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Home My WebLink About193-053Cu ogu PLUGGING ~ LOCATION CLEARL ~CE REPORT State of Alaska ALAS~ 0IL & GAS CONSERVATION COMMISSION · · . PTD Lease None casi-~q size, wt, depth, c:~= vol, & procedure. Perf i~=a~za!s - tops: 0 Review the well file, and-comment on plugging, well head scat'as, and location ciear~nce - mrovide loc. clear, code. Well head cu= off: ~.0" ~arker ~ost or plate: Location Clear~ce: Code , ? Date PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' Date: 04/11/95 RUN DATE_RECVD 93-053 5676 h~T DLL/CN/ZDL/C3R RUN 1 07/02/1993 93-053 407 ~R~' COMP DATE:06-12-93 07/26/1993 93-053 DAILY WELL OP. 'q~4'12-93 TO 6-22-93 07/26/1993 93-053 SURVEY [~ ANADRILL 07/26/1993 93-053 SURVEY ~'MWD DIRECTIONAL 08/31/1993 93-053 CBT '~L/5'' 07/30/1993 93-053 DLL/GR l~tL/OH, R1,2&5'' 1 05/06/1993 93-053 GR &L/9100-9394, MD 01/14/1994 93-053 GR/CCL .,JL/RUN 1, 5" 06/28/1993 93-053 GR/CCL ~L/7800- 9366 1 08/06/1994 93-053 PERF ~900-9330 i 11/03/1994 93-053 PFC/GR (PACK) c~J~ CH, R1,5" 1 05/10/1993 93-053 SSTVD :~L~ OH, R1, l&2" 1 05/06/1993 93-053 ZDL/CNL/GR ~L~' OH, R1,2&5'' 1 05/06/1993 Are dry ditch samples required? yes no And received? yes no Was the well cored? yes ~nalysis & descript/on-'~eceived?~/ yes no Are well tests required? yes ifno '~Received? no Well is in compliance I~/t~al COMMENTS ¢-~ ;: '~ ~'?; i. '~i /'-':i. ' ~) ' STATE OF ALASKA I ~. j i ' i.~ASKA OIL AND GAS CONSERVATION COIV, MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS E~ SUSPENDED [~] ABANDONED [~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-53 3 Address 8 APl Number P.O. Box 100360, AnchoraCe, AK 99510-0360 50-029-21396-01 4 Location of well at surface ,~ ........... :. 9 Unit or Lease Name 1587'NSL, 998'WEL, Sec2, T10N, R15E UM ; .,_.,.~.;~.,; ,.- PRUDHOEBAYUNIT AtTop Producing Interval .... ' .... "" ~ 10 Well Number 2526' NSL, 2187' WEL, Sec 2, TION, R15E UM i!! .....,~.., ,,,.,_'~~'! 9-31A At Total Depth ": ~'C...~/~. ! 11 Field and Pool 2751' L, 2023' WEL, Sec 2, TION, R15E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 50' ADL 28327 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. [ 15 Water Depth, if offshore [16 No. of Completions 4/15/93. 6/12/93. 6/12/93 (Comp); 7/12/94 (P&A). I N/A feet MSL{ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+-I-VD) '19 ~)irec'tio~,~l Survey 20 Depth where SSSV set I 21 Thickness of permafrost 9526' MD / 9071' TVD 9370' MD / 8974' TVD YES J'~ NO ['-'] 2096' feet MD I 1900' (approx) 22 Type Electric or Other Logs Run DEN/CNL/DLL/GR; GR/CCL; GR/CBL; PDC/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 111' 30" 1800 # Polyurethane 13-3/8" 72 #/68 # L-80/K-55 Surf 2533' 17-1/2" 2500 sx OS III & 400 sx CS II 9-5/8" 47.0 # L-80 Surf 8405' 12-1/4" 500 sx G & 300 sx CS I 7" 29.0 # L-80/13CR 8234' 9394' 8-1/2" 264 cuft Olass G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE 'DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9289' & 8843' 9270' & 8774' None. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETO DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6/6/93. Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED 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. N0V 2 9 1994 *NOTE: 9-31A Cement Plug &Abandon Summary attached. ~ ~) ~ i'~\i /2~\ i Alaska Oit & Oas Cons. Commission Anch0ra~¢ *NOTE: This Completion Report is submitted as required tor the approved Application Sundry (Apprvl # 94-t Coil Tubing Sidetrack drilling of 9-31B (7/94) followed the 9-31A P&A. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity', MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 8946' 8638' N/A Top of Zone 3 9068' 8742' Top of Zone 2 9106' 8773' Top of Zone lB 9370' 8970' RECEIVED NOV 29 1994 AiSS[~3 0il & Gas Cons. Commission Anchorace 31. USTOF AT'I'ACHMENTS Summary of 9-31A Plug & Abandonment, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ 'Z~.. ~_ ~' "~ Title EnaJneorina Sul3ervisor_ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 9-31A DESCRIPTION OF WORK COMPLETED PRE-COIL TUBING SIDETRACK PLUG & ABANDONMENT 7/9/94' Tagged fill at 9377' MD. 7/12/94: RIH w/CT & jetted from 9377' to 9470' MD. Unable to work deeper w/nozzle. Located nozzle at 9350' MD & pumped 3 bbls of Neat Latex Acid Resistive Cement, followed by 5 bbls of Latex Acid Resistive Cement w/1% Polypropylene Fibers (BWOC). Pressured up to 1500 psi for I hour to squeeze cement. Rigged down. 7/1 6/9 4 · RIH & tagged hard cement plug top in the 7" liner at 9370' MD. Left the lower wellbore plugged & abandoned for Coil Tubing Sidetracking of 9-31B. RECEIVED NOV 29 19~4 ~i~ska Oij & Gas Cons. Commission Anchora¢? GeoQuest 600 W. International Airpod Road Anchorage, AK 9~618-11~ ATTN: Sherrie NO. 9080 Company: Alaska OII & Gas Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 11 ~3~94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 01-03 --7 ~ ---[~ :BORAX INJEo LoG (10-23-94) 1 1 " D.S. 2-31'~/'~ '~l ~" BAKER INFLATABLE BRIDGE PLUG RECORD (10-2094)' 1 1 D.S. 3-14 ~ ~?._ PERF RECORD (10-22-94) 1 1 D.S. 4-32 ~ .~---- (.p.~J CNT-G (10-24-94) .. 1 1 D.$.9-13 "~"7- (.g ~'~'_ I PROD PROFILE (10-21-94) " 1 1 D.S. 9-31A _~.~ -. ~,~'~?~..~LpERF RECORD (10.24.94) i' 1 D.$. 17-12 ~; L.J~-~ LJ~ IBP SETTING RECORD i10-22-94) . . 1 ' 1 j .,, , ,, Ple~::~se sign and return one copy of this ti'ansmitta, ,o Shen'ie at the above add,e.. Th(Ink yo'~ ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: August 3, 1994 ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 265-6547 Distribution P.O. Box 100360, A .... ~orage, AK Transmittal #: 94068 Well Log Date' Tool Type '' Contractor Number (M-D-Y) 01-03 7-4-94 Leak Det I scH 03-12 7-2-94 Inj Prof 1 scH 03-19 7-7-94 Prod Prof I SCH 03-25A 7-7-94 i Perf Record I ' ' SCH 04-02 7-3-94 Leak Det 1 SCH *04-07 ST1 7-8-94 Perf Record I SC'H 05-01 7-9-94 Tubing Cutter ' 1 SCH 05-11 7-9-94 Perf Record 1 SCH' 06-11 7-2-94 Dual Burst TDT-P 1 SCH 06-21 7-1-94 Prod Prof 1 SCH 06-22A, 7-4-94 Perf Record .1 SCH 07-02 7-4-94 Prod Log I SCH 04-31A 7-8-94 G R/Collar 1 SCH , ,, 09-32 7-7-94 Dual Burst TDT-P 1 SCH 15-01 7-2-94 ' Prod ~rof 1 SCH 16-02 7-5-94 Inj Prof 1 SCH 16-10 7-6-94 "' In.j Prof 1 SCH .,. ,16-24 7-3-94 Perf Record 1 sCH 17-07 7-5-94 Leak Det 1 SCH *The correct APl number for 04-07 ST1 is 50-029-20189-00. Number of Records: 19 .., ! KaHa Zuspan Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil Please acknow e re b s~ n~n and r .~ acknow~edg.~ re.~.~y 'g' g eturnin~ ARCO Alasl(a, Inc. Is a Subsidiary of AtianflcRlchtleldCornpany STATE OF ALASKA ALASKA LAND GAS CONSERVATION CC_. ,/IISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation 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 ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1587' FSL, 988' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2526' NSL, 2187' WEL, Sec. 2, T10N, R15E, UM At effective depth At total depth 2751' NSL, 2023' WEL, Sec. 2, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED JUN 1 4 1994 ka 0il & 6ss Cons. Commission Anchorage 6. Datum of elevation(DF or KB) 54 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-31A 9. Permit number 93-53 10. APl number 50 - 029-21396-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9452' feet Plugs(measured) 9139 feet Effective depth: measured 9407 feet true vertical 8997 feet Junk(measured) Casing Length Size Cemented Conductor 111' 20" 1800 Ct Polyurethane Surface 2483' 13-3/8" 2500 sx CS III & 400 sx CS II Production 8355' 9-5/8" 500 sx CIG & 300 sx CS I Liner 1175' 7" 246 cu ft CIG Measured depth True vedicaldepth 111' 111' 2533' 2533' 8405' 8374' 9394' 8989' Perforation depth: measured Open Hole' 9398-9525' true vertical Open Hole: 8991-9070' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, 13 CR, NSCT w/Tail @ 9289' MD RECEIVED ~,,- 0il & Oas Cons. 6ommissio Anchorage Packers and SSSV (type and measured depth) Baker SABL-3 @ 8774' MD, Camco TRCF-4A SSSV @ 2096' MD 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation July, 1994 16. If proposal was verbally approved Name of approver Date approved Detailed operations program I15. Status of well classification as: Oil X Gas Suspended Service BOP sketch 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~---~¥--~'~"~'~ ~ Title Engineering Supervisor ) FOR COMMI~;~ION ll~;E ONLY ConditionsUof approval: No~,~f..~ri~ssion so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ./%/o~ Date IApproval No. ¢ y .-/, S'-~ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 1114/9 SLW cc: JED, JWP ~.;r¢ginal Signed By '~avid W. Johnston Commissioner Approved Copy Returned Date ~/~./'"~/x<" ~ , SUBMIT IN TRIPLICATE~ DS 9-3 lA Pre-CT Sidetrack Drilling Plug & Abandonment Intended Procedure OBJECTIVE: Cement squeeze the open hole. Test squeeze. INTENDED PROCEDURE: Rig up cementing equipment and cement squeeze the open hole, leaving the cement top at E 9390' MD. R CEIVF_.D ..- , .-, Ok! & Gas Cons. oommission &w,s~ Anchorage AiSSk8 Oil & Gas Cons. Cornmissior; Anchorage 6 3 2 COILED TUBIN~ UNIT BOP EOU] pMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PS! 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~)O0 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX ECEIYED i i 2 " '-,- [,TU, Gas Cons. Commission Anchorage Oil & Gas Cons. Oomrnissior', Anchorage HIRELINE BOP EOUIPMENT 1. ~)000 PSI 7" WELLHEAD CONNECTOR FLANGE " 2. 5000 PSI WIRELINE RAUS (VARIABLE SIZE) i 3. 5000 PSI 4 1/6" LUBRICATOR ! , 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: ~-~ 5-03A 5/31-6/11/93 ~'5-6 ~ · 9-3 lA 4/16 -17/93 q~- b~ · · 9-36A 3/31-4/6/93 ~Z-~% t ** * 16-4A 02-19-93 ~'-oZ AGI-5 05-10-93 ~" .;~ '~'? AGI-6 05-10-93 Slim I GR ~ ~ II~ev Run~L&2, 2"&5" Ana MWD: GR ~c-q~ ~" MD] MWD: GR ~z~-~'~'~. ~,, ~... ~ SS~ ~oo~o- ~o R~ 1, 1"&2" ~ ,~.~.~- - ,~ R~ 1, 5" Sch ~ ~' '-'..- R~ 1, 5" Sch Please sign and return the attached copy as receipt of data. RECEIVED BY ; ~.~- '/ /~-~' ~' Have A Nice Day! John DeGrey ATO-1529 APPROVED '.~-~'-- Trans# 9400~-~ '~ .... # CENTRAL FILES # CHEVRON #D&M # ANO8 GEOLOGY # EXXON # MOBIL # PHILLIPS # PB WELL FILES # BPX # STATE OF ,~n&SKA The corrected API# for 9-31A is 50-029-21396-01. The corrected API# for 9-36A is 50-029-21429-01. The corrected API# for 16-4A is 50-029-20561-01. Al~ka Oil a Gas Cons. .A~orag~ ARCO .al_~ska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MW]) Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Aha Job#AKEI30010 Sperry Job#1209 BHI Ana Ana Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#AKEI30009 Sperry Job# 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Aha Aha Ana Job//1159 Teleeo Job# 1175 Teleeo Job//1167 Tele¢o Job #AKMM911128 Sperry Job#AKMM911231 Sperry Sperry Aha Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job#1168 Teleeo Job#1172 Teleeo Teleco Job# 1185-450 Teleeo Job# 1185 Teleco Job#1190 Teleco Job# 1195-450 Teleco Job#1205 BHI Please sign and return the attached copy as receipt of data. C. ATO-1529 CHEVRON # PB WELL FILES # CLINT CHAPMAN # BPX # EXXON # ST. OF AK. (2 COPIES) MOBIL # LUCILLE JOHNSTON ARCO Alaska~ 1nc. P.O2~x 100360 Anchorage, .~l~s~ 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 3_ 18A ~'~.18.93 5-13 77- ~ 5-28-93 5-24~/'/~ 5-22-93 5-32 ~ ~?~ 5-27-93 6-12A ¢'~ }~ 5-29-93 6-14A ~2475-19-93 7-147~1 5-25-93 9-3 5-18-93 9-3 ?s~ ~- 5-24-93 * 9-4A ~-z? 5-26-93 9-5A ~ ~ ~ 5-30-93 ** 9-28A ~Y- ~ 5-28-93 9-31A g~-f35-19-93 9-32 ~-//(5-30-93 12-15 e~-~z 5-27-93 12-23 ~-~5-27-93 ~ ~./~ ~ 18-29A ~'~5-18-93 AGI- 1 ~ 5-20-93 AGI-I~*'I 5-20-93 AGI-2 ~.~¢c~j-23-93 AGI-2 ~5-23-93 Perf Record AGI-3 a, ~5s 5-20-93, CzR/CCL AGI-3 ' , ~5-21-93 Prinmry Perf Record AGI-4 ~Aa~5-22-93 Initial Perf Record Completion Record Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch GR/Coltsr Run 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Prod Profile Run 1, 5" Sch Perf Record R~_m 1, 5" Sch Frod Profile R,~ 1, 5" Sch Production Log R-n 1, 5" Sch Completion Record R~m 1, 5" Sch Production Log R~m 1, 5" Sch CBT R-r~ 1, 5" Sch Completion Record R-_n 1, 5" Sch Completion Record Run 1, 5" Sch - Leak Detection R.n 1, 2" Sch Perf Record R~m 1, 5" Sch PITS R~m 1, 5" Sch Perf Record R~_~_n 1, 5" Sch Jewelry Run 1, 5" Sch Perf Record Run 1, 5" Sch Jewelry Run 1, 5" Sch R~_~,~ 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Please sign and return the RECEIVED 1/ Have A Nice ~ Sonya Wallace ATO-1529 # STATE OF ALASKA The correct well name for this log is 9-4A. The correct API# for 9-28A is 50-029-21292-01. STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION CO,v,MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Serv~'~ell OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I-i 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-53 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21396-01 4. Location of well at surface 9. Unit or Lease Name 1587' NSL, 998' WEL, SEC. 2, TION, R15E f _ ~,TE , ~ ; ,. ' Prudhoe Bay Unit At Top Producing Intervaf t ~'~~i ~ `?~'? '~:;?";' - 10. Well Number 2526'NSL, 2187'WEL, SEC. 2, TION, R15E ! '/~RIF!EI~ ! ~';., At Total Depth L-.~..-~.~_~ '- ~ - Prudhoe Bay Field/Prudhoe Bay Pool 2751'NSL, 2023' WEL, SEC. 2, TION, R15E 5. Elevation in leel (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE - 50' I ADL 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I15. Water Depth, if offshore 116. No. of Completions 4/15/93 4/16/93 6/12/93I N/A feet MSL J One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD: 19. Directional Survey ~20. Depth where SSSV set J21. Thickness of Permafrost / 9526'MD/9071' TVD 9407'MD/8997' TVD YES [] N~ [] 2096' feet MD ! 1900'(Approx.) 22. Type Eleclric or Olher Logs Run DEN/CNL/DLL/GR 23. CASING, LINER AND CEMENTING ~ SEI-r~NG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.51t H-40 Surface 111' 30" 1800 # Polyurethane 13-3/8" 72#/68tl L-80/K-55 Surface 2533' 17-1/2" 2500 sx CS 111/400 sx CS II 9-5/8" 47# L-80 Surface 8405' 12-1/4" 500 sx "G"/300 sx CS I 7" 29# L-80/13CR 8234' 9394' 8-1/2" 264 cuft 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) Open hole completion 4-1/2" 9289' 9270'& 8774' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/6/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE ~GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.,m,. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosily, fracture~, apparent dips, and presence of oil, gas or waler. Submit core chips. Alaska Oil & Gas Oons. Ar~chorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS . _ -~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 8946' 8638' Top Zone 3 9068' 8742' Top Zone 2 9106' 8773' Top Zone lB 9370' 8970' ,Il..// /. ,., .4lask,?,, Oil ~ ~as Co~'~s. (;orr~m. issio~ 31 LIST OF A'I-rAOHMENTS .' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge - .. ~-~_ , Signed .~ , :-'1 Title Drilling EngineerSuoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 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 BP/ALI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 9-31A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/11/93 07:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 04/12/93 ( 1) TD: 8600 PB: 8600 04/13/93 ( 2) TD: 8600 PB: 8600 04/14/93 ( 3) TD: 8600 PB: 8600 04/15/93 ( 4) TD: 8600 PB: 8170 04/16/93 ( 5) TD: 8805' ( 0) 04/17/93 ( 6) TD: 9222' ( 417) 04/18/93 ( 7) TD: 9394' ( 172) TEST BOPE MW:10.1 WBM RELEASE RIG F/ WELL #DS9-36-A & MOVE RIG. RIG ACCEPTED 1900 HRS. 04/11/93. RUG UP & PULL BPV W/ LUBRICATOR. CIRC OUT FREEZE PROTECT FLUID & CIRC BOTTOMS UP. SET BPV. N/D TREE. NU BOPE & CHANGE RAMS TO 7". TEST BOPE. CHANGE PACKOFF. MW: 8.5 Seawater R/D LUB. PULL HGR. POOH, L/D 5-1/2" TBG. TEST BOPE. L/D BHA. RIH W/ SECTION MILL. SET STORM PKR. N/D BOPE. CHANGE PACKOFF. CIRC. MW: 9.6 KC1 CHANGE PACKOFF. TEST SAME. N/U BOPE. TEST BOPE. L/D STORM PKR. RIH TO 8602'. TEST CSG. OK. DISP WELL TO KCL. MILL WINDOW F/ 8400'-8450' CIRC. RIH W/ BIT. MW: 9.7 KC1 CIRC. POOH. L/D MILL. RIH W/ MULE SHOE. WASH F/ TOP WINDOW @ 8400'-8550' REV CIRC. SET MULE SHOE @ 8549' -- PUMP 25 BBLS WATER, BBLS CMT, 6.6 BBLS WATER. DISP W/ MUD. POOH TO 7609'. SQZ CMT W/ 2000 PSI FOR 1 HR. SQZ'D 1 BBL AWAY. TOC @ 8185' EST. POOH. L/D SHOE. TEST BOPE. RIH W/ BIT, MTR. DRLG. MW: 9.4 VIS: 48 RIH. TAG TOC @ 8301'. DRLG CMT TO 8405' KICKOFF. DRLG TO 8805' DRLG. MW: 9.5 VIS: 51 DRLG TO 9022'. CIRC. POOH. CHANGE BIT, BHA. RIH. REAM F/ 8919'-9022' DRLG TO 9222' R/U TO RUN 7" LNR. MW: 9.5 VIS: 50 DRLG F/ 9222'-9394' TD WEL @ 13:30 HRS, 4/17/93. CBU. POOH. L/D BHA. R/~ ATLAS. LOG RUN: CNL/DLL/GR. R/D ATLAS. RIH W/ 7" 13 CR LNR. WELL : DS 9-31A OPERATION: RIG : NABORS 2ES PAGE: 2 04/19/93 ( 8) TD: 9398 PB: 9359 04/20/93 (9) TD: 9398 PB: 9359 04/21/93 (10) TD: 9394 PB: 9359 04/22/93 (11) TD: 9394 PB: 9359 DRAG LC. MW: 9.6 KC1 RIH W/ 7" 13 CR LNR ON DP. CIRC. WASH TO TD. PUMP 25 BBLS 11 PPG ARCO SPACER, 75 BBLS PREFLUSH, 47 BBLS 15.7 PPG CMT. DISP W/ MUD. SET BAKER HGR W/ 3000 PSI, PKR W/ 4000 PSI. RELEASE F/ HGR. REV OUT 10 BBLS CMT. POOH. TIH W/ BIT. WASH F/ 9125'-9184' DRAG CMT TO 9319'. DRAG LC PLUG. RUN 4-1/2" TBG. MW: 8.6 Seawater DRAG LC TO 9359' CIRC WELL TO SEAWATER. TEST CSG. REV CIRC. POOH. L/~ DP. R/U ATLAS. RUN GR/JB. RIH W/ BAKER 'FB-i' PKR & TAIL ASS'Y. SET PKR @ 9270' (WLM). R/D ATLAS. RIH W/ 4-1/2" 13 CR TBG. ND/BOPE & NU TREE MW: 8.6 Seawater RIH W/ 4.5" 123CR COMPLETION. BAD THREAD ON PIN END OF TOP GLM--SEND SAME TO MACHINE SHOP TO GET CHANGED OUT & RETURNED. FINISH RUNNING COMPLETION. MAKE UP HANGER & P.T. RIG DOWN TBG. RUNNING EQUIPMENT. ND BOPE & NU TREE. RIG ON NEW PAD MW: 8.6 Seawater NU TREE AND ADAPTER FLANGE. RIG UP LUBRICATOR. MIX AND PUMP INHIBITOR DOWN ANNULUS. SET BPV--SECURE TREE--CLEAN CELLAR AND RELEASE RIG. SIGNATURE: (drilling superintendent) DATE: JUl... Alaska 0il & ~Jas Cons. f.;(~FHH'fissiOH Anchorage 9-31A DESCRIPTION OF WORK COMPLETED COIL TUBING DRILLING FOR WELLBORE EXTENSION 5/7/93 · RIH & tagged bottom at 9339' MD. 5/15/93' MIRU CTU & PT equipment to 4000 psi. RIH w/2" CT mounted drilling assembly, consisting of a 3.75" diamond bit and underreamer w/4" diamond bit blades. Drilled an extension wellbore out of the 7" float shoe from 9336' to 9384' MD, and circulated out wellbore cuttings w/1.5# Biozan gel. POOH w/CT assembly. Rigged down. 5/16/93: RIH & tagged hard bottom at 9359' MD. 5/31/93 - 6/2/93: MIRU CTU & PT equipment. RIH w/2" CT mounted drilling assembly with a 3.625" diamond bit. Continued drilling extension wellbore down to 9400' MD. POOH w/CT assembly & replaced broken downhole motor shaft, then ran CT mounted 3.75" diamond bit followed by underreamer w/5.75" diamond blades. Reamed extension wellbore to 5.75", down to 9399' MD. Drilled underbalanced w/well on gaslift while circulating 2# Xanvis during the job. POOH w/CT. Rigged down. 6/4/93 · MIRU CTU & PT equipment to 4000 psi. RIH w/2" CT mounted drilling assembly with a 3.75" diamond mill. Tagged bottom at 9397' MD, then started circulating 2# Xanvis & continued drilling 3.75" extension wellbore down to 9455' MD. POOH w/CT assembly. Rigged down. 6/11/93 - 6/1 2/93: MIRU CTU & PT equipment to 4000 psi. RIH w/2" CT mounted drilling assembly with a 3.75" diamond mill followed by an underreamer w/5.5" diamond blades. Tagged bottom at 9408' MD, then started circulating 2# Xanvis & continued reaming/drilling the extension wellbore down to 9525' MD. POOH w/CT assembly. Underreamer blades had worn down to 3.75". Rigged down. 6/14/93' RIH & tagged bottom at 9526' MD. 6/19/93' RIH & tagged bottom fill at 9404' MD. 6/22/93 · RIH & tagged bottom fill at 9407' MD. Placed well on production w/gaslift & obtained a valid welltest. Current (7/93) production rates are 100 - 200 BOPD, 0 - 400 BWPD, 200 - 1000 Mscf/D, @ 330 psi FTP w/Choke at 84 Degs. Alask~ Oil & Gas Coi'~s. Coi.r~t~issiot~ Anchorag.~ ****w****** SURVBY F~:OOF~M ******~**** WELL ~AD LOCATIOH: LAT(N/-S) 0.00 D~P(£/-W) AZI~TH ~'Of'l ROI'ART TABL~ TO T~ IS 46.22 TI~ IN POINT(TIP) MEA..q~ED DB'TH 8400,00 TRUE VE.RT D~q'H 8131,0,0 INCLINATION 15,97 AZIMUTH 303,~ LATITUDE(N/-S) 767,00 DEP~TUR~(E/-W) -1195.00 MiCrO'FILMED . .[_ ~; ~ ~ .... ,,. Alask~ 0il & Gas Cons. (;onm'dssx~n Anchora,~ MEASURED INT~3AL UL~R~ICAI. D~P~ DEPTH ft ft ft ~00,~ C,O ~131.~ 8730,~ ~,0 ~6.~ 8761,80 30.9 84~,05 8792.67 ~,9 8~3,~ ~-~*~,,*~***** AHADRI~ *~,~*~**** SU~9~Y CALCULATiOHS ,~**~x-****** ~IHIMUM CURVATU~£**w***w* TAJ~G~T STATIDN AZI~rtH LATITLrDP. SECTION INCLN, N/-S ft deo deo ft -332.35 15,97 303,90 767,~ -302.51 20,95 2.13 843,9q -293.65 21,85 %20 855,57 -284,03 22,87 12,89 867.11 -273.50 23,fq 17,~2 878,94 D~PAF~L~I~ DISPLACemENT at £/-W ft ft -1195,00 1419,97 -1227.42 1487.57 -I226,25 1495.23 -I223,~ 1500.01 -1220,73 1504,23 AZIMUTH deo 30P..~.9 304.51 304,'~'0 3(~,31 305,75 de~/ lOOft 0,00 6,11 8.54 5,61 7,31 8824,I8 8853,46 8884,76 8916,16 8946,9i 31,5 8532,04 ~,3 8558,44 $1,3 8586,45 31,4 8614,34. 30,8 8641,48 -261,74 25,16 22,33 891,23 -250,06 26,09 24,78 902.84 -236,87 26,91 29.~ 715.26 -222,95 27,79 32,~ 927,60 -208,74 26,37 38.06 937,37 -1216,23 I507.81 306,23 -1211,16 1510,64 30~.70 -1204,80 I513,03 307,22 -1197.34 1514,62 307.77 -1168,94 1515,26 308,31 7,00 4.83 7,04 5,88 8.12 8?78,62 7010,05 9041,82 ?073,57 9101,21 31,7 8669,I7 31,4 8696,14 31,8 87~,04 31.7 8747,65 27,6 877.2,45 -193.40 29,97 40,~0 951,30 -177,34 31,81 40,35 963.56 -160,53 32,42 40,Si 976,38 -143,32 33,72 38,77 98%70 -127.80 35,1I 40,77 1001,70 -1179,12 1515,03 308.v0 -1168,63 1514,64 3(7~.51 -1157,64 1514,42 313.I4 -1146.,56 1514,63 310,80 -1136,57 1514,~ 311,~ 6,57 5,91 2.07 5,3? 6,48 9131,64 9162,78 9193,88 9225,75 9257,60 30.4 8797,05 31,3 8821,75 30,9 8845,44 31,9 8869,2~~ 31,? 8892,7? -109o99 37,00 39,98 1015,34 -90,90 38,98 36.23 1030,52 -7i,41 40,97 34,48 1046,72 -50,80 42,0q 32,64 1064,32 -29,89 42,82 32,87 1082,40 -1124.97 1515.41 312.07 -1113.08 1516,88 317.79 -110I,~ 1517,57 313,54 -108~,73 1523,3<) 314.32 -1078.2q 1527,84 315.11 6.38 9,70 7.38 5,21 2,33 9289,12 31,5 7315,99 26.9 ?394,00 78,0 8915,76 89~,96 8988.03 -8,82 43,66 34,23 110C,40 9,49 45,10 32,34 1116,11 64.97 49.15 32,.30 I164,41 -I066.36 1532.31 315.~0 -I056.0~ 1536,53 316.58 -1025,49 1551,61 31~.63 4,00 7,26 5,20 ARCO ALASKA INC Attn. SONYA WALLACE ATO 1529 700 G STREET ANCHORAGE AK, 99501. U.S.A. Date: 30 June 1993 RE: Transmittal of Data ECC #: 5930.00 Data: LDWG Dear Sir/Madam, Reference: 9-31A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE & LISTER Run # 1 Sent by COURIER Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: RECEIVED JUL 02 199;~ A.faska Oil & ~s 6,¢n~, 6¢mmi_s~sic.n MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W ~on date: Chairman%,~-" file: thru: Blair EWondzell 6/~o/93 subject: Petr Insp Supervisor from: Bobby Fos!e' '~-~ Petr Inspector June 29, 1993 061193.doc BOP Test- CTU AAI-PBU-DS 9-31 Prudhoe Bay Field PTD 93-53 Friday, June 11, 1993: I traveled this date to AAI's DS 9-31 and witnessed the preventer body test of the BOP's on the well head. The annular preventer and the valves on the well head were tested to 4000 psi. After th,, RI=iA w~ pi~.k,~H up th,=, ~Ti I nr~v~nf~rq ~nrl riq~r waq fia,qn~rl m mn fn the head; the rams and pack off were tested to 2500 psi. The kill line, choke line and the Choke manifold valves were tested to 2500 psi. Summary: Everything tested fine. ARCO Alaska~ Inc. P.O~Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: ~_..~_~~1-14 ,3-33 14-22A 17-19 17-21 L8-9A L8-16A 6-9-93 5-6-93 Static Pressure l~_m 1, ~' Sch 5-8-93 Prod Profile Run 1, ~' Sch 5-10-93 Production l~m 1, 5" Sch 5-11-93 CBT~ew TBG/Jewelry Run 1, 5" Sch 5-10-93 Leak Detect/Spin/Temp/Press l~m 1, 2' & 5" Sch 5-4-93 USIT (Cement & Corrosion) (Color) Run 1, ~' Sch 5-3-93 lnJ Profile/Spin/Temp/Press Run 1, 5" Sch 5-2-93 Inj Profile/PITS Run 1, 5" Sch 4-24-93 Leak Detect/Spin/Temp/Press Run 2, 5" Sch 5-7-93 D-_~! Burst/TDT-P (Borax) Run 1, 5" Sch 5-6-93 Vertilog l~m 1, lY' Atlas 5-8-93 GR/Coll_~r Run 1, 5" Atlas 56-93 Perf Record Run 1, 5~' Sch 5-7-93 GR/iX~ l~m 1, 5" Sch 5-10-93 CNL Run 1, ~' Sch 5-11-93 Leak Detect l~m 1, 2' & 5" Sch 5-7-93 Perf Record Run 1, 5" Sch 5-9-93 TDT-P ~Borax) l~m 1, 5" Sch 5-3-93 Leak Detect/Spin/Temp/Press Run 1, 5" Sch 5-3-93 Perf Record Run 1, 5" Sch 5-4-93 Production Run 1, 5" Sch 5-5-93 CCL/Perf Record Run 1, ~' Atlas 5-8-93 SBT/GR/CCL l~m 1, ~' Atlas 5-7-93 GR/CCL (Color) Run 1, 5" Sch 5-10-93 GR/CCL (Color) Run 1, ~' Sch 5-10-93 GR/CCL (Colo~ Run 1, ~' Sch 5-3-93 SBT/GR/CCL Run 1. 2' & ~' Atlas Please sign and return the attached copy as receipt of data~ Ri CEIVED B¥_..~~~~ Sonya Wallace %. ~//j ~/. APPROVED__ AT0-1529 ~. v~ ~ /~.,Trans# 93068 # CENTRAL FILES~%,..~. ~, '~ # PHILLIPS # CHEVRON "~.~a. PB WELL FILES # CLINT CHAP~ "~.~ # BPX # EXXON # MOBIL # STATE OF ALASKA ARCO .aJaska~ Inc. P.O.Box 100360 Anchorage, .~losl~ 99510 DATE: 5-20-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS DLL/'Ivrr.?.!AC!CN!GR/ZDL/DEL2!SI., DLLIAClCNIGR DLLICNIZDLIGR DLLIAClCNIGR DLL/~./AC/GR Run 1 Job~5940 Atlas Run 1 Job#5927 Atlas Run 1 Job~5930 Atlas Run I Job~~ Atlas l~m I Job~.01 Atlas Please sign and return ~he attached copy as receipt of data. CEiVE Have A Nice Day! {/i,~ Sonya Wallace APPROVED___~_ AT0-1529 Trans# 93061 CENTRAL FILES (CH) CI-IRVRON D&M # BOB ~AS (OH/GCT) # EXXON MARATHON MOBIL # PHILIXPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO The correct APl# for 3-20A is 50-029-20980-01. MEMORANDUM ALASKA OIL AND GAS CONSERVATION COMMISSION STATE OF ALASKA to: David W. John~ date: CommissionerS~~-~ file: thru: Blair E Wondzell ~ ~_*'~/, [,~--,~,.. sub) ectJ Petr Insp Supervisor from: ~o~n Spaulding Petr Inspector June 2, 1993 053193.doc BOP Test C.T.U. D/S ARCO/PBUig-31 PTD 93-53 Sundry 93-112 Monday, May 31, 1993: I traveled to ARCO-PBU well 9-31 to witness BOPE test for coiled tubing drilling. A full body test was performed to all associated lines and valves prior to testing BOPE, All BOPs, choke and annular tested good. This type of drilling is still in the experimental stages and there was some confusion of the contractors part. Given the fact that this was a job that came under state regulations and some pipin_? configurations were changed everything went quite well. Summary: Tested BOPE Dowel {/Schlumberqer CTU, eight hours test time, no failures attachments STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: / Workover:. ~'"~'~ ~-J~f~/ q~'///- DATE: :. ~]/~ ~ ~-~ ~ ~._ Operator:., ,A-P~ 4) ~ ~ Rep. Well Name: ~/-,~/ Rep. CesingSize: ~,~,~/~' Set~ ~-~ ~ Feet Localion:$ec. ~_ T. /~'R. . Merd. zx,/A. Test: Initial ~ Weekly Other ' ' .......... j iii J i . i s __ _ . ...... --.. -,. _ . _. , .-, -.-.~-,-.-o -.., ,.__. _, ...i. '":'"'"::~':~'~':'.'~:.~':-'~iii.-'.-:!i~k:~i:i~.>:::!:i:.:~,.:::: ........ ..:.:-::-.::~ ..:'~.:-;ii:::,i::.:..'..,::i:::...~,:,,:,.~-:.:i:::~.::g.;:~:~::~',~:! .............. !-~:~:.-:::: .- - -.. ~..:~:i:iii~i~:~..~!~i::::i::~i~.....i~:..::..`.i:i~i~.`:~:!~.i~i.~!F::::~.::::~!~:''.':':'::×::::.< ........ .~-~,-~×-.~' '.~!:~.--::::.-'.':':~.~ii~.~:".::~-~:~:.~:.:~.~:::-~:::~:: ~.:~.~.~,.:~...~, ........................... - ............................................ :.-: ................................................... - ......... ~$T.'-DA ..... :: ......................................... ::--,-:. ................. ~ .......... ~---.~:~. ~-~,.o-~.,:~.~.~-,..:. .......... < ...... MISC. INEPECTIONS: Location Gen.: Housekeeping: ---~(Gen) Reserve Pit Well ~ign Dr~o Rig Test Qua.. Pre~ssum _/. '"~ ~_~ P/F FLOOR ~ VALVE~: Upper Kelly Lower Kelly i~11 Type Inside BOP Test Quan. Pressure P/F BOP STACK: Ann. Preventer Pipe Rams / Blind Rams ~2, Chk/Ln Valves / HCR Valves _/ Kill Une Valves ~, Check Valve CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: 6ystom Pressure ~c-~ I/~ Pressure After Closure . ~ ~ o <~ !/~ 200 pei Allained After CIo~ure minutes / / ~m Pre~ure Atlained / minutes ~, _~ Blind Switch Covem: ~ ~ Remote: Nigh. Btrs: ~/,~ ' ¥1UD SYSTEM: LigM Alarm Trip Tank ../V'. d . Pit Level Indicators Flow Indicator i i. Ges Detectors ~~ :.'.~ .:-: ~ '~:.;:..'&;:~ ::::: '.-'...: :::~:.~::' ::'- ": ?:-" :: ?..'.-:~!'-.::.::-:-:: .'.-:..'-' ~. :.:.'~' '.::' :.::: _'::f:':~: :-':: .::~ '.'~::.:::: ::: ::::.'-.:<.':.::::-~.~ :.~..~:..:..'<-?;~.<:~.:~ ea ~.. I-:::: ~ e~eee~.:.~e-:.-.-..~....~:. :..~.:..:.~.-.~.. ~~?..x I U /I , I I II ' lei ........................ I ............ I'Y' I'"'l I ..... :"l'lll' L' ~ ......................... N mberofFadures ~ TestT~me ~ Hours Number of vaives tested / . Repair or Replacement of Failed Equipment shall be made within ~ days. Notify the Inspector on duty and follow with Writton or Faxed vedlication to the AOGCC Commission ~ at: F~x No. 27~-7~,12 Inspector North Slope Pager No. ~-3607 if your call is not returned by the inspector within 12 hours pleese conlact the P. I. Supervisor ~t 279.1~13 Distribution: od~.Well File c - Oper~ c - D~tobese c - T~ip Rpt File c - Inspector STATE WITNE~S8 REQUIRED? YES ~" NO 24 HOUR NOT~CE GIVEN YES,~/ NO _ . Waived By:. W~essed By:. FI-021LXI. T Rev. 1/93 MEMORANDUM STATE OF z,ASKA ALASKA OIL AND GAg CONGER VA TION COMMISSION TO: David Johnst_~ Chairman THRU:. Blair Wondzell P.I. Supervisor FROM: ~oug Amos Petroleum Inspector DA TE: May 14, 1993 FILE NO: DA-51493. DOC PHONE NO.: 279-1433 gUBJECT: BOPE Test Pool 7 AAI Pt Mclntyre P1-04 Prudhoe Oil Pool PTD No. 93-53 Thursday May 13,1993: I traveled this date from my residence to Prudhoe Bay to stand by for the BOPE Test on Pool Rig No. 7, at AAI's Pt. Mclntyre P1-04 Well. .Friday May 14,1993:. The testing commenced this date at 5:30 a.m. and was concluded at 9:30 a.m.. As the attached AOGCC BOPE Test Report indicatesxthe hydrogen sulfide detector in the Cellar failed, the Rotary and Shell Shaker hydrogen sulfide detectors ,and the Rotary methane gas detector were out of calibration. The methane detector was calibrated this date, however the hydrogen sulfide detectors could not be calibrated until a quantity of 100 ppm calibration ampoulae, can be shipped to the North Slope. Saturday. May 15, 1993: I was contacted this date by Terry Jordan, AAI representative and informed that all gas detector failures had been corrected and retested. The rig was in good repair,, the crew was professional and familiar with the BOP equipment and the test procedure. The location foot print is small and in the development stage it is cluttered with miscellaneous construction and flow equipment, which does not leave room additional pumping equipment should the need arise. This situation is typical of the new compact drill sites with individual production modules. IN SUMMARY, "Tested the BOPE on Pool Rig No. 7, test time 4 hours, 3 failures." Attachment DA-51493.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DATE: 5/14/93 POOL Rig No. 7 PTD # 93-53 Rig Ph.# 659-4815 / 4818 ARCO ALASKA INC. Rep.: TERRY JORDAN PT MclNTYRE P1 - 04 Rig Rep.: JIMMY GRECO 10 3/4 Set @ 3,982' Location: Sec. 16 T. 12N R. 14E Meridian UMIAT X Weekly Other MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: OK Well Sign YES Upper Kelly/IBOP Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly/IBOP Reserve Pit N/A Ball Type Inside BOP BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250/5,000 P 1 250/5,OOO P 1 250/5,000 P 1 250/5,000 P Test Pressure P/F P P P P P P P N/A N/A Quan. Test 1 250/5,000 Pressure P/F 16 250/5,000 P 1 250~5,000 1 25015,000 1 250/5,000 2 250/5,000 2 250/5,000 2 250/5,000 0 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 37 250/5,000 P ACCUMULATOR SYSTEM: System Pressure 3,100 J Pressure After Closure 2,250 I MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 28 Trip Tank OK OK System Pressure Attained 1 minutes 16 Pit Level Indicators OK OK Blind Switch Covers: Master: YES Remote: Flow Indicator OK OK Nitgn. Btl's: 2 @ 2,700, 2 @ 2,750 Gas Detectors SEE REMARKS 2 @ 2,800 Psig. sec. sec. YES Number of Failures: 3 Test Time: 4.00 Hours Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 3 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The Rotary and Shaker Hydrogen Sulfide gas detectors were out of calibration, the Cellar detector failed to operate. The Rotary Methane Gas detector needs calibration. Please correct these items and contact the above listed pager number when they are ready for retesting. 5/15/93 I was contacted by AAI rep Terry Jordan and informed that all gas detectors were repaired and retested. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Signed: Doug Amos FI-021L (Rev. 2/93) DA-51493.XLS P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO CASED HOLE FINALS ~1-24A 2-7-93 ~~0A 4-13-93 ~~20A 4-2S-93 /"/7 ~iA~ 4-23-934'28"3 ~ 4-23-93 1-29-93 -~o 77~ ~ ~-~-,a ~-12A ~.~ ~ 4-24-'3 GR/CCL/Jewelry/Temp Tubing Cutter SBT/OR/CCL Perf Record Jewelry/GR/CCL Tie-In CNL/GR Color USIT/GR Color Leak Detect Static Press/Temp Leak Detect Prod Profile Production Log Pressure Build-Up Press/Temp Perf Record Production Log ~2f (. ? 4,23-93 7-7A ~"~3 4-21-93 Dual Burst TDTP (Borax) .~9-27 ~ 5---~.~ 4-20-93 P~rf Record ~-31A ~-~ 4-19-93 PFC/GR (Packer ~t) . ~-40 ~/~ ~ 1-1-93 lnJ ~ome ~,/e~~~2-13 ~/~ ~ ~ 1-2-03 ~ ~tect ~" -- **r~2-14ST F/~/~4-27-~3 ~ ~tect ~3-20~2-~ 4-25-~3 ~.~ ~tect ~13-25 C2-~/ 12-26-93 InJ ~-43 ~-/~ 1-3-93 ~od ~6-27 ~.3g 12-27-92 ~od ~o~e ~~7-13~V~;7~ 4-18-93 ~ ~tect ~GI-9 ~)~ 4-11-93 SBT/GR/CCL Plebe s~ ~d ret~ at~~ c~ ~ re~ of ~. Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1,. Run 1, Run 1, Run 1, l"&5" Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, 5** Run 1, Run 1, :~'&5" Run 1, Run 1, 2'&5' TrafficS. 9305~'~' ....... PB WELL FILES. # BPX # STATE OF ALASKA The Correct wen nnme for this log is 1-24A. The correct APl# for 3-20A is 504)2~209804)1. The correct APl# for 12-14ST is 50-029-206594)0. Camco Atlas Atlas Sch Sch Sch Sch Camco Sch Sch Camco 9ch Sch Sch Sch Sch Sch Atlas Camco Camco Sch Sch Camco Camco Camco Sch Atlas ARCO Alaska, Inc. Post Office Bo× 100360 Anchorage Alaska 99510=0360 Telephone 907 276 1215 May 7, 1993 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: As per the attached Form 10-403, ARCO.Alaska Inc. is requesting that the required working pressure for the~r~OPE for DS 9-31A be 3500 psi. The reasons for this request are as follows: 1) The inability to obtain -50 -°F AP1 5000 psi working pressure flanges in a timely manner for this well. The current manifold that is set up for coiled tubing work has ANSI 1500 flanges installed. These flanges have a test pressure of 5000 psi and a working pressure of 3705 psi at -50 -oF. Our problem has been finding -50 °F AP1 flange material from which to build the manifold. We have ordered some 5000 psi working pressure flanges, but are not going to be able to take delivery of them for approximately 12 weeks. We need to start this work however, around May 15, 1993. 2) The maximum surface pressure for this well is expected to be approximately 70% of the working pressure of the ANSI 1500 flanges. This well has been drilled and a 7" liner set to 9398'. The liner shoe is set in the top of the LR 1 sand and all other producible sands are behind the casing. Drilling operations with the coiled tubing will be through the LR 1 and 2 sands to approximately 9450'. The expected bottom hole pressure for this sand body is less than 3500 psi, therefore the expected maximum surface pressure is i 2500 psi which is lower than the working pressure of the flanges. 3) The equipment will be tested to 3500 psi which is approximately the working pressure of the flanges. MAY ! 0 t99,3 .alaska 0il & Gas Cons. Comr,~ission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Mr. D. W. Johnst~,~ May 7, 1993 Page 2 This information has been discussed with Bobby Foster, John Spaulding, and Blair Wondzell of the AOGCC and has met with their approval for use of the ANSI 1500 flanges for this well. Sincerely, Stephen L. Ward Sr. Engineer SLW/008 Attachment cc' d.L. Cawvey - ATO 1520'~.~ ,~iaska Oil & (-las Cons. Comrlfission /~nchorage ~--, STATE OF ALASKA ALASKA i' . AND GAS CONSERVATION CO,''~ '~,ISSION on Suspend ~ Operation shutdown ~ Re-enter suspended well /'//"~ Alter casing Repair well Plugging Time extension Stimulate _.~/..~ Change approved program Pull tubing Variance Perforate Othe¢//~'/ 5. Type of Well 6. Datum of elevation(DF or 54 RKB '~etI 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Development X Exploratory Stratigraphic 7. Unit or Property Service Prudhoe Bay Unit 8. Well number 9-31A 9. Permit number 10. APl number 50 - 029-21396--¢/ 11. Field/Pool Prudhoe Bay Oil Pool 4. Location of well at surface 1587' FSL, 988' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2445' FSL, 2305' FEL, Sec. 2, T10N, R15E, UM At effective depth 2531' FSL, 2389' FEL, Sec. 2, T10N, R15E, UM At total depth 2556' FSL, 2413' FEL, Sec. 2, T10N, R15E, UM MAY ! 0 !99;¢ rul ,-, ,.-, ,.,,, & uas ~,0ns. C0mr,qissio~, Anchorage 12. Present well condition summary Total depth: measured 9452' feet Plugs(measured) Cement Plug @ 9046' MD (11/18/92) true vertical 9139 feet ~-~ ~,j~-~ Effective depth' measured 9046 feet true vertical 8755 feet Junk(measured) ~~ .~Jo Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 1800 # Polyurethane 111' 111' Surface 2479' 13-3/8" 2500 sx CS III & 400 sx CS II 2533' 2533' Production 8869' 9-5/8" 500 sx CIG & 300 sx CS I 8923' 8636' Liner 740' 7" 300 sx CIG 9448' 9135' Perforation depth: measured 8978-8991 '; 9008-9012'; 9012-9018'; 9018-9020'; 9024-9026'; 9026-9030'; 9030-9034'; 9034-9041 '; 9041-9044' true vertical 8689-8701;8718-8721'; 8721-8727'; 8727-8729'; 8733-8735'; 8735-8738'; 8738-8742'; 8742-8749'; 8749-8752' Tubing (size, grade, and measured depth) 7", 29#, L-80, PCT @ 3782' MD, 5-1/2", 17#, L-80, PCT @ 8664' MD, 4-1/2", 12.6#, L-80, PCT Tail @ 8744' MD Packers and SSSV (type and measured depth) Baker SB-3 @ 8642' MD, 7" Camco BaI-O SSSV @ 2191' MD 13. Attachments Description summary of proposal 14. Estimated date for commencing operation March, 1993 16. If proposal was verbally approved Name of approver Date approved Detailed operations program BOP sketch X X I 15. 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 ~. ;z~~ ~.~, ~ ~'2__,//,~itle Engineering Supervisor Date " " FOR (~OMMISSlON U~ ONLY ' Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity BOP Test Location clearance ,~::, CC0"J ~-'~'~ Mechanical Integrity Test Subsequent form required 10- /.v'~_'., ::","¢\"'~,~.~,i"i~3~ ,,-- Req'd working pressure for BOPE: 3500 psi, crU O3o¢~ o~[j~¢__- Approved by order of the Commissioner O~igi~al Si~ned By Commissioner Date ~-L/~) Form 10-403 Rev 06/15/88 Dav}d W. ~o~nston SUBMIT ~N I~IPk~CAYE 963/1 SLW cc: SW, JWP sed Rig/CT Sidetra~,. for 9-31 A 4-1/2" TRSSSV 4-1/2" Production Tubing 13-3/8" Casing Gas Lift Mandrels 9-5/8" Casing b,,~~o Otis X Nipple 3.81 3" ID 7" Liner Rig Drilled 7" Isolation packer w/4-1/2" g tail Otis X Nipple 3.81 3" ID 7" Float Jt. w/3.958" ID or 7" Bushing w/4.5" PB ._- 3-3/4" Open Hole CT Drilled 2-3/8" or 2-7/8" Slotted Liner or Pre-Perforated Pipe uO/'7S. (.,Oh'ilfiJSSJ6~ ",':~nchorage ARCO Alaslr~, Inc. P.O. Box 100360 Anchorage, Aluka 99510 DATE: 4-29-93 REFERENCE: ARCO ~INAL8 4-13-93 SSTVD Run 1, 1"&2' 4-13-93 DLL/GR/SP Run 1, 4-13-93 BHCA/ GR Run 1, 2"&5" 4-13-93 CNL/GR Run 1, 2"&5" 3-23-93 8STVD Run 1, 1"&2' 3-23-93 DLL/GR/SP Run 1, 2'&5" 3-23-93 - BHCA/GR Run 1, 2"&5" 3-23-93 CNL/GR Run 1, 2"&5" 3-23-93 BH Profile Run 1, 5" 3-31-93 DLL (Simultaneous) Run 1, 2'&5" 3-31-93 BHCS/SSTVD Run 1, 5' 3-31-93 BHC8 Run 1, 2"&5" 3-31-93 CNL Run 1, 2'&5" 3/26-31/93 MWD: DPR/GR Runs 1-3, 2"&5'q~D 3/26-31/93 MWD: DPR/GR Runs 1-3, 2"&5'~/D 4-17-93 SSTVD Run 1, 1'&2" 4-17-93 DLL/GR Run 1, 2"&5~ 4-17-93 ZDL/CNL/GR Run 1, 2'&5" 3/13-18/93 LWD: CDN Mad Pass Composite, 2"&5" 3/13-17/93 LWD: CDN Drilling Pass Composite, :~'&5" 3/13-18/93 LWD: CDR Mad Pass Composite, 2"&5" 3/13-17/93 LWD: CDR Drilling Pu~ Composite, 2"&5" 3/13-18/93 LWD: CDN N/F Mad Pass Composite, 2"&5" 3/13-17/93 LWD: CDN N/F Drilling Pass Composite, 2"&5" 3/13-18/93 LWD: CDN Mad Pass TVD Composite, 3/13-17/93 LWD: CDN Drilling Pass TVD Composite, 2'&5" 3/13-18/93 LWD: CDR Mad Pass TVD Composite, 2"&5" 3/13-17/93 LWD: CDR Drilling Pass TVD Composite, 4-6-93 SSTVD Run 1, 1"&2~ 4-6-93 DLL/GR Run 1, 2"&5" 4-6-93 BHCA/GR Run 1, 2"&5" 4-6-93 CNL/GR Run 1, 4-6-93 4 Arm Cal/GR (BH Profile) Run 1, 5" 3-19-93 ~ Induction Electrolog Run 1, 2"&5" 3-20-93 CNL/GR Run 1, 2"&5" 4-20-93 DLL/MLL/GR/SP/Cal Run 1, 4-20-93 BHCA/GR Run 1, 2'&5" 4-20-93 BH Profile Run 1, 5" 3-28-93 SSTVD Run 1, 1"&2" 3-28-93 DLL/MI.L/GR/Cal Run 1, 2"&5" 3-28-93 BHCA/GR Run 1, 2"&.5" 3-28-93 BH Profile Run 1, 5" Please sign and return ~/e attach~d.._copy as receipt of data. RECEIVED BY___~___~ Have A Nice Day! ~ Sonya Wallace E['EII,/E r s.93051 -- ATO-1529 ~PPROVED ~ CErrR,~ ~']~ES U/~Y 0 6 7993 ~ ~~ ~ C~ON ~ PB ~LL ~ t D · M ~ Oil & Gas Cons. Com~issl~ ~c~c~ - - u~nchora"e ~ ~oN ~ STATE OF ~~ ~ MOB~ ~ T~CO * The lo~s for this well ail sa~' field, but are actuall7.finals. Atlas Atlas Atlu Atlas Atlas Atlu Atlas Atlas Atlas Sch Teleco Teleco Atlas Atlas Atlas 8ch 8ch 8ch 8ch Sch 8ch 8ch 8ch ach 8ch Atlu Atlu Atlas Atlas Atlas Atlas Atlu Atlas Atlu Atlas Atlas Atlas Atlas Atlas Gas to well Flowline Optional Trico Skid Pressure Release Line Trico HP Relief Tank 1502 3" Hardllna Hammer U , I Technical I Conference Room ISqueeze Trailer Dual Choke Manifold w/Bypass BOPE Console Ranged Fire Resistant Kelly Hose I Lt~ ~iled Tubing Unit Locations of equipment may be switched if easier to rig-up Ext. 300 Bbls 60/40 400 Bbl Upright 4O0 Bbl Upright 2%KCL with By-pass C.T. Pump Preferred Major Equipment Layout for CT Drilling in DS 9-31A Flanged Rre Res. Hose ITrplxI 60/40 Tool Racks Standby Equipment Suction Manifold Cenlrlfugal'~ Pum~ ----' Optional Pump Tie-In CGB 4/21/93 '~ferred 9-31A C T Drilling Wellhead Detni ~ CT InJ~:~or Head I~tl~noi Injeotion 4-1/16" ID CT 80P Slack =~I ~ 10,000 psi Wo~lng Pressure ._~ ,~/Sluffing Box (Pack-Off), 10,000 psi Working Pressure ~ Rams or Combination Culler/Blinds CuUem or ~tlon Cut~'/Si~:[s ,Slip rams Pipe rams Fk~ge Fla~ed Fire Res~tant Kelly Hose To Dual / Manual Valve HCR (2~ 2.0' (24") Test Gauge t .67 Appmxirnate top of WeUhouse C~3tiomd: Spa~e wiU~ q~3oi pieces or valves to top of welihouse oi~o~ ~ outing o~u~g \ 6"-8" Une To Plant Annular BOP (Hydrll), 5-1/8" ID 5,000 psi working pressure Manual Valves 3.167' (38') 2" to 3-1/2" Valvee Fire Res[slant Kelly Hose Io Flange by Hammer Up 1/4 Turn Valve on DS Ha/dllne 10' from 5.75' 1 1.427' (17-1/~') 0 ..---- Ilandatoi~ SSV t 5.604' (67.25") Top of Pad Level 0.458' (5.5') --- Optional Mam~ Master Valve or Hydraulio SSV (24.5" for ssv) APR 2 ~ 199~ 9-5/8' Annulus Alaska Oil & Gas Cons. Commissio~ i Anchorage 1~ ~nulus ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (g07) 279-1433 TELECOPY: (gO'/) 276-7542 April 6, 1993 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit DS 9-31A ARCO Alaska Inc 93-53 1587'NSL, 998"WEL, Sec 2, T10N, R15E, UM 2844'NSL, 1899'WEL, Sec 2, T10N, R15E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance wit'h 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North slope pager at 659-3607. David W ,.~e,~nston Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl "-" STATE OF ALASKA ALASKA ..)IL AND GAS CONSERVATION CL,,vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillE]llb. Type of well:Exploratory• Stratigraphic Test• Development OilE1 Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska,/nc. KBE = 54'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchorage. Alaska 99519-6612 ADL 28327 4. LoCation of well at surface 7. Unit or properly Name 11. Type Bond(se,, 2o ^^c 25.025) 1587'NSL, 998' WEL, SEC. 2, TION, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 2787'NSL, 1957' WEL, SEC. 2, TlON, R15E, UM 9-31A U-630610 At total depth 9. Approximate spud date Amount 2844'NSL, 1899' WEL, SEC. 2, TION, R15E, UM 4/15/93 $200,000.00 i2. Distance to nearest ' 13. Distance to near(~st Well 14. Number of acres in property15. Prol~osed depth(uDand'rvD) property line ADL 28324-2491 feet No Close approach feet 2560 9459' MD/9009' TVDfeet r16. To be completed for deViated wells 17. Anticipated pressure (s~e 20 Mc 25.035 (,,)(2)) I Kickolf depth ~4oofeet Maximum hole angle 55 o Maximum surface 3330pslg At Iolal depth (TVD) 8800'/4390PS~g 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" .7" 29# L-80/ NSCC 1208' 8250' 7988' 9458' 8954' 275 cu ft Class "G" ., 13CR8¢ ,, ,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. !\ L, ! Present well condition summary Total depth: measured 9452feet Plugs (measured)APR- 5199; true vertical 9139 feet Effective depth: measured 9330feet Junk (measured) Ala. s~ 0{[ & Gas 60rls. true- vertical 9033 feet Anch0rag~. Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 111' 20" 1800#Poly. 111' 111' Surface 2533' 13-3/8" 2500 sx CS II! & 2533' 2533' Intermediate 400 sx CS I Production 8923' 9-5/8" 5oo sx "G"/3OO sxCS / 8923' 8636' Liner 740' 7" 300 sx Class "G" 9448' 9135' Perforation depth: measured 8950'-9353' (4 Intervals) true vertical 8666'-9046' (4 Intervals) 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drillin. g fluid progr.am [] Time vs depth plot [] Refraction analysis[] Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby cedify tha,t the foregoing is true and correct to the best of my knowledge Signed /Z .~~/~.//~¢, ~.¢r~,..~ ,~. ,' Title Drilling Engineer Supervisor Date /"///~'/¢,._~ Commission Use Only Permit Number " IAPI number IApproval date See cover letter c]',~ _ ,¢"~ 15 O- O ;2._c/ - ~1 ..~' c/Z,, - ~! I ;'~-"~' '" ~'1~~ for other requirements COnditions of approval Samples required [] Yes ~.No Mud log required Yes 'E No ' Hydrogen sulfide measures [] Yes E2LNo Directional survey requ~rea 123. Yes [] No Required working pressure for BOPE'FI2M; EI3M; [~5M; I-I10M; F-i15M; Other: Or;g~na~ 5~9ned 13¥ by order of Approved by David 'W. johnston Commissioner tne commission Date~~¢,---~ Form 10-401 Rev. 12-1-85 Submit in triplicate DS 9-31A CT SIDETRACK AND COMPLETION INTENDED PROCEDURE Complete drilling in LR2 with CT while underbalanced. Underream as necessary. Produce well. Run pre-perfed liner as necessary. This work will be performed following the plug and abandonment of the original wellbore and the conventional sidetrack of the well to the LR2 formation as described under a separate Sundry Application issued by Prudhoe Bay Drilling. Procedure: 1. MIRU CTU and Trico production test unit. Install BOP's and test to 3500psi. , MU 3-3/4"drilling BHA on CT and drill slightly underbalanced to the Base Sadlerochit at about 8990' ss. Underream open hole to 5-1/2" as necessary. 3. RD and move CTU. Place well on production. , Optional: MU 2-3/8" slotted liner in open hole section and set packer in 7" heavy wall liner section. (Based on well testing and fill accumulation.) Proposed Rig/CT Sidetrack for 9-31 A 4-1/2" TRSSSV 4-1/2" Production Tubing 3-3/8" Casing Gas Lift Mandrels 9- 5/8" Casing Otis X Nipple 3.81 3" ID 7" Liner Rig Drilled 7" Isolation packer w/4-1/2" Tubing tail Otis X Nipple 3.81 3" ID 7" Float Jt. w/3.958" ID or 7" Bushing w/4.5" PB ~ 3-3/4" Open Hole CT Drilled 2-3/8" or 2-7/8" Slotted Liner or Pre-Perforated Pipe STATE OF ALASKA ... AL/ \ OIL AND GAS CONSERVATION COMMISS APPLlCA'I1ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing ~ Repair well ~ Plugging x Time extension ~ Stimulate ~ Change approved program Pull tubing ~ Vadance ~ Perforate ~ Other x ~ Plugback for redrlll 2. Name of Operator 5. Type of Well: 6. ARCO Alaska,/nc. Development. x Exploratory ~ 3. Address Stratigraphic ~ 7, P. O. Box 196612, Anchorage, Alaska 99519-6612 Service ~ 4. Location of well at surface 8. 1587'NSL, 998'WEL, SEC. 2, TION, R15E, UM At top of productive interval 9. 2445' NSL, 2305' WEL, SEC. 2, TION, R15E, UM At effective depth 10. 2531' NSL, 2389' WEL, SEC. 2, TION, R15E, UM At total depth 11. 2556' NSL, 2413' WEL, SEC. 2, TION, R15E, UM Datum elevation (DF or KB) KBE ,= 54 feet Unit or Property name Prudhoe Bay Unit Well number 9-31 Permit number 85-161 APl number 50- 029-21396 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 111' Surface 2533' Intermediate Production 8923' Liner 740' Perforation depth: 9452 feet Plugs (measured) 9139 feet 9330 feet Junk (measured) 9033 feet Size Cemented 20" 1800 #Polyurethane 13-3/8" 2500 sx CS III & 400 sx CS ! 9-5/8" 500 sx "G"/ 300 sx CS I 7" 300 sx Class "G" Field/Pool Prudhoe Bay Field/Oil Pool measured 8950;9353' (14 intervals) RECEIVED APR - § 199,3 Alaska 0il & Gas Cons. CornmisSio~ Measured depi~nch0rage True vertical depth 111' 111' 2533 2533' 8923' 8636' 8708;9448' 9135' true vedical 8666;9046' (14 intervals) Tubing (size, grade, and measured depth) 7", 29#, L-80 to 3792'; 5-1/2", 17#, L-80 to 8640~ 4-1/2", 12.6#, L-80 to8741' Packers and SSSV (type and measured depth) Baker SB-3 @ 8642', 7" Camco Bal-O SSSV @ 2191' 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 4/1/93 16. I~ proposal was verbally approved Name of al)prover Date approved 15. 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 u"'~..~ ~ ~/~, ~¢~._.,ff~.," T, le Drilling Enginoer Supervisor ~' /~' ..... FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test L ' nce Approved by order of the C?m Form 10-40'3 Rev 06/15/88 ' ¢-" "\ Approval No. ~,..~._ ~7 '~ 7 Commissioner SUBMIT IN TRIPLICATE ~--" DS 9-31A REDRILL ~"'- Ob!ective: The objective of the DS 9-31A redrill is water shut-off. Severe corrosion in the liner has made it impossible to squeeze the water producing zone and the well is producing at 94% watercut. The liner should be drilled to the top of the LR2 sands so this tight zone can drilled underbalanced with coiled tubing after the rig moves off. Scope: The scope of the 9-31A redrill is as follows: Plug and abandon the original perforations and pull the7" x 5-1/2" tubing. Mill a 50' section in the 9-5/8" casing starting at 7920' MD. Lay a cement plug across the section, kickoff and ddll a new 8-1/2" hole to a target about 300' east of the original wellbore. Obtain E-line logs. Run and cement a 7" 29# L-80 / 13CR liner. Clean out to just past the float shoe. Once the 4-1/2" 13CR tubing is installed, the rig will be released and a coiled tubing unit will move in and drill underbalanced through the LR2 to the base of the Sadlerochit. Timing: This project is presently scheduled for Nabors 2ES in mid April, 1993. The duration of the rig work is estimated at 13 days. ..... DS 9-31A REDRILL ' Procedure Outline: 19. 20. 1. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 5-1/2" tubing at 8600' MD. Freeze protect. 2. MIRU workover rig. Test intermediate packoff to 3500 psi. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set BPV. ND tree. 5. NU BOP's. Install tree test plug. Test BOP's to 5000 psi. Pull tree test plug and BPV. 6. Pull and lay down 7"x 5-1/2" tubing. 7. RIH with a 9-5/8" section mill and cut a 50' section in the 9-5/8" casing starting just aboVe 8400' MD. (casing collars @ +/- 8407' and 8446' MD below Rowan 35 KB) 8. RIH with open-ended DP. Mix and pump a minimum of 165 ft3 of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. 9. Replace intermediate packoff (Failed pressure test 2-25-93). 10. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to target depth of 9458' MD / 8954' TVDss or to the top of the LR2 sands. A 50° minimum angle is required at TD. 11. RU wireline and Icg with the DLL / Microlog / GR / SP / Sonic / Neutron. Make wiper trip depending on hole conditions and logging time. 12. Run 7" 29# 13CR FOX x 7" 29# L80 NSCC liner assembly w/4-1/2" shoe joint (concentric in 7" shoe joint) to TD with liner top packer and +/- 150' lap. Crossover from 13CR to L-80 at _+8400' TVDbkb (300' MD above highest future perfs). 13. Cement liner with a minimum of 275 ft3. (Ensure that all oil bearing sands are cemented across) 14. Clean out liner to landing collar and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. 15. Drill out 7" landing collar and liner to top of concentric shoe joint. Change over to clean inhibited seawater. 16. RIH w/7" isolation packer w/4-1/2" tailpipe (contingent upon OHL's) on wireline and set at depth to be determined. Omit the SWN nipple. See notes on next page. 17. RIH with 4-1/2" 12.6# completion string w/7" packer. Space out, land completion, and place packer at 8800' MD based on 200' above the top perforation. Drop ball. 18. Set BPV. ND BOP's. NU the adapter flange and 6-1/8" 5M tree. Install tree test plug and test to 5000 psi with diesel. Pull tree test plug and BPV. Pressure down tubing and set packer. Test down tubing to 4000 psi. Bleed tubing pressure down to 1000 psi. Test tubing x casing annulus to 3500 psi. Shear RP valve and freeze protect. Set BPV. Release rig. DS 9-31A REDRILL PRELIMINARY WELL INFORMATION WELL: DS 9-31A Redrill PBU EOA APl No.' 50-029-21396-00 (on the original 9-31 well) LOCATION' Surface: 1587' FSL, 998' FEL, Sec. 2, T10N, R15E Target' 2787' FSL, 1957' FEL, Sec. 2, T10N, R15E @ 8954 TVDss BHL TD: 2844' FSL, 1899' FEL, Sec. 2, T10N, R15E @ 9009 TVDss ESTIMATED START' 15 April, 1993 OPR. DAYS TO COMPLETE: 13 CONTRACTOR' Nabors Rig #2 ES DIRECTIONAL- Kickoff at --. 8400' MD with a 6°/100' build and right turn to 55° inClination (maximum hole angle) on an azimuth of N 46° E. No close approaches. TOP OF PRODUCTIVE INTERVAL' Sadlerochit, 8977 MDBKB, 8616 TVDss WELLBORE' Item TVDss MD(BKB) Mud Wt, 13-3/8" SHOE 2479' 2533' N/A KOP 8077' 8400' 9.0 TOP SAG RIVER ABSENT TOP SHUBLIK ABSENT TOP SADLEROCHIT 8616' 8977' 9.2 TARGET (TOP ZONE 1) 8954' 9458' 9.2 TOTAL DEPTH 9009' 9556' 8.9 w/gas lift Note that interval 9458-9556 MDBKB will be drilled with coiled tubing after the rig moves off the well LOGGING PROGRAM' 8-1/2" Hole' Anadrill CDR by MWD. Atlas GR / SP / DLL / BCS / CNL by electric line. 3-3/4" Hole' None DS 9-31A REDRILL MUD PROGRAM: The milling / drilling fluid program will consist of a 9.0 - 9.2 ppg Biozan polymer / KCI water based mud in the 8-1/2" hole. The drilling fluid for the coiled tubing drilled 3-3/4" hole will be 8.8 - 9.0 ppg Xanvis polymer / KCI water. Annular gas lift is planned to provide a ~300 psi underbanced condition while drilling with coiled tubing. DEPTH DENSITY PV YP INT 10 MIN fTVDss~ (PPG~ (CP)(#/FT)GEL GEL 8131' to 8954' to 9009' FL OIL SOLIDS MUD cc/30min (%) (%) TYPE 9.0 5 25 10 20 5 TR TR Water to to to to to to Base 9.2 10 45 15 25 6 8.9 w/gas lift 10 45 1 5 25 6 'IR -IR Water base MUD WEIGHT CALCULATIONS / WELL CONTROL: Est. Pore Press. Sadlerochit: 3600 psi/8800' ss 'I-VD. Mud Wt.: 8-1/2" Hole = 9.2 ppg. Overbalance Top Sadlerochit: 610 psi Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH BURST COLLAPSE TENSILE 7" 29# L-80 NSCC / 13Cr-80 NSCC ~8250' - 9458' MD 8160 psi 7020 psi 676 klbs DS 9-31A REDRILL CEMENT CALCULATIONS' 7" LINER: Measured Depth: Basis' Total Cement Vol: 8250'MD (Hanger)o 9458'MD (Shoe) 40% open hole excess, 40' shoe joint, 150' liner lap and 100' excess above liner with DP. 275 cu ft or 233 sxs of Class G blend @ 1.18 Cu ft/Sk ..TUBING DETAILS' MUD 4-1/2" 12.6# 13CR-80 NSCT (Surface - 8850' MD) NABORS RIG NO. 2ES SOLIDS CONTROL EQUIPMENT 2 - Continental Emsco Fl000 Mud Pumps 1 - Derrick FIoLine Cleaner Shale Shaker 1 - Mud Cleaner 1 - Centrifuge 1 - DRECOGas Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 HP Flash Mixer Agitator 3 - Abcor 10 HP Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console GRi LA/~iD DIRECTIONAL DRiLLIi~G, Corporate Office 2211 East 80th Avenue ~uchora~e, /t~: 99518 (907) 3~9-4511 Fax 349-2487 DIRECTIONAL WELL PLD_N for PRUDHOE BAY DRILLING ..:ell ......... : DS 9-31A (Pg) Field ........ : PRUDHOE BAY DRILL SITE iompu~a~ion..: MINIMUM CURVATURE 3nits ........ : FEET Prepared ..... : section KB elevation.: 03/24/93 46.23 54.00 ft LEG3~L DESCRIPTION 3urface ...... : 1587 FSL 998 FEL S02 T10N R!5E UM fie-in ....... : 2354 FSL 2!92 FEL S02 T10N R15E ~4 Farget ....... : 2787 FSL 1957 FEL S02 T10N R15E UM 5HL .......... : 2844 FSL 1899 FEL $02 T10N R15E tim X ~SP ZONE 4 ¥ 717376,19 5943026.83 716159.95 5943759.06 716382.10 5944198,65 716439.04 5944256.4q PROPOSED WELL PROFILE STATION M~AS INCLN VERT-DEPTHS IDENTIFICATION DEPTH ~2¢GLE BKB SUB-S TIE-iN SECT DIST 8400 15.97 S!3! 8077 -332 8500 14.80 8228 8174 -333 8600 15.92 8325 8271 -323 8700 !8.93 8420 8366 -303 $800 23.09 8513 8459 -274 DIRECTION AZIMUTH 303.90 326.23 348.63 6.!0 18.21 REL-COORDINATES DL/ FROM-WELL~E_kD !00 767 N 1~5 W <TiE 785 lq 1213 W 6.0 809 N 1223 W 6.0 839 N 1224 W 6.0 874 N 1216 W 6.0 LCU/SD~LEROCH!T PGOC ZONE 3 8900 27.91 8604 8550 -234 8977 31,85 8670 86i6 -198 9000 33.08 8690 8636 -186 9001 33.16 8691 8637 -185 9090 37.93 8763 8709 -135 26.58 3i.33 32.58 32.65 36.68 913 N 1200 W 6.0 947 1'$ 1181 W 6.0 957 ~4 1174 W 6,0 958 N 1174 W 6.0 1000 N 1145 ~7 6.0 ZOblE 2/2C ZONE 2B/T~.N~O ZONE_ 10./LOWE~ ZONE 2A/ROMEO F/{D OF CUR%CE 7" ~ASING POINT TARGET/EF{D RIG DRILL BASE SADLEP, OCi-II T TD 9!00 38.48 8771 8717 -128 9152 4!.35 8Ri! 975V -95 9200 44.01 8846 8792 -63 9224 45.34 8862 8809 -46 9300 49.62 89!4 8860 10 923~ 53.99 8962 8908 70 9377 53.99 8962 8908 70 9400 55.30 8975 8921 89 9412 55.97 8982 8928 99 9458 55.97 9008 8954 137 ~%58 55.97 9008 8954 137 952~ 55.97 90~6 8992 !93 9556 55.97 9063 9009 218 27.08 39.03 40.63 4i.37 43 .52 45 .43 45 .43 45.96 46 .23 46.23 46 ,23 46.23 46 .23 !005 N 1141 W 6.0 1032 N 1120 W 6.0 1056 N 1099 W 6.0 1069 ~ !089 W 6.0 1110 N 1051 W 6,0 1!53 ~ i008 W 6.0 1153 N 1008 W 6.0 1167 N 995 W 6.0 1173 ~ 988 W 6.0 1200 N 960 W 0.0 1200 N 960 W 0.0 1239 N 919 W 0.0 1256 N 901 ;4 0.0 ?---'DD (c)92 D$~31A BI.z_3 6:4¢ PM 2) Harker identification ~O DKB SECTN [NCLN A) TiE-iN 6~00 813I -33~ BI ENO OF CURVE 941e B9~2 9g 55.97 CI 7" CASING P0:NT 9458 9008 ]37 55.97 o] TA~G£T/~ND ~3 DRILL gz58 go0~ ~7 55.97 E] 7D 9556 9063 2J8 5§.97 PRUDHOE BAY DR ILL I NG DS 9-~A (Pg) VERTICAL SECT.~,Q.N~: V~ ,E ~ Section at' 46.23 i'~" TVD Sca~.' ~ ~ncI~ = 200 Dpawn ' 03/a4/9~ ) I I ; I , I ; i i i : ; , : i ._ ! -DO0 -500 -400 L. . i" ~ · -300 -2.00 -'., O0 0 Section Departur'e ._ 200 300 F'Fi-T"'F'" 1 500 600 I 7oo 800 PRUDHOE BAY DRILLING DS 9-3 A (P9) CLOSURE ' 1546 feet at Azimuth 324.34 DECLINATION.' 30.20 E SCALE · ~ inch : 200 feet DRAWN · 03/2~/g3 Land Z)JrectJona] ZgrJ]]Jng ' I ; ' Marker IdentJFica[ion MD N/S A) T~E-IN 8400 767 N B) END OF CURVE 9z~2 1~73 N C) ?' CASING POINT 9458 J200 N O} TARGET/END NIG DRILL 9458 J200 N E) TO 9556 J255 N E/W 988 ~ ~60 960 ~ 90i W ! i I ' I i [ , ;if ' i I I . I ~250 i I ~200 t150 l~.O0 !050 ~OOO 900 85O <- WEST mi ... , . iT. -il BOO 750 TOTAL P. 04 [~D-I-I ~SVS~ I qOOdS 991 SSOMO [AIVI::I qdld i SSO~O t-- ,Zg'9~ IAIVI::! CINI-IE] l~VJ:::l =ldld -i:IA:I-! '(]NNOHE) ,Z ,Og' I. I ,89' I. ~( "11 I::ICIAH NVd dlk:lCl --IE~ (DJ.. ':dH J !sd 000'g ,,8/~ 8 I. S::i ~; SEIOEIVN . J ,ZS'~ ,g6'1~ -~' · H~. MUD PUMP No2 / Bob ST^O~4 - 13 ~8 5oo0+ · A]J~,SKI'--'"L AND GAS CONSERVATION C -'MISSION APPLICA i'ION FOR SUNDRY AI-,PROVALS 1. Type of Request: Abandon Suspend OperalJon shutdown Re-enter suspended well AItercasing Repairwell Plugging Time extension Stimulate . Change approved program Pull tubing Vadance Perfor.~te (~ther X 5. Type of Well Development X Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1587' FSL, 988' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2445' FSL, 2305' FEL, Sec. 2, T10N, R15E, UM At effective depth 2531' FSL, 2389' FEL, Sec. 2, T10N, R15E, UM At total depth 2556' FSL, 2413' FEL, Sec. 2, T10N, R15E, UM 6. Datum of elevation(DF or KB) 54 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-31A 9. Permit number · -86---1-6-1- ¢'~- ~..3 ~, ~. ~., 10. APl number 50 - 029-21396-d I 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical -'~iu~")9046' MD (11/18/92) 9452' feet Plugs(measured) ~C~rtt 9139 feet Effective depth: measured 9046 feet true ve~ical 8755 feet Junk(measured) ~,~: '-~.,',~," . ,'~.?' ..... -.. ,,;~ ~, ,~c.- Measured depth True vertical depth Casing Length Size Cemented Conductor 111' 20" 1800 ~ Polyurethane ?"~'~ ..... 111' 111' Sudace 2479' 13-3/8" 2500 sx CS III & 400 sx CS II 2533' 2533' Production 8869' 9-5/8" 500 sx CIG & 300 sx CS I 8923' 8636' Liner 740' 7" 300 sx CIG 9448' 9135' Perforation depth: measured 8978-8991'; 9008-9012'; 9012-9018'; 9018-9020'; 9024-9026'; 9026-9030'; 9030-9034'; 9034-9041 '; 9041-9044' true vertical 8689-8701;8718-8721 '; 8721-8727'; 8727-8729'; 8733-8735'; 8735-8738'; 8738-8742'; 8742-8749'; 8749-8752' Tubing (size, grade, and measured depth) 7", 29#, L-80, PCT @ 3782' MD, 5-1/2", 17#, L-80, PCT @ 8664' MD, 4-1/2", 12.6#, L-80, PCT Tail @ 8744' MD Packers and SSSV (type and measured depth) Baker SB-3 @ 8642' MD, 7" Camco BaI-O SSSV @ 2191' MD 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation March, 1993 16. If proposal was verbally approved Oil x. Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor "" FOR COMMISSION H~E ONLY 15. Status of well classification as: Gas __ Suspended Conditions of approval: Notify Commission so representative may witness Approval No. ~ ~ ~ . ~ -- .... .\ C,c::?";' ' '~ -' / '-~ '~ Plug integrity BOP Test × Location clearance Mechanical Integrity Test , Subsequent form required 10- Req'd working pressure for DOP~ ~d BY Orlg~na~ Approved by order of the Commissioner David W. johnston: Form 10-403 Rev 06/15/88 963/1 SLW cc: SW, JWP SUBMIT IN TRIPLICATE Page 1 9-31ACtdT.XI..S State: Well: Field: State Permit Dsg.-31A Prudhoe Bay 98.-53 Engineer: Work Shee~ Date: ~ N, hde,' Cement Vo/~zme Calculation,~ 3/31/99 Ca~g T.,,,pe Casing Size -Inches Casing Length - Feet Hole Diameter -Inches Cement- Sacks 111 Cement-YieldII1 Cement- Cubic ft 111 Cement- Cubic ft 111 Cement- Sacks 112 Cement- Yield 112 Cement- Cubic fl. 112 Cement-Cubic fl II2 Cement- Sacks 113 Cement- Yield 113 Cement- Cubic fl 113 Cement- Cubic fl 113 Cement- Cubic fl. / Vol Cement- Fill Factor Conductor 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 OLO00 0.1300 ItDIV/O! Surface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 11000 0.000 0.000 0.000 0.000 0.000 I~gIV/O! Liner 7.000 1,208000 8.500 0.000 0.000 0.000 275.000 0.000 0.000 0.000 0.000 275.000 1.795 Ca~ing TJ,,l:,e Casing Size -Inches Ca~g Depth - Feet Hole Diameter .-Inches Cement- Sacks 111 Cement-Yield 111 Cement- Cubic fl 111 Cement- Cubic fl 111 Cement- Sacks 112 Cement- Yield 112 Cement-Cubic fl 112 Cement- Cubic fl 112 Cement-Sacks 113 Cement- Yield 113 Cement- Cubic fl:113 Cement-Cut~c fl: 113 Cement- Cubic fl / Vol Cement-Interval fl: Top of Cement- Feet Intermediate 111 0.000 0.0130 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! I~DIV/O! Intermediate 112 0.000 0.000 0,000 0.00 0.00 0.00 0.00 0.00 0.130 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! I~IV/O! Production 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! IIDIV/O! Nleasured Depth Sta~e: Alaska Borough: Well: Dsg-31A Field: Prudhoe Bay St. Perm ;93-53 Dale Engr: 9-31AXLS 3/31193 M. Minder Casing Interval Interval Size Bottom Top lA 7 8954 7988 ZA 0 0 0 3A 0 0 0 4A 0 0 0 5A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Length 1208 0 0 0 0 0 0 0 0 0 Tension Lbs Grade Thread Lbs 29 L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/it psi/It 9.2 0.478 0.378 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -43.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure psi 8330 0 0 0 0 0 0 0 0 0 Yield psi BDF 8160 2.5 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DNIO! 0 #DIV/O! 0 #DIM/0! 0 #DIV/O! 0 #DIV/0! 1C 2C 3C 4C 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 35.032 0 0 0 0 0 0 0 0 0 K/Lbs TDF 676 19.30 0 #DIV/O! 0 #DIV/O! o #DIM/O! 0 #DIM/0! 0 #DIV/O.I 0 #DIM/O.I 0 #DIV/O! 0 #DIM/O! 0 #DIV/O.I Collapse Collapse Pr-Bot-Psi 3388 0 0 0 0 0 0 0 0 0 Resist. CDF 7020 2.072 0 #DIV/O! 0 #DIM/O! 0 #DIM/O! 0 #DIM/O! 0 #DIM/O! 0 #DiV/O! 0 #DIM/O! 0 #DIM/O! 0 #DIM/O! Page 1 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee (2) Loc [2 thru 8] [9 thru 13] [10 $ 13] (4) Casg -,,~ \..?, ,?, 3-~l- ? ~'-, [14 thru 22] (5) BOPE /~-~/. . o' ~- -~',7;' _ ?,E [23 thru 28] Company YES 1. Is permit fee attached., ............................................. /~ .... 2. Is well to be located in a defined pool .............................. /~ 3. Is well located proper distance from property line ................... ~ 4. Is wel 1 located proper distance from other wells ..................... j(~ 5. Is sufficient undedicated acreage available in this pool ............. ~ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Lease & Well ~/~D~ NO / REMARKS 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nc~nber appropriate .......................................... 13. Does well have a unique name & number ................................ 14. Is conductor string provided ......................................... 15. Wil 1 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension, and burst. 20. Is well to be kicked off from an existing wellbore ................... 21. Is old wellbore abandonment procedure included on 10-403 ............. 22. Is adequate wellbore separation proposed ............................. 23. Is a diverter system required ........................................ 24. Is drilling fluid program schematic & list of equipment adequate ..... 25. Are necessary diagrams & descriptions of ~ BOPE attached .... 26. Does BOPE have sufficient pressure rating -- test to ~5'~O~ psig ..... 27. Does choke manifold comply w/API RP-53 (May 84) ...................... 28. Is presence of H2S gas probable ...................................... (6) Other -- [29 thru 31] (7) Contact [32] (8) Addl //~. ~. ~/( 29. 30. 31. 32. 33. geology' engineering :~ DWJ MTM~ RAID RPCfi~/~/_~ BEW JDH_~ LG rev 12/92 FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... / // Add i t i ona 1 requ i rements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE · Additional remarks' MERIDIAN: UM.~ SM Ek~[~.k TYP, E,: Redr FT1 Rev 0 ~C) 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. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 5930.00 SHOREY REEM/SMITH D.S. 9 - 3lA 500292139601 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 06-MAY-93 RUN2 RUN3 2 10N 15E 1587 998 55.00 54.00 22.00 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8400.0 8.500 9394.0 DLL/CN/ZDL/GR CIRCULATION STOPPED: 16: 30 17-APR-93. MAIN PASS IS A COMPOSITE OF A LOWER INTERVAL PASS & AN UPPER INTERVAL PASS. SPLICING WAS DONE IN THE FIELD. ZDEN FAILED ON REPEAT PASS DUE TO SURFACE MALFUNCTION. NEUTRON IS CALIPER CORRECTED, CHISM FILTERING IS ACTIVE. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DLL 2435 SDN $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 8381.0 9312.0 8381.0 9364.0 8750.0 9319.0 8750.0 9337.0 GR (MEASURED DEPTH) BASELINE DEPTH LL3 8381.0 8381.0 8404.5 8405.0 8406.0 8407.0 8413.5 8414.5 8438.0 8438.5 8454.5 8455.0 8564.0 8564.0 8575.0 8575.0 8585.0 8585.0 8595.0 8595.5 8608.0 8608.5 8615.5 8616.5 8621.0 8621.5 8633.0 8633.5 8635.0 8635.0 8648.5 8649.0 8650.5 8651.0 8662.0 8662.5 8672.0 8672.0 8720.0 8720.0 8814.0 8828.0 8828.5 8830.0 8831.0 8832.0 8833.5 8883.0 8939.5 8942.5 8947.5 8960.0 8960.5 8960.5 8975.0 8996.0 9010.0 9013.0 9013.5 9016.0 90Z~.5 9026.5 9031.5 9046.5 9049.0 9047.5 all runs merged; EQUIVALENT UNSHIFTED DEPTH RHOB NPHI 8381.0 8381.0 8814.0 8883.0 8943.0 8947.0 8959.0 8975.0 8995.5 9013.5 9016.5 9027.0 9032.5 9045.0 8939.5 8947.0 8959.5 8995.5 9010.0 9014.5 9045.0 no case 9054.5 9055.0 9052.5 9058.5 9058.0 9062.5 9061.0 9067.0 9065.5 9092.0 9092.0 9137.5 9137.0 9138.0 9139.0 9169.0 9170.0 9184.5 9185.0 9191.0 9191.0 9195.0 9195.5 9200.0 9227.5 9226.5 9230.5 9230.0 9236.5 9235.5 9237.0 9259.0 9257.0 9266.0 9266.5 9264.5 9282.0 9282.0 9283.5 9290.0 9290.0 9295.0 9295.5 9304.0 9304.0 9500.0 9500.0 9500.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 2 DLL 1 2 2435 1 2 SDN 1 2 $ REMARKS: CN WN FN COUN STAT 9055.0 9066.0 9138.0 9185.0 9200.0 9239.5 9267.0 9283.5 9289.5 9500.0 MERGE TOP MERGE BASE 8381.0 9312.0 8381.0 9364.0 8750.0 9319.0 8750.0 9337.0 OPEN HOLE PORTION OF MAIN PASS. LLD, SP, CALl, MTEM, TENS, & TEND WERE SHIFTED WITH LL3. DRHO & PEF WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. $ : ARCO ALASKA INCORPORATED : D.S. 9 - 3lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 2 LL3 DLL 68 1 3 LLD DLL 68 1 4 SP DLL 68 1 5 MTEM DLL 68 1 6 TEND DLL 68 1 7 TENS DLL 68 1 8 NPHI 2435 68 1 9 NUCT 2435 68 1 10 FUCT 2435 68 1 11 RHOB SDN 68 1 12 DRHO SDN 68 1 13 PEF SDN 68 1 14 CALl SDN 68 1 * DATA RECORD (TYPE# 0) Total Data Records: 140 GAPI 4 OHMM 4 OHMM 4 MV 4 DEGF 4 LB 4 LB 4 PU-S 4 CPS 4 CPS 4 G/C3 4 G/C3 4 BN/E 4 IN 4 966 BYTES * 56 4 57 515 01 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 46 103 82 4 46 103 82 4 98 211 23 4 98 211 23 4 98 211 23 4 22 779 91 4 22 779 91 4 22 779 91 4 22 779 91 Tape File Start Depth = 9500.000000 Tape File End Depth = 8381.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 33586 datums Tape Subfile: 2 289 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 8111.0 8381.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION OF MAIN PASS. $ : ARCO ALASKA INC : D.S. 9 - 3lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 MTEM GR 68 1 DEGF 3 TEND GR 68 1 LB 4 TENS GR 68 1 LB 4 21 990 60 6 4 45 987 88 5 4 10 579 41 1 4 10 579 41 1 16 * DATA RECORD (TYPE~ 0) Total Data Records: 16 1006 BYTES * Tape File Start Depth = 8381.000000 Tape File End Depth = 8000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3816 datums Tape Subfile: 3 41 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH GR 8110.0 DLL 8357.O 2435 8750.0 ZDL 8750.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9332.0 9384.0 9330.0 9351.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN PCM ZDL KNJT TEMP PCM KNJT MIS DLL FTS FTS $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 17-APR-93 FSYS REV. J001 VER. 1.1 1630 17-APR-93 2311 17-APR-93 9394.0 9377.0 8100.0 9364.0 1800.0 TOOL NUMBER 3974XA 3517NA 1309XA 2435XA 3508XA 2222EL/MA 3921NA 2806XA 3506XA 3921NA 3967NA 1229EL/MA 8.500 8400.0 8381.0 KCL/XANVIS 9.40 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 48.0 10.0 5.4 175.0 0.130 0.052 0.110 0.000 0.190 0.000 70.0 175.0 70.0 0.0 70.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 0.000 TOOL STANDOFF (IN) : 0.0 REMARKS: MAIN PASS. CNC IS CALIPER CORRECTED. CHISM FILTERING ACTIVE. $ CN WN FN COUN STAT : ARCO ALASKA INC : D.S. 9 - 3lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF SPD DLL 68 1 F/MN CHT DLL 68 1 LB TTEN DLL 68 1 LB CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L SSN 2435 68 1 CPS LSN 2435 68 1 CPS ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 11 639 82 1 4 46 103 82 1 4 46 103 82 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 83 368 34 1 4 84 023 70 1 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 * DATA RECORD (TYPE# 0) Total Data Records: 429 1014 BYTES * 68 Tape File Start Depth = 9500.000000 Tape File End Depth = 8000.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 141605 datums Tape Subfile: 4 514 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH GR 8664.0 DLL 8715.0 2435 8724.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9332.0 9384.0 9330.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN PCM ZDL KNJT TEMP PCM KNJT MIS DLL FTS FTS $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LD/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): 17-APR-93 FSYS REV. J001 VER. 1.1 1630 17-APR-93 2357 17-APR-93 9394.0 9377.0 8100.0 9364.0 1800.0 TOOL NUMBER 3974XA 3517NA 1309XA 2435XA 3508XA 2222EA/MA 3921NA 2806XA 3506XA 3921NA 3967NA 1229EA/MA 8.500 8400.0 8381.0 KCL/XANVIS 9.40 48.0 10.0 5.4 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 175.0 0.130 0.052 0.110 0.000 0.190 0.000 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 0.000 TOOL STANDOFF (IN): 0.0 REMARKS: REPEAT PASS. CNC CALIPER CORRECTED. CHISM FILTERING ACTIVE. $ CN WN FN COUN STAT : ARCO ALASKA INC : D.S. 9 - 3lA : PRUDHOE BAY : NORTH SLOPE : ALASKA 70.0 175.0 70.0 0.0 70.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 RS DLL 68 1 OHMM 4 3 RD DLL 68 1 OHMM 4 4 SP DLL 68 1 MV 4 5 TEMP DLL 68 1 DEGF 4 6 SPD DLL 68 1 F/MN 4 7 CHT DLL 68 1 LB 4 8 TTEN DLL 68 1 LB 4 9 CNC 2435 68 1 PU-S 4 10 CNCF 2435 68 1 PU-S 4 11 CN 2435 68 1 PU-L 4 12 SSN 2435 68 1 CPS 4 13 LSN 2435 68 1 CPS 4 14 CAL ZDL 68 1 IN 4 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 11 639 82 1 4 46 103 82 1 4 46 103 82 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 83 368 34 1 4 84 023 70 1 4 24 115 90 6 56 DATA RECORD (TYPE~ 0) 966 BYTES * Total Data Records: 226 Tape File Start Depth = 9500.000000 Tape File End Depth = 8600.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57832 datums Tape Subfile: 5 308 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 6 is type: LIS 93/ 5/ 6 01 **** REEL TRAILER **** 93/ 5/ 7 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 7 MAY 93 10:52a Elapsed execution time = 49.11 seconds. SYSTEM RETURN CODE = 0