.11 psi/ft, this shows that formation breakdown would not occur before a surface pressure of 2,520 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The 31-12L1 wellbore, will kick off out of the 7" casing below both the K-10 and K-5 intervals. A Formation Integrity Test will be performed prior to ddlling ahead and will test the immediate area around the window and any shallow formations which are in communication along the 31-12 wellbore. If the Formation Integrity Test shows that the K-10 and K-5 intervals are not isolated and will not hold the desired equivalent mud weight, a cement squeeze at the window could be performed to help isolate these intervals. Off-set drilling data shows that wells in the area of 31-12L1 have been drilled to TD with 11.7 ppg mud and no loses. The kick-off point in 31-12L1 is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 5800' MD / 5121' TVD 63.3° (in sidetrack portion) No Hazards Page 2 Loqgin_~ Program- Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CBT/CCL Notes: All ddll solids generated from the 31-12L1 lateral will be hauled to CC-2A in Prudhoe Bay for gdnd and inject. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 31-12L1 GENERAL MULTI-LATERAL PROCEDURE PRE-RIG WORK: 1. RIH with wireline and pull valve from bottom GLM. Dummy off all others. 2. Set BPV in tbg. Install VR plug in annulus valve. GE . , . . . . . 10. 11. 12. 13. NERAL WORKOVER PROCEDURE: MIRU Nordic Rig 2. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. (0.5 day) Load pits w/kill wt brine (expected kill wt = 11.5 ppg). Circulate well to brine. Ensure well is dead. (0.75 day) ND tree. NU and test BOPE. (0.25 day) Screw in landing joint. POOH laying down 2-7/8" tubing and all jewelry. (1.0 day) PU DP. RIH w/overshot for 3.25" slick-stick and scraper spaced-out as close as possible to overshot. Pull retrievable packer. Work packer to relax elements and run scraper through new packer setting depth. POOH standing back DP. LD packer and tubing tail. (1.0 day) RU E-line unit. RIH and set Baker 'D' permanent packer with 'solid nose' shear-out-sub in tail-pipe to provide isolation to lower perfs in odginal 31-12 wellbore. Log up from packer, logging casing collars to determine space-out needed for setting depth of Baker 'ML' packer. (0.5 day) RIH with anchor for 'D' packer, 2-7/8" tubing as needed to space-out 'ML' packer with KOP, and 7" 'ML' packer. (Run debris catcher in place, landed just below the 'ML' packer in cross-over to 2.688" seal bore.) Latch into 'D' packer with anchor and test annulus to 2500 psi for 15 minutes. Pressure up on DP and set 'ML' packer. Release from packer and POOH. (0.75 day) PU assembly with 'ML' anchor (with 25K shear ring) and MWD. RIH and latch into 'ML' packer. Circulate up toolface with MWD and determine orientation of Packer Lug. Shear out and spot high-vis viscosified brine pill on top of 'ML' packer. POOH. (0.75 day) MU and RIH with whipstock and window milling assembly. Latch into 'ML' packer and shear milling assembly from whipstock. Displace brine from hole, circulating well to milling fluid. Mill and ream window until smooth window is achieved. POOH with milling assembly. (1.5 days) RIH with 6-1/8" PDC bit, mud motor, MWD/LWD, and remaining drilling assembly. Orient motor and slide out window. Kick-off well and directionally drill to total depth as per directional plan. Short trip up into 7" casing. POOH. (5.25 days) MU whipstock pulling assembly. RIH and retrieve whipstock, shearing anchor from 'ML' packer. (0.75 days) MU and RIH with guidestock and window dressing assembly. Latch into 'ML' packer and shear assembly free from guidestock. Check MWD orientation. Ream in and out of window to dress-off window and confirm accessibility out window. POOH. (0.75 days) MU 6-1/8" bit and BHA similar to what the well was drilled with. RIH to TD to wipe the hole and condition well for running liner. POOH. (0.75 days) Page 4 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. Run 4-1/2" liner to TD, planning for 15' of liner lap above window. Circulate and condition well for cement job. Cement liner. Bump plug and increase pressure to release from running tool. Unsting from setting sleeve and pull +/-200' above the liner top. Break circulation and circulate any cement above that point from the well. POOH. (1.75 days) WOC as needed. (0.5 day) RIH with 6-1/8" bit and cleanout assembly. Clean out cement in 7" casing down to top of liner. POOH. (0.5 day) RIH with 3-3/4" bit and cleanout assembly on 2-3/8" DP. Clean out cement in 4-1/2" liner to PBTD. POOH. (0.75 day) RIH with 4-1/2" and 7" scrapers spaced out to take 4-1/2" scraper to TD and 7" scraper to top of liner. Displace well to kill weight brine at TD. POOH. (0.75 day) RU E-line. Run CBL and perforate well. Make gauge ring / junk basket run and set 4-1/2" 'D' packer +/-75' outside of window. (Shear-out-sub below packer to be equipped with 'solid nose'.) (0.5 day) RIH with 3-1/2" x 2-3/8" tubing workstdng to enable pumping HPBD. Sting into 2.688" seal bore with seal assembly. Space out and land tubing. Pressure test workstring to 3000 psi. Increase pressure to 3500 psi and shear shear-out-sub from below packer. (0.75 day) RU Dowell HPBD equipment. Perform HPBD on well. Displace wellbore to kill weight brine upon completion. Allow well to stabilize and assure well is dead. (1.25 days) Back out lock down screws and POOH standing back 3-1/2" and 2-3/8" tubing as needed. (0.5 day) RIH with 'SB' packer plug for 4-1/2" 'D' packer and 4-1/2" Retrieva-Matic test packer, spaced out one joint above 'SB' running tool. Set packer plug in 'D' packer. PU and set Retrieva-Matic in 4-1/2" liner. Test 'D' packer and packer plug to 3500 psi. Pull Retrieva-Matic up in 7" casing and spot sand plug on top of 'D' packer. Displace well to milling fluid at top of sand plug. POOH. (1.0 day) RIH with pilot milling assembly. Mill 4-1/2" casing down to +/-5' of top of window in 7" casing. POOH and PU washover assembly. RIH and washover remaining liner lap and mill liner at window. Continue to wash down until engaging dogs on control bushing with washpipe. PU and shear anchor from 'ML' packer. POOH with liner lap and equipment down to 'ML' packer. (2.25 days) RIH to top of 'ML' packer with 3-1/2" DP and 2-3/8" tubing singer. Wash down cleaning out inside of 'ML' packer to top of debris catcher. Circulate well clean, reverse circulating as necessary, and POOH. (0.5 days) PU and RIH with guidestock. Latch into 'ML' packer and shear assembly free from guidestock. POOH. (1.0 day) RIH with overshot for 'SB' packer plug. Wash down into 4-1/2" liner, circulating any metal debris and sand from on top of packer. Displace well to kill weight brine at max rate. Latch onto packer plug and pull from 'D' packer. POOH. (0.75 day) PU DP and RIH with guidestock pulling assembly. Retrieve guidestock, shearing anchor from 'ML' packer. (0.75 days) RIH to top of 'ML' packer with 3-1/2" DP and 'GS' spear. Wash down cleaning out inside of 'ML' packer. Once the well is clean, latch debris catcher and POOH. (0.75 day) PU the scoophead diverter and running assembly. RIH and latch into 'ML' packer with anchor. Confirm latch-in with tension and test anchor seals with pressure. Increase pressure to shift circulation by-pass sleeve and circulate 1-1/4" tripping ball into place. Pressure up and release running tool. POOH. (0.75 day) Page 5 31. 32. 33. 34. 35. 36. PU seal assembly for 2.688" seal bore, 2-3/8" CS Hydril tubing as needed, and liner tie-back sleeve on running tool. (The Camco 1.562" 'D' nipple will be incorporated into the seal assembly and will have a standing valve run in place while RIH with this equipment.) RIH on 3-1/2" DP. Run seals out into new wellbore circulating down thru port in seal assembly watching pressure and returns as an indication of seals entering PBR. Continue to RIH and latch tie-back sleeve in top of scoophead diverter. Pressure test seals in 2.688" seal bore. If space-out is adequate, drop trip ball and pressure up to release running tool. POOH laying down DP. (1.25 days) PU the completion assembly including the SRT, parallel seal assemblies, an 'FHL' retrievable packer, and the remaining 3-1/2" completion tubing and equipment as required. RIH and land parallel seal assembly into top of schoophead. Verify correct position of parallel seal assembly with pressure and overpull due to latch snap. (0.75 day) RU slickline. RIH and set standing valve in 2.75" 'AR' nipple below 'FHL' packer. Slack-off on slickline and pressure tubing to 2500 psi to set 'FHL' packer. POOH and RD slickline. PU and shear PBR. Space out and land tubing. Pressure tubing to 2500 psi to test all seals and completion equipment. Hold pressure for 30 min. Bleed off pressure. (0.25 day) Set BPV. ND BOPE. NU and test tree. (0.25 day) Pressure tubing to 3500 psi and shear SOS in tailpipe of original wellbore. Bleed off pressure. Pressure annulus to 3000 psi and shear dump kill valve in GLM immediately above 'FHL' packer. Displace well to sea water and freeze protect to 2000' TVD. Secure well and RDMO Nordic Rig 2. (0.5 day) RIH with slickline. Run selective re-entry tool (oriented to enter new wellbore) to SRT. Pull standing valve from 1.562" 'D' nipple and then pull selective re-entry tool. Dummy off GLM above 'FHL' packer. Lower Limit: 28 days Expected Case: 32.5 days Upper Limit: 48 days Only minor problems. Encounter problems but nothing major. Numerous problems encountered with a few being major. WSI 03/28/97 P~e6 ARC 0 ALAS KA,. Inc. Structure: Pod 31 Well : 12L1 Field : Kuparuk River Unit Location : North Slope, Alaska fCrealed by janes For: B lsaacson] Date plotted: 27-Mar-g7 Plot Reference i$ 12A Version ~7. [ Coordinates are In i'eet ret*fence slot ~12A. J Yeti;cai Dept. h~e RKB (Nordic "]'l II",J'J'l~ I 5100 5250 5400 5550 5700 5850 J TD LOCATION: J 15.36' FSL, 1008' FWL SEC. 56, T15N, RBE KOP - SIDETRACK PT TVD=5121 TMD=5800 DEP=2102 45.91 52.24 DLS: 6.50 deg per 100 ft 58.60 EOC %/D=5352 TMD=6174 DEP=2392 <- West (feet) 4350 4200 4050 3900 .3750 .3600 3450 3300 3150 3000 2850 2700 2550 2400 2250 2100 1950 1800 I I I I I I 1 I(...)O~.~ )~ I I~,3 I I I I I I I I I I I I I I I I I I I I I I I I SEC. 36, 113N, RSE / d AVERAGE ANGLE 63.34 DEG B/ HRZ TVD=Sg07 TMD=7411 DEP=3497 C30 TVD:5572 TM0=6664 OEP=2830 1500 1350 I 1200 Z 0 ..+. 1050 go0 750 600 6000 K-1 MARKER TV0=6032 TM0=7690 OEP=5746 6~5o ~', TAJ~GET ~:/ KUP UNIT C~TVD=6154 TMD=7962 DEP=3989 T/ UNIT D ~D=6154 TMD=7917 DEP=3950 ~ -%> ""~" ~ T/ UNIT A3 WD=6189 TMD=8040 DEP=4059 :-.-'-: ~ ...... L, .... B/ KUP SNDS WD=6287 TMD=8258 DEP=4254 6~oo ~' <~ ~'0 · ~ TD ~D=6377 TMD=8458 DEP=4433 6600 I t I I I I I I II II I I I I I I I I I 1950 Bo 2250 ~-'~400 2550 2700 2850 3000 3150 3300 5450 3600 5750 3900 4050 4200 4350 4500' ~] Vertical Section (feet) -> ,., Azimuth 287.22 with reference 0.00 N, 0.00 E from slot ~12A 287.22 AzimuLh 4433' (TO TD) ***Plone of Proposal*** KRU 31-12L1 Proposed Existing Wellbore Completion J. Baker Model 'ML' 7" perm packer (4.25" ID) with crossover to 2.688" Seal Bore Extension. I. Baker 2.688" ID Seal Bore Extension (5' effective stroke) with crossover to 2-7/8" EUE 8rd pin down. H. 2-7/8" x 10' L-80 EUE 8rd blast joint. G. 2-7/8" L-80 EUE 8rd tubing as needed to space out 'ML' pacer to KOP. F. Baker 80-32 Anchor Seal Assembly (2.406" ID thru seals) w/2-7/8" 6' EUE 8rd L-80 handling pup on top. E. Baker 84-32 Model 'D' 2-7/8" x 7" perm packer set on E-line (3.25" Seal Bore ID). D. Pup jt 2-7/8" x 10' L-80 tbg C. Camco 2-7/8" 'D' nipple, 1.562" No-Go profile B. 1 full jt 2-7/8" L-80 EUE 8rd tbg A. Baker 2-7/8" solid nose shear out sub pinned for ???? psi. 7", 26#, J-55 WSI 04/1/97 KRU 31-12L1 Multi-Lateral Proposed Liner w/Perfs & Tie-Back Packer Window milled in 7" casing from +/-5800' MD to 5816' MD. D. 4-1/2" Baker Size '23-26' Model 'D' permanent packer (3.75" OD, 2.688" ID). C. Baker 10'x 2.688" ID seal bore extension (12' total effective stroke with packer) with 3-1/2" FL-4S pin down. B. 3-1/2" x 10' FL-4S tubing pup. A. 3-1/2" FL-4S Solid Nosed Shear out Sub, pinned for 3500 psi. Perforations 7", 26#, K-55 4-1/2" 12.6 ppf, L-80, NSCT Liner as needed. WSI 4/1/97 KRU 31-12L1 Multi-Lateral Proposed Final Completion P. 3-1/8" 5M FMC Gen III tubing hanger with 3-1/2" L-80 EUE 8rd pup, pin down. O. 3-1/2" L-80 EUE 8rd Mod tbg to tubing hanger. N. 3-1/2" CAMCO 'DS' landing nipple with 2.812" ID No-Go profile set at +/- 500' MD. 6' L-80 handling pup on top and 6' L-80 flow coupling on the bottom. M. 3-1/2" L-80 EUE 8rd Mod tubing to 'DS' landing nipple. L. 3-1/2" x 1-1/2" CAMCO MMM mandrel w/DCR-1 dump kill valve & RKP-2 latch (3000 psi casing to tubing shear). 6' L-80 handling pups installed. K. 1 jt 3-1/2" L-80 EUE 8rd Mod tbg J. 3-1/2" CAMCO 'W' landing nipple with 2.812" ID Selective profile. I. 3-1/2" Baker '80-40' PBR w/10' stroke (32,000 lb shear). 6' L-80 handling pup installed. H. Baker 'FHL' 3-1/2" x 7" retrievable packer. (60,000 lb shear or rotational release). G. 2 jts 3-1/2" L-80 EUE 8rd Mod tbg F. See attached detailed drawing of SRT and Parallel Seal Assembly. E. Liner tie-back sleeve, size 47 (1.935" ID, 2.890" OD) with 2-3/8", 4.7#, Hydril CS pin down. D. 2-3/8" 4.7#, L-80, Hydril CS tubing as needed (1.995" ID, 2.705" Couping OD). C. Tubing Seal Assembly for 15' x 2.688' Polished Bore with ported spacer tube placed between two full sets of seals. 2-3/8" 4.7# Hydril CS box up and crossover to 2-1/16" 3.25# Hydril CS box on bottom. B. 2-1/16' Camco 'D' landing nipple w/1.562' No-Go profile, 2-1/16" 3.25# Hydril CS pin x pin connections. 2.330' max OD. A. Tubing Seal Assembly blank spacer tube (+/-2') with mule shoe on bottom and crossover to 2-1/16' 3.25# Hydril CS box looking up. 7", 26#, J-55 WSI 4/1/97 KRU 31-12L1 Multi-Lateral Parallel Seal Assembly 3-1/2" x 6' 9.3 ppf, L-80, EUE-8rd Mod pup. Crossover to 3-1/2" EUE 8rd-Mod. 2-3/8" 4.6 ppf, L-80, VAM tubing. (Cut to length as needed to accomodate make-up of SRT and parallel seal assembly.) Baker 7" Selective Re-entry Tool with Baker 'AR' profile for landing diverter assembly. Diverter assembly is locked into profile with the 'SR' lock (1.810" rain ID). 2- 3/8" 4.6 ppf VAM box down on both legs out of SRT. 2-3/8" 4.6 ppf, L-80, VAM tubing. (Cut to length as needed to accomodate make-up of SRT and parallel seal assembly.) Parallel Seal Assemblies. 2-3/8" 4.6 ppf VAM pin up on both seal assemblies. WSI 04/1/97 7-1/16" 5000 PSI BOP STACK !/~N N U LAR ~ b Rm I ~~J 5 BLIND RAM~ I I CROSS 4 3 RAM ACCUMULATOR CAPACITY TEST 1. 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 SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOp ,STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSETOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2. 11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4. 7-1/16" o 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER iq::_° i99' Alaska 0il & ~:;as Co~ls, Oornmis5'~' Ar, chui'atje NORDIC RIG g2 LEVEL 1 ~' v Z Z EMSCO F-800 (~ TRIPLEX MUD PUMP SPIRAL .. STAIRS C~TROL ~CO~OLE NORDIC RIG g2 LEVEL 2 NORDIC RIG LEVEL I UNE I [SP°°~LI LISTER AIR HEATER MUD TANK 750 BBLS SPIRAL STNRS CHOKE: MANIFOLD i WATER TANK /GLYCOL TANK 15'-6' HM3RAUUC 'CATWALK 123' --0' 15'-6' RAMP WELL PERMIT CHECKLISToo. .Y INIT CLASS. PROGRAM: expo dev~redrlr] servO wellbore se~ann disp para UNIT, /1t ,O ON/OFF SHORE reqO ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING · Y · Y .Y .Y · Y · Y · Y .Y .Y · Y .Y · Y REMARKS 14. Conductor string provided ................ f N'7 15. Surface casing protects all known USDWs ......... Y i~.-. 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N! N 19. Casing designs adequate for C, T, B & permafrost .... ~ 20. Adequate tankage or reserve pit ............. O N 21. If a re-drill, has a 10-403 for abndnmnt been approved. .~-----N~;~-- 22. Adequate wellbore separation proposed .......... ~A 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/Alii RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N,/__ 31. Data presented on potential overpressure zones ..... ~/N~~/~ 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ...... ~/~ . Y N ' 34. Contact name/phone for weekly progress reports . //. . . Y N [exploratory only] ENGINEERING: COMMISSION: JDH-~"-- mcm ~ Comments/Instructions: 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 : ARCO ALASKA, INC. WELL NAME : 3I - 12L1 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API 1VUIVI~ER : 50-029-21565-60 REFERENCE NO : 97480 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... * ............................ . COMPANY NAME : ARCO ALASKA, INC. WELL NAM~ : 3I - 12L1 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUIVlBER : 50-029-21565-60 REFERENCE NO : 97480 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT~1997 11:00 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 97/10/27 ORIGIN . FLIC REEL NAME : 97480 CONTINUATION # PREVIOUS REEL COf~4~NT : ARCO ALASKA INC, KUPARUK, 31-12L1, API #50-029-21565-60 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE . 97/10/27 ORIGIN : FLIC TAPE NAM~ : 97480 CONTINUATION # : 1 PREVIOUS TAPE : CO~94FAVT : ARCO ALASKA INC, KUPARUK, 31-12L1, API #50-029-21565-60 TAPE HEADER Kuparuk River CASED HOLE WIRELINE LOGS WELL NAME: 3I - 12L1 API NUMBER: 500292156560 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 27-0CT-97 JOB lqUMBER: 97480 LOGGING ENGINEER: John Majcher OPERATOR WITNESS: Bobby Morris SURFACE LOCATION SECTION: 3 6 TOWNSHIP: 13 N RANGE: 8E FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 62.50 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 5800.0 12.60 2ND STRING 4. 500 8488.0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NU~ER : PASS ~ER : DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH REMARKS: ***NOTE*** THIS EDIT DOES NOT STRICTLY APPLY TO THE LDWG FORMAT. TWO RUNS HAVE BEEN SPLICED TO CREATE A COMPOSITE RUN - PRESENTED IN FILE 3 AND 6. This tape contains the LDWG cased hole edit for ARCO Alaska well 31-12L1 primary depth control gamma ray. The GR was obtained in two sections. The initial section (5500 - 6118 ft md) was obtained from the CET run 9/23/97. The CET couldn't get below 6118 ft. The lower section was run with GR/CCL run to TD for Perf depth control (9/24/97). It covers the interval 7690 - 8400 ft md. Both logs were correlated to the Sperry Sun ROP/DGR/EWR4. The interval between the logs is represented by absent values. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENO~fBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~k~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 6307.0 5549.5 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: BASELINE CTIRVEFOR SHIFTS LDWG CURVE CODE: NONE PASS--ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH REMARKS: This file contains the Gamma Ray from the CET run. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E 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 1094414 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 1094414 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 1094414 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CET V 1094414 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: DEPT. 6307. 000 GRCH. CET DEPT. 5549.500 GRCH. CET 62.219 TENS. CET 70.813 TENS. CET 610. 000 CCL. CET 2240.000 CCL.CET 0.002 -0.004 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASSNUPiBER: 2 DEPTH INCREFiENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8400.0 7691.5 $ CURVE SHIFT DATA - PASS TO PASS (lVlEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUM~ER: BASELINE DEPTH $ .......... EQUIVALF2Fr UNSHIFTED DEPTH .......... GRCH LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: ~S: This file contains the Gamma Ray from the GR/CCL log run with the perf guns. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 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 NLTM~ SAMP ELEM CODE (HEX) DEPT FT 1094414 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH GRCH GAPI 1094414 O0 000 O0 0 2 1 1 4 68 0000000000 TENS GRCH LB 1094414 O0 000 O0 0 2 1 1 4 68 0000000000 CCL GRCH V 1094414 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ~:* DEPT. 8400.000 GRCH. GRCH 60.844 TENS.GRCH 1825.000 CCL.GRCH DEPT. 7691.500 GRCH. GRCH 72.250 TENS.GRCH 1875.000 CCL.GRCH 0.000 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: **** FILE TRAILER **** FILE NAFiE : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NOMBER: DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8388.0 5549.5 $ CURVE SHIFT DATA - PASS TO PASS (I~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH REMARKS: This file contains the composite Gamma Ray from the CET and CCL/GR. Absent values are present between the two runs. No depth shifting was applied as this GR becomes the primary depth control. ** NOTE ** pass number not labeled because it is a composi re. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 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 NUlVfl3SAMP ELEM CODE (HEX) DEPT FT 1094414 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH GRCH GAPI 1094414 O0 000 O0 0 3 1 1 4 68 0000000000 TENS GRCH LB 1094414 O0 000 O0 0 3 1 1 4 68 0000000000 CCL GRCH V 1094414 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8400.000 GRCH. GRCH 60.844 TENS.GRCH 1825.000 CCL.GRCH DEPT. 5549.500 GRCH. GRCH 70.813 TENS.GRCH 2240.000 CCL.GRCH 0.000 -0. 004 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: **** FILE TRAILER **** FILE NA~iE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 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 SUFk~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 6118.0 5549.5 GRCH LOG HEADER DATA DATE LOGGED: 23-SEP-97 SOFTWARE VERSION: CP 44.2 TIME LOGGER ON BOTTOM: 929 23/--SEP~97 TD DRILLER (FT): 8392.0 TI) LOGGER (FT) : 8388.0 TOP LOG INTERVAL (FT) : 7690.0 BOTTOM LOG INTERVAL (FT) : 8388.0 LOGGING SPEED (FPHR): 3000.0 DEPTH CONTROL USED (YES/NO) : NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CET COLLAR LOCATOR CAL YA 030 CET CEMENT BOND ECH KC 2840 CET CE~IENT BOND SGC SA 479 CET CEMENT BOND CBS DA 86 CET CE~iENT BOND HCH AB 90 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 5800.0 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) : Brine 9.90 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REMARKS: This file contains the raw data from the CBT GR. Correlation Log: Sperry-Sun ROP/DGR/EWR4. Deepest point reached with CBT was 6118. No free pipe in behind 4 1/2" liner GR/CCL run to TD for Perf Depth Control $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 i 0 66 1 ** SET TYPE - CHAN ** NA~E 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 1094414 O0 000 O0 0 4 1 1 4 68 0000000000 GR CBT GAPI 1094414 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CBT LB 1094414 O0 000 O0 0 4 1 1 4 68 0000000000 CCL CBT V 1094414 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 6307. 000 GR. CBT 62. 219 TENS. CBT 610. 000 CCL. CBT O. 002 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11: O0 PAGE: 11 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREM~IVT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GRCH 8388.0 $ 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) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CET CET CET CET CET $ 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) : COLLAR LOCATOR CEFIENT BOND CEMENT BOND CEME~IT BOND CEMENT BOND STOP DEPTH 7690.0 24-SEP-97 CP 44.2 316 24-SEP-97 8392.0 8388.0 7690.0 8388.0 3000.0 NO TOOL NUMBER CAL YA 030 ECH KC 2840 SGC SA 479 CBS DA 86 HCHAB 90 5800.0 Brine 9.90 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: 12 BOTTOM HOLE TEMPERATURE (DBGF): 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): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REMARKS: This file contains the raw data from the CCL/GR. Correlation Log: Sperry-Sun ROP/DGR/EWR4. Deepest point reached with CBT was 6118. No free pipe in behind 4 1/2" liner GR/CCL run to TD for Perf Depth Control $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: 13 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFi~ 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 1094414 O0 000 O0 0 5 1 1 4 68 0000000000 GR CCL GAPI 1094414 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CCL LB 1094414 O0 000 O0 0 5 1 1 4 68 0000000000 CCL CCL V 1094414 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 8400.000 GR.CCL 60.844 TENS.CCL 1825.000 CCL.CCL DEPT. 7691.500 GR.CCL 72.250 TENS.CCL 1875.000 CCL.CCL O. 000 O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: 14 FILE HEADER FILE NUM~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: DEPTH INCREMENT: O. 5000 FILE SURmD~Y VENDOR TOOL CODE START DEPTH GRCH 8388.0 $ 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) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ 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): STOP DEPTH 5549.5 24-SEP-97 CP 44.2 8392.0 8388.0 7690.0 8388.0 NO TOOL NUMBER 5800.0 Brine 9.90 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: 15 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 0 ArEAR COUNT RATE LOW SCALE (CPS): 0 ArEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REMARKS: This file contains the raw spliced file for the depth control gr. Correlation Log: Sperry-Sun ROP/DGR/EWR4. Deepest point reached with CBT was 6118. No free pipe in behind 4 1/2" liner GR/CCL run to TD for Perf Depth Control ** NOTE ** pass number not labeled because it is a composite. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 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 1094414 O0 000 O0 0 6 1 1 4 68 0000000000 GR CBT GAPI 1094414 O0 000 O0 0 6 1 1 4 68 0000000000 TENS CBT LB 1094414 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1997 11:00 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~S MOD NUMB SAMP ELEM CODE (HEX) CCL CBT V 1094414 O0 000 O0 0 6 1 1 4 68 0000000000 * * DA TA * * DEPT. 8400.000 GR.CBT 60.844 TENS.CBT 1825.000 CCL.CBT DEPT. 5549.500 GR.CBT 70.813 TENS. CBT 2240.000 CCL.CBT O. 000 -0.004 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA3KE : EDIT DATE : 97/10/27 ORIGIN : FLIC TAPE NAME : 97480 CONTINUATION # : 1 PREVIOUS TAPE : COI4F~MVT : ARCO ALASKA INC, KUPARUK, 31-12L1, API #50-029-21565-60 **** REEL TRAILER **** SERVICE NAIVE : EDIT DATE : 97/10/27 ORIGIN : FLIC REEL NAME : 97480 CONTINUATION # : PREVIOUS REEL : COt~IENT : ARCO ALASKA INC, KUPARUK, 31-12L1, API #50-029-21565-60 Sperry-Sun Drilling Services LIS Scan Utility Thu Oct 23 09:35:28 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Tape Header Service name ............. LISTPE Date ..................... 97/10/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: Library. Scientific 31-12 L1 500292156560 ARCO A~A. SKA, INC. SPERRY-SUN DRILLING SERVICES 23-OCT-97 MWD RUN 3 AK-MM-702 66 R. MCNEILL D. WESTER MSL 0) 36 13N 08E 131 66 62.50 .00 .00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.130 7.000 5800.0 4.500 8485.0 8485.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUNS 1, 2 AND 3 REPRESENT WELL 31-12L1 WITH API#: 50-029-21565-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8485'MD, 6381'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). -SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH RPD 5789.5 RPM 5789.5 RPS 5789.5 RPX 5789.5 GR 5789.5 FET 5824.5 ROP 5826.5 $ STOP DEPTH 8439.5 8439.5 8439.5 8439.5 8432.5 8439.5 8485.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 5789.5 5800.5 5802.5 5809.5 5811 5 5813 5 5816 5 5820 5 5822 0 5824 5 5826 0 5827 0 5831 0 5833 5 5834 5 5836 5 5837 5 5839 0 5879 5 5884 5 5886 5 5888 5 5890 5 5901 5 5913 0 5914 5 5918 5 5959 5 5961 0 5966 0 5991 0 5993 0 6000 0 6003 5 6008 0 6010 5 6012 5 6020 5 6026 0 6028 5 6035 0 6038 5 6045 0 6048 5 6053 5 6055 0 6059 0 6061 0 6063.-5 6066 5 6068 0 6072 5 6075 5 6103 0 6104 0 GR 5790.0 5801.0 5804.0 5809.0 5811.0 5815.0 5816.5 5822.0 5824.5 5826.5 5827.5 5829.0 5830.5 5832.5 5834.5 5836.5 5838.5 5839.0 5878.5 5880.5 5884.0 5888.0 5891.0 5904.0 5914.0 5915.0 5917.5 5955.5 5957.5 5963.0 5989.0 5992.5 5998.5 6002.5 6008.5 6010.5 6012.5 6019.0 6024.5 6027.5 6035.0 6037.5 6046.5 6048.5 6051.0 6053.0 6056.5 6060.0 6062 0 6065 5 6066 0 6070 5 6073 0 6102 0 6104 5 6105 7695 7698 7704 7706 7738 7741 7744 7747 7749 7758 7768 7778 7804 7824 7834 7835 7840 7844 7852 7854 7855 7857 7861 7863 7892 7897 7899 7906 7909 7913 7915 7917 7919 7934 7937 7939 7955 7962 7977 7983 7985 7996 8013 8016 8027 8029 8031 8042 8057 8073 8077 8078 8082 8085 8124 8125 8129 8131 8134 .5 .0 .0 .0 .0 .0 .5 .0 .0 .5 .5 5 0 0 5 0 5 0 .5 .5 .5 .5 .0 .0 .5 .0 .0 .0 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .0 .5 .0 .5 .0 .5 0 5 0 0 0 0 0 0 5 0 5 0 6106 7695 7698 7703 7706 7738 7742 7744 7746 7750 7759 7767 7781 7804 7823 7832 7836 7840 7843 7853 7854 7855 7857 7861 7863 7893 7897 7900 7906 7908 7913 7915 7918 7922 7938 7940 7942 7956 7962 7978 7983 7986 7995 8013 8016 8027 8029 8032 8042 8058 8073 8076 8078 8081 8085 8123 8126 8130 8133 8134 0 5 5 0 5 0 5 5 5 0 5 0 0 0 5 5 0 5 .0 .0 .0 .0 .5 5 0 5 0 0 0 5 0 0 0 0 5 0 5 0 5 .5 .5 .0 .5 .5 .0 .5 0 0 5 0 5 5 5 5 0 5 5 0 5 0 8137 8138 8150 8167 8176 8178 8182 8200. 8202. 8207. 8209 8210 8212 8214 8221 8234 8236 8237 8239. 8270. 8272 8291 8292 8296 8300 8304 8307 8309 8319 8320. 8327. 8338. 8342. 8350. 8353. 8354. 8356. 8359. 8374. 8382. 8385. 8485. $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 8136.5 8139.5 8150.5 8169.0 8174.0 8175.5 8181.5 8200.0 8202.0 8207.0 8208.5 8211 5 8213 0 8215 0 8221 5 8236 0 8238 0 8240.0 8241 0 8270 5 8272 0 8289 0 8290 0 8294 0 8298 0 8299 5 8303 0 8305 0 8318 0 8320.5 8326.5 8338.0 8342.5 8351.0 8354.0 8355.5 8356.0 8358.5 8375.0 8381.0 8385.0 8484.5 BIT RUN NO MERGE TOP MERGE BASE 3 5826.0 8485.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD AAPI 4 1 68 MWD OHN~4 4 1 68 MWD OHMM 4 1 68 MWD OH~M 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 5789.5 8485 7137.25 5392 ROP 8.2464 1538.08 131.034 5318 GR 33.7373 551.111 127.112 5287 RPX 0.2702 2000 7,17355 5301 RPS 0.0752 2000 8.20775 5301 RPM 0.0714 2000 7.87912 5301 RPD 0.05 2000 7.68223 5301 FET 0.3994 10.4854 0.998085 5231 First Reading 5789.5 5826.5 5789.5 5789.5 5789.5 5789.5 5789.5 5824.5 Last Reading 8485 8485 8432 5 8439 5 8439 5 8439 5 8439 5 8439 5 First Reading For Entire File .......... 5789.5 Last Reading For Entire File ........... 8485 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FI LE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE STAJRT DEPTH STOP DEPTH RPD 5790.0 8439.0 RPM 5790.0 8439.0 RPS 5790.0 8439.0 RPX 5790.0 8439.0 GR 5790.0 8432.0 FET 5826.5 8439.0 ROP 5828.0 8484.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5.03 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM .ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MVJD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 16-SEP-97 ISC 5.06 DEPII 2.17F / SLIMP4 MEMORY 8485.0 5826.0 8485.0 52.7 65.5 TOOL NUMBER P0717SP4 P0717SP4 6.130 6.1 GEL/BARITE 10.10 55.0 9.5 1600 4.5 1.000 1.000 1.200 1.400 138.0 .6 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 AAPI 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 ROP MWD 3 FT/H 4 1 68 FET MWD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 5790 8484.5 7137.25 5390 GR 33.7373 551.111 127.113 5285 RPX 0.2702 2000 7.20238 5299 RPS 0.0752- 2000 8.23117 5299 RPM 0.0714 2000 7.70621 5299 RPD 0.05 2000 7.69571 5299 ROP 8.2464 1538.08 131.337 5314 FET 0.3994 10.4854 0.996992 5226 First Reading 5790 5790 5790 5790 5790 5790 5828 5826.5 Last Reading 8484.5 8432 8439 8439 8439 8439 8484.5 8439 First Reading For Entire File .......... 5790 Last Reading For Entire File ........... 8484.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File