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Home My WebLink About183-047 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 RECEIVED t\U G 3 Mit August 22, 2011 °1181 as Cogs. 91 011 Wert. Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue q. fit. , ?tl`l Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L2 l Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Lisburne 02 Date: 7/7/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal L2 -03A 1980620 500292146501 Top Plate NA NA NA NA NA L2 -06 1830470 500292093000 2" NA 2" NA 0.90 7/7/2011 L2 -07A 2040530 500292291001 14" NA 14" NA 8.50 6/30/2011 L2 -08A 1981400 500292176101 Top Plate NA NA NA NA NA L2 -10 1870850 500292174600 Top Plate NA NA NA NA NA L2 -11 1980960 500292288500 14" NA 14" NA 6.80 6/30/2011 L2 -13A 1980780 500292144001 Top Plate NA NA NA NA NA L2 -14B 2040950 500292175802 Top Plate NA NA NA NA NA L2 -16 1870970 500292175400 Top Plate NA NA NA NA NA L2 -18A 1981060 500292176601 Top Plate NA NA NA NA NA L2 -20 1851340 500292137600 Top Plate NA NA NA NA NA L2 -21A 2041040 500292148501 Top Plate NA NA NA NA NA L2 -24 1850900 500292134600 Top Plate NA NA NA NA NA L2 -25 1860060 500292152500 Top Plate NA NA NA NA NA L2 -26 1851040 500292135900 Top Plate NA NA NA NA NA L2 -28 1850350 500292129800 62" NA 62" NA 35.70 7/5/2011 L2 -29 1852970 500292150500 Top Plate NA NA NA NA NA L2 -30 1850090 500292127200 Top Plate NA NA NA NA NA L2 -32 1871370 500292177800 Top Plate NA NA NA NA NA L2 -33 1860220 500292153400 Top Plate NA NA NA NA NA Schlumherger Alaska Data 6 ConsulUng Services 2525 Gambell Stroet, Suite 400 Mchwage, AK 99503-2836 ATTN: Beth Well Job 8 NO. 5353 ~~ /" ~J ~ ~~Q Company: State of Alaska 1~ 1 Alaska Oil & Gas Cons Comm ~ t V Ann: Christine Mahnken 333 West 7th Ave, Suite 100 Mchorage, AK 99501 Log Description Date BL Color CD osii ~ios ~ r.' ;~ V-02 W-26A H-32 B2WY-00018 B1JJ-00033 ANHY-00102 MEM PRODUCTION PROFILE ' MEM PRODUCTION PROFILE ~ PRODUCTION PflOFILE ~ L- 07l27/09 07/2W08 07/25/09 1 1 1 1 1 1 P2-29 L2-11 L2-OB AYTU•00052 ANHY-00106 869K-00007 INJECTION PROFILE '~. ~-~ LDL ~ CROSS Fl W CHECK OB/04/09 OB/02/09 07/31/09 1 7 1 7 7 1 ~ P2-28 L-213 V-22/ AYTUA0051 B2WY-00019 AXB0.00037 INJECTION PROFILE C, -~ MEM INJECTION PROFI E' MEM INJECTION PROFILE " 08/01/09 07/29/09 07/28/09 1 1 7 ~ 1 1 L-220 07-22 04-02A B1JJ-00035 AZCM-00036 AYS4-00091 MEM INJECTION PROFILE PRODUCTION PROFILE - ° USIT ~ 07/30/09 08/09/09 08/11/09 1 1 1 1 1 1 J-11A L7-09 X•28 AWLB-00029 AYS4-00089 AXBD-00026 USIT - PRODU TION PROFILE '_(Jp MEM INJECTION PROFILE U' 08/OS/09 08/OB/09 05/17/09 1 1 1 1 1 1 L2-06 3-29/J•32 06-04A B3SQ-00020 AP30A0055 BSJN-00009 PRODUCTION PROFILE IBP SET RECORD W/CROSSGLOW , RST 08/14/09 08/OB/09 08/23l09 1 7 t~ 1 1 1 15-098 82NJ-00013 MCNL 07/15/09 1 1 03-328 09AKA0030 OH MW0/LWD EDIT 02/28/09 2 7 G448 AWJI-00043 MCNL 07/2M09 1 ~ L2-13A AWJI-00036 MCNL - O6/17/09 ~ 18•028 AWJI•00045 MCNI - V Q~ 08/77/09 1 1 P1-05 AWLB-00032 RST 08/09/09 1 1 B-16A B2WY-00020 MCNL ' - ' 08/03/09 1 1 J-20B AXBD-00020 MCNL (REVISED) .~ ;"~. OM72/09 ~ P1 FeCF e(`K~.Inwl Cnre oer e~or nv e~r_r.n~i r_ we~n o~r..e~.u.ir ....~ ........ ~..... ~.. 8P Exploration (qlaska) Inc. Pelmtechnical Data Center LR2-1 900 E. Benson Bivd. Alaska Data 8 Consulling Services 2525 Gambell Siree~, Suile 400 Anchorage,AK 99503-2838 •`.l >A". ~ /+~.i: h.Y r' wv' r .NU..,:t7' ,. ~ . ~ i ~ ~-~~ ~ ~~~l1~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 y~yt ; Anchorage,AK 99503-2838 ~;: ~ ~ . ~` ~' bt ~ ,. . ATTN: Beth . ~>`~.- °. ":"Y Well Job # Log Description Date 08/27/09 NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT ~- 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE C ~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK C 07/16/09 1 1 M-06A AZCM-00034 PRODUCTION LOG j' - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (a ~ 07/21/09 1 1 02-11A AYS4-00084 LDL - J 07/20/09 1 1 W-212 B3SQ-00011 INJ PROFILE W/WFL ' - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL p- 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -(X L 07/24/09 1 1 H-29A AYQQ-00027 RST '~ 05/19/09 1 03-28 B148-00067 RST j- 07/17/09 1 1 B-27A AXBD-00029 MCNL L. O6/12/09 1 1 C-15A AWJI-00038 MCNL - 06/25/09 1 1 Q-04A B1JJ-00023 MCNL ~ ' 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/08 1 1 07-066 AWJI-00042 MCNL 07/21/09 1 1 02-33B 09AKA0149 OH MWD/lWD EDIT L O6/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT ~ 05/12/09 1 1 H-19B B2WY-00004 MCNL (REPLACEMENT) - L 05/07/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ J ~J ~~ • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 25, 2009 7:57 AM To: 'Preble, Gary B (SAIC)' Subject: RE: L2-06 (183-047) Welcome back Gary. You can send the new perf sheet via email. Tom From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Tuesday, August 25, 2009 7:54 AM To: Maunder, Thomas E (DOA) Subject: RE: L2-06 (183-047) Tom, Good catch. I will redo the Perf Attachment sheet to show that the plug was pulled on the 5tn From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 19, 2009 4:15 PM To: Preble, Gary B (SAIC) Subject: L2-06 (183-047) Gary, I am reviewing the 404 for perforating and stimulating this well. On the perf sheet the last line is "BPS" at 8986 which occurred on 8/1. However it appears that the IBP was pulled on 8/5. The work on 8/6 was conducted deeper than the BP depth. Would you please reconcile? Message back with your findings and then we can discuss the paper necessary. Thanks, Tom Maunder, PE AOGCC .~_~,,,,. <<;,1~ '~ :. ~v~~;: ~-' g ,aci~ . t~~ ~,,. 8~25~2~~9 „ ~ STATE OF ALASKA ~ ALAS IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS ~~.~~~ ~~~..~ -~~ ~iJ ~~ ~ ? ~%f~~1~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q O~her. ~ Performed: Alter Casing ~ PuII Tubing ~ Perforate New Pool ~ Waiver~ Time ~ztens on~ ` °' °` ",~?;'` Change Approved Program ~ Operat. Shutdown ~ Perforate - Re-enter Suspended Well ~_` 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~lopment ~': Exploratory I~ 183-0470' 3. Address: P.O. Box 196612 Stratigraphic ~~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20930-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 51.5 KB L2-06' 8. Property Designation: 10. Fieid/Pool(s): _ ADLO-028321 PRUDHOE BAY Field/ LISBURNE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10301 - feet Plugs (measured) None true vertical 10298.7 feet Junk (measured) 9436' Effective Depth measured 9528 feet true vertical 9526 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20" SURFACE - 80 SURFACE - 80 1490 470 SURFACE 2654 13-3/8" 72# N-80 SURFACE - 2654 SURFACE - 2654 4930 4760 INTERMEDIATE 8076 9-5/8"47# N-80 SURFACE - 8076 SURFACE - 8075 6870 4760 LINER 1076 7-5/8" 33.3# S-95 7712 - 8788 7711 - 8787 LINER 1666 5" 18# S-140 8484 - 10150 8483 - 10148 INER TIE BACK 4731 7-5/8" 33.3# S-95 2974 - 7705 2974 - 7704 Perforation depth: Measured depth: SEE ATTACHED True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 8476' 0 0 - Packers and SSSV (type and measured depth) 7-5/8"X4-1/2" S3 PKR $398 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 735 5749 143 780 Subsequentto operation: 705 6267 158 296 14. Attachments: 15. Well Class after qroposed work: Copies of Logs and Surveys Run Exploratory lf~ Development ~- Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~- Gas I~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 8/11/2009 ,-, Form 10-404 Revised 04/2006 Submit Ori 'nal O~ y ~ ~~ . ~~ ~ ~~ ; <:~ ~~(?~; ~~~ ~~/l f~G3f ~2-fl6 '! 83-047 PERF ATTACHMENT • . Sw Name Operation Date Perf O eration Code Meas Depth Top Meas De fih gase 7vd Depth Top Tvd Depth Base ~2-06 6127/83 PER 10,020. 9 Q,038. 10,017.92 10,Q35.9'1 L2-06 6128183 SQZ 10,02Q. 10,038. 10,017.92 '~O,Q35.99 L2-06 7'13183 PER 8,930. 5,980. 9,927.58 9,977.95 L2-06 719183 SQZ 9,930. 8,580. 9~927.98 9,977.95 L2-06 7t'i0183 PE#2 9,628. 8,T30, 9,626.16 9,728.1'! L2-0$ 7/12!$3 St2Z 9,528. 8,730. 9,526.23 9,72$.19 L2-06 7l12/83 PER 9,204. 9,206. 9,202.59 9,204.58 L2-0S 7112I83 BFS 9,525. 10,150. 9,523.23 10,947.$4 L2-06 7/12183 PER 9,Q84. 9,086. 9,082.67 9,084.67 L2-06 7/13183 SQZ 9,204. 9,206. 9,202.59 9,2a4.58 L2-06 7114183 SQZ 9,052. 9,08fi. 9,O~Q.69 S,iI84.$7 L2-06 7117183 PER 9,918. 9,198. 9,1'~6.65 5,196.59 L2-06 7/25183 SQZ 8,988. 9,086, $,986.71 9,084.87 L2-06 7130183 PER $,996. 9,045. 8,994.T1 5,044.59 L2-06 812f83~ PER 8,864. 8,536. $,862.73 8,934.73 L2-06 816/83 PER 8,973. 8,983. $,971.72 8,981.71 L2-06 816183 PER 9,06Q. 9,081. 9,058.69 9,0T9,68 L2-06 816/83 PER 9,1fl0. 9,192. 3,098.66 9,110.65 L2-06 716108 RPF 8,118. 9,198. 9,116.65 9,196.59 L2-06 ?111/08 RPF 8,996. 9,Q46. 8,994.71 9,Q44.69 L.2-06 7111108 RPF 9,060. 9,080. 9,058.69 9,Q78.68 L2-06 7I11/08 RPF 9,90Q, 9,'~12. 9,08$.66 9,110.65 L2-06 7131109 Ai~F 8,973. 8,983: 8,974.72 8,9$1.71 L2-06 811109 BPS 8,986. / 9,002. 8,984,74 9,OOQ.71 L2-06 ( 815109 BPP 8,9$6. 9,OQ2. 8,98d.7'i 9,OQ0.7'[ AB ABANDONEp PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED S~ SLOTTEp LIl~ER BPS BRIQGE PLUG SET SPR SAN~ PLllG REMOVE~ ~CO FILI. CLEAW DUT SAS SAND PLUG SE"f FIL FILL SQF SQUEEZE FAILED M!R MECHANICAL 1SOLATED REMOVED SQZ SQU~EZE MIS MECHANICAL 1$OLAI'~D STC STRADDLE PACK, CLOSED MLK MECHANICAL L~AK ~ STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ U ~ ~ L2-06 183-047 PERF ATTACHMENT w Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L 6 6/27/83 PER 10,020. 10,038. 10,017.92 10,035.91 L2-0 6/28/83 SQZ 10,020. 10,038. 10,017.92 10,035.91 L2-06 7/3/83 PER 9,930. 9,980. 9,927.98 9,977.95 L2-06 7/9/83 SQZ 9,930. 9,980. 9,927.98 9,977.95 L2-06 7/10/83 PER 9,628. 9,730. 9,626.16 9,728.11 L2-06 7/12/83 SQZ 9,528. 9,730. 9,526.23 9,728.11 L2-06 2/83 PER 9,204. 9,206. 9,202.59 9,204.58 L2-06 7/1 3 BPS 9,525. 10,150. 9,523.23 10,147.84 L2-06 7/12/8 ER 9,084. 9,086. 9,082.67 9,084.67 L2-06 7/13/83 S 9,204. 9,206. 9,202.59 9,204.58 L2-06 7/14/83 SQZ 9,052. 9,086. 9,050.69 9,084.67 L2-06 7/17/83 PER 9,118. 9,198. 9,116.65 9,196.59 L2-06 7/25/83 SQZ 8,988. 9,086. 8,986.71 9,084.67 L2-06 7/30/83 PER 8,996. 9,046. 8,994.71 9,044.69 L2-06 8/2/83 PER 8,864. 8,936. 8,862.73 8,934.73 L2-06 8/6/83 PER 9,060. 9,081. 9,058.69 9,079.68 L2-06 8/6/83 PER 9,100. 9,112. 9,098.66 9,110.65 L2-06 8/6/83 PER 8,973. 8,983. 8,971.72 8,981.71 L2-06 7/6/08 RPF 9,118. 9,198. 9,116.65 9,196.59 L2-06 7/11/08 RPF 96. 9,046. 8,994.71 9,044.69 L2-06 7/11/08 RPF 9,0 . 9,080. 9,058.69 9,078.68 L2-06 7/11/08 RPF 9,100. 9,112. 9,098.66 9,110.65 L2-06 7/31/09 APF 8,973. 8,983. 8,971.72 8,981.71 L2-06 8/1/09 BPS 8,986. ~/ 9,002. 8,984.71 9,000.71 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVE FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQt1EEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~:~a~~~~~~~~~;> ~ ~~ sr~-~~~ ~ ~~~ ~~_. ~ i L2-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/31/2009E"""WELL FLOWING ON ARRIVAL*"* (ELINE ADPERF, CROSSFLOW CHECK, 'SET IBP) ;SSV=O,MV=O,WV=O,SV=C, IA/OA=OTG ~WELL SHUT-IN BY PAD OP LRS UNABLE TO CONNECT TO IA, CANCEL LOADING IA. ;LRS PUMPED 290 BBL CRUDE DOWN TUBING. T/I/O: 0/1500/0 ' PERFORATED 8973' TO 8983' (DEPTH REFERENCED TO SLB LONG SPACED gS0 GAMMA RAY, DATED 14-JUNE-1983) ;T/I/0: 290/1450/0 (TUBING PRESSURE IS SLOWLY INCREASING) ~LOG 40/80I120 UP/DOWN OVER THE INTERVAL 8800'-9120', !SPINNER/TEMP/PRESSURE/GRADIO TO CHECK FOR CROSS FLOW. ~STOP COUNTS TAKEN AT 8850', 8960', 8995', 9052'. CROSS FLOW DETECTED AND FLUID IS 0.3 GM/CC (GAS) AT IBP SET DEPTH. BLEED IA FROM 1450 PSI TO 580 PSI, DOWN FLOWLINE LRS PUMP 290 BBL CRUDE DOWN TUBING AFTER IA BLEED. ORDERING UP BOT CROSSFLOW IBP ;"*JOB IN PROGRESS, CONTINUED ON 1-AUG-2009**" - _ _-,_-----.~__ ____._.... -------------- ----_ __ ._. _--...______.____~_._------~___.. 7/31/2009~T/I/0=900/1620/20 Assist E-Line (Perforating) Loaded Tbg w/ 3 bbls methanol ¢spear, and 292 bbls Crude. FWP's = 0/1580/50 aTurn well back over to E-Line ***JOB CONTINUED FROM 31-JULY-2009*** (ELINE ADPERF, CROSS FLOW CHECK, SET IBP) LRS DONE PUMPING 290 BBL CRUDE DOWN TUBING. T/I/O = 0/580/0. LOGGED UP/DOWN PASSES AS WELL AS STOP COUNTSj DETECTED BAKER BROUGHT OUT RESERVOIR CROSSFLOW IBP. SET IBP AT 8986' MID ELEMENT DEPTH. FERENCED TO LONG SPACED SONIC GAMMA RAY LOG DATED 14-JUNE-1983. IBP DID NOT S RING. FISHING NECK = 1-3/8" JDC. IBP PINNED FOR 5500 POUNDS TO RELEASE. BAKER TO BRING EXACT TOOL DIAGRAM TO WELLS GROUP FOR FISHING INFORMATION. WELL LEFT SHUT-IN, SV = C, MV = O, WV = C, SSV = O, GV = O, AL LATTERAL = O, IA LG VALVE = C, OAV = O. FINAL PRESSURES = T/I/O: 1100/700/0 DSO NOTIFIED THAT WELL IS SHUT-IN AND SECURE AND OF VALVE PLACEMENT. **''JOB COMPLETE**" ~ • ~ 8/1/2009 ASRC Test Unit #3, Move Unit to location, Stand by for E-Line, Begin rig up, ~~~~ ~ ~ '`**Job in Pro ress*''* m ~ ~....___~._~ _ 8/2/2009 ~ ASRC Test Unit #3, Comlpete rig up, stand by for Acid Stim Ops. ***Job im ~ ~ Progress*** 8/3/2009 CTU #9 Job scope: Selective VDA SXEStim . MU/RIH w/ WOT MHA, IGS Data Coil Sub and Baker TEL w/ 3.4" JSN for drift. Make test TEL passes across ~ SSSV nipple @ 2122' @ 40 & 5 fpm. Got data @ 5 fpm. RIH. Make passes ~ across nipples in TT @ 20 fpm and 5 fpm. Got data @ 5 fpm. Correct +8'. ~~ ~~ ~~ ~ Continued on 08/04/09 WSR. , ` 8/3/2009 ~ ASRC Test Unit #3, Stand by for Acid Stim Ops. **"Job in Progress*** 8/4/2009~ ~ Continued from 08/03/09 WSR. «Interact Publishing»Coil 9 w/ 2" coil. Make ~ j ~ repeat TEL pass w/ corrected depth across nipples from 8455' to 8370'. Make ~ new depth correction of -6' to new reference log. Repeat pass, OK. Net depth ~ , shift was +2'. Drift hole to 8970'. Light tag on IBP. Flag coil @ 8930'/TEL. Test ~ IGS mem CCL and Real Time testing. POOH. MU/RIH w/ WOT 3 3/8" IRPP w/ ~ petredat gauges. Tie into corrected flag, set packer @ 8950'. Pump 6 stage job ~ w/ 45 bbl 15% HCL & 60 bbl 20% SXE acid. fireatin rate initiall was .3 b m € 3300 CTP final was 3.5 b m 3300 CTP. Pull release packer @ 8k# over. ~ ; Relax element. POOH. Packer not sheared. Appeared to roll off rubbers or ~ ~ ~ ~ shear @ 8865'. No problems at TT. Continue POOH. Continued on 08/05/09 ; ~~~~ 8/4/2009 WSR. ~ A~T t U it #3 i b i i **" *** ~ n es , Cont nue stand d St m, Job in Pro ress for Ac Y 9 l _.__. ~ 8/5/2009 Continued from 08/04/09 WSR. «Interact Publishing». POOH w/ WOT IRPP. ~ j All acker elements were recovered. Additional work to recover 3/4" aluminium ~ ~ ball. Petredat data is good. Max treating BHP was 4370 psi. RIH fish IBP latch ~ ~ IBP pull free and let IBP deflate for 40 mins. POOH with IBP recovered IB , t e ~ ~ packer elements were stripped off. Lay down IBP. MU & RIH 3 1/8" Venturi ~ basket. ~ ~ ? 1 ~ """`Job Continued on 08/06/09**"" ! ~ ~ ~~ 8/5/2009 i ~ ASRC Test Unit #3, Stand by for Acid Stim ops., "*"Job in Progress*** ~ ` 8/6/2009 Continued from 08/05/09 WSR. «Interact Publishing» RIH w Venturri, Venturi j ~ ` from Tubing tail to 9300'. POOH, Lay down venturi, recover middle packer ring ' ~ and -1 quart of of cement chunks, MU& RIH 3 3/8" WFR IRRP with Petradat ~ ~ gauges below, RIH w/ WFD packer set at 9094' , Pumped 70 bbls of 15% VDA ~ acid 210 bbls 20% SXE acid 130 bbls fo 15% HCL 91 bbls of 2% KCL + F103 + U67 160 bbls of 2% KCL + F103. Pull to 40K & released packer let deflate for 30 = ~ i mins POOH. """""Job is complete""""" ~ ; ! i i ~ I ~ 8/6/2009g ~ ASRC Test Unit #3, begin flow back, ***Job in Progress*** ~ j ~_. _ .~ ..~ ; 8/7/2009 ASRC Test Unit #3, Continue flowback, *""Job in Progress*** ~ ~ _._ . ~ 8/8/2009 ' _ _ ~_.___ _.___.. .~ ___~ . ~ . _ __._ ___ ~__ W ~ ASRC Test Unit #3, Start 12 hour test, **''Job in Progress*** ~ -__ ~~ ~ ~ 8/9/2009~ASRC Test Unit #3, End 12 hour test, Begin rig down, ***Job in Progress**" FLUIDS PUMPED BBLS 1 DIESEL 9 METH 3 60/40 METH 160 2% KCL W/0.6% SAFELUBE 70 15% VDA ACID 210 20% SXE ACID 130 15% HCL ACID 91 2% KCL+F-103+U67 160 2% KCL+ F103 139 2% KCL 973 TOTAL ~, STATE OF ALASKA ~~ ~" ~~'1 ALASKA OIL AND GAS CONSERVATION COMN~ON `1(,1;x. REPORT OF SUNDRY WELL OPERATIONS ~~~~~.~, ~.. ~ ~ 20t;~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other -~ t:r,-~ ~,, Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ f.: ', f`O Change Approved Program [] Operat. Shutdown Perforate ~ ~ Re-enter Suspended Well ~ 4 ,;'~ ~~'/~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Deveiopment - Exploratory ~' 183-0470 3. Address: P.O. Box 196612 Stratigraphic SerwCe L~' 6. API Number: Anchorage, AK 99519-6612 50-029-20930-00-00 7. KB Elevation (ft): 9. Well Name and Number: 51.5 KB L2-06 8. Property Designation: 10. Field/Pool(s): ADLO-028321 ~ PRUDHOE BAY Field/ LISBURNE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10301 ~ feet Plugs (measured) None true vertical 10298.7 ~ feet Junk (measured) 9436' Effective Depth measured 9528 feet true vertical 9526 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" SURFACE - 80 SURFACE - 80 1490 470 SURFACE 2654 13-3/8" 72# N-80 SURFACE - 2654 SURFACE - 2654 4930 4760 INTERMEDIATE 8076 9-5/8"47# N-80 SURFACE - 8076 SURFACE - 8075 6870 4760 LINER 1076 7-5/8" 33.3# S-95 7712 - 8788 7711 - 8787 LINER 1666 5" 18# S-140 8484 - 10150 8483 - 10148 INER TIE BACK 4731 7-5/8" 33.3# S-95 2974 - 7705 2974 - 7704 Perforation depth: Measured depth: SEE ATTACHED True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 8476' 0 0 - Packers and SSSV (type and measured depth) 7-5/8"X4-1/2" S3 PKR 8398 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~ii ~rl~~~ ~~~ ~ ~ ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 816 1760 124 530 Subsequent to operation: 806 1888 129 530 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development ,, Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG fi' GINJ ~' WINJ ' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 7/15/2008 /'q, ~ ~ ~ ~ f M ~ - `~~> `~ 9 1~~~ Submit Original Only .,~ Form 10-404 Revised 04/2006 f [ t ~ ~, ~a !. ~jt L2-06 183-0470 PERF ATTACHMENT ;~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L2-06 6/27/83 PER 10,020. 10,038. 10,017.92 10,035.91 L2-06 6/28/83 SQZ 10,020. 10,038. 10,017.92 10,035.91 L2-06 7/3/83 PER 9,930. 9,980. 9,927.98 9,977.95 L2-06 7/9/83 SQZ 9,930. 9,980. 9,927.98 9,977.95 L2-06 7/10/83 PER 9,628. 9,730. 9,626.16 9,728.11 L2-06 7/12/83 BPS 9,525. 10,150. 9,523.23 10,147.84 L2-06 7/12/83 PER 9,084. 9,086. 9,082.67 9,084.67 L2-06 7/12/83 PER 9,204. 9,206. 9,202.59 9,204.58 L2-06 7/12/83 SQZ 9,528. _ 9,730. 9,526.23 9,728.11 L2-06 7/13/83 _ SQZ 9,204. 9,206. 9,202.59 9,204.58 L2-06 7/14/83 SQZ 9,052. 9,086. 9,050.69 9,084.67 L2-06 7/17/83 PER 9,118. 9,198. 9,116.65 9,196.59 L2-06 7/25/83 SQZ 8,988. 9,086. 8,986.71 9,084.67 L2-06 7/30/83 PER 8,996. 9,046. 8,994.71 9,044.69 L2-06 8/2/83 PER 8,864. 8,936. 8,862.73 8,934.73 L2-06 8/6/83 PER 8,973. 8,983. 8,971.72 8,981.71 L2-06 8/6/83 PER 9,060. 9,081. 9,058.69 9,079.68 L2-06 8/6/83 PER 9,100. 9,112. 9,098.66 9,110.65 L2-06 7/6/08 APF 9,118. 9,198. 9,116.65 9,196.59 L2-06 7/11/08 APF 8,996. 9,046. 8,994.71 9,044.69 L2-06 7/11/08 APF 9,060. 9,080. 9,058.69 9,078.68 L2-06 7/11/08 APF 9,100. 9,112. 9,098.66 9,110.65 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL_ FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED _ SQZ SQUEEZE MIS MECHANICAL ISOLATED STC _ STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • L2-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY C ACTIVITYDATE SUMMARY' 7/6/2008' "**WELL SHUT IN*** : INITIAL T/I/O = 1200/1250/0 PSI. RIG UP E-LINE FOR PERFORATING 4 : ZONES WITH 3.5" PJ OMEGAS 3506 ,PEN = 44.2" EH= 0.44" : PERFORM EMERGENCY EVACUATION DRILL WITH DSO, AND ' COMPANY REP. ' RUN 1 INTERVAL 9168'-9198', RUN 2 INTERVA,~ 1'~8=-9168'- RUN 3 INTERVAL~118'-9138', MISFIRE ON RUN 3, POOH, CHANGE ', ' DETONATOR, RIH AND SHOOT INTERVAL 3. ' PULLED 800 LBS OVER TN WHILE PULLING OUT OF HOLE WITH RUN 3, MSOP = 900 TN= 1700, PULLED 2500 MAX AND HELD TENSION. ' UNINTENTIONALLY J'ULLED OFF OF WEAKPOINT AT 8405' CCL DEPTH ' AFTER HOLDING TENSION, PROBABLE STUCK IN X-NIP AT 8422', '', ' ID=3.813. FISHING NECK = 1 3/8", OVERALL TOOL LENGTH = 29', TOOL ' STRING WEIGHT IN FLUID = 500 LBS, TOOL STRING WEIGHT IN AIR = : 570 LBS. MAX SWELL OF 20' 3.5" OD PERFORATING GUN = 3.72" WHEN SHOT IN FLUID. "**JOB CONTINUED ON 7-JULY-08*"* _ _ 7/6/2008' T/I/0= 1300/1320/0 Temp= S/I Assist E-line (perforating) *** Job : continued on 07-07-08 WSR*** 7/7/2008 *** *** ped ~~~Job continued~from 07-06-08 ~WSR Assist E-line (Perforating) Pum 2 bbls meth and 74 bbls crude down Tbg to knock down wellhead pressure. FWHPs= 0/1380/0 Valve positions at time of departure; Swab closed, wing closed, SSV open, master open, IA open, OA open. __ _ ..-_--- -_._.... .. 7/7/2008 .._ ..._... . ....... _ .... _ _~~ .__...z ~_~. ~-..... _~ _ _ ~ _ .... """JOB CONTINUED FROM 6-JULY-08"`'` '.. CONTINUE POOH, LRS START PUMPING TO KILL WELL, PUMP 13 BBLS ' AND WAIT 30MIN BEFORE BLEEDING TO TRY AND BLEED GAS, ' DURING BLEEDING THERE WERE FLUID RETURNS -WELL IS FLUID ', ' PACKED, PUMP 7366LS TO GET OPSI ON TUBING. POOH RIG DOWN ' AND LEAVE LOCATION. WILL RETURN AFTER SL FISHES GUN TO ' COMPLETE PERFORATING. FINAL T/I/O = 0/1300/0 ***JOB INCOMPLETE""' _ 7/8/2008 ***WELL S/I ON ARRIVAL*** RAN 4.5 GR W/ BOWEN OVER SHOT 3.70 OD, 2' 5" OAL, PLANT OVER : SHOT ON E-FISH /PERF GUNS, UNABLR TO PULL FISH. RAN 3.75 CENT, W/ 2' 1 7/8, 2" BLIND BOX PUSHED E-LINE FISH TO 9382'SLM. ,OPEN PERF @ 9198' MD (have to bring in braided line} *"*NOTIFIED DSO OF WELL STATUS, LEFT TAG ON MASTER D-GUN IN ' HOLE*'`" ~J 7/9/2008' """WELL S/I ON ARRIVAL "`* (fish a-line toolstring /perf gun) LRS LOADED TBG. 'CURRENTLY IN THE PROCESS OF RIGGING UP BRAIDED LINE. "** CONT JOB ON 07/10/08 WSR **" 7/9/2008 T/I/0=1500/1300/0 Assist SLB w. TBG load. (Perforating) Pumped 5 bbls :60/40 meth followed by 274 bbls crude, 5 bbls diesel down TBG to Load. '*"Annulus casing valves open to gauges, tags hung S/L in control of well on :departure**" FW P's=vac/1260/0 7/10/2008''`*'`WELL SHUT-IN ON ARRIVAL\"`' (E-LINE PERFORATIONS). INITIAL T/I/O: 100/1120/0. RIG UP E-LINE. ***JOB IN PROGRESS AND CONTINUED ON 11-JULY-2008 WSR*** 7/10/2008 `** CONT FROM 07/09/08 WSR *""` (fish perf gun) LATCH FISH AT 9344' BLM AND PUH TO X-NIPPLE AT 8378' MD AND ''ATTEMPT TO JAR FISH THROUGH X-NIPPLE. CAME FREE DUE TO OJ'S HAVING STRIPPED OFF. RIH AND JAR ON FISH 8353' BLM FOR 45 MIN AND SHEARED TOOL. DRIFT WITH 10' x 3-3/8" DUMMY GUN TO TOP OF FISH AT 9340' BLM. *** LEFT WELL S/I. TURNED WELL OVER TO DSO'`** 7/11 /2008 '`'`'`*JOB CONTINUED FROM 10-JULY-2008*""* (E-LINE PERFORATIONS). INITIAL T/IA/OA: 1500/1120/0. ALL GUNS WERE 3-3/8" PJ 3406 HMX, 6- SPF, 60 DEG PHASING. PERFORATED INTERVALS: 9100'-9112', 9060'-9080', 8996'-9046'. API DATA: PENETRATION = 36.5", EH = 0.37" FINAL T/I/O = 1700/1100/50 PSI. INFORMED DSO WELL IS READY TO POP. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 Total 06/27/08 ~I~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wou . i„ti ~ i .... nee.. ..~:.... ~~~~`~7 n... m NO.4763 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 N-04A 11962603 ~.,.r;._.. ~C~`~ •T~., PRODUCTION PROFILE ~"~-_~_ 06/23/08 1 1 L2-06 11999020 PRODUCTION PROFILE ~~. ~ ._ r. ~ °;~- rt- f; -,?~, 06/15/08 1 1 L3-31 12005214 MEMORYSBHP -to-~. ,-,,~~q ~¢!.~"as=9ri 06/11/08 1 1 C-02 11982437 PRODUCTION PROFILE 1`~r ~-_ - "'/' + ~ ~°'"~~'~'/"~, 06/20/08 1 1 E-39A 12066529 SCMT =./e~~ -- ~~'~ ~ ~~~ ~°''°A 06/19/08 1 1 MPC-09 12005215 MEM PROD PROFILE ;'~~~ ~°°•~`"^'~~, ;~°~~~~~'`~ 06/12/08 1 1 W-31 12014027 LDL /~a~sr ••- ~~-~' ~ ~'-"- ~~ `=~ 06/15/08 1 1 02-04A 11962602 USIT r°%~` :°' - ~ ? ~ ° r: -E". r~ (:? 06/22/08 1 1 02-04A 12086662 USIT '~`y^`~- `-~'~ r` r ~~ - ; a, r' e_~..,~ _s 06/20/08 1 1 r...~...a~.~v n~~v rr a,cvaa~n~...ur~ o^ a1~a1v11vV NIYV 1'iC1 Y171VIIVl7 VIYC liV 1'T CAIiA 1V: BP Exploration (Alaska) Inc. ' " Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 +~ 1i iC Date Delivered: Alaska Data & Consulting Services r" 2525 Gambell Street, Suite 400' I Anchorage, AK 99,503-2838 :% ATTN: Beth 1~ j 1 .I i i Received by: ~ - • r~ L J ~~~;~ v t ~ STATE OF ALASKA °~'~Ol~ `~ ~'~ ALASKA OIL AND GAS CONSERVATION COM~ION FED ~' ~' ~~~~ t %'~~~~''~' REPORT OF SUNDRY WELL OPERATIONS leaks Oil & Gas Gon~Y ~t~a~~~fl Anl:horet»~ 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension - 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 183-047 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20930-00-00 - 7. KB Elevation (ft): 51.5' i 9• Well Name and Number: P BU L2-06 8. Property Designation: 10. Field /Pool(s): ADL 028321 ' Prudhoe Bay Field !Lisburne Pool 11. Present well condition summary Total depth: measured 10301 ~ feet true vertical 10299 ' feet Plugs (measured) None Effective depth: measured 9528 feet Junk (measured) 9436 true vertical 9526 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2654' 13-3/8" 2654' 2654' 4930 2670 Intermediate 8076' 9-5/8" 8076' 8075' 6870 4760 Production Liner 1076' 7-5/8" 7712' - 8788' 7711' - 8787' Liner 1666' 5" 8484' - 10150' 8483' - 10148' Liner Tieback 4731' 7-518" 2974' - 7705' 74' - 7704' ~,-~- FED ~ ~ 20~f} Perforation Depth MD (ft): 8864' - 9198' Perforation Depth TVD (ft): 8863' - 9197' 4-1/2", 12.6# 13Cr80 8476' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker'S-3' packer 8398' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut & Pull Tubing. Run 7-5l8" Tieback. Cement 7-5l8" Tieback w/ 98 Bbls Class'G' (550 cu ft / 474 sx). Clean out and run 4-1/2" Tubin . 13. Re resentative Dail Avers a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 908 78 1056 2050 700 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 308-002 Printed Name Terrie Hubble Title Grilling Technologist S f1 Q Prepared By Name/Number: Z ~ ignatur ~ Ej4-4628 Date aTerrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~d,.g~~~~sr ~~~ F~IS ~ ~' ~~~~ Submit Original Only 1~1.11~1~1j~~ • Page 1 of 1 . Well History Welt Date Summary L2-06 12/5/2007 *** CONTINUE FROM 4 DEC 2007 *** INITIAL WHP: 600/500/0 SH T 2.5"JET CUTTER AT 8370' IN FIRST FULL JOINT ABOVE PACKER AT 8420'. CUT DEPTH WAS CHANGED TO 8370' TO AV I KINLEY BUTTONS IN 3 1/2" TUBING AROUND CUT DEPTH. TAGGED TD AT 8431'. WELL LEFT SHUT IN. *****JOB COMPLETE***** FINAL WHP: 600/500/0 L2-06 12/5/2007 *** CONTINUE FROM 4 DEC 2007***INITIAL WHP: 600/500/0 JET CUT 3 1/2" TBG AT 8,370' IN FIRST FULL JOINT ABOVE PACKER. TIE-INTO TUBING TALLY DATED 8-07-83. CUT DEPTH WAS CHANGED AS PER APE AND FIELD PE TO LEAVE ~9' STEM OF 3- 1/2" TUBING. CUT ~ 8,370' WAS ABOVE LOWER KINLEY BUTTON AT 8,379'. WELL LEFT SHUT IN. FINAL WHP: 600/500/0 '**JOB COMPLETE*'* L2-06 12/30/2007 ***WELL S/I ON ARRIVAL*** (PRE-RWO) MIRU SWCP DC#3 TO SET TRSV HOLD OPEN SLEEVE. ***CONTINUED ON WSR 12-31-07*** L2-06 12/31/2007 ***CONTINUED FROM WSR 12/30/07*** (PRE-RWO) DRIFTED TO SSSV @ 2126' MD W/ 2.84" NO-GO CENT SET TRDP-1A HOLD OPEN SLEEVE ON 3-1/2" CR LOCK AT 2126'MD. PULL W/ 3-1/2" GS /SERIAL # 30005, MIN ID 1.75", OAL 119". ***WELL LEFT S/I, DSO NOTIFIED OF STATUS*** L2-06 1/3/2008 T/I/0=420/140/0 Circ out (Rwo Prep) Pumped 5 bbl meth spear, 150 bbls 9.8 brine down tbg taking returs up IA to open top tanks. Continued on 01-04-08 L2-06 1(4/2008 Continued from 01-03-08 WSR Circ-Out Pumped 250 bbls 9.8 Brine down tbg taking returns up IA to opentop tank. Shut in returns, Bullheaded 125 bbls down tbg at 5 bpm 1500 psi., for a total of 375 bbls 9.8# brine pumped down tbg.freeze protected w/ 8 bbls diesel RU to IA, Bullheaded 509 bbls 9.8# Brine down IA, freeze protected w/32 bbls Diesel MIT-OA PASSED to 1000 si. Pumped 2.3 bbls diesel down OA to pressure to 1000 psi. On 4th attempt OA lost 20 psi in 1st 15 min. A lost 20 psi in 2nd 15 min. Bled OAP to 0 psi, all fluid (-2 bbls). Bled TP to 0 psi, all fluid <1 bbl. Verify casing valves open to gauges, tag well & notify operator. Final W H P's=0/0/0 L2-06 1/5/2008 T=0 Set Gray 5-1/8" "K" type BPV (Pre-rig 4ES) 1-2' ext. used; tagged @ 108'; Good set ***Complete*** (Best/Wortham) Print Date: 2/21/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WI Info/Reports/ReportViewer.aspx 2/21/2008 • L2-06 L2-06 Spud Date: 1/3/2008 WORKOVER Start: 11312008 End: 1/26/2008 NABORS ALASKA DRILLING I Rig Release: 1/26/2008 NABORS 4ES Rig Number: BP EXPLORATION Page 1 of 12 ~ Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To j Hours ~ Task i Code NPT Phase ~~ Description of Operations 1/6/2008 02:00 - 06:00 4.00 RIGD N WAIT 06:00 - 07:30 1.50 MOB N WAIT 07:30 - 09:00 1.50 MOB P 09:00 - 10:30 1.50 MOB P 10:30 - 12:00 1.50 MOB N WAIT 12:00 - 15:00 3.00 MOB P 15:00 - 16:00 1.00 RIGU P 16:00 - 17:00 1.00 RIGU P 17:00 - 18:00 1.00 RIGU P 18:00 - 20:00 2.00 RIGU P 20:00 - 22:00 2.00 RIGU P 22:00 - 23:00 1.00 RIGU P 23:00 - 00:00 1.00 PULL N WAIT 1/7/2008 00:00 - 02:00 2.00 PULL N WAIT 02:00 - 04:00 2.00 PULL P 04:00 - 06:00 2.00 PULL i N 06:00 - 06:30 i 0.50 ~ PULL ~ P 06:30 - 09:30 3.00 KILL P 09:30 - 10:00 0.50 KILL P 10:00 - 11:00 1.00 WHSUR P 11:00 - 13:30 I 2.501 WHSUR I P PRE R/D rig & equip. Waiting on trucks to move rig. PRE Wait on rig move & for trucks PRE Scope down & lower derrick. PRE Move rig off well L1-31. P/U rig mats & herculite. Clean location. PRE Wait on security to escort rig move. PRE Move rig sub & pipe shed from L1-31 to L2-06. Move was ~7 miles. PRE Spot rig sub over well. Spot in pipe shed. Begin R/U equip. PRE Raise derrick. Con't to R/U equip. PRE Move camp & pits from L1-31 to L2-06. Spot camp & pits. PRE Crew change. PJSM. Scope up derrick. Con't to R/U equip. DECOMP R/U lines to tree & install 2nd annulus valve. Take on 9.8 ppg brine. Accepted rig C~ 2000 hrs. DECOMP R/U Hi-Pressure lines to tiger tank and adjust berm. DECOMP Wait on DSM to bring lubricator to pull BPV DECOMP Con't to wait on DSM with lubricator. DECOMP PJSM with Cameron and Well Support crew. P/U and M/U lubricator & tested to 2000 psi. Pull BPV and UD lubricator. RREP DECOMP PSJM Test lines 250/3500 psi for displaceing well -Waiting on #2 Cat, Generator is down. DECOMP Crew change. Service rig. Check PVT alarms -PVT system down. Inspect derrick. DECOMP SITP = 0 psi, SICP =Vacuum. Open well & circulate out diesel freeze protection. Pump 4 BPM ~ 860 psi, Pressure dropped to 640 psi C~ end of circulation. Annulus pressure went from 0 to 230 to 60 psi. Pumped total of 625 bbls. No noticible gas. Recovered - 6 bbls of diesel. S/D pump, TP & CP dropped to 0 psi. Lost 34 bbls during circulation. DECOMP Monitor well. Well Dead, tubing & annulus on s ig vacuum. DECOMP M/U 5" "K" plug on lubricator & install in hanger. UD lubricator. P/U T-bar & install Blanking plug in "K" plug. UD T-bar. DECOMP Pressure test "blanked off "K" plung from top W/ 3500 psi for 30 min, Test OK. Pressure up & test plug from below by pumping in annulus ~ 3 BPM for 30 min. Final injection 13:30 - 14:30 1.00 WHSUR P 01:30 - 17:00 15.50 WHSUR P 17:00 - 18:00 18:00 - 00:00 1/8/2008 00:00 - 00:30 00:30 - 08:30 08:30 - 09:30 09:30 - i 1:00 11:00 - 12:00 1.00 WHSUR P 6.00 BOPSU P 0.50 BOPSU P 8.00 BOPSU P 1.00 BOPSU P 1.50 WHSUR P 1.00 PULL P pressure 800 psi. Pumped total of 103 bbls. Bled off annulus & got back 4 bbls. DECOMP R/D test equip. Blow down lines. Drain tree. DECOMP Bleed off hanger void. N/D tree & adapter flange. Remove tree & adapter from cellar. M/U 5 7/8" ACME X-Over into top hanger threads, 19 turns. Threads look good. DECOMP Raise rig and pipe shed to acommadate adding a test spool below BOP'S .Measure 4 es RKB, 19.45'. DECOMP PJSM. N!U BOPE, test spool and change rams to 3 1/2" X 6" VBR. M/U test joint. DECOMP Set test plug DECOMP Test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by John Crisp w/ AOGCG. Tested rams & annular w13 112 & 5 112" test jts. DECOMP R/D test equip. Blow down & set back kelly. Drain BOP stack. DECOMP P/U T-bar pull test dart & UD same. P/U lubricator & test to 500 psi. Pull "K" plug. UD plug & lubricator. DECOMP P/U & M/U X-overs & landing jt into hanger. P/U & attempt to Printed: 214/2008 11:20:55 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: L2-06 Common Well Name: L2-06 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To Hours Task ~ Code NPT 1/8/2008 111:00 - 12:00 I 1.001 PULL I P 12:00 - 13:00 1.00 PULL P 13:00 - 15:30 2.50 PULL P 15:30 - 20:00 I 4.501 PULL I P Start: 1 /3/2008 Rig Release: 1/26/2008 Rig Number: Page 2 of 12 Spud Date: 1 /3/2008 End: 1 /26/2008 Phase Description of Operations DECOMP pull hanger free. (String wt = 67K + 12K blocks) Worked up to 150K. ~70K overpull. No success. M/U heat blanket around wellhead & apply steam. Lock down brake w/ 150K. After 15 min hanger came free. Work hanger up thru stack & pull to floor w/ 78K. DECOMP Break out, L/D hanger & landing jt. R/U circulating pin. DECOMP Circulate bottoms up. Pump 4 BPM C~ 420 psi. Took 19 bbls to fill hole & break circulation. No aas noticed durina circulation. Pumped total of 540 bbls. DECOMP POH L/D 3-1/2" completion tubing and control line. 66 jts. tubing laid down. (-6927). Recovered SSSV. 20:00 - 20:30 0.50 PULL P DECOMP R/D control line spooler. Recovered 37 SS bands. 20:30 - 00:00 3.50 PULL P DECOMP Con't POH L/D 3-1/2" completion tubing. Pitting in PIN /BOX start C~ Jt # 84(6265' ) 1/9/2008 00:00 - 04:30 4.50 PULL P DECOMP Con't to POH L/D 3-1/2" completion.Thin layer of scale coating on entire joint with minor Pin /Box pitting Starting at jt# 95 (-5975). Jt #264 cut C~? 10' 04:30 - 05:00 0.50 PULL P DECOMP Clean & clear rig floor 05:00 - 05:30 0.50 PULL P DECOMP Load BHA in pipe shed and SLM, Install short wear bushing ID= 05:30 - 06:00 0.50 PULL P DECOMP Pre-tour HSE meeting with day crew. PJSM -PUMU BHA. 06:00 - 06:45 0.75 FISH P DECOMP Service rig: Grease drawworks & blocks, check PVT alarms & derrick inspection. 06:45 - 09:30 2.75 FISH P DECOMP Install wear bushing - ID = 8.875". PUMU BHA #1 as follows: 6-1/2" OS guide, 5-3/4" HMC, 5-3/4" O/S, 5-3/4" O/S Extension, O/S Top Sub, 4-3/4" LBS, 4-3/4" Oil Jar, 9' 4-3/4" DC's, 4-3/4" Intensifier, 4-3/4" POS. Steamed each connection to thaw and ensure good makeup torque achieved. Pipeshed heater inoperable. 09:30 - 17:00 7.50 FISH P DECOMP RIH w/BHA #1 on 3-1/2" DP 1 x 1 from Pipeshed. Pipeshed heater returned to service C«~ 14:00-hrs. Tag C~ 8348'. 17:00 - 18:00 1.00 FISH P DECOMP Kelly up, establish milling parameters and break circulation C~ 4.0-BPM C~2 650-PSI. PUW = 126K, SOW = 130K, Free Trk = 2500 ft.-Ibs. Mill off top of bell on tubing stub. 18:00 - 19:00 1.00 FISH P DECOMP Tagging hard C~ 8348'. Rotate & wash down 3' in 1' intervals checking P/U wts. On third foot took 2K weight & pump pressure increased to 750 psi. S/D & P/U w/ 20K & bleed jars. Pull 50K over fish en a ed. S/O & had down ward movement of 8' (Travel jt closing?). P/U 50K over & fire jars. Con't to P/U 75K over & fish is moving. Wait 5 min & allow rubbbers to relax. Work pipe up & down, have drag. Blow down & set back kelly. L/D 2 singles, fish swabbing slightly. Drop ball & open pump out sub w/ 2500 psi. 19:00 - 21:00 2.00 FISH P DECOMP Circulate bottoms up 4 BPM ~ 800 psi. Pumped total of 550 bbls. No pas observed while cirulating. No losses & No gains during circulation. 21:00 - 23:00 2.00 FISH P DECOMP UD 1 single. POOH idle speed. Fish wanting to swab. Pulled total of 4 stands & double when hole started to take fluid. Pulled remainder of stand + 1 more & drag fell off & fluid level went south. Attempt to fill hole w/ 50 bbls, no good. 23:00 - 00:00 1.00 FISH P DECOMP Con't to pull out of hole & stand back 3 1/2" DP. Ind hole on continuous fill until 200 bbls gone. Then started filling hole w/ pipe displacement + 10 bbls every 5 stands. Printed: 2/4/2008 11:20:55 AM • BP EXPLORATION Operations Summary Report 'Legal Well Name: L2-06 (Common Well Name: L2-06 Event Name: WORKOVER Start: (Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: Date ~ From - To I; Hours !. Task ~ Code NPT I Phase 1/10/2008 00:00 - 02:30 ~ 02:30 - 03:30 03:30 - 05:30 05:30 - 06:00 06:00 - 10:30 10:30 - 12:00 12:00 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 21:00 21:00 - 23:30 1 /3/2008 1 /26/2008 Page 3 of 12 Spud Date: 1/3/2008 End: 1/26/2008 Description of Operations 2.50 FISH P DECOMP Con't to POOH & stand back 3 1/2" DP. Filling hole w/ pipe displacement +10 bbls every 5 stands. 1.00 FISH P DECOMP POOH & stand back DCs._Pull fish thru floor. Have 100% recovery. Break out & UD BHA. 2.00 FISH P DECOMP Break out & UD fish. Having to punch tubing & check for trapped gas. Fish was plugged w/debris, (Waited on SWS Hot Tap equip for 1 hr.) Recovered Cut Off Jt, Pup Jt, Expansion jt, Baker FHL Packer, XO, Pup Jt, XO, Landing nipple w/ Plug. 0.501 FISH I P 4.501 FISH I P 1.501 CLEAN I P 3.00 ~ CLEAN P 1.001 CLEAN I P 0.50 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 2.50 CLEAN P 2.50 CLEAN P 23:30 - 00:00 0.50 CLEAN P 1!11/2008 00:00 - 00:30 0.50 DHB P 00:30 - 04:00 3.50 DHB P 04:00 - 04:30 0.50 DHB P 04:30 - 06:00 I 1.501 DHB I P 06:00 - 11:00 I 5.001 DHB I P DECOMP Pre-tour HSE meeting; Discussed plan forward, reviewed tripping in hole with DP procedure and tasks assigned to each individual on crew. DECOMP Service rig: Grease drawworks, blocks and crown. Check PVT's and general HSE walkaround. Cllear and clean rig floor. DECOMP Reconfigure BHA to include 7-5/8" scraper. PMUM &RIH w/BHA #2 as follows: 3-1/2" muleshoe, 3-1/2" pup jt., XO, 7-5/8" scraper, 2 ` 4-3/4 boot baskets, XO, 6 jts. of 3-1/2" DP, XO, 9-5/8" casing scraper, 2' 7" boot baskets, XO, 4-3/4" LBS, 4-3/4" oil jar and 9 ' 4-3/4" DC's. DECOMP RIH w/BHA #2 on 3-1/2" DP from derrick. Filling hole with 10-Bbls. 9.8-ppg brine every 5 stands RIH. unable to keep Tagged top of 7-5/8" liner ~ 7705' DPM with 9-5/8" casing scraper. Ran 7-5/8" casing scraper to 7875'. DECOMP Make up circulating pin and break circulation at 4.5-BPM C~3 150-PSI. Pumped away 87-Bbls. trying to obtain returns. No returns noted. Shut down pumping. DECOMP Blew down lines and prepare to POH w/BHA #2. DECOMP POH w/BHA #2 standing DP in derrick. DECOMP Crew change. Inspect derrick. Check PVT alarms. DECOMP Con't to POOH & stand back 3 1/2" DP. DECOMP BD/LD BHA #2. & 7" boot baskets recovered 5 gallons of loose scale. 4 3/4" baskets recovered 2 gallons of loose scale. 9 518" & 7 5/8" scrapers in good condition w! no damage. DECOMP Clear & clean rig floor. TIEBi PJSM. PU/MU HES 7 518" RBP & running tool... TIEB1 RIH w/ 7 5/8" RBP, (9) 4 3/4" drill collars on 3 1/2" DP. TIE61 Set 7 518" R8P ~ 7808' DPM. P/U weight = 126K. Sl0 weight = 125K. Set down on plug 16K and overpulled 5K to confirm set. lop of FN ~ 7804' DPM. TIE61 P/U off RBP. Fill hole w/ 9.8 brine @ 4 1/2 BPM ~ 150-200 psi. Pumped away -447-Bbls. brine trying to fill hole. TIEB1 Troubleshooting inability to fill hole. Shot sonic fluid level C~ 2580 ffs. Waited 30 minutes and shot sonic fluid level at 2664 ffs. pumped 75-bbls. brine in well. Waited 30 minutes for fluid to fall and stabilize. Shot sonic fluid level C~3 2564 ffs. Waited 30 minutes and shot last sonic fluid level at 2622 ffs. Static fluid level is at -2600 ffs. 11:00 - 11:45 0.75 DHB P TIE61 Release RBP. POH UD one jt. 3-1/2" DP. Reset RBP at 7774' with running tool engaged and 15K downweight on RBP. 11:45 - 13:00 1.25 DHB P TIEB1 Pump 4.5-BPM ~ 150-PSI to fill hole. Obtained returns with 183-Bbls. pumped. S/D pump and observe well. Fluid falling awa .Close annular preventer. Pump down DP ~ 3.0-BPM with a starting pressure of 117-PSI and a final DP pressure of Printed: 2/4/2008 11:20:55 AM • BP EXPLORATION Page 4 of 12 I Operations Summary Report Legal Well Name: L2-Oli Common Well Name: L2-06 Spud Date: 1/3/2008 Event Name: WORKOVER Start: 1/3/2008 End: 1/26/2008 Contractor Name: NABOBS ALAS KA DRILLING I Rig Re{ease: 1/26/2008 Rig Name: NABOBS 4ES Rig Number: Date I From - To II Hours ~ Task I Code NPT I Phase ~~ Description of Operations 1/11/2008 11:45 - 13:00 1.25 DHB P TIE61 700-PSI with 250-PSI on IA. Pumped away 59-bbls. Charted infectivity test. 13:00 - 14:00 1.00 DHB P TIEBi POH UD 2 jts. DP. Rig up sand hopper. 14:00 - 16:00 2.00 DHB P TIEB1 Dump 1300# (26 sks.) of 20/40 sand down DP to too of RBP usin sand ho er. Allow sand to settle for one hour. 16:00 - 16:30 0.50 DHB P TIEB1 PU RIH w/1 jt. DP and tag TOS C~? 7720'. 16:30 - 21:00 4.50 DHB P TIE61 POH w/RBP running tool standing DP in derrick. . 21:00 - 21:30 0.50 DHB P TIEB1 Set back 4 3/4" DCs. Break out & UD RBP running tool. 21:30 - 22:30 1.00 EVAL P TIEB1 P/U RTTS & running tool. RIH on 4 3/4" DCs. 22:30 - 23:30 1.00 EVAL P T{EB1 RIH w! RTTS on 30 stands of 3 1/2" DP. 23:30 - 00:00 0.50 EVAL P TIEB1 Space out & set RTTS ~ 3100' DPM. 1/12/2008 00:00 - 01:00 1.00 EVAL P TIEB1 R/U & Pressure test 9 5/8" casing from 3100' to surface. Tested to 3500 psi for 30 min. Tested good. harte test. Bled 01:00 - 02:00 I 1.001 EVAL I P I ITIEBI 02:00 - 02:30 0.50 EVAL P TIEB1 02:30 - 03:00 0.50 WHSUR P TIEB1 03:00 - 04:00 1.00 CASE P TIEB1 04:00 - 06:00 2.00 CASE P TIE61 06:00 - 06:30 0.50 CASE P TIEB1 06:30 - 07:00 0.50 CASE P TIE61 07:00 - 09:30 I 2.501 CASE I P I I TIEB1 09:30 - 18:00 I 8.501 CASE I P I I TIEB1 18:00 - 18:30 0.50 CASE P TIEB1 18:30 - 21:00 2.50 CASE P TIE61 21:00 - 21:30 0.50 CASE P TIEB1 21:30 - 22:30 1.00 CASE P TIEB1 22:30 - 00:00 1.50 CASE P TIEB1 1/13/2008 00:00 - 01:00 1.00 CASE P TIEB1 01:00 - 01:30 0.50 CASE P TIEB1 01:30 - 07:30 6.00 CASE N WAIT TIE61 07:30 - 08:00 0.50 CASE N WAIT TIE61 08:00 - 13:30 5.50 CASE N WAIT TIE61 P/U & unset packer. Allow rubbers to relax. POOH & stand back 50 stands of 3 1/2" DP. Stand back 4 3/4" DCs. UD RTTS & running tool, P/U running tool. Pull & UD Wear bushing. Clear & clean rig floor. Finish liner prep. R/U 7 5/8" liner handling tools. Pre-tour HSE meeting with day crew from 05:30-06:30. Service rig, derrick inspection, check PVT's. PJSM: Reviewed liner running procedure and running order with crew and Baker Packer rep. PUMU 7-5/8" liner shoe track. Made up BTC-Mod connections to mark. Baker-Lok'd all connection below top landing collar. Rigged up torque turn equipment per recommended practice for making up premium casing connections. RIH w/7-5/8" 29.7# L-80/S-95 STL liner 1 x 1 from pipe shed. Torque turned and recorded mdivi ua connection data. Used Jet Lube Seal Guard thread compound. 40 jts. RIH ~ 14:00-hrs. Ambient temp. _ -46F. 65 jts. RIH ~ 16:00-hrs. RIH w/ 85 jts. Crew change. Service rig. Inspect derrick. Check PVT alarms. Con't to RIH w/ 7 5/8" 29.7#, L80, STL liner. Torque turn all connections to 5300 ft-Ibs. Used Jet Lube Seal Guard thread compound on all connections. Fill liner every 5 jts. RIH w/ 114 jts (117 jts W/ assys) See runnning detail. P/U & M/U liner hanger & packer assy. M/U X-Over to 3 1/2" IF DP. R/D 7 5/8" handling tools & Torque Turn equip. R/U 3 1/2" DP handling tools. RIH w/ 7 5/8" liner on stands of 3 1/2" DP. Fill every 5 stands. Con't to RIH w/ w/ 7 5/8" liner on stands of 3 1/2" DP. RIH w/ 30 stands. Filled DP every 5 stands. Space out & tag up on liner recepticle. 30 stands + 2 singles + 2'. Tagged ~ 7704'. P/U 5', set slips & install TIW valve. Wait on temperature to get above -40 degrees to cement well. Current weather conditions C~ DS L2-06: -46F, 4-mph f/SW, -60F WC, 1019 hPA rising. Current weather conditions C~ DS L2-06: -48F, 9-mph f/WSW, -74F WC, ,1020hPA falling. Printed: 2/4/2008 11:20:55 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: L2-06 Common Well Name: L2-06 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date I From - To ~ Hours Task Code NPT - - -- ~ - { I Start: 1 /3/2008 Rig Release: 1/26/2008 Rig Number: Page 5 of 12 ~ Spud Date: 1 /3/2008 End: 1/2612008 Phase Description of Operations 1/13/2008 13:30 - 17:00 I 3.50 CASE ~ WAIT TIEB1 17:00 - 00:00 I 7.001 CASE N ~ WAIT ~TIEB1 1/14/2008 100:00 - 06:00 I 6.001 CASE I N I WAIT ITIEBI 06:00 - 14:00 I 8.001 CASE I N I WAIT I TIEB1 14:00 - 16:00 I 2.001 CASE I N I WAIT ITIEBI 16:00 - 00:00 8.001 CASE ~ N ~ WAIT ~ TIE61 1/15/2008 00:00 - 06:00 6.00 CASE N WAIT T1EB1 06:00 - 08:00 2.00 CASE N WAIT TIEB1 08:00 - 11:30 3.50 CASE N WAIT TIE61 11:30 - 13:00 I 1.501 BOPSUR P 13:00 - 14:00 1.00 80PSUf~P 14:00 - 18:00 4.00 BOPSU P 18:00 - 20:00 I 2.001 BOPSURP 20:00 - 21:30 1.50 BOPSU•~ P 21:30 - 00:00 2.50 CEMT P 1(16!2008 100:00 - 02:30 I 2.501 CEMT I P TIEB1 T1EB1 TIEB1 TIE61 TIEB1 TIEBi TIE61 Current weather conditions @ DS L2-O6: -48F, 10-mph f/WSW, -76F WC, ,1020hPA steady. Con't to wait on temperature to get above -40 degrees. Temp C~ 24:00 hr = -48 degrees. Wind 9 Mph from SW. Wind Chill -74 degrees. Con't to clean & paint rig. Con't to wait on temperature to get above -40 degrees. Temperature ~ 05:00 hrs = -43 Degrees, Wind 10 Mph from SW, Wind chill -70 degrees. Con't to clean & paint rig. Weather conditions C~ 14:00-hrs.: -42F, Wind 13-mph f/SW, -71 F WC, Barometric Pressure steady ~ 1020 hPa. Weather conditions ~ 14:00-hrs.: -41 F, Wind 10-mph f/SW, -67F WC, Barometric Pressure steady @ 1020 hPa. Continue to clean, paint and perform preventive and active maintenance. Con't to wait on temperature to get above -40 degrees. Temp C~ 24:00 hrs =-44, Wind 8 Mph from WSW, Wind Chill -68 degrees. Con't to clean & paint rig. Con't to wait on temperature to get above -40 degrees. Temperature @ 0500 hrs = -46 degrees. Wind 8 Mph from WSW. Wind chill -70 degrees. Con't to clean & paint rig. Con't to wait on temperature to get above -40 degrees. Temperature ~ 08:00 hrs = -44 degrees. Wind 0 Mph from WSW. Wind chill -44 degrees. Con't to clean & paint rig, Ordered out 9-5/8" Halco RTTS packer w/storm valve to hang off DP and liner and perform weekly BOPE test. Notified AOGCC -Lou Grimaldi of intent to do ROPE test. Con't to wait on temperature to get above -40 degrees. Temperature C~3 11:30 hrs = -46 degrees. Wind 7 Mph from E. Wind chill -68 degrees. Con't to clean & paint rig. POH UD 3 jts. 3-1/2" DP. PUMU 9-5/8" Halco storm packer and hang liner and DP ~ 34' below rotary table. P1T packer to 1000-psi. for 30-charted minutes. Rig up BOPE test equipment and set test plug, Perform weekly BOPE test per BP/AOGCC requirements to 250-psi Lo/3500-psi Hi. Tested 3-1/2" x 6" VBR's w/3-1/2" and 4-1/2" test joints. Tested blind rams, annular preventer, choke manifold valves, HCR valves, floor valve, IBOP, upper and lower kelly valves. Testing witnessed by AOGCC -Lou Grimaldi. Weather conditions: -35F, Wind 16-mph ENE, -66F Wind chill. Held crew change and performed pre-tour checks. Continued testing BOPE to 250 psi low / 3500 psi high. Upper kelly valve failed pressure test. Did not retest immediately due to potential for fluid freezing. Deadhorse temp -31 deg F (-61 WC) at 20:00 hrs. Alerted SWS to upcoming scab liner cement job. Pulled test plug. MU RTTS retrieving tool. RIH, engaged and upset RTTS, POH and LD same. PU 2 joints DP. Tagged with finer and re-spaced out. MU cementing head. Filled wellbore with 28 bbls 9.8 ppg brine. Circulated 3 bpm, 415 psi to warm wellbore. Ambient Deadhorse temp rose to -29 deg F. Called out cementing service. Continued circulating through finer equipment 3 bpm at 415 psi. Printed: 2/4/2008 11:20:55 AM • • BP EXPLORATION Operations Summary Report Page 6 of 12 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: ~ From - To ~ L2-06 L2-06 WORKO NABOB NABOB Hours j VER S ALASK S 4ES Task DRI ~ Code LING NPT I Start I Rig Rig , Phase I Spud Date: 1/3J2008 : 1J3J2008 End: 1/26/2008 Release: 1/26/2008 Number: Description of Operations 1/16!2008 00:00 - 02:30 2.50 CEMT P TIEB1 Fluid losses about 20 bph. RU cementing service. 02:30 - 06:45 4.25 CEMT P TIEB1 Held PJSM with all personnel. Tested lines to 4500 psi. Mixed and pumped 27 bbls Class G cement + 50 bbls Class G cement w/CemNET + 21 bbls Class G cement. Initial parameters 5 bpm, 1400 psi, 15.8 ppg. Pressure dropped to 770 psi as cement fell. Pumped total of 98 bbls slurry. Released DP wiper plug and SWS displaced with 9.8 ppg brine. Did not see pressure spike when DP wiper plug caught liner wi er lu .Pressure gradually increased to 2050 psi as cement rose in annulus. Gradually reduced rate to 1.7 bpm. Bum ed lu at calculated dis lacement of 234 bbls. SO 25k Ib and increased pressure to 4500 psi to set ZXP packer and release hydraulic running tool. Bled pressure, had 2-314 bbls returned and floats held. P/U 11' and observed pressure bleed off. P/U additional 25', close in annular preventer and reversed out cement C~ 4.5-BPM. Recovered -10-Bbls. neat cement and -10-Bbls. diluted cement too en to tank. Reversed i additional 20-Bbls. ~ 4.5-BPM. Broke off cement head and first jt. DP and stood in mousehole. UD 2 jts. DP and 5' DP pup. PUMU cement head and jt. DP from mousehole. Hook ~ up lines and reverse additional 60-Bbls. ~ 4.5-BPM while reciprocating pipe. UD cement head. 06:45 - 07:45 1.00 CEMT P TIEBi Clear rig floor and prepare to POH UD hydraulic liner running tool. 07:45 - 09:00 1.25 CEMT P TIEB1 POH standing DP in derrick. BO/LD hydraiuc liner running tool and DP dart assembly. Dog sub sheared indicating positive set of liner top packer. 09:00 - 10:00 1.00 CEMT P TIEB1 Clear and clean rig floor. Prepare to changeout casing packoff. 10:00 - 10:30 0.50 WHSUR P TIEB1 PU casing packoff pulling tool. Screw pulling tool onto packoff. BOLDS. Pull packoff with 35K upweight including block weight. Break out packoff. 10:30 - 16:00 5.50 WHSUR P T1EB1 MU packoff tool to new casing packoff. Run in and set packoff. Attempt to drive into position with blocks. RILDS. Packoff not in correct osition. BOL S. Pull packoff and inspect. ac o seals damaged. Wait on new packoff to arrive. Install new packoff. RILDS. Test primary seals to 5000-psi and secondary seals to 3800-psi per well plan. Initial test on secondary seals failed and it was discovered that test was being perfomred through wrong port on tubing spool. Retest upper kelly valve and #12 valve on choke manifold. 16:00 - 17:00 1.00 CASE P TIE61 Cement achieved 1000-psi compressive strength ~ 13:35-hrs. per Schlumberger lab. Close blind rams. P/T 9-5/8" x 7-5/8" _ casin to 3500-PSI for 30 charted minutes. Good test. Open blind rams. 17:00 - 18:00 1.00 CEMT P TIEB1 Prepare to PU RIH w/BHA #3: 6-1/8" bit, 2 * 4-3/4" boot basket, XO, 4" flex jt., 6-3/4" string mill, LBS, oil jar, 9 * 4-3/4" drill collars and POS. Install wear ring. Wear ring I.D. = 9-1/8". 18:00 - 19:00 1.00 CEMT P TIEB1 Held crew change and performed pre-tour checks. PUMU BHA ~ #3. 19:00 - 22:00 3.00 CEMT P TIE61 RIH with 78 stands 3-1/2" DP. Entered 7-5/8" scab liner top with no resistance. Tagged soft cement at 7600' DPM. PU and SO 119k Ib. Printed: 2/4/2008 11:20:55 AM • • BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: L2-06 Common Well Name: L2-06 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date I From - To~~Hours j Task~Code NPT 1/16/2008 122:00 - 00:00 I 2.00 CEMT I P I~ 1/17/2008 100:00 - 07:00 I 7.001 CEMT I P 07:00 - 14:45 I 7.751 CEMT I P 14:45 - 17:45 I 3.001 CEMT I P 17:45 - 20:30 2.75 CEMT P 20:30 - 23:00 2.50 CEMT P Spud Date: 1 /3/2008 Start: 1/3/2008 End: 1/26/2008 Rig Release: 1/26/2008 Rig Number: Phase '~ Description of Operations TIEBi TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 23:00 - 00:00 1.00 CEMT P TIEB1 1/18/2008 00:00 - 02:15 2.25 CEMT P TIEB1 02:15 - 03:15 I 1.001 CEMT I P I I TIEB1 03:15 - 05:00 I 1.751 CEMT I P I I TIE61 05:00 - 07:00 2.00 CEMT P TIEB1 07:00 - 10:40 3.67 CEMT P TIEB1 10:40 - 12:00 1.33 CEMT P TIEB1 12:00 - 13:20 1.33 CEMT P TIEB1 13:20 - 15:00 1.67 CEMT P TIEB1 15:00 - 17:30 2.50 CEMT P TIE61 LD 7 joints DP. RIH 2 stands. PU kelly, established parameters: PU 122k Ib, SO 122k Ib, Rot 122k Ib, 5 bpm, 930 psi, 100a, 2000 Ib-ft, 65 rpm. Rotated and washed to hard spot at 7624'. 4k - 5k WOB. Continued drilling hard cement to 7635'. No fluid losses. Continued drilling cement in shoe track with 100a, 2000 Ib-ft, 65 rpm. Varied WOB up to 10k Ib and pump rates from 5 bpm to 1 bpm and RPM 40-70. Pump pressure varied from 930 psi to 150 psi. Drilled to 7637' at 05:30 hrs. No fluid losses. Drilled through top landing collar at 7643' at 07:00-hrs. Drilling ahead w/12K WOB, 62-RPM, 176-GPM C~3 685-PSI and 3500 ft.-Ibs. torque. Drill out through bottom insert landing collar at 7704' and continue on down to 7720' with bit. String mill depth - 7701'. Mix and pump 40-Bbl. Hi-Vis sweep ~ 5.0-BPM C~ 1025-PSI. reciprocate pipe while circulating. POH with bit ass'y (BHA #3). Stood back DC. Broke out BHA #3. No wear visible on string mill or bit. One-half cubic inch sized piece of metal jammed between mill blades. Cleared boot baskets. Recovered about 1 gal cement pieces and metal debris from boot baskets. Cleared floor. PU and MU BHA #4: jet basket, boot baskets, jar, DC. RIH with BHA #4. Held crew change and performed pre-tour checks. Continued RIH with BHA #4. PU kelly and RU to circulate. Established parameters: PU 123k Ib, SO 123k Ib, Rot 124k Ib, 5 bpm, 1220 psi, 60 rpm, 100 a, 2000 Ib-ft. Tagged at 7714'. Rotated and washed to 7743'. Pumped 40 bbl High-Vis sweep and circulated around at 5 bpm and 1220 psi. Slipped and cut drilling line. POH w/BHA #4. Break out RCJB and boot baskets and inspect type and quantity of debris recovered. Recovered large section of Baker insert landing collar and 4 small pieces of aluminum from landing collar in jet basket. Also recovered -1/2 gallon of cement and non-metallic cuttings from boot baskets. MU boot baskets and RCJB and RIH on 4-3/4" drill collars. Crew changeout and service rig. Grease drawworks, blocks and crown. Derrick inspection, check PVT's and environmental walk-around rig. Check motors and boilers. RIH RCJB BHA #5 - 2nd run. Kelly up. Establish parameters: PUW = 122K, SOW = 125K, 60-RPM, 1150-PSI @ 5.0-BPM. Tag sand at 7743'. Wash down to 7767'. Pump 40-Bbl. Flo-Vis sweep ~ 5.0-BPM C~ 1200-PSI. 17:30 - 21:00 3.50 CEMT P TIEB1 POH with BHA #5 (RCJB run 2). 21:00 - 23:30 2.50 CEMT P TIEB1 Held crew change and performed pre-tour checks. Broke out and LD BHA #5. Cleared baskets. Recovered 9 x 1" pieces, 2 x 5" pieces, 1 x 9" piece of aluminum from jet basket. Also recovered about 1/2 gal cement and non-metallic cuttings from Printed: 2/4/2008 11:20:55 AM • 23:30 - 00:00 0.50 CEMT P TIEBi 00:00 - 02:30 2.50 CEMT P TIEB1 BP EXPLORATION Operations Summary Report 02:30 - 05:00 { 2.501 CEMT I P I I TIEB1 (Legal Well Name: L2-06 Common Well Name: L2-06 Spud Date: 1/3/2008 Event Name: WORKOVER Start: 1/3/2008 End: 1/26/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/26/2008 Rig Name: NABORS 4ES Rig Number: Date I From - To ~I Hours li Task I! Code li NPT li Phase `_ - ~ ~ I___-- ,1/18/2008 21:00 - 23:30 ~ 2.501 CEMT P TIEB1 1 /19/2008 1 /20/2008 05:00 - 05:45 0.751 CEMT I P I ITIE61 • Page 8 of 12 ~ Description of Operations boot baskets. Cleared floor. Discussed plan forward with WO Engineer. MU RBP retrieving tool. RIH with RBP retrieving tool on 3-112" DP. Continued RIH with RBP retrieving tool. Worked retrieving tool into 7-5/8" liner top at 2974'. PU 1 joint 3-112" DP. RU to reverse circulate. Closed annular, doped DP. Pumped in reverse 3 bpm, 440 psi, SO 112k Ib, PU 123k Ib. Washed to 7775' DPM. SO 25k Ib, had sand and metal chunks in returns at bottoms up. Increased pump rate to 4 bpm and 1100 psi. Displaced 9.8 ppg brine to seawater. 05:45 - 06:45 1.00 CEMT P TIEBi Pre-tour HSE meeting with day crew. Service rig: Grease drawworks, blocks and crown, derrick inspection and check PVT alarms. Environmental walk around rig. 06:45 - 08:30 1.75 CEMT P TIEB1 Confirmed RBP free, LD 1 jt DP. POH, standing back 3-1/2" DP. Single DP displacement + 10-Bbls./hr. for well control scheme while POH. Rig lost power at 08:30-hrs. 08:30 - 09:30 1.00 CEMT N RREP TIEB1 Generator engine failed and unable to get backup engine running promptly. 09:30 - 10:45 1.25 CEMT P TIEB1 Resume POH w/7-5/8" Halco RBP. Single DP displacement + 10-Bbls./hr. for well control scheme while POH. L/D 4-3/4" drill collars. BO/LD RBP. Unable to release pulling tool from RBP fishing neck. Laid RBP and pulling tool down as one piece. 10:45 - 12:45 2.00 CEMT P TIEB1 Clear and clean rig floor and prepare to PUMU BHA #6. 12:45 - 15:30 2.75 CLEAN P DECOMP PUMU BHA #6: 4-1/8" MM Mill, 3 * 3-1/2" Boot Basket, XO, 3-1/8" Bumper Sub, 3-1/8" Oil Jar, XO, 12 * 3-1/8" DC's, 2-7/8" POS, 12 * 2-7/8" PAG DP, XO. 15:30 - 18:00 2.50 CLEAN P DECOMP RIH w/BHA #6 on 3-1/2" DP from derrick. 18:00 - 19:00 1.00 CLEAN P DECOMP Held crew change and performed pre-tour checks. Continued RIH w/BHA #6 on 3-1/2" DP from derrick. PU 12 singles from pipe shed. Held weekly Rig Leadership meeting, attended by WSLs, toolpushers, RLG, Graff. 19:00 - 00:00 5.00 CLEAN P DECOMP Soft tagged at 8954' DPM. Established parameters: PU 138k Ib, SO 138k Ib, Rot 145k Ib, 100 amps, 2000 Ib-ft, 60 rpm, 1 bpm C~3 0 psi, 2-1/2 bpm ~ 150 psi, no returns. Encountered hard bottom at 8964'. 5k Ib - 7k Ib WOB. Milled apparent fill and sunk to 8979'. Continued milling 5" packer 8979' - 8981'; 00:00 - 00:30 0.50 CLEAN P DECOMP RIH, chased packer to refusal at 9068' DPM. 00:30 - 04:00 3.50 CLEAN P DECOMP POH with BHA #6. Stood back 89 stands 3-1/2" DP. Added single pipe displacement plus about 10 bph seawater to wellbore. 04:00 - 04:45 0.75 CLEAN P DECOMP Stood back 4 stands 2-7/8" PAC drill pipe and 4 stands 3-1/8" PAC drill collars. LD 4-1/8" mill and boot baskets. Cleared boot baskets. 04:45 - 06:00 1.25 CLEAN P DECOMP MU BHA #7: 2-7/8" ITCO Spear (2.438" Grapple), 3-1/8" Bumper Sub, 3-1/8" Oil Jar, XO, 12 * 3-1/8" DC's, XO, 3-1/8" Intensifier, XO, 12 8 2-7l8" PAC DP, 2-7/8" POS, XO. 06:00 - 07:00 1.00 CLEAN P DECOMP Pre-tour HSE meeting & service rig. Daily derrick inspection, grease drawwoorks, blocks and crown. Check PVT's and envirnmental walkaround. 07:00 - 07:45 0.75 CLEAN P DECOMP RIH w/BHA #7 on DP from derrick. Printed: 2/4/2008 11:20:55 AM • • BP EXPLORATION Operations Summary Report Page 9 of 12 ~ Legal Well Name: L2-06 Common Weil Name: L2-06 Spud Date: 1/3/2008 Event Name: WORKOVER Start: 1!312008 End: 1/26/2008 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 1/26/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code I NPT Phase I Description of Operations 1/20/2008 07:45 - 08:20 0.58 CLEAN P DECOMP Stop and fill DP at 4500' RIH. 2-7/8" Spear has 3/8" I.D. circulating port. Took 28-Bbls. to fill. 08:20 - 09:30 1.17 CLEAN P DECOMP Resume RIH w/BHA #7 on DP from derrick. 09:30 - 10:30 1.00 CLEAN P DECOMP Kelly up. PUW = 135K, SOW = 134K. Fill DP at 5.0-BPM C~3 20-PSI. Tag fish ~ 9068'. Set down and engage grapple. PU and gained additional 12K PUW. 10:30 - 14:30 4.00 CLEAN P DECOMP POH slowly for first 24 jts. DP. Fish dragging up to 30K over string weight. Lost drag when fish pulled out of liner top C~? 8484'. Using double DP displacement while POH. 14:30 - 15:00 0.50 CLEAN P DECOMP BO/LD 5" packer fish and memory oauaes. Memory aauaes 15:00 - 16:00 I 1.001 CLEAN I P 16:00 - 18:00 I 2.001 CLEAN l P DECOMP Weekly HSE meeting with all crew: Discussed hand injuries DECOMP PUMU BHA #8: 4-1l8" packer mill, boot baskets, bumper jar, oil jar, PAC DC, POS, and PAC DP. Open kill line to pits to ; monitor in pits registering hi level 18:00 - 20:00 ~ 2.00 ~ CLEAN ~ P 20:00 - 21:30 I 1.501 CLEAN I P 21:30 - 22:00 0.50 CLEAN P 22:00 - 22:30 0.50 CLEAN P 22:30 - 00:00 I 1.50 I CLEAN I P 1/21/2008 100:00 - 02:15 I 2.251 CLEAN I P 02:15 - 06:00 I 3.75 I CLEAN I P Investi ate alarm for validit .Alarm is real. Closed kill line and monitored well. SICP = 270-psi. Discussed plan forward with Ops WO Superintendent and WO Engineer. Notified L2 Pad Operator and AOGCC (C. Scheve). Shot echo fluid level, but results inconclusive. SICP increased to 520 psi. Called out LRS for additional pumping capacity and vac trucks with seawater. DECOMP Held crew change and performed pre-tour checks. Spotted and RU LRS pumping unit to pump through IA valve. Spotted vac trucks. Held PJSM with all personnel. SICP increased to 600 psi. DECOMP Bullheaded seawater into well with rig and LRS. Rig pumped 6 bpm at initial 750 psi. LRS pumped 4.8 bpm at initial 800 psi. Injection pressure fell to 315 psi over the next 20 minutes of injection. Caught well fluid level at about 270 total bbls injected. Continued pumping to a total of 785 bbls injected. Final injection pressure 280 psi. ISIP 0 psi. DECOMP Monitored well; SIP remained 0 psi. DECOMP Opened well on strong vacuum as fluid fell away. Added 60 bbls seawater to well using rig pump. DECOMP RIH with BHA #8 on 3-1/2" DP. Added 60 bph seawater to well using charge pump. RD and released LRS. DECOMP Continued RIH with BHA #8, adding 60 bph to well with charge pump. PU kelly. Scraped pad and spread nut plug around rig for traction. DECOMP PU 122k Ib, SO 122k Ib, Rot 130k Ib, 2 bpm, 10 psi, no returns, 60 rpm, 90 a, 1800 Ib-ft. Tagged at 9073' DPM. Milled 5" packer with 5k Ib - 6k Ib WOB. Reduced pump rate to 06:00 - 06:30 0.50 CLEAN P DECOMP Crew change and service rig. 06:30 - 07:45 1.25 CLEAN N WAIT DECOMP Vac trucks unable to keep up with fluid losses. Down to 80-Bbls. in pits. S/D pumping/milling and wait for fluid to arrive. 07:45 - 09:00 1.25 CLEAN P DECOMP Load pits with seawater. Resume milling and pumping ~ 1.0-BPM ~ 7-PSI w/o returns. 09:00 - 09:30 0.50 CLEAN P DECOMP Pick up off fish. Stop rotating. Continued pumping 1.0-BPM into well. Closed annular preventer and took two separate Printed: 2/4/2008 11:20:55 AM • BP EXPLORATION Page 10 of 12 Operations Summary Report !Legal Well Name: L2-06 (Common Well Name: L2-06 Spud Date: 1/3/2008 iEvent Name: WORKOVER Start: 1/3/2008 End: 1/26!2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/26/2008 Rig Name: NABOBS 4ES Rig Number: Date i From - To 1,112112008 09:00 - 09:30 09:30 - 15:00 15:00 - 18:00 Hours I Task Code i NPT Phase Description of Operations 18:00 - 18:45 18:45 - 20:00 20:00 - 21:30 21:30 - 22:30 22:30 - 00:00 1 /22/2008 00:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 10:00 10:00 - 11:00 11:00 - 12:00 1.00 CLEAN P 12:00 - 13:00 1.00 CLEAN P 13:00 - 16:00 3.00 CLEAN P 16:00 - 18:00 2.00 GLEAN P 18:00 - 19:30 1.50 CLEAN P 19:30 - 20:15 ~ 0.75 ~ CLEAN I P DECOMP sonic fluid level shots. Fluid level is ~ 1014' from surface. Both shot were identical. DECOMP Resume milling as before and continuing to pump 1.0-BPM into well with no returns. Rotated C~ 9075' for -8-hrs. without gaining any depth. Applied 2-10K WOM, varied RPM 40-70, milled without pumping, milled with 4-BPM pump rate, spudded on fish to no avail. DECOMP Set back and blow down kelly. POH w/BHA #8 standing DP in derrick. Notified AOGCC ~ 15:20-hrs. of impending weekly ROPE test. Chuck Scheve waived AOGGC right to witness test. DECOMP Held crew change and performed pre-tour checks. Continued POH with BHA #8. DECOMP Stood back PAC DP and DC. Broke out and LD BHA #8 with packer mill #2. Found pump out sub sheared open. Significant wear on mill body. Mill nose rounded off with metal jammed in nose cavity. No cutting structure left on mill nose. Photos E-mailed to WO Engr. DECOMP Pulled wear ring. Set test plug. PU 3-1/2" and 4-1/2" test joints. DECOMP Held weekly safety meeting with all night rig personnel. Discussed hand awareness and reviewed rig incidents involving hand trauma. Continued addin 60 b h seawater to DECOMP ~ Tested BOPE 250 psi low / 350 psi high. Test witnessed by W SL and toolpusher. Continued adding 60 bph seawater to well. DECOMP Continued testing BOPE to 250 psi low / 3500 psi high. Tested VBR with 3-1/2" and 4-1/2" test joints. Continued adding 60 bph seawater to well. DECOMP Pulled and LD test plug. Installed wear bushing. Wear bushing I.D. = 9.125" DECOMP PUMU BHA #9: 4-1/8"junk mill, boot baskets, bumperjar, oil jar, PAC DC, PAC DP. While making up BHA, found 3-1/8" DC plugged with rubber which possibly explains pump out sub being sheared open. DECOMP Crew change and service rig. Daily derrick inspection, check PVT alarms, grease drawworks, crown and blocks. DECOMP Resume RIH w/BHA #9: 4-1/8"junk mill, 3' 3-1/2" Boot Baskets, Bumper Sub, Oil Jar, XO, 11 ' 3-1l8" DC's, 30' 2-718" PAC DP, XO, 3-1/2" POS on 3-1/2" DP from derrick. DECOMP Tag ~ 9074'. Kelly up and establish milling parameters: PUW = 126K, SOW = 126K, circ. = 3.0-BPM C~3 450-psi., 72-RPM, 3500 ft-Ibs. torque. Mill 5" packer to 9476' DECOMP PJSM. Stand back kelly. Prep to RIH. DECOMP RIH & ush acker to 9436', 263 jts DP + 7' in on #264. DECOMP PJSM. POOH w/ 3 1/2" DP. DECOMP LD BHA #9, 2-7l8" PAC DP and 3-1 /8" PAC DC. DECOMP Held crew change and performed pre-tour checks. Continued LD BHA #9. Cleared boot baskets. Cleared rig floor. Continued seawater additions with charge pump. DECOMP PUMU 6-1/8" bit and 7-5/8" casing scraper. Continued seawater additions. 0.50 CLEAN P 5.50 CLEAN P 3.00 CLEAN P 0.75 CLEAN P 1.25 CLEAN P 1.50 BOPSU P 1.00 BOPSU P 1.50 BOPSU P 4.50 BOPSU P 1.00 BOPSU P 0.50 CLEAN P 0.50 CLEAN P 3.50 CLEAN P 1.00 CLEAN P Printed: 2/4/2006 11:20:55 AM • BP EXPLORATION Page 11 of 12 Operations Summary Report '(Legal Well Name: L2-06 ..Common Well Name: L2-06 Spud Date: 1/3!2008 (Event Name: WORKOVER Start: 1/3/2008 End: 1/26/2008 (Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/26/2008 Rig Name: NABOBS 4ES Rig Number: Date I From - To Hours I Task I Code I NPT I Phase Description of Operations 1/22/2008 20:15 - 23:30 3.25 CLEAN P DECOMP RIH with bit and scraper on 89 stands 3-i/2" DP. PU 6 singles. ~ Filled well continuously with charge pump. 23:30 - 00:00 0.50 CLEAN P DECOMP PU 129k Ib. SO 129k Ib. Tagged at 8468' DPM. Reciprocated it and scraper across new acker settin de th at 8390'. Held kick while tripping drill; response time 2 minutes. 1123/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Cleared and cleaned rig. Held PJSM. 01:30 - 02:30 1.00 CLEAN P DECOMP POH, LD 3-1/2" DP. Went to Phase 2 weather at 02:30 hrs. 31 jts LD, 239 jts in hole. Bit at 7445'. 02:30 - 06:00 3.50 CLEAN N WAIT DECOMP High winds (35+ mph) and very low visibility made transferring pipe from pipe shed dangerous. Waited for wind to subside. Performed general rig housekeeping. 06:00 - 19:00 13.00 CLEAN N WAIT DECOMP Continue to wait on weather. Phase 3 conditions declared in GPB ~ 0730. (crew was changed out at 0600 hrs. (2) truck loads of seawater on location C~ 06:00. Filling hole ~ 30 bph beginning ~ 07:30. We have enough fuel for at least (2) days and enough boiler water for at least 24 - 36 hours. All personell and fuel /water reported to BP safety Alan Graff. 19:00 - 22:00 3.00 CLEAN N WAIT DECOMP Weather starting to subside. Arrangements made for crew change. Arrangements made to convoy (2) truck loads of seawater to rig after crew change completed. C~ 2000 hours down to 170 bbls of seawater in the pits. Permission granted to go to 10 bph hole fill until more seawater arrives. 22:00 - 00:00 2.00 CLEAN N WAIT DECOMP Looks like seawater will get here some time after midnite, filling wellbore @ 20 bph. ~ 23:15 hrs went to Phase 2, Level 2 on all main roads, Level 3 on access roads. 1!2412008 00:00 - 01:00 1.00 CLEAN N WAIT DECOMP Phase 2, Level 2 on all main roads, level 3 on access roads. 01:00 - 06:00 5.00 CLEAN N WAIT DECOMP Take on load of seawater. Give the wellbore a 75 bbl drink. Hole fill rate stepped up to 30 bph. Dig out around location and various pieces of equipment. 06:00 - 06:30 0.50 CLEAN P DECOMP Check crown o matic, PVT system, derrick inspection, OK. 06:30 - 12:30 6.00 CLEAN P DECOMP PJSM. POOH LDDP. Continuous hole fill. L/D scraper and bit. 12:30 - 13:30 1.00 CLEAN P DECOMP PJSM. Pull wear bushing. 13:30 - 15:30 2.00 BUNCO RUNCMP PJSM. Rig down spinners. Rig up double stacked tongs and torque turn equipment. 15:30 - 18:00 2.50 BUNCO RUNCMP Prep floor for running completion, dig completion equipment out of snowbank. 18:00 - 19:30 1.50 BUNCO P RUNCMP Held crew change and performed pre-tour checks. PUMU packer and WLEG ass'y. 19:30 - 00:00 4.50 BUNCO RUNCMP PJSM. PU, RIH with 4-1/2" 12.6#/ft, 13Cr-80 VAM Top tubing. Continuous hole fill with charge pump. Replaced joint #46, replaced collars on jts #45 and #47. Completion jewelry plus 47 joints run at 00:00 hrs. 1125/2008 00:00 - 06:00 6.00 BUNCO P RUNCMP Continued RIH with 4-112" 12.6#/ft, 13Cr-80 VAM Top tubing. Continuously added seawater with charge pump. 130 joints run at 05:30 hrs. Continued clearing location of drifts. 06:00 - 06:30 0.50 BUNCO RUNCMP Derrick inspection, check crown o matic, PVT system, OK. 06:30 - 08:00 1.50 BUNCO RUNCMP Continue to RIH w/ 4 1/2", 12.6#, 13cr80 Vam Top completion. Continuous hole fill. Make up Camco BAL-O Nipple. 08:00 - 10:30 2.50 BUNCO RUNCMP Rig up spooling unit to run dual stainless steel control lines. _ 10:30 - 15:00 4.50 BUNCO P RUNCMP PJSM. Continue to run in hole w/ above completion & dual control lines. Tag top of liner 18' in on jt #197. 15:00 - 18:00 3.00 BUNCO RUNCMP PJSM. Space out. Lay down Jts # 197, 196 & 195, make up space out pups, 2.07', 7.77', 9.80', & 9.87', make up Jt #195 Printed: 2/4/2008 11:20:55 AM • BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: L2-06 Common Well Name: L2-06 Spud Date: 1/3/2008 Event Name: WORKOVER Start: 1/3/2008 End: 1/2612008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/26/2008 Rig Name: NABOBS 4ES Rig Number: Date ~ From - To ~~ Hours j Task Code ~ NPT ~ Phase ~I Description of Operations 1/25/2008 15:00 - 18:00 3.00 BUNCO P RUNCMP and tubing hanger & landing jt. 104K up wt, 104K down wt. Landed tubing hanger, RILDS. Broke out and LD landing joint. Tested control lines to 5000 psi for 10 minutes. 18:00 - 19:30 1.50 BUNCO RUNCMP Held crew change and performed pre-tour checks. RD control j line spooler and tubing handling equipment. Per L2-06 Sundry A royal dated 114/2008 notified A ~ J. Crisp waived integrity test witness 18:00 hrs, 1125/2008. 19:30 - 00:00 4.50 BUNCO P RUNCMP Reverse circulated 180 bbls 140 deg seawater and 300 bbls 140 deg seawater with corrosion inhibitor. Pumped 3 bpm at 50 psi. Phase 1 weather conditions declared at 22:30 hrs. 1126!2008 00:00 - 05:00 5.00 BUNCO P RUNCMP Dropped ball/rod. Filled well, pressured u tubin to set packer. Increased tubing pressure to 3500 psi, attempting to all lines, found no leaks. Changed chart recorders. Pressure response appears temperature related. Obtained passing test on tubin ,bled ressure to 1500 si. Tested IA to 3500 si for 30 minutes, assed on first test. 05:00 - 06:00 1.00 BUNCO P RUNCMP Bled tubing pressure to shear DCK valve. Confirmed circulation both ways through DCK. 06:00 - 07:00 1.00 BUNCO RUNCMP Held crew change and performed pre-tour checks. PU lubricator and extension. Tested same to 100 psi for 5 minutes. 07:00 - 08:30 1.50 BUNCO RUNCMP Set BPV and blanking plug. Tested from above to 3500 psi for 30 minutes. Tested from below to 1000 psi for 30 minutes. 08:30 - 10:30 2.00 BOPSU P RUNCMP ND ROPE. Tested control fines to 5000 psi for 15 minutes. Left 5000 psi on control lines. 10:30 - 14:00 3.50 WHSUR P RUNCMP NU adapter flange. Tested hanger void to 5000 psi for 30 minutes. NU tree. Filled tree with diesel and tested to 10001 5000 psi. 14:00 - 15:00 1.00 WHSUR P RUNCMP RU lubricator and tested to 100 psi. Pulled and LD BPV and blanking plug. 15:00 - 18:00 3.00 BUNCO RUNCMP RU Little Red Services. Pumped 125 bbls hot diesel down IA. Allowed diesel to U-tube into tubing. 18:00 - 19:00 1.00 BUNCO RUNCMP Held crew change and performed pre-tour checks. Continued U-tubing diesel freeze protection. 19:00 - 20:30 1.50 BUNCO WAIT RUNCMP Waited on DSM to set BPV. 20:30 - 22:00 1.50 BUNCO P RUNCMP RU lubricator. Set BPV and blanking plug. Tested BPV to 1000 psi for 30 minutes with LRS. 22:00 - 23:00 1.00 BUNCO P RUNCMP Secured tree and cellar. Released rig @ 23:00 hrs 1/26/2008. Printed: 2/4/2008 11:20:55 AM ~ TREE= 4-1/16" 5M DRLG DRAFT L2-06 2122' 4-1/2" CAMCO BAL-O Nipple ID = 3.813" r_n c ~ icT AAA Nf1RFl C 13-3/8" CSG, 72#, N-80, ID = 12.347" ~ 2654' Minimum ID = 3.813" @ 8378' 4-112" X NIPPLE 7-518" CSG. 29.7#. L-80. ST-L. ID = 6.875" 2973' TOP OF 7-5/8" LNR 7712' 9-5/8" CSG, 47#, N-80, ID = 8.681" 4-1i2" TBG, 12.6#, 13Cr80, Vam Top, .0152 bpf, ID = 3.958" TOP OF 5" LNR 7-518" LNR, 33.7#, S-95, .444 bpf, ID = 6.765" 76' PERFORATION SUMMARY REF LOG: GO/GR ON 08/22/83; SWS GRICCL ON 08/24/83 A NGLE AT TOP PERF: 1 @ 8864' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL OpnlSgz DATE 3-3/8" 1 8864 - 8880 O 08/02/83 3-3/8" 1 8880 - 8936 O 08/02/83 3-3/8" 1 8973 - 8983 O 08!06/83 3 318' 4 8988 - 8990 S ? 3-3/8" 1 8996 - 9046 O 07!30183 3-318" 1 9060 - 9081 O 08/06/83 3-3/8" 4 9084 - 9086 S 07/13/83 3 318' 1 9100 - 9112 O 08/06/83 3-318" 1 9118 - 9198 O 07/17183 3-318" 4 9204 - 9206 S 07113183 3-318" 1 9628 - 9730 S 07/10/83 3-3/8" 1 9930 - 9980 S 07/03!83 3-3/8" 1 10020 - 10038 S 06/27!83 ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 4834 4833 1 KBG-2 DOME BK-2 16 02101/08 3 6709 6708 1 KBG-2 SO BK-2 20 02/01/08 2 7660 7658 1 KBG-2 DMY BK-2 0 01/25/08 1 8309 8308 1 KBG-2 DMY BK-2 0 01/25/08 8378' 75' 4-112" HES "X" NIP, ID = 3.813" ~ 7-518" X 4-112" BAKER S3 PKR, ID = 3.875" 4-1/2" HES "X" NIP, ID = 3.813" 4-1/2" WLEG FISH - DB PKR PUSHED TO BTM RIG (01/22/08) ~CEMFNf RETAINER, 07/12/83 ~ LISBURNE UNff WELL: L2-06 PERMfT No: 1830470 API No: 50-029-20930-00 SEC 18, T11 N, R15E, 3676.29' FEL & 3838.39' FNL BP Exploration (Alaska) ~D (INCLUDES SOME "DRLG JUNK") i~ 951b' r 5" LNR, 18#, 5-140, .0177 bpf, ID = 4.276" 10150' 4ES Incident • Maunder, Thomas E (DOA) From: Willingham, James M (ASRC ENERGY SERVICES) [James. Willingham@bp.comj Sent: Tuesday, January 22, 2008 1:52 PM To: Maunder, Thomas E (DOA) Cc: Rossberg, R Steven; Reem, David C Subject: 4ES Incident Tom, Here's what I've got so far. Dissect as needed: Page 1 of 2 On Jan 20, 2008, at approximately 16:00 hours, Nabors 4-ES had a well control incident on L2-06 (PTD: 183- 047). The events unfolded as follows: 15:00: The rig crew finished laying down fish. While laying down the recovery BHA, the fishing rep discovered that a crossover had swelled and a replacement was needed. While waiting on crossover, the rig team decided to conduct their weekly safety meeting. The well was secured by closing the blinds. 15:00 -16:00: Weekly safety meeting was conducted with both crews. During the meeting, fluid was not pumped through the kill line (This well has a 6.14 ppg equivalent mud weight and once the perforations were exposed during the decomplete, the well has been on a vacuum and unable to gain returns at any pump rate). 16:00: Upon conclusion of the safety meeting, the rig crew mobilized the components for the next BHA. Before opening the blinds, the rig crew opened the well through the choke to check for pressure. High level gas alarms tripped and the choke was immediately closed and the well monitored. Shut-in well pressure was 270 psi. 16:00 -18:00: Calls were made to the workover operations superintendent, workover engineer, pad operator and Chuck Scheve with the AOGCC. An echo fluid level was shot, but results were inconclusive. Well pressure had built to 520 psi. Little Red Services was called out to assist rig for a bullhead kill. 18:00 - 20:00: Rig crew change was made and Little Red Services arrived on location. Spotted Little Red pumping unit and rigged unit up to pump through IA valve while rig would pump down kill line. Held pre job safety meeting with all personnel. Well pressure had built to 600 psi. 20:00 - 21:30: Began bullhead kill operations. Rig pumped 6 bpm at an initial pressure of 750 psi. Little Red pumping unit pumped at 4.8 bpm at an initial pressure of 800 psi. Injection pressure fell to 315 psi after 20 minutes of injection. Kill reached well fluid level at 270 bbls injected (3688'). Continued pumping to a total of 785 bbls injected (1.5 wellbore volume). Final injection pressure 280 psi. Shut down pumps. Well pressure 0 psi. 21:30 - 22:00: Monitor well. Pressure remained at 0 psi. 22:00 - 22:30: Opened well. Well went on strong vacuum as fluid fell. Added 60 barrels seawater per hour for remainder of workover. Continued with operations. Jan 21, 2008, 09:00: Suspended milling operations, closed annular preventor, and shot two echo fluid levels. Both shots showed fluid level at 1,014'. Jan 21, 2008, 22:30 -Jan 22, 2008, 04:30: Out of hole with packer milling BHA. Set test plug and conducted 2/27/2009 ~ ~' " 4ES Incident Page 2 of 2 • weekly BOP test. Chuck Scheve with AOGCC waived witnessing of BOP test. This test was the first time the blind rams were tested since the well control incident. The well control incident was discussed between the rig team (Wellsite leader and toolpusher) and town Workover staff during the morning rig call on Jan 21. Root cause for the incident was determined on not pumping fluid into the well while the well was shut in. This allowed the fluid level to fall and unbalance the well. During the call, it was also noted that the blind rams had not been tested before running into the hole with the next BHA. The rig team was reminded that whenever a component of well control equipment is used for the purpose of well control, that component used must be tested at the earliest possible time. The rig team was also instructed to keep filling the well at 60 barrels per hour. Jim Willingham Workover Operations Supt. Office 564-5915 Cell 748-5821 Frank Roach Workover Engineer Office 564-4373 Cell 244-1674 2/27/2009 - ~ea.. ___ ~ ~ _ r' ~' ; - ~ + SARAH PALIN, GOVERNOR ~~ ~. ~- _> __- m.d- ~l ~~ ~~ ,~ ~. _a~ _~ ~~aTT~~++ Ai~tt~tr~-~7t~r~~lT ®~ro~ i~i1 ~[ SST 333 W. 7th AVENUE, SUITE 100 C®ls-7E~~Aii®as C®~i1•'II~S'`I®1s ,, ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 ~~`'~~-~ JAN ~° ~ 200 Anchorage, Alaska 99519-6612 .0~7 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L2-06 ~,~~ Sundry Number: 308-002 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this 1 ' day of January, ~..,.~ Encl. Cin nvraly i STATE OF ALASKA ~' 1 J~B $ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~r ~ 1 lad' 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ' ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 183-047 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20930-00-00 ° 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU L2-06 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028321 51.5' A Prudhoe Bay Field / Lisburne Pool ~ 2. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10301 10299 9525 9523 8422 & 8991 8983 Ca in L n th ize MD TVD Burst Colla se Structural Conduct r 80' 2 80' 80' 1490 47 Surface 2654' 13-3/8" 2654' 2654' 4930 2670 Intermediate 8076' 9-5/8" 8076' 8075' 6870 4760 Production Liner 1076' 7-5/8" 7712' - 8788' 7711' - 8787' Liner 1666' 5" 8484' - 10150' 8483' - 10148' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8864' - 9198' 8863' - 9197' 3-1/2", 9.2# N-80 8424' Packers and SSSV Type: 3-1/2" Camco'TRDP-1A' SSSV; Packers and SSSV MD (ft): 2126' 7-5/8" x 3-1/2" Baker'FHL' packer 8408' 13. Attachments: 14. Well Class after proposed work: . ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 9, 2008 ®Oil ~ ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 Printed Name avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature ~ Phone 564-5743 Date ~ ~ Q~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: - ~Z Conditions of approv l : Notify Commission so that a representative may witness a . ,/ ^ Plug Integrity 1~ t3OP Test mechanical Integrity Test ^ Location Clearance ~~~1 ~+'t`~~ . Other. ~ 7c~5`f ~~~' ~% Ic~i%rip`}, _ L~~,r#,.~~.~~) ~' ~ f 3~ (5~~a CCESIkic' !'li,+.ts~sT ~r~ 1`~ct -~Ck- 3CG~ , ~^ z~ ~ t ~t~K~ ~ ~' U+~'I'}'~~~s s~ ~~'1~~ : tl ~ ~''~•4-,~iv~ ~ t ~c:Jl c.:r-u,~ ~ ~ ~.35Z; ~ ;~ ~ ~ I U' `i - t P - ~~c ~~r ~?5 ~-~~'~r,fcl Subsequent Form Required: ~ ~ L ~- APPROVED BY ~ ' ~ ~ A roved B OMMIS NER THE COMMISSION Date Form 10-403 Revised 06/2006 5~~~. ~~~vj~ ~o~~ ORIGINAL Su it In Duplicate i• ~F. o~ ~~-~/~ i .~ C' ~Ta t er Pr s r ~'6 n e Bay L2-06 Rig Workover Scope of Work: Pull 3-'/2" N-80 completion, recover production packer, mill and retrieve two (2} isolation packers, scab over 9-5/8" casing with 7-5/8" casing to 3000' (top of liner), replace 9-5/8" pack-offs, and run 4-%2' 13Cr80 completion. MASP: 1950 psi Well Type: Producer Estimated Start Date: Januaryv , 2008 Prp.Rie~ O .._L- 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaks a check one at a time . PPPOT-T and IC. S 2 Lock open SSSV (Cameo TRDP-1A) @ -2126' (Ref 08/07/1983 tubing summary). Drift tubing for Power Jet cutter and memor caliper. Caliper tubin from CA-2 lu --8842' to surface. E 3 Punch tubing string. Power jet cut 3-%2" tubing @ 8381' MD (Ref 08/07/1983 tubing summary). Jet cut desired to be in the first full ~oint above packer, below the Kinle buttons. F 4 Circulate well with 9.8 ppg NaCI brine thru the cut and cap with diesel. MITOA to 1000 psi. Bleed WHPs to 0 psi. No CMIT required due to leakin Kinley button and cretaceous leaks. O 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test ROPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean 9.8 ppg brine through the cut. 2. Pull and LD 3-'/2" tubing string to the cut. 3. Retrieve production packer and tubing tailpipe. 4. Run 7-5/8" RBP and set at ~7840'md (3ro joint of 7-5/8" liner below liner top. PT RBP to 1000 psi to prove up barrier (may be hindered due to cretaceous leak). Stack ~50 ft of sand on RBP. 5. RIH with 7-5/8", 29.7#, L-80 scab liner, sting into tieback receptacle in current 7-5/8" liner. Cement 7- 5/8" scab liner to top of liner. Note: VBR's will not be changed to 7-5/8" pipe rams as the well has a barrier (RBP) to the reservoir and safety joint will be on the rig floor while the scab liner is run. c~~ ~g,2 ~~4i ~,, ' ~. Mill and retrieve two (2) isolation packers from 5" production liner. 7. Run 4-'/2" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -8400' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2000' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. 7 ~1~,'' X ~~~'' ct~x`_cti~ •`s O.i67 ~f~ ~~i ~t re~.;~,,~ >~7-f- ~~c~b Inner +~ 3~?~.;; b~z~clne. ~~n = 7 ibbi -t- Z,~~f XS ,k.L~ ~ sa lL~.~u+%~ Q~~c eE: -5 ~2,n (t o 4 I .TREE= ? 13-3/8" CSG, 72#, N-80, ID = 12.347" TOP OF 7-5/8" LNR u 7712' 9-5/8" CSG, 47#, N-80, ID = 8.681" ~-~ 8076' L2-06 2126' -~3-1/2" CAMCO TRDF 1A SSSV, b = 2.812" I GAS LIFT MANDRELS 5T MD TVD DEV TYPE VLV LATCH PORT DATE 1 5007 5006 1 CA-KBUG DMY BK 0 09!19/06 8332' 1KINLEY BUTTON, 1/4" ORFICE W/CHECK 8338' KINLEY BUTTON, 1/4" ORFICE W/CHECK Minimum ID =1.813" ~ 9097' ' " 8369 KINLEY BUTTON, 1/4 ORFICE W/CHECK CAMCO D NIPPLE 8374' KINLEY BUTTON, 1/4" ORIFICE W/CHECK $40$' 7-5/8" X 3-1/2" BAKER FHL PKR, ID = 3.0" 8422' 3-1/2" CAMCO D NIP, ~ = 2.75", ELMD 8422' 3-1/2" CA-2 PLUG (09/24106) 3-1/2" TBG-PC, 9.2#, N-80, .0087 bpf, ID = 2.992" $424' 8424' 3-1/2" TUBING TAIL TOP OF 5" LNR 8484' 8424' ELMD TT LOGGED 0-8/04/88 7-5/8" LNR, 33.7#, S-95, .444 bpf, ID = 6.765" 8788' PERFORATION SUMMARY REF LOG: GO/GR ON 08/22/83; SWS GRlCCL ON 08/24/83 ANGLEATTOPPERF: 1 @ 8864' Note: Refer to Production DB for h~torical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 1 8864 - 8880 C 08/02/83 3-318" 1 8880 - 8936 C 08/02/83 3-3/8" 1 8973 - 8983 C 08/06/83 3 3/8' 4 8988 - 8990 S ? 3-3/8" 1 8996 - 9046 C 07/30/83 3-3/8" 1 9060 - 9081 C 08/06!83 3-3/8" 4 9084 - 9086 S 07!13/83 3 3/8' 1 9100 - 9112 C 08/06/83 3-3/8" 1 9118 - 9198 C 07/17/83 3-3/8" 4 9204 - 9206 S 07/13/83 3-3/8" 1 9628 - 9730 S 07/10/83 3-3/8" 1 9930 - 9980 S 07/03/83 3-3/8" 1 10020 - 10038 S 06/27/83 PBTD (INCLUDES SOME "DREG JUNK") 11 9525' 5" LNR, 18#, S-140, .0177 bpf, ID = 4.276" 10150' 8983' 12 CORROSION COUPONS, EXTENSION I FROM KINLEY GUN, FILL $984' 5" X 2-718" BAKER FAB-1 ISOLATION PKR 8991' 2-7/8"CAM D NP, ID = 2.25" W/CA-2 PLUG ~~ & 2 MEMORY GAUGES HUNG FROM NIP 8992' 2a/s" TBG 9087' 5" X 2-3/8" BAKER DB PKR 9097' 1 2-3/8" CAMCO D NIP, ID = 1.813" 9098' 2-3/8" TBG 9098' ELMDTTLOGNOTAVALABLE 9528' CEMENT RETAINER, 07/12/83 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/08/83 OWGINAL COMPLETION 03/01/07 RL DATUM MD 11/04/01 RNITLP CORRECTIONS 05/13/02 GRGTLH PERF CORRECTIONS 06/16/03 CMO/TLP MAX ANGLE CORRECTION 09/21/06 DAV/PAG GLV GO (09!19!06) 10/11/06 RCTlRH PLUG SET (09/24/06) LISBURNE UNfT WELL: L2-06 PERMff No: 1830470 API No: 50-029-20930-00 SEC 18, T11 N, R15E, 3676.29' FEL & 3838.39' FNL BP Exploration (Alaska) ,TRt~= 4-1/16" 5M WELLHEAD= GRAY ACTUATOR = AXELSON KB. ELEV = 51.5' BF. ELEV = KOP= 0 Max Angle = 3 @ 9372' Datum MD = 8953' Datum 7VD = 8900' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" 7-518" CSG, 29.7#, L-80, ST-L, ID = 6.875" TOP OF 7-5/8" LNR 9-5/8" CSG, 47#, N-80, ID = 8.681" 771 ~~ 4-112" TBG, 12.6#, 13Cr80, Vam Top, .0152 bpf, ID = 3.958" TOP OF 5" LNR ~-'( 8484 7-5/8" LNR, 33.7#, S-95, .444 bpf, ID = 6.765" PERFORATION SUMMARY REF LOG: GO/GR ON 08/22/83; SWS GR/CCL ON 08/24/83 ANGLE AT TOP PERF: 1 @ 8864' Note: Refer to Product~n DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 1 8864 - 8880 C 08/02/83 3-3/8" 1 8880 - 8936 C 08/02/83 3-3/8" 1 8973 - 8983 C 08/06/83 3 3/8' 4 8988 - 8990 S ? 3-3/8" 1 8996 - 9046 C 07/30/83 3-3/8" 1 9060 - 9081 C 08/06/83 3-3/8" 4 9084 - 9086 S 07/13/83 3 3/8' 1 9100 - 9112 C 08/06/83 3-3/8" 1 9118 - 9198 C 07/17/83 3-3/8" 4 9204 - 9206 S 07/13/83 3-318" 1 9628 - 9730 S 07/10/83 3-3/8" 1 9930 - 9980 S 07/03/83 3-3/8" 1 10020 - 10038 S 06/27/83 PBTD (INCLUDES SOME "DREG JUNK") 9525' 5" LNR, 18#, S-140, .0177 bpf, ID = 4.276" 10150' ~4-112" HES "HXO" SSSV, ID = 3.813" ) CHAS LIFT MANDRELS ST MD DEV TYPE V LV 1 4801 1 4-112" 1" 2 6701 1 4-112" 1" 3 7651 1 4-112" 1" 4 8300 1 4-112" 1" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/08/83 ORIGINAL COMPLETION 03/01/07 RL DATUM MD 11/04/01 RN/TLP GORRECTIONS 05/13/02 GRClTLH PERF CORRECTIONS 06!16/03 CMO/TLP MAX ANGLE CORRECTION 09121!06 DAV/PAG GLV C/O (09/19106) 10/11/06 RCT/TLH PLUG SET (09/24/06) 4-112" HES "X" NIP, ID = 3.813" 7-5/8" X 4-1t2" BAKER S3 PKR, ID = 4-1 /2" HES "X" NIP, ID = 3.813" 4-1121 /2"WLEG~ ~CEMENTRETA9VER,07/12/83 ~ LISBURNE UNfT WELL: L2-06 PERMff No: 1830470 API No: 50-029-20930-00 SEC 18, T11 N, R15E, 3676.29' FEL & 3838.39' FNL BP Exploration (Alaska) L2-06 Proaosed CJ • AOGCC Memorandum Date: January 4, 2008 To: Well File -PBU L2-06 PTD 183-047 ~? ., 1 ~G"~~1 4j ,^~,~ ~~( From: Jim Regg, Petroleum Engineer Subject: Sundry 308-002 U The subject Sundry application outlines a rig workover (RWO) planned by BP to repair a Cretaceous leak in the Surface casing of PBU L2-06. Nabors 4ES will perform the RWO beginning January 6, 2008. Work planned includes pulling the existing 3.5" completion and installing a scab liner from top of existing 7-5/8" liner to cover the Cretaceous leak in the 9-5/8" casing; length of scab liner is approximately 4700 ft. I contacted Frank Roach (BP; 907-564-4373) with several questions about the application; his responses are summarized below. Follow-up contact with Dave Rheem (BP; ---) clarified the contingency in place as alternate to changing to 7-5/8" casing rams for the scab liner run. 1. Volume of cement planned for scab liner? - capacity of 7-5/8" by 9'5/8" calculates to 79 bbls; plan to pump an additional 25 bbl cement (total volume cement is 104 bbls} 2. Liner top packer for scab liner? - Yes; set at approximately 3000 ft MD 3. Pressure test planned for scab liner? - Will test scab liner to 3500 psi prior to milling 5" isolation packers in production liner 4. Reason why 7-5/8" casing rams not installed for running scab liner? - I explained that 20 AAC 25.286 requires rams be run and tested. Mr. Rheem indicated that their contingency is 7-5/8" XO made up to TIW and 1 safety joint of drill pipe above the TIW; all this staged in mousehole ready to be picked up and stabbed onto 7-5/8" liner if needed. This has been approved by AOGCC in past. Contingency plan confirmed in writing (electronic mail) -attached. • BPXA Justification: Alternative to 7-5/8" Casing Rams While Running Scab Liner L2-06 additional sundry information From: Roach, Frank [Frank.Roach@bp.com] Sent: Friday, January 04, 2008 2:08 PM To: Regg, James B (DOA) Cc: Reem, David C Subject: L2-06 additional sundry information Mr. Regg, Per your conversation with Mr. Reem regarding the pipe ram configuration and procedure for running the 7-5/8" scab liner in L2-06 the additional information is as follows: There will be an open safety valve crossed over to 7-5/8" BTC on the rig floor. In the event of a well control event while running the 7-5/8" casing, the safety valve with crossover will be screwed into the 7-5/8" casing and the valve will be closed. One (1) joint of 3-1/2" IF drill pipe will be screwed into the top of the safety valve and lowered to where the drill pipe will be across the BOP equipment. The VBR's and annular preventor will then close around the 3-1/2" drill pipe. The well will then be safed out. I hope this additional detail clarifies the original scope of work document submitted with the sundry application. If more is needed please don't hesitate to give myself or Mr. Reem a call. Thank you and Regards, -Frank Roach LZ-06 additional sundry informat~ • Page 1 of 1 Regg, James B (DOA) From: Roach, Frank [Frank.Roach@bp.com} Sent: Friday, January 04, 2008 2:08 PM ~ ~ ~t,~ To: Regg, James B (DOA) ~\~~~~~ ~ ~ Cc: Reem, David C Subject: L2-06 additional sundry information Mr. Regg, Per your conversation with Mr. Reem regarding the pipe ram configuration and procedure for running the 7-5/8" scab liner in L2-06 the additional information is as follows: There will bean open safety valve crossed over to 7-5/8" BTC on the rig floor. In the event of a well control event while running the 7-518" casing, the safety valve with crossover will be screwed into the 7-5/8" casing and the valve will be closed. One (1) joint of 3-1/2" IF drill pipe will be screwed into the top of the safety valve and lowered to where the drill pipe will be across the BOP equipment. The VBR's and annular preventor wiN then close around the 3-1/2" drill pipe. The well will then be safed out. I hope this additional detail clarifies the original scope of work document submitted with the sundry application. If more is needed please don't hesitate to give myself or Mr. Reem a call. Thank you and Regards, -Frank Roach l /4/2008 01/05/2007 Scblumberger NO. 4101 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth U,-r~ l~ --6~~J SCANNED JAW 1 () 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD 17-20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10/06 1 R-04 11536188 LDL 12/12/06 1 17-12 N/A PRODUCTION PROFILE 11/27/06 1 B-01 N/A LDL 11/28/06 1 J-12 11513655 PRODUCTION PROPILE 11/29/06 1 13-24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01/06 1 P-25L 1 11513656 LDL 12/05/06 1 W-29 11549353 USIT 12/18/06 1 P2-50B 11513652 SCMT 11/26/06 1 03-08 11536186 SCMT 12/10/06 1 M-15 11486170 USIT 12/02/06 1 S-31A 11478134 USIT 11/27/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: ~J!\N '] «) i007 Received by: . . " ~ /"""""'\, !! . ¡'rU~' t:;-? Ir;~\ C:;~r :?,' , ¡ , v. \ '! L. <'\. ¡ I ¡ H \ !! ::¡ @) U Ln.'J U .1 (-;:.,~, ~, ¡ ¡ i ¡ ! ¡ ¡¡I L, , '" r lQJJ ¡:', ,OJ r~-\ '-;:"\ n n F\ 1<\1, JI\,,(\U¡¡(i'f'\ ¡¡I\!! fL'\\""'¡¡{!'\' ¡UII! 1'\ \'if'\ i'-Ó\ lJìJ ~ Lflj æJ U D lrL1 FRANK H. MURKOWSKI, GOVERNOR ! i / / ^',ASKAOILAND GAS CONSERVATION COMMISSION ,/ l 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12, 2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 } iíY 0 L/-7 Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location PBU L1 PBU L2 PBU L3 Date ofSVS Test April 23, 2004 April 26, 2004 April 27, 2004 Failure Rate 30.0% 16.7% 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part ofthe SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU L1, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to' th SVS test. Sincerely, 2J~ J . Norman, Chair Commissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) r--., /"'"'.., Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Permit Separ Set Number PSI PSI 1830470 448 350 1870850 2032140 448 350 1870970 1851340 1852750 448 350 1850900 1860060 1851040 1850350 1852970 1850090 1871370 1860220 3 Components: Operator: BPX Submitted By: Ron Marquez Date: 04/26/2004 Operator Rep: Rob Endebroc1 Unit/Field/Pad: Greater Pt McIntyre/Lisbume/L2 AOGCC Rep: None Separator psi: LPS HPS 448 ----- Test Test Date Tested and or Oil, WAG, GINJ, Code Code Passed Retest or SI GAS, CYCLE, SI P P O~ 11/9/1996 SI 4/27/2004 OIL 5/16/1995 SI 6/29/1995 SI OIL 81 81 81 81 SI SI SI 81 LIP Test Trip Code 280 P 250 P 4 p Wells: Remarks: 320 p P p 3/28/1995 3/23/1996 11/8/1996 8/4/2000 2/24/1994 8/4/2000 6/9/2003 3/28/1995 6 Failures: 1 Failure Rate: Page 1 of 1 SVS PBU LIS L2 04-26-04.xls ARCO Alaska, Inc. ' -' Post Office Box ~100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 July 30, 1993 Ms. Joan Miller AOGCC 3001 Porcupine Drive Anchorage, AK 99501 RE: Delinquent Subsequent Sundry Notices Dear Madam: Enclosed are delinquent subsequent sundry notices for the Lisburne Oil Pool. Please refer to the list below. Form 10-404 Well p_crmit Approval Date ~ ~ L1-15 89-132 90-314 5/8/90 Stimulate Co m ,p, leted L1-30 90-18 90-798 11/1/90 Pe d/Stimulate L2-06 -83:47 9-928 10/20/89 Install Kinley Buttons ',', L2-10 87-85 90-850 12/3/90 Stimulate L2-16 87-97 90-865 12/13/90 Stimulate Job Canceled L2-18 87-118 90-851 12/13/93 Peal/Stimulate Com,p, leted L2-30 85-9 9-955 11/1/89 Install GLVs ,, L3-01 86-161 90-779 10/16/90 Acid Wash ,, L3-28 89-66 90-807 11/9/90 Peri/Stimulate ,, L4-03 88-67 91-248 8/27/91 Peal/Stimulate ,, L4-15 83-71 91-308 10/16/91 Stimulate ,, L4-30 88-101 90-800 10/24/90 Stimulate ,, L5-12 87-10 90-781 10/16/90 Sli mu late ,, L5-21 87-57 90-609 8/9/90 Stimulate /, dS,.,.'.', · ~.. :- , -, ~ ;._~.- ....: :~:--...,.. ~.- '.,.~, ,' f ?~:? - . Sincerely, George K. Phillips Engineering Supervisor Lisburne/Point Mclntyre Engineering Cqx~:LSL:ib Enclosures cc: R.G.M. Oba, ARCO Alaska, Inc. (Without Enclosures) At..!6 - 6 Alaska Oil & Ga:;, Cons, 6oi.l~rnissio~ Ancl]0rage ARCO Alaska, Inc. Is a Subsidiary of Allanlic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate __ Pull tubing Alter casing Repair well Plugging Perforate _ '~~,~4~'~ · Pull tubing O 6. Datum elevation (DF or KB) - y.~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1320 FSL, 1320 FWL, Sec.18,T11N,R15E,UM At top of productive interval 1320 FSL, 1320 FWL, Sec.18,T11N,R15E,UM At effective depth 1320 FSL, 1320 FWL, Sec.18,T11N,R15E,UM At total depth 1320 FSL, 1320 FWL, Se¢.18,T11N,R15E,UM RKB 52' tee! 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number L2-06 9. Permit number/approval number 8;~-47/9-.928 10. APl number 50-029-209:~0-00 11. Field/Pool LISBURNE OIL POOL 12. Present well condition summary Total Depth: measured 1 011 5' feet true vertical feet Plugs (measured) Effective depth: measured 1 011 5' feet true vertical feet Junk (measured) NONE Casing Length Structural Conductor 8 0' Surface Intermediate Production Liner Size Cemented 20" 2295# Poleset 1 33/8'' 2200 sx Fondu & 400 sx PF "C" 95/8" 500 sx Class G 75/8'' 293 sx Class G 5" 300 sx Class G Measured depth True vertical depth 80' 80' 2654' 2654' 8O76' 8076' 8788' 8788' 8484' 8484' Perforation depth: measured 8864-8880, 8880-8990, 8996-9086, 91 00-9206 true vertical n/a (vertical hole) Tubing (size, grade, and measured depth) 31/2'' N-80 @ 8424' i packers and SSSV (type and measured depth) Baker 'FHL' Packer @ 8408'. Camco SSSV TRDP-1A 2.812" ID @ 2126 RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to the attached. Anchorage 14. Representative Daily Average Production or Injectiorl Datci OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation n/a Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned Georce K. Phill Title En~ Form 10-404 Rev 05/17/89 Lisb/Pt Mc Date SUBMIT IN DUPLICATE Lisburne Well L2-06 Kinley Buttons Installation Procedure 10/25/89 First run: Rigged up e-line and RIH with Kinley Button gun SITP 750#. Experienced difficulties getting down to 8380' location. Set button at 8474'. POOH. Button appeared to be set. Pressure tested to 3500#. Second run: RIH with Kinley Setting Tool. Fired charge at 8369'. ]0128189 Returned well to operations. NOTE: Kinley Button Device failed. RECEIVF D ^iaska 0i1 & C-~ars Cons. ~OFIil'f!iSSIO0 Anchorage ARCO ALASKA INC. LISBURNE ENGINEERING DATE: FROM: May 23, 1991 Laura S. Lahrson ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: (1 blueline) L2-14 Perforating Record 1 L2-06 Collar Locator Log to spot 1 Kinly Buttons 4122191 1/21/91 Schlumberger Schlumberger SIGN AND RETURN TO: LAURA S. LAHRSON, ATO 409 ARCO ALASKA, INC. 700 G STREET; ATO 409 ANCHORAGE, ALASKA 99510 RECEIVED BY: AOGCC TRANSMITTAL # 644 ,~z ~Y',o'~q ~. ~ WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 13, 1991 Sue Morgan c/o Dr. Keith Watts Geophysical Institute 301-B University of Alaska Fairbanks Fairbanks, AK 99775 Re: Data on PBU L2-06, L3-08, L4-15 Dear Ms Morgan: Please find enclosed the well histories for PBU L2-06, L3-08, L4-15. Each well file contains a completion report and lists of data available for each well. I have also enclosed an informational sheet listing the services and data provided by the AOGCC and services offered by various companies in the Anchorage area. If you have further questions please feel free to call me at 279-1433 or call the company direct. Microfilm Equipment Operator Enclosures ARCO ALASKA INC. LISBURNE ENGINEERING DATE: 11-8-89 FROM: TINA KINCAID ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: %~ L2-6 '~"~' L2-18 L3-1 ~ L3-1 "%"%~ "L3-1 ~%'~" L3-28 L4-2 ~L4-2 'R~ L4_2 '. ' L4-2 L4-2 ~L4-2 ~ L4-2 ~ L4-2 "~ L4-31 '~"~ L4-31 ~t L4-31 LOGS: LGI-06 LEAK DETECTION COLLAR LOG INJECTION PROFILE COLLAR LOG CEMENT BOND LOG CEMENT EVALUATION COLLAR LOG PHYSICAL FORMATION COMPENSATED NEUTRON LITHO DENSITY - POROSITY COMPENSATED NEUTRON LITHO DENSITY- RAW DATA REPEAT FORMATION TESTER NATURAL GAMMA RAY SPECTRA LOG DUAL LATERLOG GAMMA RAY COLLAR LOG ACOUSTIC CEMENT BOND LOG CEMENT BOND LOG CEMENT EVALUATION LOG GCT GYRO DIRECTIONAL SURVEY RUN 1 10-12-89 RUN 1 10-25-89 RUN 1 10-13-89 RUN 1 10-20-89 RUN 1 10-23-89 RUN 1 10-23-89 RUN 1 10-27-89 RUN 1 10-13-89 RUN 1 10-22-89 RUN 1 10-22-89 RUN I 10-22-89 RUN 1 10-22-89 RUN 1 10-22-89 RUN1 11-1-89 RUN1 11-1-89 RUN1 11-1-89 RUN1 11-1-89 RUN1 11-1-89 CAMCO ATLAS CAMCO ATLAS SCHLUMBERGER SCHLUMBERGER ATLAS ANADRILL SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER ATLAS ATLAS SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER TAPES' L4-2 OPEN HOLE LOGS L4-2 RFT RUN 1 10-23-89 RUN 1 10-23-89 SCHLUMBERGER SCHLUMBERGER SIGN AND RETURN TO: RECEIVED BY: ~ STATE~OF-A[~A~i(~ TRANSMITTAL # 625 TINA KINCAID ARCO ALASKA, INC. 700 G STREET; ATO 409 ALASKA 995! .~. t 0RI ,INA ?~',~ OIL AND C-.-.-.-.-.-.-.-.~ CONSERVATION ~SSlON APPL.,;ATION FOR SUNDRY A, .'ROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ 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 4. Location of well at surface 1320 FSL, 1320 FWL, Sec. 18, T11N, R15E, UM At top of productive interval 1320 FSL, 1320 FWL, Sec. 18, T11N, R15E, UM At effective depth 1320 FSL, 1320 FWL, Sec. 18, T11N, R15E, UM At total depth 1320 FSL, 1320 FWL~ Sec. 18~ T11N, R15E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service _ 1 01 1 5' feet Plugs (measured) feet Norie 1 01 1 5' feet Junk (measured) feet None 6. Datum elevation (DF or KB) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Size Cemented RKB 52' feet 7. Unit or Property name Prudhoe Ba~/ Unit/Lisburne 8. Well number L2-06 9. Permit number 10. APl number 50-029-20930-00 11. Field/Pool Lisburne Oil Pool Measured depth True vertical depth 20" 2295# Poleset 80' 1 3 - 3 / 8" 2000 sx Fondu & 2 6 5 4' 400 sx PF "C" 9-5/8" 500 sx Class G 8 0 7 6' 7-5/8" 293 sx Class G 8 78 8' 5" 300 sx Class G 8 4 8 4' measured 8864-8880, 8880-8936, 9069-9081, 9084-9086, true vertical 8973-8983, 8988-8990, 9100-9112, 9118-9198, Tubing (size, grade, and measured depth 3-1/2" N-80 @ 8424' Packers and SSSV (type and measured depth) Baker 'FHL' Packer ~ 8408'. Camco SSSV TRDP-1A 2.812" ID ~ 2126 13. Attachments Description summary of proposal _ Detailed operation program X Kinley Button Installation Procedure and Well Schematic 80' 2654' 8076' 8788' 8484' 8996-9046, D OCT 1 9 989 -' 14. Estimated date for commencing operation October 24. 1989 16. If proposal was verbally approVed Status of well classification as: Oil ~ Gas_ Name of approver Date approved Date 15. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'('_~("~.~ Title Engineering Aide ) FOR COMMESSION USE ONLY lO- Commissioner Conditions of approval: Notify Comm[csion so representative may Witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Commission L~,-~'~,~IE C. SMITH Suspended _ Oct 17r 1989 IApproval No. Returned lC, Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE L2-06 KINL~Y BUTTONS INSTALLATION PROCEDURE AFE AP2138 . Rig up E-line and RIH with CCL and senior perforating tool. Install 1/4" Kinley check valve at approximately 8380' MD (being careful to avoid tubing connections). POOH. RIH for second run with CCL and senior perforating tool. Install 1/4" check valve 5' above first setting point at approximately 8375' MD (again being careful to avoid tubing connections). 3. POOH. Rig down E-line. 5~ Gradually unload backside 10'2 ppg brine with existing 1" valve at 5007' MD and the two new Kinley check valves. Shut-in well. Rig up slickline unit and pull 1" valve at 5007' MD. Replace with equalizing dummy valve. 6. Put well on gas lift and produce to dean up. 7. Return well to production with approximately 4000 GLR. t £C£1V£D OCT 1 91989 0il & ~a~ Cons. Cotnmi$$lon AnchOrage JWELL L2-06 SCHmAT C J APl ~ so-o2g-2oo3c j I0~112 I ! 13 16 14 15 17 18 19 21 23 Surface Locatlo~ 1320FSL, 1320FWl,,Sec. 18,T I I N,R I 5E,UI'I Top L Isburne Loc: 1320FSL, 13~'-':WL.Sec. 18,T I I N,R I SE,UPI RKB To Tubing Hanger:. 36 Fee To{) of W~oo: 8863 I'1D/8812 SS Oatum:8951 ~10/8900 SS Reference Lo~ Annulus F'lulds · Gas lift gas to $007. IO.2 13Dg brlne below. Si)ua Date: 4-4-83 Com~letlort 8-9-83 I'llnlmum ID: 2.75' · 8422' I'ID I. 36 tlD--3- I/2" TBG HANGER, 3 I/2' X 9.2~ N-80, I PC 2. 2126 rlD -- CAI'ICO SSSV TRDP- I A, 2.812'ID 3. 2654 I'ID -- 13-3/8' X 72~N-80 CSG. SET 4. GAS LIFT I'IANDREL DEPTH I'IANDREL TYPE VALVE LATCH TRO 50071'1D CAi'ICO I' KBUG 3/16' BK2 '1400 5. 7712 I'ID - TOP OF 7-5/8'X33.5~ 5-95 LINER 6. 8076 I'IB - 9-$/8'X47* N-80 CASING 7. 8408 ELI'ID - BAKER'FHL' PACKER 8. 8422 ELI'ID - CAtlCO 'D' NIPPLE,2.75'ID 9. 8424 EI.I'ID - TUBING TAIL,BOTTOI'I OF 3-1/2" N-80 TAILPIPE SS DEPTH (4956 SS) 10.8'484 HO - TOP OF 5'X 18~ S 140 LINER 11.8788 I'ID - 7-5/8'CSG SET 12. WAHOO 7 PERFORATIONS USPF GUN (8813-8829' SS) 8864- 8880 I CSG 13. WAHOO 6 PERFORATIONS (8829-8939' SS) 8880 - 8936 I CSG 8973 - 8983 I CSG 8988 - 8990 SOUEEZED (1~945-9035' SS) (9049-9155' SS) 14.8984 ELP1D - BAKER'FAB- 1" ISOLATION PACKER # NOTE: ObStrUCtion on top o1' packer w/I'111 partially coverlng obstruction. 15.8991 ELI'ID - 2-7/8'CAtlC0 'D' NIPPLE, 2.25'1D w/CA-2 PLUG AND 2 I'IEI'IORY GAUGES HUNG FROI'I NIPPLE. 16.8992 ELI'ID - TAIL PIPE 17.WAHOO 5 PERFORATIONS JSPF GUN 8996 - 9046 I CSG 9069 - 9081 I CSG 9084- 9086 SOUEEZED 18. 9087 HD - BAKER 5' 'DB' PACKER 19. 9097 I"ID - CAtlCO 'D' NIPPLE, 1.813'1D 20. 9098 I'ID - BOTTOI'I OF 2-3/8' TAILPlPE 21. WAHOO 4 PERFORATIONS JSPF GUN 9100 - 9112 i CSG 9118 - 9198 I CSG 9204- 9206 SOUEEZED 22. 10 I-1S I'ID - PBTD 23. i01 I$ I'ID - TD I'IAXII'IUtl WELL DEVIATION:STRAIGHT HOLE HOLE ANGi E THRU WAHOO: STRAIGHT HOLE MAXIMUM H2S LEVEL MEASURED · 6 PPI'I Revision Date: 9-25-89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate__ Plugging Pull tubing __ Alter casing ~ Repair well __ Pedorate ~ Other~ Water Injection 2. Name of Operator ARCO A.]_as]~ Inc. 3. Address P 4. Location of well at surface 1320' FSL, 1320' FWL, Sec. 18, TllN, At top of productive interval 1320' 'FSL, 1320' F~C_J, Sec. 18, TllN, At effective depth 1320' FSL, 1320' FWL, Sec. 18, TllN, At total depth 1320' FSL, 1320' FWL, Sec. 18, TllN, 12. Present well condition summary Total depth: measured 10301 feet true vertical feet 5. Type of Well: Development Exploratory Stratigraphic Service R15E, UM R15E, UM R15E, UM R15Er UM Plugs(measured) None 6. Datum elevation (DF or KB) RKB 52 ' feet 7. Unit or Property name 8. Well number L2-6 9. Permit number/approval number 83-47/8-04 Effec!ive depth: measured 10301 feet true vertical feet Junk (measured) None Casing Length Structural ,~: .;.: Conductor Surface Intermediate Production Liner Perforation depth: measured 8864 ' -8936' 8966 ' -9046 ' · · true vertical Size 20" 13-3/8" 9-5/8" 7-5/8" 5" Cemented 2295 # Poleset 2000 sx Fondu & 400 sx PF "C" 500 sx Class G 293 sx Class G 300 sx Class G 10. APl number 50-- 029-20930 11. Field/Pool Lisburne Oil Pool Measured depth 80' 2654' 9060'-9081' 9100'-9112' 9118'-9198' · · Tuevedicaldepth 80' 2654' 8076' 8788' 8484' Tubing (size, grade, and measured depth) 3-1/2", L-80 @ 8435' Packers and SSSV (type and measured depth) "DB" 9087 ' Camco 13. Stimulation or cement squeeze summary TRDP-1A ¢ 2126' Intervals treated (measured) a-Il Treatment description including volumes used and final pressure 8076' 8788' 8484' RECEIVED 14. JAN 1 ? ]989 Tubing Pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf Water-Bbl Casing Pressure Prior to well operation 750 2625 38 50 380 Subsequent to operation 1100 3300 100 50 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ._Z;. Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Technical Aide 380 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 A1TACHMEi~ 1 L2-6 ON DECEMBER 20. 1987 ARCO ALASKA INC, SUBMITTED A SUNDRY REQUEST FOR WELL L2-6. OUR REQUEST WAS TO CONVERT THE WELL TO A WATER INJECTOR, THE WELL WAS TEMPORALLY CONVERTED TO WATER INJECTION AS PART OF A 4- CYCLE IMBIBITION TEST. THE WELL CURRENTLY IS TO REMAIN A PRODUCER,_ RECEIVED JAN 1 7 t989 Oil & Gas Cons. Con, mission July 13, 1988 DATE: FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Final - Cased Hole L2-6 Injection Profile Log 6-16-88 Run i 5" Camco L3-30 Completion Record 6-23-88 Run 2 5" Sch k,_.../' Aqas~(~ 0i~, & ,~s Cons. Commission Anchorage RECEIVED BY: PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES D&M EXXON PLANO STANDARD 'STATE OFAEASKA .... · TRANSMITTIAL# 559 o. STATE OF ALASKA ALAStx~ OIL AND GAS CONSERVATION COMN,.oSION Feet REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other>ID Water Znjection 2. Name of Operator ARCO Alaska ]:nc, Box 100360 Anchorage, Aiaska 99510 3. Address PoOo 5. Datum elevation (DF or KB) RKB 52 ' 6. Unit or Property name Prudhoe Ba¥/Lisburne 7. Well number L2-6 8. Approval number 8-04 9. APl number 50-- 029-20930 10. Pool L~.sburne Oil Pool 4. Location of well at surface 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UM At effective depth 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UM At total depth 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UM 11. Present well condition summary Total depth: measured true vertical 10301 feet feet Effective depth: measured feet 10301 true vertical feet Casing Length Size Structural Conductor 20" 13-3/8' Surface I ntermed late 9 - 5 / 8" Production 7 - 5/8" Liner 5" Perforation depth: measured Plugs (measured) Junk (measured) Cemented NONE NONE Measured depth 2295# Poleset 2000 sx Fondu & 400 sx PF "C" 500 sx Class G 293 sx Class G 300 sx Class G 8864'-8936'8966'-9046', 9060'-9081 ' , 9100'-9112' , 9118'-9198' true vertical Tubing (size, grade and measured depth) 3-1/2", L-80 @ 8435' Packers and SSSV (type and measured depth) "DB" @ 9087' SSSV: Camco TRDP-1A 12. Stimulation or cement squeeze summary 80' 2654' 8076' 8788' 8484' Intervals treated (measured) a 11 13. pkr: 7-5/8" FHL @ 8420', 2,812" @ 2126' 5" FAB-'1 ¢ 8991' 8076' 8788' 8484' Form 10-404 Rev. 12-1-85 Prior to well operation 750 2625 38 50 380 Subsequent to operation 1100 3300 1 00 50 380 14. Attachments Daily Report of Well Operations [~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Technical Aide Date 6-30-88 Submitin-Duplicate Rue Verticaldepth 80' 2654' Treatment description including volumes used and final pressure Representative Daily Average Production or Inject¢~nO~ta Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure L2-6 IMBIBITION TEST 1. TEST L2-6 2. CONVERT L2-6 TO SOURCE WATER INJECTION. INJECT 5000 BBL SEAWATER IN 48 HOURS AND DISPLACE WITH LIFT GAS. 3. CONVERT WELL TO PRODUCTION. DIVERT L2-6 TO TEST SEPARATOR AND PUT ON PRODUCTION. INJECT 2 MMCFD LIFT GAS UNTIL WATERCUT DROPS BELOW 25%. INJECT 1 MMCFD LIFT GAS UNTIL WATERCUT STABILIZES BELOW 5%. SAMPLE PRODUCTION AND SHAKEOUT 6 TIMES PER DAY THEREAFTER. PERFORM 6 HOUR TEST DAILY FOR APPROXIMATELY 7 DAYS. 4. REPEAT STEPS 1 AND 2 FOR A TOTAL OF FOUR INJECTION/PROD- UCTION CYCLES. 5. PUT WELL ON FULL TIME INJECTION AFTER FOURTH PRODUCTION CYCLE. Oil & Gas Cons. Ancho~afie 5-24-88 DATE: FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Final for,:,¢L2-6 Injection Profile Temperature Survey 4-18-88 Run 1 5" Camco RECEIV 1. PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D&M EXXON STANDARD STATE OF ALASKA TRANSMITTIAL# 427 STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other E~ Wate~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] 2. Name of Operator ~oqat~"rbelevation (DF or KB) ARCO ALA,~,A ]:NC. feet 3. Address p 0 Box 100360 Anchorage Alaska 99510 6. Unit or Property name · ' ' Prudhoe Bay/Lisburne 7. Well number L2-6 8. Permit number 83-47 9. APl number 50--029-20930 10. Pool Lisburne Oil Pool 4. Location of well at surface 1320' FS1, 1320' FWL, Sec. 18, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 18, TllN, R15E, UM At effective depth 1320' FSL, 1320' FWL, Sec. 18, TllN, R15E, UM At total depth 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UM 10301 feet feet Plugs (measured) NONE 11. Present well condition summary Total depth' measured true vertical Junk (measured) NONE Effective depth: measured 10301 feet true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 20" 2295# Pol eset 80' 80' Surface 13-3/8" 2000 sx Fondu & 2654' 2654' 400 sx PF "C" Intermediate 9-5/8" 500 SX Class G 8076' 8076' Production 7-5/8" 293 SX C,t'.~ss G 8788' 8788' Liner 5" 300 SX 61ass 6 8484' 8484' Perforation depth: measured true vertical Tubing (size, grade and measured depth) 3-1/2", L-80 @ 8435' PER: 7 5 8 "FHL" @' 5" "FAB-I' Packers and SSSV (tyRe and measured deBth1---- /-" 8420', ~ 9087' SSSV: Camco TRDP-1A 2.812" e 2126' 12.Attachments Description summary of proposal ~3 Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation February 1, 1988 14. If proposal was verbally approved Subsequent Work Reported on , Name of approver Fozl~No./D'-rfD.~.Datedf~-/~----~;~/- -' '/ - --~'"~ Date approved Date 12- 20- 87 15. I herel~ certify that the foregoing is true and correct to the best of my knowledge Signed p~ ~~~~ Title Technical Aide Conditions of approval Approved by ORi61.NAt.. S!qNED BY Form 10-403 Rev 12-1-1~15INNI~: 6. ,SMITH Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP,Test [] Location clearanceI Approved Copy Returne~ .. i2'0mnSiSsion-e~ by order of the commission Date /-~ Submit in triplicate(~ INJ. ATTACHMENT 1 ARCO ALASKA INC. PROPOSES TO CONVERT LISBURNE WELL L2-6 TO WATER INJECTION FOR THE LISBURNE PILOT WATER- FLOOD. EXPECTED DATE OF CONVERSION IS FEBRUARY 1, 1988. RECEIVED JAN o ~ ~"~ Oil & Gas Cons. Commission Anchorage ALASKA OIL AND CONSERVATION COMMISSION / 3OOl PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 / . TELEPHONE (907) 279-1433 November 24, 1987 Telecopy No. (907) 276-7542 , ADMINISTRATIVE APPROVAL NO. 207.9 Re= Lisburne Southern Pilot Waterflood Project C H Robinson Sr Operations Engineer Lisburne ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Mr Robinson: By correspondence dated November 19, 1987 ARCO Alaska, InC requested approval to expand a pilot waterflood project in the Lisburne Oil Pool of the Prudhoe Bay Field approved April 17, 1987. The proposed pilot will evaluate injectivity, benefits of pressure maintenance, implementation strategies, and feasibility of waterflood operations in the Lisburne Oil Pool. The pilot will include an additional three injection wells (L2-6, L2-10, L2-16) and one producing well (L2-14) enclosing a pattern of approximately 320 acres drilled from the L2 drilling pad. Fluid injection into the Lisburne Oil Pool is governed by Area Injection Order No. 4 issued to ARCO Alaska, Inc on July 11, 1986. The Commission has determined the proposed pilot project to be a necessary step for the purpose of developing a prudent enhanced recovery method for the pool. The pilot project will not create waste, and is approved as proposed. In addition to the reports required by Title 20, Chapter 25 of the Alaska Administrative Code, a report summarizing the facts and progress of the project will be submitted every six months by the 20th day of the month following the reporting period. Sin. cerely, . ,~...."'"-- .... - i'._'"' .. ; .... Commissioner BY ORDER OF THE COmmISSION jo/3.AA207 ."---' STATE OF ALASKA ~'--. AL,..,~A OIL AND GAS CONSERVATION CO. ,IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska Inc. 52 ' RKB Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay/Lisburne 4. Location of well at surface 1320' FSL, 1320' FWL, Sec. 18, TllN, R15E, UM At top of productive interval 1320' FST,, 1320' FWL, Sec. 18, 711N, R15F., UM At effective depth 1320' FS~L 1320' FWL, Sec. 18, T11N, R15F., UM At total depth' 1320' FSL, 1320' FWL, Sec. 18, T11N, R15:E, UM 7. Well number f,2-6 8. Approval number 7-847 9. APl number 50-- 029-20930 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical 10301 feet feet Effective depth: measured 10301 true vertical Casing Length Size Structural Conductor 20" Surface 13-3/8" Intermediate Production 9-5/8" Liner 7-5/8" 5" Perforation depth: measured 9118'-9198', 8966'-9046', 8864'-8936' true vertical Plugs (measured) NONE feet feet Junk (measured) NONE Cemented Measured depth True Vertical depth 2295# Poleset 80' 80' 2000 sx Fondu & 400 2654' 2654' sx PF "C" 500 sx class G 8076' 8076' 293 sx class G 8788 8788 300 sx class G 8484 8484 , 9060'-9081', 9100'-9112' Tubing (size, grade and measured depth) 3-1/2", L-80 @ 8435' Packers and SSSV (type and measured depth) 7-5/8" FSL @ 8520', 5" FAB-1 @ 8991', DB @ 9087' SSSV: TRDP-1A 2.812 @ 2126' 12. Stimulation or cement squeeze summary Intervals treated (measured) Wahoo 4,5,6 znd 7 Treatment description including volumes used and final pressure RECEIVED 13. Representative Daily Average Production or Injection:3C~tt;aUII & GaS Cuns. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tu6ing Pressure Prior to well operation Subsequent to operation 721 3276 7 10 400 705 2975 35 50 406 Copies of Logs and Surveys Run [] 14. Attachments Daily Report of Well Operations 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed p¢_,~"~ L(~ ~.~ Form 10-404 Rev. 12-1-85 Title Technical Aide Datell-6-87 Submit in Duplicate (~ L2-6 ACID TREATMENT SUMMARY THE FOLLOWING PROCEDURE WAS PERFORMED BY ARCO ALASKA INC. ON 10-26-87 10 BBL DIESEL W/10% MUTUAL SOLVENT 54 BBL GELLED 15% HCL W/300 SCF/BBL NITROGEN 95 BBL DIESEL FLUSH W/300 SCF/BBL NITROGEN 159 BBL TOTAL LOAD RECEIVEI) NO'../ ~'"'" ~" z .-. ,z?~ Oil & Gas Cons. Commiss[..:: '" ~"F'!'1' ~'~ r STATE OF ALASKA "-'- ALA,--.,A OIL AND GAS CONSERVATION COk..~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] StimulateXl~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO ALA~/::, ]:NC. 3. Address P.O. BOX 100360 ANOHORA6E, ALASKA 99510 4. Location of well at surface 1320' FSL, 1320' FWL Se.c 18, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' Fk'L, Sec. 18, T11N, R15E, UM At effective depth 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UiVl At total depth ]320' FSL. 1320' FWL. Sec. 18. T11N: R15E: UM 5¢i D~v~;m elevation (DF or KB) 6. Unit or Property name PRUDHOE BAY/L]:SBURNE 7. Well number L2-6 8. Permit number 83-47 9. APl number 50-- 029-20930 10. Pool Lisburne 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10301 feet feet 10301 feet feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9118'-9198', true vertical Size 20" 13-3/8'' 9-5/8" 7-5/8" 5" feet Plugs(measured) ~,~,E~~ ,-.-,---,--:;-? Junk (measured) ~. ):.., i c. - ~ta¢~ 0i~ & G~s Oo~s. 6om~issi0~ Cemented Measured ~86pth A~O~g~ertical depth 80I 2654 8O76 8788 8484 2295# Poleset 80 20C'0 sx Fcndu & 4002654 sx PF "C" 500 sx class 6 8076 293 sx class G 8788 300 sx class G 8484 Tubing (size, grade and measured depth) 8966'-904.6' 8864'-8936' 9060'-9081' 9100'-9112' 3-1/2" L-80 ~, 84351 , "DE" 6 9087' Packers and SSSV (type and measured depth) 7-5/8" "FHL" @ 8420 5I' "FAB-11' @ 8991, SSSV I'RDP-1A 2_,R12 0 2126' 12.Attachments Description summary of proposal~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation Uctob~r 26, 1987 Date approved 10-26-87 14. If proposal was verbally approved Name of approver Bi l l Barnwel 1 Date 10-26-87 15. I here%certify that the foregoing is true and correct to the best of my knowledge Signed F~,~ L(~F")~~f Title Technical Aide Conditions of approval Commission Use Only Notify commission so representative may witness i ApprovalNo. [] Plug integrity [] BOP Test [] Location clearance by order of Approved by ~:/ ~!:i:, ~.- .--~ :;.~ Form 10-403 Rev 12-1-85 ........... Commissioner the commission Date//~) "'c~ ~ Submit in triplicate I/~' L2-6 ARCO ALASKA INC. PROPOSES TO STIMULATE WAHOO 4,5,6 & 7 AS FOLLOWS. 1. 10 BBL DIESEL PRE-FLUSH 2. 50 BBL 15% GELLED HCL ACID-NITRIFIED W/500 SCF/BBL 3. 95 BBL DIESEL FLUSH-NITRIFIED W/300 SCF/BBL "--'- STATE OF ALASKA AL, ,{A OIL AND GAS CONSERVATION CC AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging ~ Perforate [] Pull tubing ~/ WELL NAME CHANGE Alter Casing ~ Other ~ 2. Name of Operator ARCO Alaska, Inc, 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1320' FSL, 1320' FWL, 5ec.18, T11N, R15E, UN At top of productive interval 1320' FSL, 1320' FWL, 5ec.18, T11N, R15E, UN At effective depth 1320' FSL, 1:320' FWL, Sec.18, T11N, R15E, UN At total depth 1320' FSL¢ 1320' FWL~ 5ec.18~ T11N¢ R15E~ UN 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing 5. Datum elevation (DF or KB) RKB 51,5' 6. Unit or Property name Prudhoe Bay Unit/Lisburne Perforation depth: measured true vertical 7. Well number L2-6 8. Approval number ,% 9. APl number 50-- 029-20930 10. Pool Lisburne Oil Pool Length Size Cemented Measured depth ARCO Alaska, Inc. has changed the well number designation from "South Point'State #1" to "L2-6". Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure N/A 13. Prior to well operation Subsequent to operation True Vertical depth RECEIVED 1 6 1987 Alaska Oil & Gas Cons. C0mmissi0ri Anchorage Representative Daily Average Production or Inj, ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments None Daily Report of Well Operations [] Copies of Logs and Surveys Run that the foregoing is true and correct to the best of my knowledge 15.1 hereby certify / Form 10-404 Rev. 12-1-85 (JG) SW02/99 Feet Signed ~ t~)/~/]f j ..¢<~/!/R'..~ , Title Associate Engineer Date /0-~, -(.~7 Submit in Duplicate AI~CO AL~ INC. LISBURNE ENGINEERING Date: July 16, 1987 From: Para Lamber Enclosed are the following: CH Finals for LiSburne Wells L2-6 Base Line Temp Log 6-17-87 Run 1 5" Camco ~ L3-18 Temp GR Log 6-17-87 Run 1 5" Camco L3-24 Flopetrol Production Logging 5~2-87 Run 1,2,3,4 5" Sch ~Gas VCon ~s. Co'remission Anchorage Received by: Please sign and return to~Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 263 STATE OF ALASKA ALASKa-, OIL AND GAS CONSERVATION COMMfoSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 3. Address P. O. Box 100_~60 Anchor'a_ne; Al( 99~,10 4. Location of well at surface 1320'FSL, 1320'FWL, Sec.18, T11N, R15E, UM At top of productive interval 1320'FSL, 1320'FWL, Sec.18, T11N, R15E, UM At effective depth 1320'FSL, 1320'FWL, Sec.18, T11N, R15E, UM At total depth 1320'FSL, 1320'FWL, Sec.18, TllN, R15E, UM 5. Datum elevation (DF or KB) 51 . 5 ' RKB feet 6. Unit or Property name Pr,,Hhn~ Ray IIn4'~/I i_~hl,rn~ 7. Well number 8. Permit number 83 -47 9. APl number 50-- 029-20930 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth SEE WELL COMPLETION REPORTz_pATED 11/14/84 True Vertical depth true vertical Tubing (size, grade and measured depth) APR I0 Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal'~ Detailed opeC~l,,f.~0~,~:~ogram [] BOP sketch [] 13. Estimated date for commencing operation As soon as possible 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~'~A,~ _~~ Title Ass°cia'ce Engineer J Commission Use Only (JG) SA/001 Date Conditions of approval Approved by NOtify commission so representative may witness [] Plug integrity I Approval No. [] BOP Test [] Location clearance by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate SOUTH POINT STATE #1 ARCO Alaska, Inc., proposes to change the well number designation from "South Point State #1" to "L2-6". SA/O01 a :tw ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 3OOl PORCUPINE DRIVE · December 19, 1985 / ANCHORAGE, ALASKA 99501-3192 _ / TELEPHONE (907) 279-1433 A D M I N I S T R A T I V E A P P R O V A L NO. 196.2 Re: The request for extension of long-term testing of the ARCO Alaska, Inc. well L2-6 (South Point State No. 1). Mr. Ben Kawakami Operations Coodinator Lisburne Operations ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Dear Mr. Kawakami: By letter dated December 4, 1985, ARCO Alaska, Inc. requests the Alaska Oil and Gas Conservation Commission to approve the continued testing of the L2-6 well through 1986. Continued testing will provide data needed for efficient field development and maximization of oil recovery. The Commission is in agreement with the need for more data. Conservation Order No. 196 and Administrative Approval No. 196.1 were issued to cover the previous testing of this well. Therefore, pursuant to Rule 5 of Conservation Order No. 196, Rule 1 of said Conservation Order is amended to read: Rule 1 Long Term Production Test A six month production test of South Point State Well No. 1 (L2-6) may be conducted. A second long term production test may be conducted during calendar year 1985. Additional long term production tests of well L2-6 may be conducted throughout calendar year 1986. Yo~s very t~Tuly, Lonnie C. 'Smith Commissioner BY ORDER OF THE COMMISSION be:3:AA196 -_ ARCO Alaska, Inc. ARCO Explora,...n - Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 S,'~4PLE TILkNS~4ITTAL SHIPPED TO: State of Alaska DATE' October 28, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 OPERATOR- Arco S;%~P LE TYPE' Sk\IP LES SENT: dry ditch 8240 - 8990 9000 - 9600 NkX~lE- SouthPoint St. #1 N~.IBER OF BOXES- 2 SHIPPED BY' " ' ' '~'~,"] / UPON ~CE~PT 0F THESE S~4PLES, PLEASE NOTE ~Y D~SCREP,~NCZES AND COPY OF TH~S FODI T0: RECEIVED BY- ARCO ALASICa~, INC. P.O. BOX 100360 ,adXlCHORAGE, ALASKA 99510 ATTN: Paleo Lab ,. ABV/100 DATE' Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ARCO Exploration - Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 October 24, 1985 Michael T. Minder 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE' October 2, 1985 request for Cutting and Core Samples from ARCO PBUL2-6 (S.Pt. St. #1) Dear Mi ke' So. PT. St. #1 was drilled to a depth of 10,301', however, Core #34 from 10263-10301 stuck in the hole and was never recovered. Dried ditch samples from 8850-9600' are being sent to you. No ditch samples were collected below 9600' due to the high concentration of metal filings from the casing. If you have any further questions on this matter, please contact Dave Shafer, Well Site Geologist for this well, at 263-4594. Sincerely, Teresa A. Gorup Paleo Lab Supervisor TG 'ml cc' Dave Shafer RECEIVED OCT 2 5 Alas~ 011 & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, thC., post Office B~, 0360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 September ~6, 1985 r C V. Chatterton · M · ' _~ Alaska _ _serVation Co~0miss~°n state o~_.~ ~d Gas con 3001 po~ ~ e AK 99501 Monthly Report of Anchorag ' ~ 28, and.L3 8 _. ~n-6, L2 24, __ onerah~onS ~' Drilling . over operations -teflon: . -.n~ and work and L3-8 for Dear Mr- Chat _ _ o~nort of Dr~11~%~24, 52-28, ~,es%iOnS or complet~°~j~2se feed Very truly yourS, j. L. BarriS Area operations Engineer JLH: ~K: c lh ~H03-2 Attachment CC: j. S. DaytOn J. j. Guerrer° S. Hasund RECEIVED ocr o 4 Alaska Oil & 6as Cons, Commission Anchorage ARCO Alaska, Inc. is a subsidiary ot AttanticRlchfleldc°mparty ' ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY REPORT C'"' DRILLING AND WORI ')VER OPERATIONS 1. Drilling well [~ Workover operation,~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-47 ' 3. Address 8. APl Number P. O. Box 100360 Anchorage, AK 99510 50-029-20930 4. Location of Well at surface 1320' FSL, 1320' FWL, Sec. 18, TIlN, R15E, ~ 5. Elevation in feat (indicate KB, DF, etc.) 51.5' RKB 6. Lease Designation and Serial No. .ADL 28321 AKL 2319 9. Unit or Lease Name Prudhoe Bay Unit-Lisburne 10. Well No. L2-6 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool For the Month of August ,1985 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run RECEIVED OcT o 4 985 Alaska Oil & Qas Cons. Ar~chor~g° Con~missioo 16. DST data. perforating data, shows of H2S, miscellaneous data Ran Pressure and Temp. profile across perforated interval (8864' - 9198') with well flowing at 1900 BOPD avg. POOH making gradient stops. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--R/~o¢o/n tills form is required for each calendar month regardless of the status of operations and must be filed in duplicate Oil and (3Vas C~nservation Commission by the 15th of the succeeding month, unless othervvisedirected. ' with the Alaska Form 10-404 Submit in duplicate Re.v. 7-1-80 October 2, 1985 ~ks. Teresa A. Gorup ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 RE: Cutting & Core Samples for AP4~O PBU L2-6 (So. Pt. St. #1) Dear Teresa Our records indicate that the subject well was drilled to a total depth of 10301'. We ~have received dried ditch samples from 2670' - 8230' and core chips from 8850' - 10263'. ~uld you please furnish the remaining ditch sample from 8230' on mud the chips from the cored interval 10263' - 10301'. Since this well data has been recently released from confidential status, please consider it as heading the list in order of priorities. Ihanks for your assistance. Sincerely, }-,~chael T. Minder Petroleum Engineer dlf :A. M~-~I. 15 ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL State of Alaska To: Alaska Oil & Gas Conservation From: Kelly Prockish Commission Address: 3001 Porcupine Drive Date: September 13, 1985 Anchorage~ AK 99501 Attn: C. V. Chatterton Transmitted herewith are the following: Final Logs for Lisburne Well L2-6: .(1 each Blueline, Folded Sepia) Temperature Log, Run One, 8-22-85 (Camco) Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, AT0-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: ~-~/ ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany ~...~'~'~ ARCO Alaska, Inc. Post Office B~.~ 100360 Anchorage, Alaska 9951'0 Telephone 907 276 1215 August 27, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: South Point State #1 Dear Mr. Chatterton' Enclosed is a copy of the South Point State #1 inclination survey. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L21 Enclosure cc: Well File RECEIVED Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany SOUTH POINT STATE #1 INCLINATION SURVEY DEPTH 609' 1400' 2667' 3212' 3705' 4199' 4724' 5249' 6364' 6644' 7140' 8240' 8791' 8810' 8911' 8926' 9113' 9146' 9205' 9372' 9409' 9518' 9648' 9767' 9827' 9946' 9977' 10,208' ANGLE .5° 1.25° 1.75° 1.5° 1.25° .25° 1.5° 1.25° 1.0° 1.5° 1.75° 1.25° 1.75° 1.25° 2.0° 2.25° 2.5° 3.0° 2.5° 2.75° 1.25° 2.0° 2.0° 2.25° 2.0° 2.25° GRU11/02: tw 08~26~85 RECEIVED AUG 2 9198,5 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of Alaska Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine Drive From: Kelly Prockish Date: August 13, 1985 Anchorage~ AK 99501 Attn: C.V. Chatterton Transmitted herewith are the following: Final copies for Lisburne Well L2-6: (Gearhart) Continuous Flow Hydro Fluid Density Log Run One, 7-5-85 (1 each Blueline, Folded Sepia) Receipt Acknowledgement: Return Receipt to: ARCOAlaska Inc. New Projects - Lisburne Attn: Kelly Prockish, AT0-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 ~-:::,"'~. ~,, ,~ ~,:,s Cons. Commission Transmittal No.: //~/ Processed by: ~~ ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of A~aska Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine Drive From: Kelly Prockish Date: August 6, 1985 Anchorage, AK 99501 Attn: C.V. Chatterton Transmitted herewith are the following: Final copies for the following Lisburne Wells: L2-6: Pressure Data Flowing Survey, 7-5-85 (Gearhart) L1-9: Pressure Data Flow & Static for Tie-In, 7-24-85 (Gearhart) Receipt Acknowledgement: Return Receipt to: /~O Alaska Inc. ~'~--New Projects - Lisburne Attn: Kelly Prockish, AT0-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 '~C~Orape' OUrrlrni$$ior~ Transmittal No.: /~z~ . ~ ARCO Alaska. Inc. is . Subs'dia y o tat'c'c' p y ~'~t/~'~ ~!~ STATE OF ALASKA ALASKA ,F--:? AND GAS CONSERVATION CC'" "MISSION SUNDRY I'ICES AND REPORT-% JN WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Al&skar Inc. 3. Address P. O. Box '100360 Anchorage, Ak. 995]0 4. Location ckf Well Surface Loc. 1320' FSL,1320' FWL,Sec:18,T-11N,R-15E 7. Permit No. Bottomhole Loc. Same as above 83-47 8. APl Number 50- 029-20930 9. Unit or Lease Name 10. Well Number L. &-..~ 5. Elevation in feet (indicate KB, DF, etc3 RKB 51.5' Pad 1!_5' 6. Lease Designation and Serial No. ADL 28321 12. 1 PRB Field/Lisburne Lisburne Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other J~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed Or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Change name of subject 'well from South Point State No. 1 to L2-6. This change is needed to allow the Lisburne delineation wells to be incorporated into the well nomenclature that is planned as part of the full Lisburne field development. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ORII~iNA[ SI~-~ED Title ~pp~-oved C~,~ ~,~t u r r'~cl Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "intentions" mn Triphcate and "Subsequent Reports" in Duplicate ALASKA OIL. AND ~AS f, ONS[~¥ATION-f, OHMISSION Bill She#ield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALAgKA 99501,1-31~2 TELEPHONE(g07) 270,'1433 / '- / Permit No. gZ-- ¢7 We wish to bring to your attention that the Co~ission has no~ yet received the following required items on the subject well which our records indicated was completed _~-~--~ " / Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. erelz C. V. Chatter~on~ Chairman lc:C.024 ARCO Alaska, Inc. i' Post Office B-,.,^' ~!00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: C. V. Chatterton Chairman Dear Sir: Attached are copies of the correlation coregraph on the following three Lisburne wells: t-S°~th-:POint State N°. 1 South Bay State No. 1 Pingut State No. 1 We request that this informatiom is maintained as confidential. If additional assistance is required, please do not hesitate to call. Sincerely, Sr. Area Engineer DKC:DR :j~'p Attachments A/°F: 1 6 Gas Cons. C0mrnJss~on Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichlieldCompany ALASKA OIL AND OAS CONSERVATION COMMISSION Date: / / / / TTanomittzz_ via Re: Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501;31'92 TEL EPHONE (907) 279.-1433 the following: Quant i ty b - (~-- ~ "o/~ k.~" Description of Item ~oo_ ,,' ~,,,,,, ~ Please acknowledge receipt by signing and returning one copy of this letter. 8±gned: .k.~.~~ Yours very truly, Dated: .~_~,-' 7-C~~-' ALAS~ OIL & GAS CONSERVATION C0~ISSION ~) L fi b~& U ALASKA OIL AND OAS CONSERVATION COMMISSION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501~-3192 TELEPHONE (907) 279.-1433 Quantity Please acknowledge receipt by Description of Item -. signing and returning one the following: copy of this letter. Signed: Dated: Yours very truly, ALASKA OIL & GAS CONSERVATION COMMISSION ALASKA OIL AND GAS CONSERVATION COMMISSION December 11, 1984 Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 TELEPHONE (907) 279-1433 A D M I N I S T R A T I V E A P P R O V A L NO. 196.1 Re: The request for an exception to the 2000:1 gas-oil ratios limitation to permit an additional long term test of the ARCO Alaska, Inc. No. 1 South Point State well. Mr. John S. Dayton Regional Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Dear Mr. Dayton: By letter dated November 20, 1984, ARCO Alaska, Inc. has informed the Alaska Oil and Gas Conservation Commission of its intention to conduct an addition test of six months or longer on the subject well and requests an exception to the limitation of a 2000-to-one gas-oil ratio during the test. It is stated that more test data is needed to more efficiently develop the field and insure a maximum recovery. The Commission is in agreement with the need for more data. Conservation Order No. 196 was issued to cover the previous testing of this well and, is amendable to provide for the requested exception to the limitation of a 2000-one gas-oil ratio for an additional production test. Therefore, pursuant to Rule 5 of Conservation Order No. 196, Rule 1 of the same Conservation Order is amended to read: Rule 1 Long Term Production Test A six month production test of South Point State Well No. 1 may be conducted. A second long term production test may be conducted during calendar year 1985. Yours very truly, Harry W. Kugler f Commis s ioner ,~ BY ORDER OF THE COMMISSION be: 1 :AA196 ARCO Alaska, Ir* Post Offic~ dox ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~' November 20, 1984 Mr. C. V..Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Intent to Commingle Production for Long Term Test at South Point State ARCO Alaska, Inc. gives notice to AOGCC of our intent to commingle hydrocarbon production from the Lisburne formation with similar production from the Sadlerochit formation during a long term production test at South Point State No. 1. This notification is in accordance to Regulation 20 ACC 25.215. The test, which is expected to begin in the first quarter of 1985 and continue for a minimum of six months, will involve surface commingling of Lisburne and Sadlerochit production at Prudhoe Bay Unit Drillsite No. 18. This extended test is the same as previously proposed in which permission to flare gas and produce at GORs in excess of 2000 SCF/STB was granted (Conservation Order No. 196, dated February 6, 1984). After additional analysis, we feel it would be more constructive to commingle the production prior to metering. This configuration will still allow for the procurement of necessary production information while eliminating the need to flare the gas flashed from the oil as it dropped from separator to stock tank conditions. We plan to utilize a flowline between South Point State No. 1 and Drillsite No. 18 to flow Lisburne production into the Sadlerochit facilities (see attached diagram). Production from the well will be measured on a periodic basis to determine the quality and quantity of produced fluids, using equipment and techniques acceptable to the Commission, such as AP1 Standards, Recommended Practices, and Specifications. This procedure adheres to Regulation 20 ACC 25.215 which states "On the surface, the production from one pool may not be commingled with that from another pool except when the quantities from each source of the production are determined by periodic well tests or other measurements." ~ :,'[CEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 0 I I NOV 2 81t! ~'j~ 4, Pas Cons. Commissior Mr. C." ~tterton Novembe~ 2u, 1984 Page 2 The well is expected to produce 220,000 STB of oil and an estimated 440 MMCF of gas during the test. The gas-oil ratio is expected to be below 2000 SCF/STB initially but to increase to over 2000 SCF/STB by the end of the test. As such, the sanctioned waiver of regulation 20 ACC 25.240 which states that "an oil well may not be produced at gas-oil ratios in excess of 2000 SCF/STB without gas reinjection into the reservoir" is still required. The produced Lisburne gas will not be reinjected, however, it will be substituted for Permo-Triassic gas and utilized as fuel within the Prudhoe Bay Unit. As stated in the original letter of request (please find attached), the longest sustained production tests to date in the Lisburne reservoir have been two month tests performed at several other Lisburne wells. The tests were only long enough to give hints of potential operational and GOR problems. Also, no decline data was obtained during the relatively short tests. While sufficient productivity and reservoir data has been obtained to justify an initial development, additional data is needed to most efficiently develop and maximize recovery from this complex reservoir. A long term test in the 1985 time frame would provide data which could be incorporated into facility design and reservoir evaluation to allow timely and efficient development of the Lisburne reservoir. In summary, ARCO Alaska, Inc. gives notice to the AOGCC of its intent to commingle hydrocarbon production at the surface during an extended Lisburne flow test. Commingling will eliminate the need to flare Lisburne gas; however, the previously granted waiver of the 2000:1 GOR limitation is still required. If you have any questions or comments, please call me at 265-4206. I would be happy to drop by and discuss this matter with you at your convenience. Sincerely, J S. Dayton JSD/JMR/dy cc: K. Brown, Director of Division of Oil and Gas G. S. Goss, Exxon File: LIE4-2(2), L1E120-1 RECEIVED NOV 2 8 Alaska 0il & Gas Cons. Commission Anchorage 'INSULATED & HEATRACED SPS #1 WELLHEAD CHOKE f~ SOUTH POI NT 2 MMBTU/HR CRUDE HEATER I ! I 4" PIPELINE TO DSI8 INSULATED I ! I ! TEST SEPARATOR1 DSI8 SOUTH POINT SIMPLIFIED FLOW DIAGRAM SOUTH POINT ST. # I EXTENDED PRODUCTION TEST '711884002 REV. ARCO Alaska, inc----,-' Post Offic~ ... ,~0 Anchorage, Alaska 99510 Telephone 907 277 5637 December 16, 1983 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Flare Request for Long Term Test at South Point State No. 1 ARCO Alaska, Inc. requests AOGCC permission to flare hydrocarbon gas during a long term production test at South Point State No. 1 and produce during the test period at GOR's in excess of 2000:1 SCF/STBD. The test is expected to begin in the first quarter of 1983 and continue until mid-1985 (approximately 18 months). The test will provide long term production decline data and GOR performance in a timely fashion for "optimizing development planning" of full field development of the Lisburne reservoir. A test facility which was installed for the two-month production test at SPS #1 will be used for the long term test. The facility includes a f!owline between SPS ~Jl and Drill Site No. 18 to allow sending Lisburne production into the Sadlerochit facilities for processing. In order to nse the Drill Site No. 18 facilities, the SPS #1 test separator has to be operated at pressure greater than 300 psi. Under this mode of operation, most of the produced gas is sent to Drill Site No. 18, but a small flare is needed to handle the gas which flashes off of the stock tank oil as it is reduced from separator pressure. For the long term test, this amount is expected to be 60 M~SCF of gas, or about 4% of the total gas production. The well is expected to produce about 600,000 STB of oil and an estimated 1200 ~$CF Of gas during the test. The gas-oil ratio is expected to be below 2000 SCF/STB initially but increase to over 2000 SCF/STB by the end of the test. Regulation 20 AAC 25.240 states that "an oil well may not be produced at gas-oil ratios in excess of 2000 SCF/STB without gas reinjection into the reservoir". Based on the importance of long term production data in order to properly size major production facilities associated with the development of the Lisburne reservoir, we also request a waiver from the above mentioned regulation. Mr. C. V. Chatterton December 16, 1983 Page Two The longest sustained production tests in the Lisburne reservoir to date have been two month tests performed at West Bay State No. 1 and South Point State No. 1. The tests were only long enough to give hints of potential operational and GOR problems and no decline data at all was obtained during the relatively short tests. Although sufficient productivity and reservoir data has been obtained to justify an initial development, additional data is needed to most efficiently develop and maximize recovery from this complex reservoir. A long term test in the 1984/1985 time frame would provide data which could be incorporated in facility design and reservoir evaluation to allow timely and efficient development of the Lisburne reservoir. If you have any questions or comments, please call me at 263-4206. I would be happy to drop by and discuss this matter with you at your convenience. Your very truly, J. S. Dayton Regional Engineer aSD/dy cc: R. K. Doughty, AT0-1988 S. Hasund, AT0-1826 D. K. Chancey, AT0-1828 RECEIVED hDV 2 Oil & Gas Cons. Commission Anchorage ARCO Alaska, Post Oft,~_ B~,,,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton, Enclosed are the requested revisions to South Point State #1, Pingut State #1, and South Bay State #1. Category #30 (Formation Tests), now includes intervals tested, quantities, flow times, shut-in times, and identifies fluids. The daily break down of drilling activities (well histories) are not included. These were submitted with original Well Completion Reports. If you have any questions, please call me at 263-4601. Sincerely, · S~ ,~,~.'~ ~ '~ ' ' ~ ~ineer JFM/DRN/tw DRN/98 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASf. -~ _ -AND GAS CONSERVATIO~' ' ~IISSION WELL COMPLETION' OR RECOMPLETIUN I: PORT.AND LOG 1. Status of INell Classification of Service Well CONF I DENT I AL REV I $ I ON OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator C0~I~1~=I~,~J~1~ 7. Permit Number ARCO Alaska, Inc. 83-47 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20930 4. Location of well at surface 9. Unit or Lease Name 1320' FSL, 1320' FWL, Sec.18, TllN, ELSE, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number Sec.18, TllN, R15E, UM 1320' FSL, 1320' FWL, At Total Depth 11. Field and Pool 1320' FSL, 1320' FWL, Sec.18, T11N, R15E, UN Prudhoe Bay Field/Lisburne 5. Elevation in feet (indicate KB, D~, etc.) I 6. Lease Designation and Serial No. Li sburne 0i ] Pool 51.5' RKB, 11.5 PadI ADL 28321 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/0#/83. 06/02/83 8/8/83-I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10301 'MD & TVD 9525'ND & TVD YES [] NO I~ . 2126feetMDI 1900' (Approx) 22. Type Electric or Other Logs Run SEE ATTACHED SHEET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT pULLED 20" 91.5# H-40 Surf 80' 30" 2295# Pol eset 13-3/8" 72.0# L-80 Surf 2654' 17-1/2" 2000 sx Fondu + 400 sx 'F "C" 9-5/8" 47.0# N-80 Surf 8076' 12-1/4" 500 sx Class "G" cmt + ;00 sx PF "C" 7-5/8" 33.7# S-95 7712' 8788' 8-1/2" 292, sx Class "G" cmt 5" 18.0# S-140 8484' 10150' 6-1/2" 300 sx Class "G" crrlt 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) 9118' - 9198' 3-1/2" 842,5' 8420' 8996' - 9046' 8864' - 8936' w/1 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 9060' - 9081 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9100' - 9112' 10,020' - 10~038' 112 sx Class "G" cmt 8973' - 8983' 9930' - 9980' 112 sx Class ,,G,, cmt 9930' - 9980' 60 bbl 15% HCL acid 9628' - 9730' 16Z sxs £1a.~.~ "C" ~mtt_ 27. N/A PRODUCTION TEST (see attached Sheet) Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OI'L 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. See Core Data Sheet · . Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/~C19 CONTINUED ON REVERSE SIDE ::...-, .- ~: ;.~..~.- GEOLOG1CMARKERS '_".." :. .... '~:~'-~ . ii "~i.'-:i?"'.~-:- ,;;. FORMATION TESTS. . , · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VER~. DEPTH GOR, and time of each phase. · . Alapah 9628' 9576'. (SS) , DST #1: f/10020'-10038'(MD), 9968'-99~6'(55), Wahoo III 9118' 9066' 'iSS)" ' 10 bbls in 1.8 hfs (fluid level increase; Wahoo il 8996' 8944' (SS) no production to surface), 100% H20, SI Wahoo I 8864' 8812' (SS) time: 10.5 hrs. DST#2: f/9930'-9980'(MD), 9878' -9928' (SS), 55 bbls in 43.8 hrs, 70% H20, 30% oil, SI time: 11 hrs. DST#3: f/9628'-9730' (MD), 9576' -9678' (SS), 3 bbls in 1.6 hrs.,(fluid level increase; no production to surface), 100% H20, SI time: 10 hrs. DST#4: f/9118'-9198' (MD), 9066' -9146' (SS), 1335 bbls in 35.7 hrs, 72% oil, 28% H20, SI time: 28 hrs. DST#5: f/8996'-9046'(MD), 8944'-8994' (SS), 7 bbls in 1.2 hrs., (fluid level increase; no production to surface), oil/H20/LCM Emulsion, SI time: 16 hrs. DST#6: f/8864'-8936'(MD), 8812'-8884' (SS), 75 bbls in 6.2 hrs, 88%.oil, 8% H20, 4% 31. LIST OF ATTACHMENTS Basic Sediment, SI time: 10 hrs. We!! History~ Page 2 of Well Cnmpl~-tlnn Rernnr~-. £nr~- 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~j~ ~ Area Drilling Engr. Signed~~-- ~~~'Fit I e 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~,07 South Point State #1 Section 22: DIL/BHCS/GR/SP LDT/CNL/Gr/Cal DIL/MSFL/GR LDT/CNL/NGT/Cal LSS/GR LDT/EPT/GR DIL/BHCS/GR FDC/GR GR/CCL CET CBL DIA-Log Attachment #1 Section 26 continued: 9084' - 9086': 160 sx Class "G" cmt. 9118' - 9198': 95 bbl 15% HC1 acid. 9204' - 9206': 100 sx Class "G" cmt. 9084' - 9086': 160 sx Class "G" cmt. 8988' - 8990': 175 sx Class "G" cmt. DRN/WC1 9b: tw South Point State #1 Core Data Core 1 8850' - 8862' Core 21 9588 - 9648 Core 2 8862' - 8895 Core 22 9648 - 9708 Core 3 8895' - 8954 Core 23 9708 - 9767 Core 4 8954' - 8993 Core 24 9767 - 9827 Core 5 8993' - 9013 Core 25 9827 - 9886 Core 6 9013' - 9020 Core 26 9886 - 9946 Core 7 9020' - 9058 Core 27 9946 - 9997 Core 8 9058' - 9114 Core 28 9997 - 10027' Core 9 9114' - 9146 Core 29 10027 - 10087 Core 10 9146' - 9190 Core 30 10087 - 10102 Core 11 9190' - 9207 Core 31 10102 - 10162 Core 12 9207' - 9248 Core 13 9248' - 9273 Core 32 10162 - 10208 Core 33 10208 - 10263 Core 14 9273' - 9312 Core 34 10263 - 10301 Core 15 9312' - 9372 Core 16 9372' - 9410 Core 17 9410' - 9460 Core 18 9460' - 9518 Core 19 9518' - 9546 Core 20 9546' - 9588 Limestone and dolomite with minor chert and shale. Poor to excellent oil shows. DRN/WC19c:tw South Point State #1 Section 22 DIL/BHCS/GR/SP LDT/CNL/Gr/Cal DIL/MSFL/GR LDT/CNL/NGT/Cal LSS/GR LDT/EPT/GR DIL/BHCS/GR FDC/GR GR/CCL CET CBL DIA-Log Attachment #1 Section 26 continued: 9084' - 9086': 160 sx Class "G" cmt. 9118' - 9198': 95 bbl 15% HCl acid. 9204' - 9206': 100 sx Class "G" cmt. 9084' - 9086': 160 sx Class "G" cmt. 8988' - 8990': 175 sx Class "G" cmt. DRN/WC1 9b: tw South Point State Core Data Core 1 8850' - 8862' Core 2 8862' - 8895' Core 3 8895' - 8954' Core 4 8954' - 8993' Core 5 8993' - 9013' Core 6 9013' - 9020' Core 7 9020 - 9058' Core 8 9058 - 9114' Core 9 9114 - 9146' Core 10 9146 - 9190' Core 11 9190 - 9207' Core 12 9207 - 9248' Core 13 9248 - 9273' Core 14 9273 - 9312' Core 15 9312' - 9372' Core 16 9372' - 9410' Core 17 9410' - 9460' Core 18 9460' - 9518' Core 19 9518' - 9546' Core 20 9546' - 9588' Core 21 9588 - 9648 Core 22 9648 - 9708 Core 23 9708 - 9767 Core 24 9767 - 9827 Core 25 9827 - 9886 Core 26 9886 - 9946 Core 27 9946 - 9997 Core 28 9997 - 10027' Core 29 10027 - 10087 Core 30 10087 - 10102 Core 31 10102 - 10162 Core 32 10162 - 10208 Core 33 1 0208 - 1 0263 Core 34 .10263 - 10301 Limestone and dolomite with minor chert and shale. Poor to excellent oil shows. DRN/WC19c: tw · ARCO Alaska, In~ Post Office aox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 17, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Reports for South Point State #1, Pingut State #1, and South Bay State #1. Please excuse the delay in filing and I hope it has not inconvenienced you in any way. Sincerely, T. L. Fithian Area Drilling Engineer TLF/DRN/tw DRN/81 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA . ~'AND GAS CONSERVATION'~ ~-~"'/llSSlON ELL COMPLETION OR RECOMPLETION REPORT AND LO ,, 1. Status of Well Classification of Service Well CONF I DENT i AL OIL ~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-47 , 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20930 4. Location of well at surface ¢6~1~I~9%t~~i1~. 9. Unit or Lease Name ~ 1320' FSL, 1320' FWL, Sec.18, T11N, RISE, UN Prudhoe Bay Unit/Lisburne . At Top Producing InterVal 10. Well Number 1320' FSL, 1320' FWL, Sec.18, TllN, R15E, UM South Point State #1 At Total Depth 11. Field and Pool 1320' FSL, 1320' FWL, Sec.18, TllN, R15E, UM Prudhoe Bay Field/Lisburne 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 51.5' RKB, 11.5 Pad ADL 28321 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 04/04/83 06/02/83 8/8/83 N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey ] 20. Depth where SSSV set I 21. Thickness of Permafrost 103,01'MD & TVD 9525'ND' & TVD . YES [] NO [] 2126 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run SEE ATTACHED SHEET 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# U-40 Surf 80' 30" 2295# Pol eset 13-3/8" 72.0# L-80 Surf 2654' 17-1/2" 2000 sX Fondu + 400 sx F F "C" 9-5/8" 47.0# N-80 Surf 8076' 12-1/4" 500 sx Class "G" cmt + 300 SXS [PF "C" 7-5/8" 33.7# S-95 '7712' 8788' 8-1/2" 293 sx Class "G" cmt 5" 18.0# S-140 8484' 10150' 6-1/2" 300 sx Class "G" emt 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) 9118' - 9198' 3-1/2" 8435' 8420' 8996' 9046' 8864' 8936' w/1 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 9060' 9081' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9100' 9112' 10~020' - 10~038' 112 Sx Class "G" cmt 8973' 8983' 9930' - 9980' 112 sx Class "G" cmt 9930' - 9980' 60 bb] 15% HCL acid 9628' - 9730' 162 SXS Class "G" cmt 27. N/A PRODUCTION TEST (see attached sheet) Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE iGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE a~' 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Core Data Sheet ~-~',: _~.,, _. !. ~/-::-""""/ "'¢"" 4..-. ' 4 ,, Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/~C16 CONTINUED ON REVERSE SIDE 29. : ' " ' 30:' ' -. GEOLOGIC MARKERS ' ' ~: ' ~' ' 'FbRMATIONTEsTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alapah 9628-' 9576' (SS}. DST #1: f/10020'-10038'(MD), 9968'-9986' (SS), Wahoo Iii 9118' 9066' (SS) 10 bbls in 1.8 hrs (fluid level increase; Wahoo il 8996' 8944' (SS) no production to surface). ~ Wahoo I 8864' 8812' ('SS). DST#2: f/9930'-9980' (MD), 9878'-9928' (SS), . _:. ~:- ' 55 bbls in 43.8 hfs · "'.." [~ST#3: f/9628'-9730' (MD), 9576'-9678' (SS), 3 bbls in 1.6 hrs.,(flui.d level increase; : no production to surface). DST#4: f/9118'-9198' (MD), 9066'-9146' (SS), ~ 1335 bbls in 35.7 hrs. DST#5: f/8996'-9046'(MD), 8944' -8994'(SS), 7 bbls in 1.2 hrs., (fluid level increase; no production to surface). DST#6: f/8864'-8936'(MD), 8812'-8884'(SS), 75 bbls in 6.2 hrs. 31. LIST OF ATTACHMENTS Well History; Page 2 of Well Completion Report; Core Data Sheet 32. I hereby certify that the foregoing is true and correct to the best of my knowledge __ 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-$itu 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 South Point State #1 Attachment #1 Section 22: D I L/BHCS/GR/SP LDT/CNL/Gr/Cal D I L/MSFL/GR LDT/CNL/NGT/Ca 1 LSS/GR LDT/EPT/GR D i L/BHCS/GR FDC/GR GR/CCL CET CBL DIA-Log Section 26 continued: 9084' - 9086': 160 sx Class "G" cmt. 9118' - 9198': 95 bbl 15% HCl acid. 9204' - 9206': 100 sx Class "G" cmt. 9084' - 9086': 160 sx Class "G" cmt. 8988' - 8990': 175 sx Class "G" cmt. CONFIDENTIAL DRN/WC1 6b: tw South Point State #1 Core Data Core 1 8850' - 8862' Core 2 8862' - 8895' Core 3 8895' - 8954' Core 4 8954' - 8993 Core 5 8993' - 9013 Core 6 9013' - 9020 Core 7 9020' - 9058 Core 8 9058' - 9114 Core 9 9114' - 9146 Core 10 9146' - 9190 Core 11 9190' - 9207 Core 12 9207' - 9248 Core 13 9248' - 9273 Core 14 9273' - 9312 Core 15 9312' - 9372 Core 16 9372' - 9410 Core 17 9410' - 9460 Core 18 9460' - 9518 Core 19 9518' - 9546' Core 20 9546' - 9588' Core 21 9588' - 9648 Core 22 9648' - 9708 Core 23 9708' - 9767 Core 24 9767' - 9827 Core 25 9827' - 9886 Core 26 9886' - 9946 Core 27 9946' - 9997 Co re 28 9997 ' - 1 0027 ' Core 29 10027' - 10087' Core 30 10087' - 10102' Core 31 10102' - 10162' Core 32 10162' - 10208' Core 33 10208' - 10263' Core 34 10263' - 10301' Limestone and dolomite with minor chert and shale. Poor to excellent oil shows. DRN/WC16c:tw ARCO ~311 and Gu Company 0 Pml~m and ~ tlli~'"J~llli~_~lljl~, ell ~ tim Wednm~ ~r a well Ii ipuddld or wooer o~tlonl I~: D~ w~ p~ ~_~ ~ ~ ~ t~ fo~ giving Inclu~l~ date~ only. . ~as~ I North Slope BorouRh Field iL,~ or Unl[ ~d~oe 5a~ ~ ~ Au~. or W.O. no. lTitle ~ ~0~22~ ] ~xplo~aco~y Wall History - Initial Report - Dally Istate A~aska ell no. SPS #1 Operator ARCO Alaska~ Inc. Spudded 4/4/83 Date and depth Complete record for each day reported as of 8:00 a.m. 4/1/83 thru 4/3/83 4/4/83 4/5/83 4/6/83 4/7/83 4/8/83 2130 Hrs, ARCO w.I. Prior stalus if a W.O. N/A Pad-to-Pad move and general rig up. 20" @ 115' NU diverter sys, prep to move camp. Accept rig @ 0200 hrs, 4/4/83. 20" @ 120' 1095', (975'), Drlg surf hole Wt. 8.8, Vis_ 300, PV 24, YP 46, PH 9.1, Sol 3, Oil 0 Fin NU 20" Hydrl & diverter system & function tst. PU 17½" BHA. Spud well @ 2130 hfs, 4/4/83. Drl 17½" hole to 1095' Survey: 609', 1/2°, S40E 13-3/8" @ 2654' 2667', (1572'), Prep to cmt Wt. 9.2, Vis 280+, PV 25, YP 48, PH 9, Sol 3, Oil 0 Drl & surv 17½" hole to 2667', circ hole cln, CBU. RU & rn 72 its, 13-3/8", 72#, L-80 butt csg w/B&W flt equip. FC @ 2566', FS @ 2654'. RU, TIH w/stab-in sub on DP. Surveys:- 1400', 1/2° 2667', 1/2° 13-3/8" @ 2654' 2667', (0'), Tst'g BOPE Frsh Wtr Stab i~to FC @ 2566', pmp 100 bbls Ligno pill. Cmt 13-3/8" csg w/ 2000 sx Fondu @ 11.7 ppg, followed by 400 sx PF "C". Displ cmt w/ 28 bbls mud. CIP @ 0900 hrs, 4/6/83. TOH, ND 20" Hydrl & diverter sys, fill 20" x 13-3/8" ann w/dry cmt. Instl tbg & csg spool. NU 13-5/8" BOPE & tst to 3000 psi. (NOTE: Due to weather, state inspector could not arrive on location and witness BOPE tst. Rec'd verbal OK f/Ben LaNorman by phone to proceed w/tst.) 13-3/8" @ 2654' 4724', (2057'), Drlg Wt. 8.6, Vis 29 (Wtr) Fin tst'g BOPE. Chg BHA, TIH, tag cmt @ 2565'. Drl FC @ 2566', cmt, FS @ 2654', CO to 2667' + 10' new hole to 2677'. Circ hole cln. Conduct leak-off tst to 11.2 EMW. Drl & surv 12¼" hole to 4724'. Surveys: 3212', 1-1/4° 3705', 1-3/4° 4199', 1-1/2° 4724', 1° The above la correbt For form preparation ~ dlltrll~Joe, -- · ee Procldurll M~nuld, 8ectlmf'lO, Drilling, Paget 86 and 87. 5/17/83 DrillinK Supgrintendent Number ill dilly well hlltory forma conlecutlv~ly I,I they me prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim netructlone: This form is used during drilling or workover operations. If testing, coring, or pedorating, show formation name in describing work performed, Number all drill slam tests sequent a y. Attach description of ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frecluently than every 30 days, or (2) on Wednssday of the week in which oil string is set. Submit weekly for workovsrs and following setting of oil strinG until completion. District ]CountyorParish IState Alaska North Slope Borough Alaska Field ~Lease or Unit Prudhoe Bay J ADL #28321 Date and depth Complete record for each day while drHUng or workover in progress as of 8:~ a.m. 4/9/83 13-3/8" @ 2654' 6550', (1826'), Drlg Wt. 9.4, Vis 37, PV 7, YP 3, PH 11, Sol 8, Oil 0 Drl & surv 12¼" hole to 6550'. Surveys: 4724', 1-i/4° 5249', 1/4° 5841' 3/4° 6364', 1-1/2° , 4/10/83 13-3/8" @ 2654' 7275', (725'), Drlg Wt. 10.6, Vis 42, PV 14, YP 5, PH 10.9, Sol 16, Oil 0 Drl & surv 12¼" hole to 6953'. Bring mud wt to 9.7 ppg. C&C, bring mud wt to 10.3 ppg. Drl to 7140', C&C gas cut mud to 10.6 ppg. Drl to 7275'. Surveys: 6644', 1-1/4° 7140', 1° 4/11/83 13-3/8" @ 2654' 7877', (602'), Drlg Wt. 10.6, Vis 43, PV 14, YP 7, PH 11.4, Sol 12.5, Oil 0 Drl & surv 12¼" hole to 7661', CBU. Drl to 7877' Survey: 7620', 1° 4/12/83 13-3/8" @ 2654' 8090', (0'), C&C f/9-5/8" csg Wt. 10.6, Vis 44, PV 17, YP 7, Sol 12.5, Oil 0 Drl & surv 12¼" hole to 8090', circ hole cln, 25 std wiper trip. C&C f/12¼" logs, TOH. RU & rn DIL/BHCS/GR/SP. Chg BHA, TIH, had I0' of fill on btm. C&C f/9-5/8" csg. 4/13/83 9-5/8" @ 8076' 8090', (0'), WOC Wt. 10.6, Vis 45, PV 16, YP 7, PH 11, Sol 12.5, Oil 0 TOH. Chg rams to 9-5/8", tst to 5000 psi. Rn & lnd 194 jts, 9-5/8", 47#, N-80 butt csg w/FS @ 8076', FC @ 8001'. M&P 500 sx Cl "G" w/l% CFR-2, .15% HR-7 @ 15.8 ppg. Bump plug. CIP @ 0050 hrs. 4/13/83. WOC, RD csg tls, chg rams to 5" & tst to 5000 psi. MU 8½" BHA, prep to TIH. 4/14/83 9-5/8" @ 8076' 8240', (150'), TIH Wt. 10.1, Vis 40, PV 10, YP 5, PH 11.3, Sol 10, Oil trc Fin PU 8½" BHA, TIH, tag FC @ 8001'. Circ, tst csg to 3000 psi; OK. Drl FC & cmt to 8065'. Circ cut mud f/10.7 ppg back to 10.1 ppg. Drl hard cmt, FS @ 8076' + 10' new formation to 8100'. Conduct formation tst. Drl (sloughing shale & gas 8100'-8240'), C&C, TOH f/ bit 10. no. SPs {/I The above is correct Signature IOate ITitle ~_~ ~,-~z~_~ 5/17/83 Drilling Superintendent For form preparation and distribut~n see Procedures Manual Section 10, ' -.. Drilling, Pages 86 and 87 AR3B-45~2-B INumber all daily well history forms consecutively as they are prepared for each well. IPag~ no. ARCO Oil and Gas Company,~, '~' Daily Well History--Interim Inltructionl: This form is used during drilling or workovar operations. If testing, coring, or perforating, show formation name in describing work performed, Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporled on "Interim" sheels until linal complelion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oil string until completion. District Alaska Field Prudhoe Ba' Date and depth as of 8:00 a,m, 4/15/83 4/16/83 4/17/83 4/18/83 County or Parish North Slope Borou_~h Lease or Unit ~pL 1128321 Complete record for each day while drilling or workover in progress A1 m.~km JWell .c;ps tt I 9-5/8" @ 8076' 8791', (551'), TOH to log Wt. 10.1, Vis 38, PV 10, YP 4, PH 11.4, Sol 10, Oil trc Fin TIH w/bit #i0, rm 8195'-8240'. Drl 8½" hole 8240'-8666'. Mud cut to 8.7 ppg. Circ out gas cut mud @ 8666' Drl 8½" hole to 8791', circ, 8 std short trip to 9-5/8" shoe. TOH, prep to log. Base of Sadlerochit @ 8689' (driller's depth) 9-5/8" @ 8076' 8791', (0'), TIH w/7-5/8" lnr on 5" DP Wt. 10.1, Vis 38, PV 10, YP 4, PH 11, Sol 11, Oil 0 Fin TOH. RU & rn DIL/BHCS/SP/GR f/8790'-8079'. Rn LDT/CNL/GR/CAL f/8792'-8079'. RD loggers. RIH, rm 30' to btm, C&C f/lnr. Chg top rams to 7-5/8", RU & rn 25 jts, 7-5/8", 33.7#, S-95 Hydrl SFJP lnr w/BOT flt equip & mechanical hgr w/tie-back slv. TIH w/7-5/8" lnr on 5" DP. Perform Arctic Pak.dn sqz while logging w/300 sx PF "C", followed by 131 bbls Arctic Pak. 7-5/8" @ 8788' 8791', (0'), TIH w/6½" bit Wt. 10.2, Vis 39, PV 9, YP 6, PH 10.9, Sol 11, Oil 0 TIH w/7-5/8" lnr on 5" DP to 9-5/8" shoe @ 8076', circ. TIH w/ 7-5/8" lnr, tag btm @ 8791', CBU. Set BOT mechanical hgr, tst cmt ins to 2500 psi. Pmp 30 bbls caustic H~0, followed by 40 bbls Sepeolite spacer. M&P 293 sx C1 "G" w/l% ~FR-2, 18% salt & .3% Halad 22-A. Displ cmt w/mud using rig pmps. Did not observe latch-up. Did not bump plug. CIP @ 1045 hrs, 4/15/83. Circ to cln DP. Chg top rams to 3½". TIH w/HWDP, TOH, LD same. TIH w/8½" bit/csg scrpr, LD 8½" stub while TIH. Tag TOL @ 7712', no cmt on TOL. Circ hole cln, TOH. PU 6½" bit, prep to TIH PU 3½" DP. TOL @ 8702', FC @ 8746', Top of 7-5/8" lnr @ 7712' 7-5/8" @ 8788' 8791', (0'), Prep to TIH w/EZSV Wt. 10, Vis 44, PV 11, YP 9, Sol 10, Oil 0 TIH w/6½" CO assy, tag top of cmt @ 7738'. Drl cmt to 8677', LC @ 8702', FC @ 8746', press tst csg to 2100 psi. Circ hole cln, TOH w/6½" CO assy. Pull 11 stds DP, verify IR w/bit @ 7697' (8 bbl/ min @ 3000.psi). Fin TOH. MU EZSV on 5" DP. The above is correct Signature For form preparation and distribution-/~ see Procedures Manual Section 10. '.~ Drilling, Pages 86 and 87 AR3B-45~2-B IOate 5/17/83 ]Title Drilling Superintendent , , . IN.robe, all daily well history Iorms c .... cufively they are prepared for each well. IPage~no. ARCO Oil and Gas Company Daily Well History--Interim InllrucllOnl: This form is used during drilling or workovar operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach deSCription of all cores. Work performed by Producing Section wilt be reporlad on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lntlrlm" sheets when filled out but not tess frecluently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovers and following setting of oil siring until complelion. District Field Alaska iCounty or Parish 1State North Slope Borough Alaska ADL #28321 SPS ~1 Prudhoe Bay Date and depth as of 8:00 a.m. 4/19/83 4/20/83 4/21/83 4/22/83 4/23/83 4/24/83 Complete record for each day while drilling or workover in progress 7-5/8" @ 8788' 8791', (0'), Drl on EZ Drl SV @ 7594' Wt. 10.1, Vis 40, PV 11, YP 6, PH 12.5, Sol 10, Oil 0 MU CR on DP & set @ 7601' Est IR of 6 bbl/min @ 1800 psi w/H~0. Displ cmt w/mud to retnr. Stab-in & sqz 155 sx C1 "G" w/1% CF~-2, 18% salt, .3% Halad 22-A into lnr lap w/final IR of 3 BPM @ 1650 psi. CIP @ 1430 hrs, 4/18/83. Unsting& rev out excess cmt, TOH. MU CO assy, TIH to 7426', tst csg to 3000'. Tag cmt@ 7477' Drl cmt to 7594' 7-5/8" @ 8788' 8795', (4'), LD Excess 5" DP Wt. 10.0, Vis 42, PV 14, YP 6, PH 12.7, Sol 10, Oil 0 Drl EZ Drl 7594'-7600', CO cmt f/7600'-7712' (TOL). MU 7-5/8" CO assy, TIH to 7727', tst csg to 3000 psi; OK. DO cmt, FC, FS + 7I new hole to 8795'. Tst formation to 12.3 ppg EMW. Rn CBL f/8792'-7396', log showed fair to good bond. POH. 7-5/8" @ 8788' 8850", (48'), MU core assy Wt. 9.6, Vis 51, PV 17, YP 12, PH 8, Sol 8, Oil 0 TIH w/6%" bit. Displ ligno mud w/9.6 ppg bland mud & circ. hole f/8802'-8850', TOH. Drl 6½" 7-5/8" @ 8788' 8875', (25'), Cut core #2 Wt. 9.6, Vis 44, PV 10, YP 5, PH 8.2, Sol 8, Oil 0 Fin MU core assy #1, core 8850'-8862', TOH, rec'd 9'. cutting core #2. Survey: 8478', 1.5°, N38W TIH, begin 7-5/8" @ 8788' 8945', (70'), Cut core #3 - Wt. 9.6, Vis 43, PV 11, YP 5, PH 8, Sol 8, Oil 0 Core #2, 8862'-8895', TOH, rec'd 41%. Dress core bbl, TIH, wsh & rm 8860'-8895'. Cut core #3, 8895'-8945', incompl. Survey: 8810', 1¼°, Sl6W 7-5/8" @ 8788' 8980', (35'), Cut core #4 Wt. 9.4, Vis 43, PV 10, YP 5, PH 8.2, Sol 8, Oil 0 Fin core #3, 8945'-8954', rec'd 59'. TIH, wsh & rm 8904'-8954' Cut core #4, 8954'-8980', incompl. Survey: 8870', 1¼°, N35E The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date ITitle - 7/27/83 AR3B-459-2-B Drilling Superintendent Number all daily well history forms consecutively as they are prepared for each well. Pagano. ARCO Oil and Gas Company,~," Daily Well History--Interim Inltmctions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lntlrlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lntarim" sheets when filled out but not less frequently [han every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workoverS and following setting of oil string until completion. District County or Parish '~State North Slope Borough I Alaska Lease or Unit IWell no. ADL #28321 I SPS Field Alaska Prudhoe Bay Oate and depth as of 8:00 a.m. 4/25/83 4/26/83 4/27/83 4/28/83 4/29/83 4/30/83 Complete record for each day while drilling or workover in progress 7-5/8" @ 8788' 9012', (32'), Circ gas cut mud Wt. 9.4, Vis 43, PV 12, YP 5, PH 8.0, Sol 9, Oil 0 Fin core #4, 8980'-8993', rec'd 39'. TIH, wsh & rm 8943'-8993' Core #5, 8993'-9010'. Coring break 9004'-9008', lost 18 bbls mud. Stop coring, observe well w/no loss or gain in drlg fluid. Cont core #5, 9010'-9012', took formation kick w/28 bbl pit gain. Circ out gas cut mud in ann via choke. Survey: 8911', 1-3/4°, S54W 7-5/8" @ 8788' 9012', (0'), Circ out gas/oil cut mud Wt. 9.6, Vis 46, PV 12, YP 4, PH 8.2, Sol 10, Oil 5 Inc mud wt f/9.4 ppg to 9.6 ppg. Mx LCM while circ out gas cut contaminated mud. Circ 9.4 ppg in, 8.8 ppg out. Circ mud w/LCM, 9.6 ppg in, 9.4 ppg out. Cont to raise mud wt. 7-5/8" @ 8788' 9012', (0'), C&C hole Wt. 10.0, Vis 44, PV 12, YP 4, PH 7.7, Sol 12, Oil 4 Circ mud w/9.6 ppg in, 9.4+ ppg out. Circ mud, wt up to 9.8 ppg. Pull 3 stds, observe well, TIH. Circ up 8.8 ppg gas cut mud. Circ wt up to 10.0 ppg. Lost 74 bbls fluid. C&C hole. 7-5/8" @ 8788' 9012', (0'), Cln'g mud pits Wt. 10+ in hole - Cln'g pits f/new bland mud C&C hole, TOH w/core #5, cut f/8993'-9012', rec'd 80%. Chg BHA, TIH w/6½" bit. Treat mud w/coarse LCM. Pull into 7-5/8" csg. Dump mud pits. Prep to mx new bland mud sys. Survey: 8926', 1¼°, S36W 7-5/8" @ 8788' 9012', (0'), CBU Wt. 10.1, Vis 55, PV 20, YP 5, PH 9.4, Sol 11, Oil 0 Cln pits, mx new bland mud. Circ 10.1 ppg bland mud, observe well, hole appears stable, TOH. PU core bbl #6, TIH, prep to cut core #6. 7-5/8" @ 8788' 9032', (19'), Cut core #7 Wt. 10.1+, Vis 54, PV 17, YP 8, PH 8.9, Sol 10, Oil trc Core #6, 9013'-9020', barrel jammed, TOH, rec'd 2.5'. Set tst plug, tst BOPE/Hydrl to 2500 psi. TIH w/core #7, wsh & rm 42' to btm, CBU. Core #7, 9020'-9032', surv'g every 5'. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IOate ' ITiUe 7/27/83 Drilling Superintendent AR3B-459-2-B Number all daily well history forms conseculively as Ihey are prepared for each well. IPag~ no. ARCO Oil and Gas Company ~, Daily Well History--Interim Inltructienl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formalion name in describing work performed. Number all drill stem tests sequentially, Attach description of all cores. Work performed by Producing Section wilt be reported on "Interim" sheets unlil linal completion. Report officiat or representative test on "Flnll" form. 1) Submit "Interim" sheets when tilled out but not less Irequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil strin; until completion. District County or Parish [State I Alaska North Slope BorouKh Fietd Lease or Unit Prudhoe Ba'~ ADL #28321 Complete record for each day while drilling or workover in progress 5/01/83 5/02/83 Date and depth as of 8:00 a.m. 5/03/83 5/04/83 5/05/83 5/06/83 Alask~ Well no. SPS #i 7-5/8" @ 8788' 9067', (35'), Cut core #8 Wt. 10.1, Vis 53, PV 15, YP 8, PH 8, Sol 10, Oil trc Fin core #7, 9032'-9058', rec'd 28'. TIH to cut core #8, wsh & rm 40' to btm, CBU. Core #8, 9058'-9067'. 7-5/8" @ 8788' 9114', (47')., C&C hole Wt. 10.1+, Vis 48, PV 14, YP 5, PH 7.8, Sol 10, Oil trc Core #8, 9067'-9098', well started to flow. Circ out gas cut mud, observe well, no flow. Fin cut core #8 to 9114', rec'd 56'. TIH f/core #9, wsh & rm 35' to btm, C&C hole. Survey: 9113', 2°, N81W 7-5/8" @ 8788' 9114', (47'), Cut core #10 Wt. 10.2, Vis 50, PV 14, YP 6, PH 7.8, Sol 10, Oil trc Core #9, 9114'-9146', rec'd 29'. TIH f/core #10, wsh & rm 40' to btm.. Cut core #10, 9146'-9174', incompl. Survey: 9146', 2¼°, S77W 7-5/8" @ 8788' 9190', (16'), C&C hole to TD Wt. 10.4+, Vis 51, PV 16, YP 8, PH 8.7, Sol 11, Oil 2 Fin cut core #10, 9174'-9176', circ 4 bbl gas kick thru choke. Build mud to 10.4 ppg. Cut core #10 f/9176'-9186', circ. Cut core #10, 9186'-9190', core bbl Jammed. Circ gas cut mud (10.4 ppg in - 9.5 to 10.1 out) in prep to TOH. 7-5/8" @ 8788' 9207', (17'), Prep to tOH w/core #11 Wt. 10.4, Vis 45, PV 15, YP 5, PH 7.6, Sol 10, Oil 2 Circ gas cut mud (10.4+ in, 10.2 out), observe well, no flow. Spot LCM pill, TOH w/core #10 (cut 44', rec'd 43'). TIH w/core #11, CBU. Cond hole (10.4+ mud in, 10.2 out). Core #11, 9190'- 9207', core bbl jammed. CBU, prep to TOH. Survey: 9190', 2¼°, S77W 7-5/8" @ 8788' 9242', (35'), Cut Core #12 Wt. 10.6, Vis 51, PV 13, YP 5, PH 7.8, Sol 10, Oil 2+ TOH w/core #11 (cut 17', rec 16.6'). RIH f/core #12, C&C, C&C mud (10.4+ mud in, 10.1 ppg - 9.0 ppg out). Raise mud wt to 10.6. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 IDate ]Title 7/27/83 Drillin$ Superintendent AR3B-459-2-B .... ' '~ ~Number all daily well history forms consecutively ,' ' '' :~"~ ,~-~/~'~-~,.las they are prepared tot each well. IPage~o. ARCO Oil and Gas Company Daily Well History--Interim Inslr~¢tiona: This form is used during drilling or work@var operations. If testing coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Sect on will be reported on "lnlerll~" sheels until Sinai completion. Report official or representative teat on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequanlly than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovers and foil@wing setting of oil siring until completion. District Field Date and depth as of 8:00 a.m. ICounty or Parish Alaska North Slope Borough I Lease or Unit Prudhoe Bay ADL #28~21 Complete record for each day while drilling or work@var in progress 5~07~83 5/08/83 5/09/83 5/10/83 5/11/83 5/12/83 5/13/83 IState Alaska. Well no. SPS 7-5/8" @ 8788' 9273', (31'), C&C Wt. 10.6, Vis 48, PV 12, YP 5, PH 7.8, Sol 10, Oil 2.5 Cut core #12, 9207'-9248', rec'd 38'. RIH f/core #13, C&C mud. Core #13, 9248'-9273', CBU, prep to POH. 7-5/8" @ 8788' 9273', (0'), RIH f/core #14 Wt. 10.6, Vis 47, PV 15, YP 5, PH 7.6, Sol 10, Oil 2 POH w/core #13, rec'd 21.5' PU 6½" bit, RIH, spot coarse LCM pill, TOH. Tst BOPE. Survey: 9273', 2-3/4°, N77W 7-5/8" @ 8788' 9337', (64'), Core #15 Wt. 10.6, Vis 47, PV 16, YP 6, PH 7.8, Sol 9, Oil 1 Core #14, 9273'-9312', rec'd 39'. TIH f/core #15. Survey: 9312', 2½°, N69W 7-5/8" @ 8788' 9409', (72'), POH w/core #16 Wt. 10.6, Vis 49, PV 15, YP 4, PH 7.7, Sol 10, Oil trc Core #15, 9312'-9372', rec'd 60'. RIH, core #16 f/9372'-9409' incompl. Survey: 9372', 3°, N75W 7-5/8" @ 8788' 9460', (51'), Core #18 Wt. 10.6, Vis 49, PV 16, YP 6, PH 7.5, Sol 10, Oil 1 Fin core #16, 9372'-9409', rec'd 37'. Cut core #17, 9409'-9460', jar & wrk thru tight spot, TOH, rec'd 47'. Surveys: 9409', 2½°, N77W 9444', 2½°, N62W 7-5/8" @ 8788' 9518', (58'), RIH f/core #19 Wt. 10.6, Vis 48, PV 14, YP 8, PH 7.5, Sol 10, Oil 1 Cut core #18, 9460'-9518', rec'd 47'. TIH f/core #19. Survey: 9518', 2-3/4°, N67W 7-5/8" @ 8788' 9588', (70'), Prep to TOH w/core #20 Wt. 10.6, Vis 51, PV 14, YP 8, Ph 8.0, Sol 10, Oil 1 Core #19, 9518'-9546', rec'd 28'. TIH w/core #20, wsh & rm 9505'-9546'. Cut core #20, 9546'-9588', prep to TOH. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 AR3B-459-2-B Date ITitle 7/27/83 Drilling Superintendent . . INumber all daily well history forms consecutively as they are prepared lot each well. IPage~o. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used dudng drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on 'Interim" sheets until final completion. Report official or representative test on "FInlI" form. 1) Submit 'lnllrlm" sheets when tilled out but not less frequently then every 30 clays, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. Districl Field Alaska Couqty or Parish Lease or Unit Prudhoe Ba' Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. Slate North Slope Borough Alaska I Well no, ADL #28321 I SPS 5/14/83 5/15/83 5/16/83 5/17/83 5/[8/83 5/19/83 5/20/83 7-5/8" @ 8788' 9648', (60'), TOH w/core #21 Wt. 10.6+, Vis 52, PV 13, YP 8, PH 7.7, Sol 10, Oil trc TOH w/core #2d, rec'd 42'. TIH f/core #21, wsh & rm 9548'- 9588'. Core #21, 9588'-9648', TOH. 7-5/8" @ 8788' 9685', (37'), Core #22 Wt. 10.6+, Vis 54, PV 19, YP 7, PH 7.8, Sol 10, Oil trc Rec'd 59' f/core #21. TIH, wsh & rm 9633'-9648'. Core #22, 9648'-9685', incompl.. Survey: 9648', 1¼°, S84W 7-5/8" @ 8788' 9708', (23'), Core #23 Wt. 10.6+, Vis 50, PV 17, YP 7, PH 7.6, Sol 10, Oil trc Fin core #22, 9685'-9708', rec'd 60'. Set tst plug, tst Hydrl to 2500 psi, rams to 5000 psi. TIH f/core #23. Survey: 9708', 2¼°, N72W 7-5/8" @ 8788' 9767', (58'), TOH w/core #23 Wt. 10.6+, Vis 48, PV 15, YP 6, PH 7.8, Sol 10, Oil 1 Core #23 f/9708'-9767', TOH. 7-5/8" @ 8788' 9820', (53'), TOH w/core #24 Wt. 10.6, Vis 49, PV 15, YP 5, PH 7.8, Sol 10, Oil 1 Fin TOH w/core #23, rec'd 59'. TIH f/core #24, wsh & rm 30' to btm. Core #24, 9767'-9820', incompl. Survey: 9767', 2°, N73W 7-5/8" @ 8788' 9843', (23'), Core #25 Wt. 10.6+, Vis 48, PV 17, YP 5, PH 7.7, Sol 10, Oil 1 Fin core #24, 9820'-9827', rec'd 58.5'. TIH f/core #25, wsh & rm 30' to btm. Core #25, 9827'-9843'. Survey: 9827', 2°, N89W .. 7-5/8" @ 8788' 9883', (40'), Core #25 Wt. 10.6, Vis 47, PV 17, YP 5, PH 7.8, Sol 10+, Oil .5 Core #25, 9843'-9883', incompl. The above is correct Signature For form preparation and'- distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 JDate JTitle 7/27/83 Drilling Superintendent AR3B-459-2-B as they are prepared tor each well. ARCO 011 and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "interim" sheets until final completion. Report official or representative test on "Fhtal" form. 1) Submit "interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil stdng ia set. Submit weakly for workovers and following setting of oil string until completion. District Field Alaska County or Parish Lease or Unit Prudhoe Ba' Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. North Slope Borough ADL #28321 Alaska IWell no. 5/21/83 5/22/83 5/23/83 5/24/83 5/25/83 5/26/83 5/27/83 7-5/8" @ 8788' 9905', (22'), Core #26 Wt. 10.6, Vis 48, PV 16, YP 6, ?H 7.8, Sol 10, Oil .5 Core #25, 9883'-9886', rec'd 59' TIH, instl 5" DP rubbers, core #26, 9886'-9905', incompl. Survey: 9886', 2°, N78W 7-5/8" @ 8788' 9946', (41'), TOH w/core #26 Wt. 10.6, Vis 48, PV 16, YP 5, PH 7.8, Sol 11, Oil 1 Core #26, 9905'-9946', CBU, TOH. 7-5/8" @ 8788' 9978', (32'), Core #27 Wt. 10.6, Vis 48, PV 15, YP 5, PH 7.8, Sol 11, Oil i Rec'd 60' f/core #26. TIH, instl 3½" & 5" DP rubbers, wsh 9905'- 9946'. Core #27, 9946'-9978', incompl. Survey: 9946', 2¼°, S76W 7-5/8" @ 8788' 10,014', (36'), Core #28 Wt. 10.6, Vis 48, PV 15, YP 5, PH 7.6, Sol 11, Oil .5 Fin core #27, 9978'-9997', rec'd 51'. TIH, wsh & rm 9910t-9997' Core #28, 9997'-10,014', incompl. Survey: 9997', 2°, S79W 7-5/8" @ 8788' 10,027', (13'), Jarring Wt. 10.6, Vis 51, PV 16, YP 7, PH 7.9, Sol 10.5, Oil .5 Core #28, 10,014'-10,027', jammed, stuck pipe below jars (30' off btm). Jar pipe w/full circ. Spot 48 bbls SFT pill. Jarring stuck pipe. 7-5/8" @ 8788' 10,027', (0'), Service core bbl Jar stuck pipe. Rn freept, pipe free to 9905'. job, circ& wrk pipe. TOH w/core #28, rec'd 30'. Perform acid 7-5/8" @ 8788' 10,027', (0'), POOH w/6½" bit Wt. 10.6+, Vis 54, PV 17, YP 7, PH 8.2, Sol 10.5, Oil 3 Service core bbl #28. TIH, set RTTS @ 5000', 6½" bit @ 8780'. Repair lower BOP &tst to 3000 psi; OK. Rel RTTS il, CBU, observe well. TOH w/RTTS. TIH w/6½" bit, rm 150' to btm, C&C, TOH. The above is correct Signature ,/~ ~,j~~ For form preparation and distribution see Procedures Manual Section tO, Drilling, Pages 86 and 87 AR3B-459-2-B IOate ]Title 7/27/83 Drilling Superintendent " .....~i: "._? .,;: ~i~:. ~" .:.?. ,~ : ' ..... ~:: l~N~mber-all daily well history forms consecutively ' " ...¥ j [ ~s-ihe'y,.~re prepared for each well. / IPag~ nO. ARCO Oil and Gas Company Daily Well History--Interim Inatructionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be repOrted on "Interim" sheets unlil final completion. Report official or rapresentetiva test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strinG until completion. District County or Parish ITM Alaska North Slope Borough I Alaska Field Lease or Un t IWe, no. Prudhoe Bay ADL #28321 I SPS ltl Date and deptll Complete record for each day while drilling or workover in progress as of 8:00 a.m. 5/28/83 5/29/83 5/30/83 5/31/83 6/01/83 6/02/83 6/03/83 7-5/8" @ 8788' 10,067', (40'), Core #29 Wt. 10.6+, Vis 51, PV 15, YP 7, PH 8.2, Sol 10.5, Oil 2 MU & orient core bbl, RIH, rm 30' to btm. Core #29, 10,027'- 10,086', incompl. 7-5/8" @ 8788' 10,097', (30'), Repair choke manifold vlv Wt. 10.6+, Vis 48, PV 15, YP 6, Sol 10.5, Oil 0 POOH w/core #29, rec'd 55'. Tst BOPE to 5000 psi, Hydrl to 3000 psi. RIH~ rm 39' to btm. Begin core #30. 7-5/8" @ 8788' 10,124', (27'), Core #31 Wt. 10.6+, Vis 48, PV 15, YP 6, PH 7.9, Sol 11, Oil 2 POOH to 7-5/8" shoe, repair choke manifold vlv, tst to 5000 psi. RIH, core #30, 10,086'-10,102', core jammed, rec'd 15'. RIH to cut core #31. 7-5/8" @ 8788' 10,124', (58'), Core #32 Wt. 10.6+, Vis 47, PV 14, YP 4, PH 7.8, Sol Il, Oil 2 Core #31, 10,102'-10,161', rec'd 59'. RIH, rm 42f to btm, begin core #32. 7-5/8" @ 8788' 10,242', (60'), Core #33 Wt. 10.6+, Vis 48, PV 15, YP 5, PH 7.8, Sol 11, Oil 2 Core #32, 10,161'-10,208' (2' drlg break 10,206'-10,208'). Shut dn f/surv, unable to start coring again. Lost 400 psi. CBU, no gas, POOH, rec'd 47'. RIH f/core #33, rm 42' to btm. Survey: 10,208', 2~°, S75W 7-5/8" @ 8788' 10,296', (54'), Core #34 Wt. 10.6, Vis 48, PV 16, YP 5, PH 7.8, Sol 11, Oil 2 Core #33, 10,208'-10,263', rec'd 55'. Core #34, 10,263'-10,296', incompl. 10,301' (5'), Wrk OS ove Wt. 10.6, Vis 49, PV 16, YP~-6~, PH 7.8, Sol 11, Oil 2 Core #34, 10,296'-10,301', pipe stuck while making connection. Jar on stuck pipe, drill string parted, lost 40,000#, TOH. Strip pin on 3½" DP, TIH w/fsh'g assy. Top of fsh @ 8827'. Att to wrk OS onto fsh, passed fsh, TOH. Guide shoe damaged, bent lip. TIH w/ fsh string #2, wrk'g OS over fsh. The above is correct Signature For form preparation and distribution '- /( see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B IDate ITitle 7/27/83 Drilling Superintendent INumber all daily well history forms consecutively as they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim laltmctloal: Th s form is used during drilling or workover operations. If testing coring, or perlorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of a cores. Work performed by Producing Secl on will be reported on "lnlerlm" sheets until final completion. Report official or representative te~t on "Flail" form. 1) Submit "Interim" sheets when tilled DUI but not less Irequently Ihan every 30 days, or (2) on Wednesdey of the week in which oil string is set. Submit weekly for workovere and following setting of oil string until completion. I County or Parish Field ILease or Unit Prudhoe Ba,I ADL #2832! Date and deptll Complete record for each day while drilling or workover in progress as of 8:00 a.m. Stale District Alaska North Slope Borough Alaska IWell no. SPS 6/04/83 6/05/83 6/06/83 6/07/83 6/08/83 7-5/8" @ 8788' 10,301', (0'), TIH w/fsh'g assy #5 Wt. 10.6, Vis 48, PV 15, YP 5, PH 7.8, Sol 11, Oil 1 TIH w/fsh'g assy #3, att to wrk OS over fsh @ 8827' w/o success, TOH. TIH w/fsh'g assy #4 w/wide ID lip guide/mill slv, att to WO fsh w/o success, TOH. TIH f/fsh'g assy #5 w/hook wall lip guide & 4-3/4" O/S grapple, att to WO fsh w/o success, TOH. 7-5/8" @ 8788' 10,301', (0'), TOH w/WL tls Wt. 10.6, Vis 47, PV 15, YP 5, PH 7.8, Sol 11, Oil 1 Unable to wrk fsh out of well bore wall, fin TOH. TIH w/fsh'g assy #6 w/extended hook wall lip guide, att to wrk fsh w/o success, TOH. (Approx 1/2 of TOF sticking out in the well bore, other half jammed in the well bore wall.) TIH w/fsh'g assy #7, tapped into TOF, RU DA, RIH w/sinker bars, colr locator & jars. Tls stopped @ 8843', TOH w/WL tls. 7-5/8" @ 8788' 10,301', (0'), WO 3~" DP to 8948' Wt. 10.6, Vis 46, PV 14, YP 4, PH 7.8, Sol 11, Oil 1 Press 3" DP to 1000 psi, break circ. Pmp 6 bbls drlg mud thru core bit w/ann returns. Re-rn sinker bar assy to 8952' (125' below TOF). TOH w/WL tls. Pull WL out of rope socket @ kelly swivel & dropped sinker bar assy dn 3½" DP. Att to BO tl jt 90' below TOF, no BO. TIH w/freept, pipe stuck 8840'-8935'. TIH w/string shot, back pipe off @ 8732', 56' inside 7-5/8" csg. TOH w/DP. TIH w/WO pipe, WO 3½" DP to 8948'. 7-5/8" @ 8788' 10,301t, (0'), Circ& jar on stuck pipe Wt. 10.6, Vis 47, PV 13, YP 5, PH 7.8, Sol 11, Oil 0 Circ @ 8948' w/WO assy, TOH, left part of WO shoe in hole. TIH w/fsh'g assy #9, made outside mechanical cut on 3~" DP @ 8923', TOH, rec'd 190+', 3½" DP. MU fsh'g assy #10 w/ 4-7/8" ID guide shoe, dress top of 3½" DP stub @ 8923', latch onto fsh, jar & wrk string. 7-5/8" @ 8788' 10,301' (0'), Break dn fsh'g tls Wt. 10.6, Vis 50, PV 15, YP 7, PH 7.9, Sol 11, Oil 1 Circ & jar on stuck pipe. Rn freept, pipe stuck @ 9900' w/fsh'g assy #11, latch onto fsh @ 8923', jar & wrk fsh. shot, backed off @ 9855', POOH w/fsh. TIH Rn BO The above is correct For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 7/27/83 ]Zit,e Drilling Superintendent AR3B-45~2-B Number all daily well history torres consecutively las ~they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim Initructione: Thi,~ form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lltllrlm" sheets until final completion. Report official or representative te~t on "Final" form. 1} Submit "lnlerlm" sheets when filled out but not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovere and following setting of oil slrin§ until completion. District ]County or Parish IState Alaska North Slome Bnrn,,~h Field ILease or Unit ' ~ Prudhoe Ba' I ADL #28321 Complete record for each day while drilling or workover in progrese 6/09/83 6/10/83 6/11/83 Date and deptll as ot 8:00 a.m. 6/12/83 6/13/83 Well no. / SP$ t~1 7-5/8" @ 8788' 10,301', (0'), TOH w/WL Wt. 10.6, Vis 50, PV 15, YP 8, PH 7.8, Sol 11, Oil 0 LD fsh, rec'd 16 its, 3%" DP + 3½" DP cut off Jt & 13, 4-3/4" DC (928' total). MU fsh'g assy #12, TIH, screw in TOF @ 9851', circ while jarring fsh. Prep acid job. Displ & spot 5000 gal, 28% HCL acid. Circ & jar up on fsh. RU & rn freept w/APRS (pipe stuck @ 9995'. TIH w/BO shot, backed fsh off @ 9979' (2 DC's below original set of jars. 7-5/8" @ 8788' 10,301', (0'), POOH Fin pull'WL/ LD fsh, rec'd total of 123' of fsh. TOF now @ 9974'. MU wshover pipe & fsh'g assy #13, RIH, WO fsh to top of stabilizer @ 10,160', CBU, POOH. Chg fsh'g tls, RIH, screw into fsh, PU wt to 210K, press dropped to 650 psi. Circ, pmp wt pill, POOH. 7-5/8" @ 8788' 10,301', (0'), POOH to PU OS Wt. 10.6, Vis 50, PV 16, YP 7, PH 7.4, Sol 11, Oil trc POOH, stop in csg & observe well; OK. POOH. Re¢'d 5 steel DC + 1 monel DC. TOF now @ 10,159' & consists of 6-1/2" stab w/box lk'g up + 2 monel + XO + 2 core bbl + core bit (box has pin inside). PU OS w/4-7/8" guide, RIH, tag fsh, CBU. Att to wrk OS on fsh w/o success - unable to get grapple to take hold, POOH. Tst BOPE to 5000 psi, Hydrl to 3000 psi. PU fsh'g string #16, RIH, dress TOF to 4-3/4", POOH to PU OS. 7-5/8" @ 8788' 10,301', (0'), MU diamond mill on OS Wt. 10.6, Vis 47, PV 12, YP 6, PH 7.4, Sol 11, Oil trc POOH. RIH w/fsh'g string #17, CBU. Wrk OS onto fsh @ 10,159'. Jar on fsh, no movement. Suspect wshfg past OS. RIH w/l-Il/16" impression block w/blind box, tag up @ 10,167' (12' below TOF @ 10,155'), POOH. RIH w/string shot, irratic CCL operation, POOH. Chg out CCL, RIH, no BO. MU fsh'g string #18 w/diamond mill shoe. 7-5/8" @ 8788' 10,301', (0'), RIH w/fsh'g string #19 RIH w/fsh'g string #18 w/diamond mill shoe, mill over stabilizer blades & wsh dn over 2 monel DC's to top of core bbl. Pmp hi-vis sweep, CBU, POOH. MU fsh'g string #19. The above is correct Signature For form preparation-and 2istrib-ulion ~ see Procedures Manual Section 10, ~ Drilling, Pages 86 and 87 IDate ITitle 8/1/8~ Drillin~ Superintendent AR3B-459-2-B I Number all daily well history Iorms /~--- : !::'-'i.; ~ las they are prepared for each well. conseculively I IPage no. 12 ARCO Oil and Gas Company Daily Well History--Interim Inetru¢llone: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ail cores. Work psrtormed by Producing Section will be reported on "Interim" sheets unlit final completion. Report official or representative tam on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish ITM North Slope Borough Alaska ILease orUnit ]Welino. ADL #28321 SPS #1 Field Alaska Prudhoe Bay Date and depth as of 8:00 a.m. 6/14/83 6/15/83 6/16/83 6/17/83 6/18/83 6/29/83 Complete record for each day while drilling or workover in progress 7-5/8" @ 8788' 10,301', (0'), RIH w/slickline impression block Wt. 10.6, Vis 52, PV 16, YP 7, PH 7.4, Sol I1, Oil trc RIH, tag fsh,'wrk OS onto fsh, Jar; no movement. Att to BO w/o success. Att to release OS w/o success. RIH w/fsh'g neck grapple, unable to latch, POOH. RIH w/lead impression block, no marks, POOH. RIH w/impression block, tl stopped @ 9940', jar tls loose, POOH. 7-5/8" @ 8788' 10,301', (0'), POOH w/Log #2 Wt. 10.6, Vis 49, PV 17, YP 8, PH 7.5, Sol 11, Oil trc RIH w/impression block, tls stuck @ 9945'±, jar loose. POOH, left lead plug f/impression block in hole. RIH w/OS, tag lead, POOH, rec. RIH, drive lead plug to 10,157' top of WL fsh, POOH. Pmp on DP, w~k pipe, pmp pill, POOH w/fsh'g string. RU Schl, log DIL/MSFL/GR & LDT/CNL/NGT/CAL. 7-5/8" @ 8788' 10,301', (0'), Log rn'#5 Wt. 10.6, Vis 49, PV 15, YP 7, PH 7.4, Sol 11, Oil trc Log #2, LDT/CNL/NGT/CAL, 10,134'-8700'. Rn log #3, LSS/GR, tl failed. Log rn #3, 10,135'-8700'. Rn log #4, LDT/EPT/GR, 10,135'- 8700'. Rn log #5, DIL/BHCS/GR. 7-5/8" @ 8788' 10,301', (0'), Log w/RFT Wt. 10.6+, Vis 49, PV 16, YP 7, PH 7.5, Sol ~1, Oil trc Log #6, FDC/GR. Log #7, HTV. Log #8, Dipmeter. Log #9, re-rn PHTV. Log #9, RFT. Log #10, RFT. 7-5/8" @ 8788' 10,301', (0'), GIH w/5" lnr Wt. 10.6+, Vis 50, PV 15, YP 7, PH 7.4, Sol 11, Oil trc Fin Log #10, C&C hole. RU to rn 5" lnr. 7-5/8" @ 8788' 10,301', (0'), GIH w/6-1/2" bit Wt. 10.6, Vis 50, PV 16, YP 7, PH 7.4, Sol 11, Oil trc Rn 48 jts~ 5", 18#, S-140 SFJP lnr w/FC @ 10,113', LC @ 9999.69', Hgr @ 8495', Tie-back @ 8484'. Recip pipe. M&P 300 sx Cl "G" w/ 1% CRF-2, 18% salt, .3% Halad 22-A. Displ w/rig pmp, bumped plug. Tst BOPE to 5000 psi, Hydrl to 3000 psi. LD wshpipe, fsh'g tls, core tls. TIH w/6~" bit/7-5/8" csg scrpr to cln 7-5/8" x 5" lnr. The above is correct For form preparation and distr~Jtion see Procedures Manual Section-10, Drilling, Pages 86 and 87 IDate ITitle 8/1/83 Drilling Superintendent AR3B-45~2-B JNumber all daily well history forms consecutively as they are prepared for each well. Pag 3 ARCO Oil and Gas Company Dally Well History--Interim Inltn~clioltl: This form is used during drilling or workover operations. If testing, coring, or peHorating, show formation name in deacriblng work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lntlrll~" sheets until final completion. Report official or representative telt on "Flail" form. 1) Submit "lnlerilW' sheets when filled out but not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovere and following setting of oil string until completion. District Field Date and depth as of B:00 a.m. Alaska Prudhoe Bay ADL #28321 Complete record for each day while drilling or workover in progress 6/20/83 6/21/83 6/22/83 6/23/83 6/24/83 6/25/83 ICounly or Parish [State North Slope Borough ILease or Unit 6/26/83 Alaska we,,no. SPS ~/1 5" @ 10,150' 10,113', (0'), Circ out cmt Wt. 10.6, Vis 47, PV 16, YP 7, PH 12.1, Sol ll, Oil trc Fin RIH w/6-1/2" bit. Drl cmt f/8165'-8484', tag 5" lnr @ 8484' Circ out cmt, POOH. PU 4-1/8" bit/BHA, TIH, drl 10' cmt to TOL. Drl cmt f/9863'-10,112' (top of FC), circ hole cln. 5" @ 10,150' 10,113' PB, (0'), RU Schl 9.8 NaC1/NaBr, Vis 28 Circ & POH, LD JB. PU csg scrpr, RIH, CBU, tst csg to 3000 psi; OK. Chg out drlg mud to 9.8 ppg NaC1, POH. RU Schl f/CBL/CET/VSP logs. PU VSP (velocity survey) & 5" @ 10,150' 10,113' PB, (0'), Log w/VSP 9. 8 NaC1/NaBr, Vis 28 RU Schl & log CBL #1 & #2. begin to log. Rn CET. 5" @-10,150' 10,113' PB, (0'), RU GR/CCL 9.8 NaC1/NaBr, Vis 28 Fin logging velocity surv. Schl f/GR/CCL. PU DST tls, rabbit all tls & pipe. RU 5" @ 10,150' 10,113' PB, (0'), Repair leaks in flow in 9.8 NaC1/NaBr TIH w/GR/CCL, tl would not go thru 2-3/8" DP, TOH. RU "GO", TIH w/ 1-7/16" OD, rn GR/CCL f/9300'-9800'. Set RTTS. Tst ins & vlvs on tst'g manifold to 5000 psi; OK. Tst flow in, found 3 leaks. 5" @ 10,150' 10,113' PBTD, (0'), TOH w/DST tls 9.8 ppg NaC1/NaBr Press tst flow in to 3000 psi f/30 min. Displ fluid in DP w/N~ to obtain 1000# under balance conditions to shoot f/DST #1. L~ad Vann gun firing bar, drop bar, guns did not fire. RU 1-3/8" OD overshot, tst lub & BOPE to 2000 psi. TIH w/OS to retrv firing bar, tls stopped @ 8340'. Wrk tls, TOH, rec'd firing bar. 5" @ 10,150' 10,113' PBTD, (0'), RU Schl to rn GR 9.8 ppg NaC1/NaBr Att to rn Camco tls to APR, tls stopped @ 8340', TOH. RD Camco, bleed off DP press, rev circ, unseat RTTS, TOH w/3½" DP & DST tls. RU Schl, rn GR/CL to correlate RTTS. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 8/02/83 Drilling Superintendent AR3B-459-2-B INumber all daily well history forms conseculively as lhey are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim nstmctlona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach descript on of all cores. Work performed by Producing Section will be reported on "Interim" sheels until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, Or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until complelion. District Field Alaska Prudhoe Bay County or Parish Lease or Unit I Slale North Slope Borough Alaska I We[I no. ADL #28321 SPS Date and depth as of 8:00 a.m. 6/27/83 6/28/83 6/29/83 6/30/83 7/01/83 Complete record for each day while drilling or workover in progress 5" @ 10,150' 10,113' PBTD, (0'), TOH w/DST tls #2 9.8 ppg NaC1 Set RTTS w/5000 psi. Rn GR/CL to confirm RTTS depth. Tst ann to 500 psi, manifold on flr to 5000 psi w/N?. Press DP w/N? to 1000 psi under balance. Load Vann gun firing bar, drop §ar, guns fired. Flow well, close APR vlv, SI well. Rn WL sample catcher, open well f/flow. Press bled to 9 psi/39 min, fluid level cont'd to rise thruout flow tst. Re-rn sample catcher, open APR, flow well, fluid rise. Shear out M-2 sample catcher, rev circ, catch samples of fluid in DP. Rel RTTS pkr, circ, TOH w/DST tls. 5" @ 10,150' 10,113' PBTD, (0'), WOC 9.8 ppg NaC1 Fin TOH w/DST tls. TIH w/EZ Drl retnr & set @ 9900'. TIH w/stab- in, est IR @ 1.5 BPM @ 1950 psi. M&P 12 sx C1 "G", displ w/9.8 ppg NaC1. Sqz 16 bbls C1 "G" w/l% CFR-2 & .4% Halad-24 into perfs, rev out DP. CIP @ 2107 hrs, 6/27/83. TOH w/stab-in tl. MU 4-1/8" bit, TIH w/CO assy to 5000'. 5" @ 10,150' 10,113' PBTD, (0'), TIH w/csg scrpr 9.8 NaCl/NaBr, Vis 29 WOC w/drlg string @ 5000' TIH, tag top of cmt @ 9894' DPM. CO cmt to 9905' (top of EZ Drl). Drl EZ Drl, CO hard cmt to 10,021' DPM, circ hole cln, tst csg to 2000 psi. TOH w/CO assy. TIH w/4-1/8'r bit & 5" csg scrpr. 5" @ 10,150' 10,113' PBTD, (0'), Instl'g new Hydrl rubber 10.0 NaC1/NaBr, Vis 30 TIH w/bit & csg scrpr, circ, displ well w/10.0 ppg NaCl/NaBr, TOH. RU Schl, TIH, set EZ Drl @ 10,018' DPM, TOH. MU CET log & rn f/ 10,012'-8450'; cmt sqz good, TOH. Press tst csg to 3000 psi. Tst rams to 5000 psi, tst Hydrl, leaked @ 800 psi. 5" @ 10,150' 10,019', (0'), TIH w/DST #2 10.0 NaC1/NaBr, Vis 29 Instl-new Hydrl rubber, tst to 3000 psi. MU DST tls, RIH, 34-std fluid gain inside DST string. TOH, M-2 sampler failed. out & TIH w/DST #2. Chg The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ' ]Title 8/02/83 Drilling Superintendent AR3B-459-2-B INumber all daily well hislory torres consecutively as. they are prepared for each well. r ARCO 011 and Gas Company Daily Well History--Interim Inilruollonl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lntltlm" sheets until tine{ completion. Report official or representative teSt on "FhlM" form. 1) Submit "lnllrlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ie set. Submit weekly for workovers and following setting of oil string; until completion. District Field Date and depth as of 8:00 a.m. Alaska county or Parish North Slope Borough Prudhoe Bay Lease or unit ADL #28321 Complete record for each day while drilling or workover in progress 7/02/83 7/03/83 7/04/83 7/05/83 7/06/83 7/07/83 ISlate Alaska Well no. ~PS #i 5" @ 10,150' 10,019' PBD, (0'), TIH f/DST #2 10.0 ppg NaCl/NaBr Fin TIH w/DST tls, dropped drift in tst string, TOH to rec drift. TIH w/open ended CO string, rev circ hole cln @ top of 5" lnr. MU DST #2 & TIH. 5" @ 10,150' 10,019' PBD, (0'), DST #2 - Closed in 10.0 ppg NaC1/NaBr Fin TIH w/DST #2, rn GR/CCL, set pkr @ 9858'. Rn DST #2 w/1000 ft wtr cushion @ 2450 psi nitrogen. Open APR vlv @ 9834', dropped GeoVann gun bar, guns fired (50 shots @ 1SPF, 9930'-9980'). Flow Flow well w/nitrogen returns. Close well in f/10-hr build-up data. 5" @ 10,150' 10,019' PBD, (0'), Swab DST String #2 10.0 NaCl/NaBr Fin 10-hr build-up data, rec'd fluid samples. Rev out formation fluid, lost 20 bbls 10.0 br to formation. Perform acid Job w/60 bbls 15% HC1 acid & 66.5 bbls diesel. Flow stopped. Swab tst string to 2140' w/ APR vlv closed. Open APR vlv, flow well, fluid level came up to 460'. Flow well & swab 3½" DP. 5" @ 10,150' 10,019' PBD, (0'), Circ hole cln @ 10,014' 10.0 NaC1/NaBr Swab 3½" DP, dropped tls. Close APR vlv, monitor build up, open APR vlv & att flow. Shear M-2 sampler, rev out, RD tst manifold. Pull RTTS free & observe well. TOH, rec'd swabbing tls. RIH w/bit & 5" csg, tag btm @ 10,019', circ hole cln. 5" @ 10,150' 10,019' PBD, (0'), Re-rn DST #2 10.0 NaC1/NaBr Circ hole cln @ 10,014', TOH & observe well; no fluid loss observed. MU DST #2 tls, TIH w/1000' wtr cushion, set pkr @ 9859', tail pipe @ 10,009' Open APR vlv @ 9835', flow well. 5" @ 10,150' 10,019' PBD, (0'), Att to flow well 10.0 NaC1/NaBr Att to flow well to surf, fluid level stopped @ 401'. Close APR vlv, RU arctic coil tbg& tst to 4000 psi. Displ diesel in coil tbg w/nitrogen, TIH while pmp'g nitrogen, open APR vlv, flow well to surf. Fluid ret's to surf stopped. TIH w/coil tbg to 8000' while pmp'g nitrogen. The above is correct For form prepa~tion and distribut(~n see Procedures Manual Section 10~' Drilling, Pages 86 and 87 AR3B-459-2-B ITitle 8/02/83 Drilling Superintendent lNumber all daily well history forms consecutively las they are prepared for each well. IPag~ no. 6 ARCO Oil and Gas Company Daily Well History--Interim Inllrucllanl: This form is used during drilling or workover operations. If testing coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Att&ch dsecription of ali cores. Work performed by Producing Section will be reported on "lnllrlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit '"lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovera and following setting of oil string until completion. District Field Date and depth as of 8:0Oa.m. Alaska County or Perish North Slope Borough Prudhoe Bay ,eaaa or unit ADL #28321 Complete record for each day while drilling or workover in progress 7/08/83 7/09/83 7/10/83 7/11183 7/12/83 IState Alaska Iwefino. SPS f!l 5" @ 10,150' 10,019' PBD, (0'), TOH w/DST tls 10.O NaCl/NaBr Fin TIH w/1¼" coil tbg to 8000', flow well & pmp nitrogen, observe fluid rise in DST string. Close APR, SI well f/12-hr tst. Rn GR/CCL/Temp T1/HP/fluid sample catcher. Shear M-2 Sampler, rev out, catching samples. Pull pkr loose, RD tst manifold. 5" @ 10,150' 10,019' PBD, (0'), TIH w/4-1/8" bit/5" csg scrpr 10.0 NaC1/NaBr RIH w/WL Howco retnr, set @ 9860'. TIH w/stab-in tl, sqz 112 sx Cl "G" w/l% CRF-2 & .4% Halad-24 cmt into perfs 9930'-9980' w/final IR of 1BPM @ 1600 psi. TOH w/sqz tls. TIH w/4-1/8" bit/5" csg scrpr, make CO rn. 5" @ 10,150' 10,019' PBD, (0'), SI f/3-hr build-up 10 ppg NaC1/NaBr Fin CO rn. TIH f/DST #3, rn GR/CCL, set RTTS @ 9571'. RU tst manifold, tst to 5000 psi. Open APR vlv @ 9548', drop Vann firing bar, flow well, close APR vlv, shut well in f/3-hr build-up data. 5" @ 10,150' 10,019' PBD, (0'), Tst'g BOPE 10.0 ppg NaC1/NaBr Shut well in f/10-hr build-up data, open APR vlv, flow well. Shear M-2 sampler, rev out, RD tst equip. Set BOPE tst plug &tst BOPE. 5" @ 10,150' 10,019' PBD, (0'), Prep to TOH 10.0 ppg NaC1/NaBr Fin tst'g BOPE. Rn & set retnr @ 9528', TIH w/stab-in tl, sqz perfs 9628'-9730' @ 1.5 BPH, 1650 psi w/162 sx C1 "G" w/l% CFR-2 & .4% Halad-24. Unsting f/retnr, rev out excess cmt. TIH w/4-1/8" bit/" csg scrpr, tat cmt @ 9526', circ & bring br wt up f/l~.0 ppg - 10.7 ppg. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling. Pages 86 and 87 AR3B-459-2-B ID.re ITitle 1/26/84 Drilling Superintendent '" '~ Number ail daily well history forms consecutivaly I as Ihey are prepared for each well. ARCO 011 and Gas Company Dally Well History--Interim Instmctlofll: This form is used during drilling or workover operations. If testing coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Produc ng Section will be reporfed on "lnllrlm" sheets until final completion. Report official or repre~,entatlve tset on "Fhtll" form. 1) Submit "latlrlm" sheets when filled out but not la. frequently Ihan every 30 dsyl. Or (2) on Wednesday of the week in which oll string ia set. Submit weekly for workover, and following setting of oil string until completion. District ]CountyorParish Stale I Alaska North Slope SorouKh I Alaska Field Lease or Unit Well no. Prudhoe ADL #28321 S?S #1 7/13/83 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 7/14/83 7/15/83 7/16/83 thru 7/18/83 7/19/83 5" @ 10,150' 9528' PBD, RD Schl 10.7 ppg NaC1/NaBr Circ, wt up br wtr, TOH w/4-1/8" bit & 5" csg scrpr. TIH, perf 9204'- 9206' w/3-1/16" perf gun @ 4 SPF. TIH w/EZ Drl, set retnr @ 9170'. Sqz perfs w/100 sx C1 "G" w/final IR of 1/2 BPM @ 1650 psi. Rev out excess cmt, TOH w/stab-in tl. Perf 9084'-9086' @ 4 SPF w/3-1/6" perf gun. TIH w/ EZ Drl, set retnr @ 9050'. 5" @ 10,150' 9528' PBD, Mill'g retnr 10.7 ppg NaC1/NaBr TIH w/retnr stab-in tl, sqz perfs 9084'-9086' w/160 sx Cl "G" w/l% CFR-2 & .4% Halad 24 @ 15.6 ppg w/final IR of 3/4 BPM @ 325 psi (final pressure 2500 psi). Displ cmt w/10.7 ppg brine. Unsting & rev out excess cmt. CIP @ 1125 hrs, 7/13/83. WOC, TIH w/4-1/8" TS mill & 5" csg scrpr, mill retnr @ 9050'. 5" @ 10,150' 9528' PBD, Milling retnr @ 9170' 10.7 ppg NaCl/NaBr Mill on retnr @ 9052', TOH. RIH w/Servco mill, mill on retnr @ 9052'- 9056', CO cmt 9056'-9085'. Rm 9085'-9270', mill on retnr @ 9170'. 5" @ 10,150' 9528' PBD, Flow well after acid job 10.7 ppg NaC1/NaBr Drl retnr @ 9170', tst csg to 1500 psi. Drl cmt to 9215', CO to 9400', cir¢ hole cln, TOH. RU & rn CBL f/9400'-8434'; sqz job good. MU DST tls, set RTTS, tst ins & manifold. Pmp nitrogen cushion w/1000 psi underbalance inside DP. Open APR vlv, drop Vann firing bar, guns fired, flowed well f/l-hr. Close APR vlv. SI well f/10-hr PBU. Open APR vlv, flow well f/6-hrs, SI well. Close APR vlv, rev out DP w/10.7 ppg NaCl/ NaBr. RU & acidize perfs w/95 bbls acid. Open well to flow after acid job. Well flowing w/string acid H20 w/40% oil. 5" @ 10,150' 9528' PBD, Flowing well 10.7 ppg-NaC1/NaBr Flowing well after acid Job thru surface tst'g equip. The above is correct Signature For form preparation and distribution~ see Procedures Manual Section 10. Drilling, Pages 86 and 87 IDate ]Title 1126/84 Drillin~ Superintendent AR3B-45~2-B all daily well history forms are prepared for each well. consecutively ARCO 011 and Gas Company "' Daily Well History--Interim Inltmctlonl This form is used during drilling or workover operations, f test ne, coring or pedorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach delcript on o! ell cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative felt on "Fi~I~" form. 1) Submit "ll~tlrll~" sheets when filled out but not lees frequently than every 30 days, or (2) on Wednesday of the week in which oil string il lit. Submit weekly for workovere and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Boroush I Lease or Unit Prudhoe Bay ADL # 28321 Complete record for each day while drilling or workover in progress 7/20/83 7/21/83 7/22183 7/23/83 thru 7/25/83 State Alaska Well no. s?s ~t 5" @ 10,150' 9528' PBD, Well SI f/PBU 10.7 NaC1, NaBr Flow well following acid job. PBU data following 28-hr flow. Close APR vlv, well SI f/ 5" @ 10,150' 9528' PBD, Att to est fluid level 10.7 ppg NaC1/NaBr Well SI f/28-hr flow. Open APR vlv, flow well f/15-min. Shear M-2 Sampler, rev circ DP. Pull pkr loose, lost 149 bbls fluid to hole. Re-set pkr, fill ann. Spot BridgeSal pill, hole cont to take fluid. Cut NaC1/NaBr wt f/10.7 ppg to 10.4 ppg w/ N O. Open by-pass vlv, hole still taking fluid, close by-pass v~v. RU fluid level instruments, att to est fluid level w/o success. Fluid loss appears to be slowing dn. Hole has taken approx 500 bbls fluid. 5" @ 10,150' 9528! PBD, Observe well 10.7 ppg NaC1/NaBr Att to est fluid level, data invalid. Pmp BridgeSal pills #3 & #4, shut pmps dn, observe well f/15-min. Pmp BridgeSal pill #5, shut dn aft displ, fluid level dropping. Unseat pkr & pull up hole 90', set pkr. Pmp BridgeSal pill #6, shut dn & observe well. Close by-pass, fill well & observe well. Fluid loss dn to 29 bbls/hr. 5" @ 10,150' 9108' DPM, RD Schl 10.7 ppg NaCl/NaBr Well SI. Open by-pass vlv, observe well, close' by-pass, fill ann, well tk total of 44 bbls. Unseat pkr & reset 8486' (TOL @ 8484'). Pmp 50 bbls, 10.4 ppg Maxical pill #1, displ thru M-2 by-pass dn ann. Hole taking fluid, appears pkr leaking. Pmp Mixical pill #2, hole standing full after displ'g w/pkr hanging in 7-5/8" lnr. Observe well. Circ to bal fluid, TOH w/DST tls #4. Rn JB to 9115'. RIH w/EZ Drl, set @ 9100' WLM. Tst csg & retnr to 1500 psi, bled off to 600 psi. RIH w/RTTS, set @ 9100', press tst to 1500 psi, bled off to 600 psi. Rel RTTS, pull up & set @ 9010'. Press tst backside to 1500 psi; OK. Leak appears to be in shot hole 9084'-9086'. Rel RTTS, rn in to 9100', circ, wt up NaC1/NaBr f/10.4 ppg to 10.7 ppg, TOH w/RTTS. The above is correct Signature For form preparerS'on and distribution see Procedures Manual Section 107 Drilling, Pages 86 and 87 AR3B-459-2-B IOate ITitle 1126184 Drilling Superintendent , INumber all daily well history Iorma consecutively .I as they are prepared for each well. I ARCO (~il and Gas Company Daily Well History--Interim nltmct onl: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number all drill stem tests sequentla y. Attach delcript on of a cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil string unlil completion. District County or Parish North Slope Borough ITM Lease or Unit ADL #28321 Field Alaska Prudhoe Bay Alaska Date and deptll as of 8:00 a.m. 7/29/83 7/30/83 7/31/83 8/01/83 8/02/83 8/03/83 Complete record for each day while drilling or workover in progress 5" @ 10,150' 9108' PBD, Circ & wrk pipe @ 9108' 10.7 ppg NaC1/NaBr Fin rn'g CET log. MU DST tls #5, RIH, tag btm 14' high, TOH. MU 4-1/8" BHA, TIH, tag btm @ 9108', circ& wrk pipe. 5" @ 10,150' 9108' PBD, Well SI f/5-Hr PBU 10.7 NaC1/NaBr Cir¢, wrk JB's, TOH. MU Vann guns, TIH w/DST tls #5. manifold, tst ann w/500 psi w/RTTS set @ 8932'-8936'. perfs 8996'-9046', flow well f/10-min. SI f/5-hr PBU. RU tst Shoot 5" @ 10,150' 9108' PBD, Circ @ 9070' Compl 5-hr SI, open APR vlv, flow well, close APR vlv, flow well. Shear M-2 Sampler, rev out, unseat RTT's, observe well, TOH w/DST tls. TIH w/4-1/8" bit & 5" csg scrpr, circ hole cln f/9070'. 5" @ 10,150' 9108' PBD, TIH w/DST Tis #6 9.8 NaC1/NaBr Circ hole @ 9070', TOH. RU Schl, set EZ Drl @ 8980', tst csg & EZ Drl w/3000 psi. TIH w/4-1/8" bit, 2 JB, 5" csg scrpr to 8980', circ & cut br wt back to 9.8 ppg, TOH. MU DST tls #6. 5" @ 10,150' 8980' PBD, SI f/10-hr PBU 9.8 NaC1/NaBr TIH w/DST tls #6, space out, set & tst pkr & surf tst equip to 5000 psi. Open APR vlv, drop GeoVann firing bar, guns fired. Flow well, SI f/5-hr build up data. Flowed well, SI f/10-hr build up data. 5" @ 10,150' 8980' PBD, C&C br Compl 10-hr SI, open APR @ 8780', flow well. Shear M-2 Sampler, rev out, TOH w/DST tls. TIH w/4-1/8" BHA, circ, bring br wt up to 10.4 ppg, observe well. The above is correct For form prepara~on and distribu~n see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ' ]Title 1/26/84 Drilling Superintendent AR3B-45~2-B INumber ell daily well hislory forms consecutively as they are prepared for each well. AtlanflcRichfieldCompany <) Dally Well History-Final Report Inibuetle~l: Prepare end M~A~LliI[~ _Si- ~1~1~_ .fl/It Wednesday after ell. ow=Il has be?ri..al~.lgned or .w. ell I1_ Plugg. ed, Abln. doned, o_r .SO. Id. "F]nM Relax)ri" ~hould be ' · _' ~ M luapended for an Indennlte or ipp_re?aole length ,o,f time. un .womoverl ween In CruCial ti.st II not required upon completion, ~ Mltllli~iIFllti I~ test datl In blocke provided. Thl FktM Relx)rt' lore ely ce uled for reporting the entire operation If apace Il evallal~---..~ . District ]county or Parilh Alaska I North Slope Borough Field ILeale or Unit Prudhoe Bay I ADL #28321 Auth. or W,O. no, ITlUe AFE 501221 I · Exploratory Oper~or ARCO Alaska, Inc. IAccountlng COlt center code State Alaska Well no. SPS Spudded or W.O. begun A.R.CO. W.I. 50% Date 4/4/83 Spudded Date and depth es of 6:00 a.m. 8/04/83 8/05/83 8/06/83 thru 8/08/83 8/09/83 Complete record for each day reported Iotal number of wells (active or inactive) on this, Dst center prior to plugging and / bandonment of this well J our Prior Itatua If a W.O. 2130 Hrs. N/A 5" @ 10,150' 9119' PBD, Drlg Jnk 10.4 NaCl/NaBr Drl EZ Drl @ 8980', cmt & Jnk to 9108', EZ Drl @ 9108', cmt & Jnk to 9119'. 5" @ 10,150' 9525' PBTD, TOH w/mill Drl ink f/9119'-8521', hole taking fluid, observe well. Build vol in pits, pmp LCMpill. TIH, rm 9261'-9291', TOH, lost 3 cones in hole. RIH w/ink mill, tag ink @ 9161', mill & psh Jnk to 9525', hole losing fluid. Circ, build vol in pits, spot LCM pill, TON. 5" @ 10,150' 9525' PBTD, Pmp diesel cap in ann Fin TOH w/mill. RU, rn DiaLog csg profile caliper f/7704'-surf. Tst lub to 1500 psi. TIH, perf 9060'-9081' @ 1HPF. Chg guns, TIH, perf 9100'-9112' & 8973'-8983' @ 1HPF. TIH w/Bkr "DB" pkr, set @ 9087' & No Go "D" Nipple w/1.813" ID @ 9098'. TIH w/Bkr FAB pkr, set @ 8991' w/ No Go "D" nipple w/2.25" ID @ 8996', TOH. RU & rn 264 its, 3½", 9.2#, N-80 butC tbg &lnd w/pkr @ 8420', safety vlv @ 2126'. ND BOPE, NU & tst tree.to 5000 psi. Pull BPV, pmp diesel cap. 5" @ 10,150' 9525' PBTD, RR Fin pmp'g diesel cap in ann. Tst lub to 2500 psi, TIH w/std'g vlv & set "D" nipple @ 8434'. Set FHL pkr, tst tbg to 3000 psi; OK. TOH w/std'g vlv. Instl BPV. RR @ 1230 hfs, 8/8/83. Old TD New TD 10,113' 9525' Released rig Date 1230 Hrs. I PB Depth 8/8/83 ]KlndofHg Rotary Clarifications (o11, gas, etc.) 0il Producing method IType completion (single, dull, etc.) Single Official mN~olr name(I) Sadlerochit Flowing Potential test data Well no. Date Racervolr Producing Interval 011 or galTeat time Production OII on test Gal per day Pump size, SPM X length Choke size T.P. C.P. Water % OCR Gravity Allowable Effective date corrected The above is correct 1/26/84 Drilling Superintendent For form preparation and di~'lbutlon, see Procedures Manual, Section 10, Drilling, Paoli 86 and 87. AR3B-45g-3-B Number all dilly well hlalory forml conlecutlvaly II they are prepared for each well. .~! ~'_ ~ Sugges~ea' ~orm to'~e- insq~tod in' each "JL~ive well folder to d~,eck i~ ~for timely compliance-with our regUlations. . Operator, Well Nam~ and Number' Reports and Materials to be received by: - ' Date' .Required Date Received _Remarks .Ccmpletion Reuort Yes · .. , -Samples y~-~ O/--2 ~-- ~ d~," · Core ~scrip~ 7~ ¢ XX Registered S~ey Plat ' ~ ~~. ~- ~?- ~~~ _ Inclina~on S~ey ~ T .~ ., ., ~ e& ~. , .. Dire~ional ~ey . Drill St~ Test ~e~:sb ~ ~ 3 ............ STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX July ~18, 1984 Mr. J. L. Fithian Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 AnchOrage, Alaska 99510-0360 Prudhoe Bay Unit_ Wells South Bay State No. 1, Pingut State No. 1. Dear Mx. Fithian: The Comm_ission considers the date that triggers the 30 day filing Period for the comPletion report, deviation survey or inclination 'survey, and other required well data to be the date the drilling rig is released whether or not preparator~i.~to extended testing of the well. Our records show that this date for the listed wells is August 8, 1983, January 10, 1984, and October 3, 1983 respectivelY. We have no record of having received all the required data. Please submit the required reports at this time. Yours very. truly, Harry W. Kugler Commis s ioner JAL/be: 1. HWK. F ARCO Alaska, Inc. Extension Exploration TRAN SM I TTAL From' Date' m.~' 14---- -- Transmitted herewith are the following' Receipt Acknowledgment- Return Receipt t~.':~ARCO Alaska, Inc. Extension Exploration P. O. Box 100360 Anchorage, AK 99510 Attn ' Processed MEMORAr :DUM TO: State of Alaska ALASKA OIL AND GAS CONSERVATION CObR~ISSION Well Files DATE: March 2, 1984 F,LE NO: 2g. 13 TELEPHONE NO: FROM: William Van Alen~ SUBJECT: Drilling Depths 12/31/83 The following are the depths that the below-listed ARCO wells were at on midnight December 31, 1983: 12:00 pm Well 12/31/83 Dep~th Pingut St. No. 1 PBU 3-26 PBU South Pt. #1 KRU 1F-16 KRU 2F-1 KRU 2F- 13 KRU WSP-1S KRU WSP-2 KRU WSP-10 KRU W. Sak SWPT ~1 11,467' 10,973' 10,301' 9,175' 3,580' 7,837' 9,360' 3,950' 4,100' 4,344' This information was relayed to William Van Alen via phone this date by JoAnn Gruber of ARCO's Drilling Department. 02-001AIRev. 10i79'~ ARCO Alaska, Inc. ARCO Explora..~n -Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 277 5637 SAMPLE TRANSMITTAL HAND CARRY SHIPPED TO: ALASKA OIL & GAS CONSERVATION COMMISSION STATE OF ALASKA 3001.PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 ATTN: MIKE MINDER OPERATOR: ARCO SAMPLE TYPE' CORE' CHIPS SAMPLES SENT: SEE ATTACHED LIST DATE' JANUARY 26,1984 NAME' SOUTH POINT STATE #1 NUMBER OF BOXES' 39 SHIPPED BY Z~ ,-z z-~ '?-~'~ j ' (~/ · ~,-f, /~ _~ff/.~,/.7..~7,~/Z PLAEO LAB TECH UPON '" ~ ........ i~OIE ~qY DiSCREP~qCiES AND I~iL Aoi~NE~e ..... ~irl OF IH~S~ S~¥1PLES, .PLEASE ~ ~ COPY OF THIS FO~ TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHO~IGE, ALASKA 99510 ATTN: R. L. BROOKS DATE' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO CORE. -CHIPS SOUTH POINT STATE#I .......... 9424-94'45 ..................... BOX~16"CONT.- 9446-9456 BOX#17 9460-9485 . 9486-9530 BOX#1J' 95.51-9587 BOX#19 9588-9626 BOX#20 9627-9657 BOX #21 9658-9698 BOX #22 9699-9707 9709-9724 9726-9739 BOX #23 9740-9766 BOX #24 9767-9810 9811-9825 9827-9845 9846-9887 BOX #25 BOX #26 BOX #27 9888-9919 9920-9941 9945-9945 9947-9975 9977-9997 BOX #28 BOX #29 BOX #50 .~- 9998-10023 ~ 10027-10044 BOX #31 10045-10081 10087-10121' BOX #32 BOX #33 10122-10150 BOX #34 10151-10175 10176-10200 10201-10225 10224-10250 10251-10263 BOX #35 BOX #36 BOX #37 BOX #38 BOX #39 JAN2 6 15'84 Alaska Oil & Gas Cods, (;ommissior~ Anchora,qe ARCO- CORE CHIPS SOUTH POIN~F STATE #1 8850-8858 8862-8872 8874-8875 8895-8902 8903-8913 8915-8936 8937-8975 7976-8980 8982-9000 9003-9009 9013-9015 9020-9046 BOX~-[ BOX#2 BOX #3 BOX #4 BOX #S 9058-9099 9100-9103 9105-9132 BOX #6 BOX #7 9133-9141 9146-9162 9164-9i~5 BOX #8 9176-9178 9180-9180 9182-9196 9198-9206 9207-9222 9224-9244 BOX #9 BOX # 10 9248-9269 9273-9283 BOX #11 9284-9308 BOX #12 9312-9353 BOX#13 9354-9382 BOX #14 9383-9410 9411'9422 BOX # 15 ~-OX # 16 ARCO Alaska, Inc.' Post Office £ _.. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 30, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: South Bay State #1 - Safety Procedures Dear Mr. Chatterton: Although we have not encountered H2S in the subject well, nor do we expect to, we have implemented additional H~S' safety procedures. The attached letter, dated December ~9 1983, outlines the various safety procedures that have been included in our H2S monitoring program on the South Bay State #1 well. If you have any questions, please call me at 263-4610. Sincer~y,~ T. L. Fithian Area Drilling Engineer TLF/03: rb Attachment cc: South Bay State #1 Well File J. Gruber, ATO 1478 J. R. Rall, ATO 1458 R. A. Ruedrich, ATO 1926 ARCO Alaska. Inc. is a Subsidiary of AllanticRichlieldCompany ARCO Alaska, Inc. Date: Subject: Internal Correspon( e December 29, 1983 Safety Procedures Impletemented on South Bay State #1 From/Location: To/Location: R. L. Hines - ATO 1470 Scott Walker - ATO 1378 As of this date, the following safety procedures have been included in our H2S monitoring program on the South Bay State well: le Four (4) automatic hydrogen sulfide monitoring devices with audio/visual alarms have been installed. These are located at the shale shaker, bell nipple, rig floor, and on the stairway leading to the mud pits. Currently, these monitors are tested and watched by the mud loggers during drilling operations. me Two (2) hand-held Draeger detection meters are on location; one in the doghouse and one located in the pit area. Use of the meters was discussed during a safety meeting. 0 Zn CO3, a hydrogen sulfide scavenger, is on location. Fourteen (14) Scott Air Packs (Scott Pressur-Pak II/Back-Pac Style) are on location. Twelve (12) are located on the rig and two (2) are in the camp. A demonstration on how to use the air packs was given during safety meetings. e A H~S Contingency Plan has been prepared showing possible escape routes from the rig and location. e ARCO Alaska, Inc.'s Fire and Safety personnel have presented a safety meeting to each of the crews on the rig. A film, "HAS Can Kill" was shown. A discussion on the properties of H2S, how t~ detect its presence, use of the "buddy system" for rescue, safe breathing areas, and how to use the Scott Air Pack followed. 7o 0 The wellhead currently being used is H2S rated. The Magcobar mud engineer performs a chemical check of the mud for H2S twice daily during drilling operations. 9~ Sensor badges that change color when H2S is present are being worn by each member of the drilling crew. 10. Sign posted at the drillsite access indicate potential H2S. 11. Audio alarm and flashing light has been installed at the test facility. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany H2S Safety Procedures - South Bay State #1 December 29, 1983 Page 2 12. There are two (2) wind socks; one at the drillsite access and one on location. 13. Station bills have been posted. 14. H2S monitoring panel installed on the rig in the doghouse for use during testing and completion operations. R. L. Hines Sr. Drilling Supervisor RLH: sw MO1 12/29/83 xc: R. A. Ruedrich W. S. Congdon South Bay State #1 Well File T. L. Fithian M. J. Hebert/E. Kirk White A~CU ~LASKA, INC. ) UT/f /N HYP~OGEN SULFIDE PRODUCTION AND DRILLING OPERATIONS / iNIMUM SAFETY AND LOSS PREVENTION PROVI~--,NS ~'~..~. ~ / (Ref: ARCO Oil and Gas Company Polic> Following is a checklist of items which must be addressed when planning for hydrogen sulfide exposure. These items should be considered minimums and should be exceeded when applicable. More detail is addressed in Texas RRC Rule 36, adopted by ARCO Oil and Gas Company as the binding standard company-wide. A. Radius of Exposure*-identification 1. Calculated from H~S source using dispersion equations (re: Rule 36) 2. For unknown sourc~ levels - 3000 feet radius is minimum 3. Exposure area is to be Plotted, all ingress and egress routes identified and inhabited facilities identified within the boundaries 4. All ingress routes are to have signs posted, clearly visible, restricting access to only authorized personnel. 5. Perimeter boundaries will have hydrogen sulfide warning signs at appropriate points as well as wind direction markers at strategic locations. Wind directional markers will be located such that a person is in visual contact at all times when leaving the lo- cation. B. Authorized Personnel Access-Training Requirements 1. All personnel having regular access to the exposure area will be requi~ed to attend training and briefing sessions prior to access. 2. As a minimum, handling will encompass: a. Effects of H?S; symptoms of exposure; identifications of exposure source b. Hands on traYning, and proof of performance, with breathing air equipment c. Briefing on fixed monitoring; personnel monitoring equipment to be used; alarm interpretations d. Evacuation procedures; process safety equipment (STV, etc.) e. Techniques of "buddy system" emergency response/rescue f. A post-test will be given and kept on file 3. Short term access to unauthorized employees (i.e., short term maintenance, etc.) will be allowed only in the accompaniment of an authorized person. C. Vehicular Access-Procedures 1. All vehicles will be parked at the facility such that they may be used for immediate emergency egress (i.e., headed out configuration; keys left in ignition) 2. Fresh air equipment being carried in each vehicle will be placed in the front seat for immediate access during emergency situations 3. All personnel entering the location must be "authorized" and have had documented train- ing as specified in B above. D. Contingency Planning 1. An emergency contingency plan will be charted before any operations take place; as a minimum, this plan will include: a. Evacuation exposure levels, alarm interpretation, shut-in procedures, personnel response b. Definition of personnel briefing area during evacuation (headcount purposes) c. Radio, telephone call list with emergency response units; local authorities d. Evacuations of adjacent facilities within exposure area. e. Intraeompany location management contacts f. Egres~ routes E. Monitoring Equipment and Breathing Air EqUipment 1. Fixed monitors will be maintained and tested daily; calibration frequency based on manufacturer's specification 2. Personnel monitors will be worn by authorized personnel such that singular personnel will wear one at all times; groups will have one worn by one member ~ 3. Fixed monitors will have both visual and audible alarms with the high level alarm set ~-~ no higher than 50 ppm '::] 4. Personnel monitors will be set at no greater than 20 ppm for low level alarm, and no ~ greater than 50 ppm high level alarm (for dual alarm models) .~i 5. All monitoring equipment will be selected from preapproved purchasing guidelines and ~..~ ~ will be selected based on constraints to temperature extremes i~i.~ ~' Breathing air equipment (NIOSH approved) will be available such that all exposed per- ~:~ ~ sonnel will have readily accessible units F~ ;i;~ocumentation '~ 1. A central file will be maintained at the production location central safety group; with i~ a duplicate copy at Anchorage Safety. Documentation will include: ~.~ a. Contingency plan ~'~ b. Training logs; including names of attendees and copies of post tests i~.~i e. Monitoring equipment calibration schedule and tests log d. Emergency dri.ll report~ e. Any other documentation regarding formalized safety activities * Further information is detailed in RRC Rule 36 regarding general public access, right-of-ways, and facilities that are Within radius of exposure. PEU030 ARCO Alaska, Inc. ~_~-'. ",. Post Office Anchorage, Alaska 99510 Telephone 907 277 5637 December 16, 1983 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Flare Request for Long Term Test at South Point State No. 1 ARCO Alaska, Inc. requests AOGCC permission to flare hydrocarbon gas during a long term production test at South Point State No. 1 and produce during the test period at GOR's in excess of 2000:1 SCF/STBD. Th~ test is expected to begin in the first quarter of 19~and continue until mid-1985 (approximately 18 months). The test will provide long term production decline data and GOR performance in a timely fashion for "optimizing development planning" of full field development of the Lisburne reservoir. A test facility which was installed for the two-month production test at SPS #1 will be used for the long term test. The facility includes a flowline between SPS #1 and Drill Site No. 18 to allow sending Lisburne production into the Sadlerochit facilities for processing. In order to use the Drill Site No. 18 facilities, the SPS #1 test separator has to be operated at pressure greater than 300 psi. Under this mode of operation, most of the produced gas is sent to Drill Site No. 18, but a small flare is needed to handle the gas which flashes off of the stock tank oil as it is reduced from separator pressure. For the long term test, this amount is expected to be 60 MMSCF of gas, or about 4% of the total gas production. Go, ooo~F~[G~?o)~ ~~cF/~ ~v~. The well is expected to produce about 600,000 STB of oil and an estimated 1200 MMSCF Of gas during the test. The gas-oil ratio is expected to be below 2000 SCF/STB initially but increase to over 2000 SCF/STB by the end of the test. Regulation 20 AAC 25.240 states that "an oil well may not be produced at gas-oil ratios in excess of 2000 SCF/STB without gas reinjection into the reservoir". Based on the importance of long term production data in order to properly size major production facilities associated with the development of the Lisburne reservoir, we also request a waiver from the above mentioned regulation. ARCO Alaska, inc. is a s.bs[diar¥ of AllanlicRichfie!oCompany Mr. C. V. Chatterton December 16, 1983 Page Two The longest sustained production tests in the Lisburne reservoir to date have been two month tests performed at West Bay State No. 1 and South Point State No. 1. The tests were only long enough to give hints of potential operational and GOR problems and no decline data at all was obtained during the relatively short tests. Although sufficient productivity and reservoir data has been obtained to justify an initial development, additional data is needed to most efficiently develop and maximize recovery from this complex reservoir. A long term test in the 1984/1985 time frame would provide data which could be incorporated in facility design and reservoir evaluation to allow timely and efficient development of the Lisburne reservoir. If you have any questions or comments, please call me at 263-4206. I would be happy to drop by and discuss this matter with you at your convenience. Your very truly, J. S. Dayton Regional Engineer JSD/dy cc: R. K. Doughty, AT0-1988 S. Hasund, AT0-1826 D. K. Chancey, ATO-1828 Glen Doughty Will Carter Scott Walker Jack Walker Harry Kugler Lonnie Smith Jim Tr imb le Harold Hedlund D. S. Supervisor Reservoir Engineer Safety Advisor - Drilling Facilities Engineer Commissioner Commissioner Engineer Engineer ARCO Alaska, Inc..-- -'-- Post Office f~ .~)360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 15, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton- Enclosed are Monthly Reports of Drilling and Workover Operations for the following' DS 4-20 DS 14-32 DS 14-31 DS 3-23 DS 3-22 DS 3-21 Pingut State #1 South Point State #1 Sincerely, ~M/A. Major ~~ A~ea Drilling Engineer MAM/DRN-tw NORTON/45 Enclosures ARCO Alaska. Inc. is a Subsidiary of Allanli. cRichfieldCompany · ~ STATE OF ALASKA ~--. .MONTHLYALASK, _ AND GAS CONSERVATION L~, MISSION .,Z ~ REPORT OF DRILLING AND WOi:IKOVER OPERATIONS 1. Drilling welIx~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 7. Permit No. 83-47 4. Location of Well atsurface 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UN 3. Address 8. APl Number P. 0, Box 360, Anchorage, AK 99510 50- 029-20930 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 51.5' RKB 11.5' Pad ADL 28321 10. Well No. South Point State #1 11. Field and Pool Prudhoe Bay Field/Lisburn Lisburne 0il Pool For the Month of August ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks I Spudded well ~ 2130 hfs, 04/04/83. Drld 17-1/2" hole to 2667'; ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 8090'. Ran logs. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8791'. Ran logs. Ran & cmtd 7-5/8" lnr. Drld cmt to 8746', set EZSV ~ 7601'. Sqz Class G cmt into lnr lap. Drld cmt & CO to 7717'. Ran CBL. Drld 6-1/2" hole to 8850'. Cut 34 cores. Pipe stuck, recovered fish. Ran logs. Ran, cmtd & tstd 5" lnr. Ran DST Run#1 & Run#2. Sqz perfs. Ran CET. Run DST#2. Sqz'd perfs. (See attached page) 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 80'. Instld w/2295# poleset. 13-3/8" 72#/ft, L-80, Butt csg w/FS @ 2654'. Cmtd w/2000 sx Fondu & 400 sx PFC cmt. 9-5/8", 47#/ft, N-80, Butt csg w/FS # 8076'. Cmtd w/500 sx Class G. cmt. 7-5/8", 33.7#/ft, S-95, hydril SFJP lnr fr/7712' - 8788'. Cmtd w/293 sx Class G cmt. 5", 18.0#/ft, S140 SFJP lnr fr/8484'-10150'. Cmtd w/300 sx Class G cmt. SEE DRILLING HISTORY 14. Coring resume and brief description See Attached Core Data l~.lLOas_ run a~ deRth where run L/BHCS/GR/SP fr/2653'-8081' LDT/EPT/GR fr/10135'-8700' CBL #2 10092'-8400' LDT/CNL w/GR & Cal fr/8792'-8079' DIL/BHCS/GR fr/10135'-8700' CET fr/10100'-8396' CBL fr/8792'-7396' DIL/MSFL/GR fr/10134'-8700' LDT/CNL/NGT/Caliper 10134'-8700' LSS/GR fr/10135'-8700' FDC/GR fr/10135'-8700' GR/CCL 9300'-9800' CET fr/10012'-8450' CBL #1 10092'-8400' DST data, perforating data, shows of 1-12S, miscellaneous data CET fr/9108'-8484' DIA-Log f/7704' -surf DST #1 10020'-10038' w/1 spf DST #2 9930'-9980' w/1 spf - Sqz'd perf w/112 sx Class G cmt DST #3 9628'-9730' w/1 spf - Sqz'd w/162 sx Class G cmt DST #4 9118'-9198' w/1 spf DST #5 8996'-9046' w/1 spf (see attached pag'~J") 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOT/E~/--Repor~ this forrr~quired for ea~d~ calendar month, regardless of the status of operations, and must ~e filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate t MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS (cont'd) South Point State #1 12. Ran DST #3, sqz perfs. Perf 9204'-9206' & sqz. Perf 9084'-9086' & sqz. Ran CBL. Ran DST #4, acidize perfs. Hole took fluid, found leak at perfs 9084'-9086'. Perf 8988'-8990' & sqz; sqz leaking perfs. Ran CET. Ran DST #5. TOH f/DST tools. Tested csg. Ran DST #6. CO to 9291'. Perf /9060' - 9081'- & f/9100' - 9112'; & f/8973' - 8933' Set pkr ~ 9087' & 8991'. Ran 3-1/2" comp assy. Secured well & RR ~ 1230 hfs, 08/08/83. SEE DRILLING HISTORY 16. Perf 9204'-9206' w/4 spf; sqz'd w/lO0 sx Class G cmt. Perf 9084'-9086' w/4 spf; sqz'd w/160 sx Class G cmt. Perf 8988'-8990' w/4 spf; sqz'd w/175 sx Class G cmt. DST #6 8864' - 8936' w/1 SPF. Perf 9060' - 9081' - w/1 SPF. Perf 9100' - 9112' - w/1 SPF. Perf 8973' - 8983' - w/1 SPF. NORTON/MR32a South Point State #1 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 2130 hrs, 4/4/83. Drld 17-1/2" hole to 2667'. Ran 72 jts 13-3/8" 72#/ft, L-80 Butt csg w/FS @ 2654'. Stab into FC w/stab-in tool @ 2566'. Pump 100 bbls ligno pill. Cmt 13-3/8" w/2000 sx Fondu followed by 400 sx PFC. ND 20" hydril & diverter system. NU & tstd 13-5/8" BOPE @ 5000 psi. Drld FC, cmt & FS. CO to 2667', 10' new hole. Perform shoe tst, held 11.2 ppg EMW. Drld 12-1/4" hole to 5841'. Wash & ream 5721-5841'. Drld to 6644'. Wash & ream 6600-6644'. Drld to 8090' (4/11/83). Ran OH logs - DIL/BHCS/GR/SP fr/2653-8021'. Ran 194 jts 9-5/8", 47#, N-80 Butt csg w/FS @ 8076'. Cmtd 9-5/8" csg w/500 sx Class G. Tst csg to 3000 psi. Drld FC & cmt. Drld cmt, FS & 10' new hole. Perform form leak-off tst, held 16.4 ppg EMW. Drld to 8240', fighting sloughing shale & gas. Ream 8195-8240'. Drld 8-1/2" hole to 8791' (4/14/83). Ran DIL/BHCS w/SP & GR fr/8790-8079', LDT/CNL w/GR & Cal fr/8792-8079'. Perform Arctic Pack dwnsqz w/300 sx PFC followed by 131 bbls Arctic Pack. Ream 30' to btm. Ran 25 jts 7-5/8" 33.7# S-95 hydril SFJP lnr w/float equip & mechanical hngr w/tieback sleeve. Cmt 7-5/8" w/293 sx Class "G" fr/7712-8788'. TOH w/5" DP & lnr setting tool. Set tst plug, chng top rams to 3-1/2". TIH & LD HWDP. TIH w/8-1/2" bit & csg scrpr. No cmt on TOL. LD 80 jts E DP, 6-1/4" DC & scrpr & bit. TIH w/6-1/2" bit. PU 3-1/2" DP. TIH w/CO assy on 5" DP. Drld cmt to 8746'. Press tst lnr lap - lap leaked. TOH w/CO assy. TIH w/EZ drl on 5" DP, PU 5" DP. Set EZ drl SV @ 7601'. Stab into EZSV, unsting. Sqz 200 sx Class G into lnr lap. Tst csg to 3000#. Drl cmt to 7594'. Drl EZ Drl fr/7594-7600'. CO cmt 7600-7712'. TIH w/6-1/2" bit, CO cmt 7712-7717. Tst csg, found leak on vlv on tbg spool, chng out. CO cmt, Drl FS & 7' new hole. Perform leak-off tst to 12.3 ppg EMW. Ran CBL fr/8792-7396. LD excess 5" DP. Displ ligno mud w/50 bbls hi vis pill followed by bland mud. Drld 6-1/2" hole to 8850'. TIH w/coring assy. Cut core #1 8850-8862, recover 9'. Cut core #2 8875-8895, recover 8.2'. Wash & ream 8860-8895'. Cut core #3 8895-8945', recover 59'. Wash & ream 8904-8954'. Cut core #4 8954-8980' recover 39'. Tst BOPs. Wash & ream 8943-8993'. Cut core #5 - 8993-9010' (coring break 9004-9008'), stopped coring, cont coring 9010-9012'. Took formation kick. Circ out ann gas bubble & oil & gas cut contam bland mud. Lost 69 bbls mud to form. Incr MW, lost 58 bbls to form, lost 44 bbls during circ~ixing cycle. Recover 15.2' core #5. Chng well over to new bland mud. Cut core #6 9013-9020' recovered 2-1/2'. Cut core #7 902'0~9032~9032-9058' recovered 28'. MO3 ... Cut Core #8, 9058'-9067', 9067'-9098', 9098'-9114', recovered 56'. Cut Core #9, 9114'-9146', recovered 29'. Cut Core #10, 9146'-9174', 9174'-9176'. Well took kick. Fin cutting core #10, 9176'-9186', 9186'-9190'. Well taking fluid. Spot LCM pill on btm. Recover 43' Core #10. Cut Core #11, 9190'-9207~. Spot LCM pill, pump dry job. Recover 16.6' Core #11. Cut Core #12, 9207' -9248', recover 38'. Cut Core #13, 9248' -9273', recover 21-1/2'. Spot 50 bbls coarse LCM pill followed by 50 bbl coarse kwik seal LCM pill 9273' -8148'. Cut Core #14, 9273' -9312', recovered 36'. Cut Core #15, 9312' -9372', recovered 60'. Cut Core #16, 9372' -9409', recovered 37'. Cut Core #17, 9409' -9460', recovered 47'. Cut Core #18, 9460' -9518', recovered 58'. Cut Core #19, 9518' -9546', recovered 28'. Wash- 9505' -9546'. Cut Core #20, 9546' -9588', recovered 42'. Wash & ream 9548' -9588'. Cut Core #21, 9588 '-9648', recovered 59'. Wash & ream 9633' -9648'. Cut Core #22, 9648' -9685', 9685' -9708'. Spot LCM pill. Recover 60' Core #22. Cut Core #23, 9708' -9767', recovered 59'. Cut Core #24, 9767' -9820', 9820' -9827', recovered 58.5'. Cut Core #25, 9827'-9843', 9843' -9883', 9883' -9886', recovered 59'. Cut Core #26, 9886' -9905', 9905' -9946', recovered 60'. Wash 9905' -9946'. Cut Core #27, 9946' -9978', 9978' -9997', recovered 51'. Wash & ream 9910' -9997'. Cut Core #28, 9997' -10014', 10014'-10027', pipe stuck below jars. Jarred pipe, spot SFT pill. Ran free pt, pipe free @.990_5~'. Perform acid job while jarring. Pipe free. Circ & work pipe. Recovered 30' Core #28. RIH w/RTTS & storm choke, set RTTS @ 5000'. Chng seals on btm BOP ram. Test seal - ok. Rel RTTS. Pump dry job. Ream 150' to btm. Cut Core #29, 10027' -10086', recovered 55'. Cut Core #30, 10087' -10102', recovered 15'. Cut' Core #31, 10102' -10161', recovered 59'. Cut Core #32, 10161'-10208', recovered 47'. Cut Core #33 10208'-10263'; recovered 55'. Cut Core #34 10263'-10296' , 10296' -10301'. Pipe stuck while attempting to PU for connection. Fish consists of 6-1/2" core bit, 2 core bbls, XO, 2 monel, stab, monel, 7 steel DCs, jars, 14 steel DCs, 20 jts 3-1/2" DP. Top of fish @ 8827'. MU several fishing strings and work overshot past fish, did not recover fish. RIH w/sinker bar assy, assy dropped dwn 3-1/2" DP. Attempt to back off tool jt, did not back off. TIH w/string shot, backed pipe off @ 8732'. Work washover shoe over TOF, part of washover shoe left in hole. TIH w/fishing assy #9, recovered 191' of ~-1/~" DP. TIH w/fishing assy #10, latch onto fish w/overshot and grapple. 5885'; failed. Latch onto fish, jar & work fish. Ran backoff shot, backed off @ 9885'. Pull WL & back off tools, pull 15 stds. TOH w/fish. Recovered 16 jts DP & 13 DCs. TIH w/fishing assy #12, screw in TOF @ 9851'. Circ & jar fish. Displ & spot 500 gals Hcl acid, cont'd jarring, did not recover fish. Ran free pt, pipe stuck @ 99~99~5~,. Backoff shot @ 9979'. Pull WL, pull 15 stds, TOH & LD fish. Recovered 3 DCs, I set jars, TOF @ 9974'. Wash over fish. Screw' onto fish, recover 5 steel DCs & I monel. TOF @ 10159'. RIH w/overshot, tag fish, work overshot on fish. RIH w/fishing assy #16, dress TOF. POOH, work overshot onto fish @ 10159'. Jar on fish. RIH w/impr blk (used as a blind box), tag up @ 10167'. RIH w/string shot, irratic CCL operation prevented tie-in; chng CCL. Tie in, shot, no backoff. Mill over stab blades. Wash over pipe. Work overshot onto fish, jar on fish, no movement. RIH w/string shot, would not back off. Second shot would not back off. Attempt to release overshot, would not release. RIH w/grapple, would not latch. RIH w/impr blk, no impr made. Reran, tool stuck @ 9945'. Jar loose. Lead plug fr/impr blk left in hole, drive to top of WL fish. Pump on DP to wash out overshot, pipe came loose during pickup. LD fishing string. Ran DIL/MSFL/GR 10134 '-8700'; LDT/CNL/NGT/Caliper 10134'-8700'; LSS/GR 10135'-8700'; LSS/GR tool failed. Ran LDT/EPT/GR 10135'-8700', LDT failed. Ran DIL/BHCS/GR 10135'-8700'; FDC/GR 10135'-8700'. Ran. PHTU, tool failed. Ran dipmeter 10135'-8700'. Reran PHTU, tool failed. Ran RFT. Ran 47 jts 5" 18# S-140 SFJP lnr fr/8484'-10150'. Cmt 5" lnr w/300 sx Class G cmt. Drl cmt to 10112'. Tst csg to 3000 psi. Chng out drlg mud w/9.8 ppg NaC1. Ran CBL #1 fr/10092'-8400' & CBL #2 fr/10092'-8400'. Ran CET fr/10100'-8396'. Ran VSP. Ran GR/CCL 9300'-9800'. Set RTTS. Run GR/CCL to confirm setting depth. Displ fluid in DP w/N2. Bar dropped. Vann Guns did not fire on DST 1, Run#1. TIH w/overshot & recover bar. Unseat RTTS. TIH for DST 1, Run #2. Ran GR/CL for correlation, t Set RTTS. Ran GR/CL. Press DP w/N2. Load firing bar, drop bar, guns fired. SI well. Take WL sample. Rel RTTS. Set ret @ 9900'. Stab into ret, POH. Sqz into perfs w/112 sx Class G cmt. CO cmt to 10021'. Press tst csg to 2000 psi. Displ we~ w/lO.O~.ppg NaC1/NaBr. Set ret. Ran CET 10012'-8450'. Press tst csg to 3000 psi. TIH w/DST tools for DST #2. Ran GR/CCL (depth check). Set pkr @ 9858'. Rerun GR/CCL. Drop bar, gun fired, shot 9930'-9980' w/1 spf. SI for 10 hr b~.il,d~up.~..~ . Perform acid job. Flow well & swab. MU DST tools. Set pkr @ 9859' tailpipe @ 10,009'. Displ diesel in coil tbg w/nitrogen. Flow well to surf. Well SI. Run GR/CCL, temp tool, HP, & fluid sample catcher. Sqz'd perfs (99-30'-9980') w/112 sx Class G cmt. TIH for DST #3, drop bar, shot 9628'-9730' w/1 spf. SI for 10 hr buildup. Sqz perfs (9628'-9730') w/162 sx Class G cmt. Perf 9204'-9206' w/4 spf, sqz'd w/lO0 sx Class G cmt. Perf 9084'-9086' w/4 spf; sqz'd w/160 sx Class G cmt. Milled ret 9050'-9170'. Drl ret @9170'. Dr~ cmt fr/9176'-9215'. Ran CBL 9400'-8434'. TIH for DST #4, drop bar, shot 9118'-9198' w/1 spf. SI for 10 hr buildup. Acidize perfs. Run swab. Flow well for 28 hrs. SI for buildup. Hole taking fluid. Pump 6 Bridge-Sal pills & 2 Mixical plugs. Lost approx 1488 bbls fluid to form. Tst csg, found leak at perfs 9084'-9086'. Perf 8988' -8990' w/4 spf. Stab in, attempt to estab breakdown rate. RIH w/jnk bskts, work thru tight spots in 5" lnr. Sqz perfs (8988'-8990' &-9084'-9086') w/175 sx Class G cmt. CO. Resqz perfs (8988'-8990') w/150 sx Class G cmt. Drl cmt to 9108' PBTD. Ran CET 9108'-8484'. TIH for DST #5. Work jnk bskts, recovered jnk. Shot DST #5 8996'-9046' w/1 spf. SI for buildup. Work DST tools out of 5" lnr. Tst csg to 3000 psi, ok. TOH f/DST tools. Set Ret @ 8980'. Test csg. TIH f/DST #6, drop bar. Shot 8864' - 8936' w/1 SPF. SI f/lO hr buildup. Drl Ret @ 8980'. CO to 9101'. TRIP f/bit. CO to 9525. Run dialog casing caliper profile f/7704' to surf. Perf f/9060' - 9081' w/1 SPF & f/9100 - 9112' w/1 SPF & f/8973' - 8983' w/1 SPF. Set isolation pkr @ 9087', w/"NO-GO" nipple set @ 9098'. Set another pkr @ 8991 w/"NO-GO" nipple @ 8996". TOH-LDDP. Ran 264 jts 3-1/2" tbg w/pkr @ 8420', SSSV @ 2126' & tailpipe @ 8435'. Tested tbg hngr & packoff to 5000 psi- ok. ND BOPE. NU tree & test to 5000 psi - ok. Displaced well to diesel. Set pkr. Secured well & RR @ 1230 hrs, 08/08/83. NORTON/DH27 09/15/83 -. To: Bill·VanA!e~ - AOGC · . . .- . Data:_ Aug. 19., 1983 o . Atlantic Ritchfield Company Arco Alaska, Inc. TR~N SMITTAL From: Dan Fortier - Ext. E×.6]orat~on. · . . -. Transmintted herewith are the following: sepias, Bluelines, Listings ARCO' S.o. Point St. #1[ 6-15-8'3 ARROW PLT 6-'27-83 FRAC ID- '' 7-7'83 Run 1 CORIBAND LISTING CLUSTER LISTING 1! 5" "Run~l Job #4832 R~ Acknowledge: ~aturn receipt' to: Arco Alaska, Inc. Attn: Lucille Johnston ?.o. Box 100360 Anchorage, AK 99510 · Ai-vAior~g~ Prepared by: Lucille Johnston ATO-101'5 'X4599 /' ' ARCO Alaska, lnc.~~ Anchorage, Alaska 99510 Telephone 907 276 1215 August 11, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton' Enclosed are Monthly Reports of Drilling and Workover Operations for the following- DS 14-25 DS 14-31 DS 3-19 DS 3-20 DD 3-21 Pingut State #1 ~-~Fc h~.o -~$ t a~l~ Al'so enclosed is a revised Well Completion or Recompletion Report and Log for DS 1-25. The report previously submitted inadvertentl~ included perforations which had been squeezed under Item #24. Sincerely, . ~./ ,~ . .-._~ - ..- ,.~. M. A. Major Area Drilling Engineer MAM/CSM41' tw 'Encl osures ARCO Alaska. Inc. ~s a Subsidiary of Allanlicl~,~chlieldCompa,"y - ~ ~-'.. STATE OF ALASKA ~' ..... ~ ' ALASK; AND GAS CONSERVATION (. .,~VlISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPE · Drilling wellX~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0, Box 360, Anchorage, AK 4. Location of Well 1320' at surface 99510 FSL, 1320' FWL, Sec. 18, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 51.5' RKB 11.5' Pad 6. Lease Designation and Serial No. ADL 28321 7. Permit No. 83-47 8. APl Number 029-20930 50-- 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. South Point State #1 11. Field and Pool Prudhoe Bay Field/Lisburne Lisburne 0i1 Pool For the Month of July ,1983 12.Depthatend~fm~nth~f~~tagedri~~ed~fishingj~bs~directi~na~dri~~ingpr~b~ems~spuddate~remarks Spudded well ~ 2130 hfs, 04/04/83. Drld 17-1/2" hole to 2667'; ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 8090'. Ran logs. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8791'. Ran logs. Ran & cmtd 7-5/8" lnr. Drld cmt to 8746', set EZSV ~ 7601'. Sqz Class G cmt into lnr lap. Drld cmt & CO to 7717'. Ran CBL. Drld 6-1/2" hole to 8850'. Cut 34 cores. Pipe stuck, recovered fish. Ran logs. Ran, cmtd & tstd 5" lnr. Ran DST Run#1 & Run#2. Sqz perfs. Ran CET. Run DST#2. Sqz'd perfs. (See attached page) 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 80'. 13 9- 7- SE Instld w/2295# poleset. -3/8" 72#/ft, L-80, Butt csg w/FS ~ 2654'. Cmtd w/2000 sx Fondu & 400 sx PFC cmt. 5/8", 47#/ft, N-80, Butt csg w/FS # 8076'. Cmtd w/500 sx Class G. cmt. 5/8", 33.7#/ft, S-95, hydril SFJP lnr fr/7712' - 8788'. Cmtd w/293 sx Class G cmt. , 18.0#/ft, S140 SFJP lnr fr/8484'-10150'. Cmtd w/300 sx Class G cmt. E DRILLING HISTORY 14. Coringresumeandbriefdescription See Attached Core Data LDT/CNL w/GR & Ca1 fr/8792'-8079~ CBL fr/8792'-7396' DIL/NSFL/GR fr/10134'-8700' LDT/CNL/NGT/Caliper 10134'-8700' LSS/GR fr/10135~-8700' LDT/EPT/GR fr/10135'-8700' DIL/BHCS/GR fr/10135'-8700' FDC/GR fr/10135'-8700' GR/CCL 9300'-9800' CET fr/10012'-8450' CBL #1 10092'-8400' CBL #2 10092'-8400' CET fr/10100'-8~96' CET fr/9108'-8484' 6. DST data, perforating data, shows of H2S, miscellaneous data DST #1 10020'-10038' w/1 spf DST #2 9930~-9980' ~/1 spf - Sqz~d perf w/112 sx Class G cmt DST #3 9628'-9730! w/1 spf - Sqz'd w/162 sx Class G cmt DST #~ 9118'-9198' w/1 spf DST #5 8996'-9046' w/1 spf (s'ee attached page) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS (cont'd) South Point State #1 12. Ran DST #3, sqz perfs. Perf 9204'-9206' & sqz. Perf 9084'-9086' & sqz. Ran CBL. Ran DST #4, acidize perf$. Hole took fluid, found leak at perfs 9084'-9086'. Perf 8988'-8990' & sqz; sqz leaking perfs. Ran CET. Ran DST #5. TOH f/DST tools as of 07/31/83. 16. Perf 9204'-9206' w/4 spf; sqz'd w/lO0 sx Class G cmt. Perf 9084'-9086' w/4 spf; sqz'd w/160 sx Class G cmt. Perf 8988'-8990' w/4 spf; sqz'd w/175 sx Class G cmt. CSM/MR19a recovered 28'. South Point State #1 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 2130 hrs, 4/4/83. Drld 17-1/2" hole to 2667'. Ran 72 jts 13-3/8" 72#/ft, L-80 Butt csg w/FS @ 2654'. Stab into FC w/stab-in tool @ 2566'. Pump 100 bbls ligno pill. Cmt 13-3/8" w/2000 sx Fondu followed by 400 sx PFC. ND 20" hydril & diverter system. NU & tstd 13-5/8" BOPE @ 5000 psi. Drld FC, cmt & FS. CO to 2667', 10' new hole. Perform shoe tst, held 11.2 ppg EMW. Drld 12-1/4" hole to 5841'. Wash & ream 5721-5841'. Drld to 6644'. Wash & ream 6600-6644'. Drld to 8090' (4/11/83). Ran OH logs - DIL/BHCS/GR/SP fr/2653-8021'. Ran 194 jts 9-5/8", 47#, N-80 Butt csg w/FS @ 8076'. Cmtd 9-5/8" csg w/500 sx Class G. Tst csg to 3000 psi. Drld FC & cmt. Drld cmt, FS & 10' new hole. Perform form leak-off tst, held 16.4 ppg EMW. Drld to 8240', fighting sloughing shale & gas. Ream 8195-8240'. Drld 8-1/2" hole to 8791' (4/14/83). Ran DIL/BHCS w/SP & GR fr/8790-8079', LDT/CNL w/GR & Cal fr/8792-8079'. Perform Arctic Pack dwnsqz w/300 sx PFC followed by 131 bbls Arctic Pack. Ream 30' to btm. Ran 25 jts 7-5/8" 33.7# S-95 hydril SFJP lnr w/float equip & mechanical hngr w/tieback sleeve. Cmt 7-5/8" w/293 sx Class "G" fr/7712-8788'. TOH w/5" DP & lnr setting tool. Set tst plug, chng top rams to 3-1/2". TIH & LD HWDP. TIH w/8-1/2" bit & csg scrpr. No cmt on TOL. LD 80 jts E DP, 6-1/4" DC & scrpr & bit. TIH w/6-1/2" bit. PU 3-1/2" DP. TIH w/CO assy on 5" DP. Drld cmt to 8746'. Press tst lnr lap - lap leaked. TOH w/CO assy. TIH w/EZ drl on 5" DP, PU 5" DP. Set EZ drl SV @ 7601'. Stab into EZSV, unsting. Sqz 200 sx Class G into lnr lap. Tst csg to 3000#. Drl cmt to 7594'. Drl EZ Drl fr/7594-7600'. CO cmt 7600-7712'. TIH w/6-1/2" bit, CO cmt 7712-7717. Tst csg, found leak on vlv on tbg spool, chng out. CO cmt, Drl FS & 7' new hole. Perform leak-off tst to 12.3 ppg EMW. Ran CBL fr/8792-7396. LD excess 5" DP. Displ ligno mud w/50 bbls hi vis pill followed by bland mud. Drld 6-1/2" hole to 8850'. TIH w/coring assy. Cut core #1 8850-8862, recover 9'. Cut core #2 8875-8895, recover 8.2'. Wash & ream 8860-8895'. Cut core #3 8895-8945', recover 59'. Wash & ream 8904-8954'. Cut core #4 8954-8980' recover 39'. Tst BOPs. Wash & ream 8943-8993'. Cut core #5 8993-9010' (coring break 9004-9008'), stopped coring, cont coring 9010-9012'. Took formation kick. Circ out ann gas bubble & oil & gas cut contam bland mud. Lost 69 bbls mud to form. Incr MW, lost 58 bbls to form, lost 44 bbls during circ/mixing cycle. Recover 15.2' core #5. Chng well over to new bland mud. Cut core #6 9013-9020' Cut core #7 9020-9032' , recovered 2-1/2' 9032-9058' CSM- ltc MO3 Aias~:,:~. Oil & ,.~as Cun,_.:~ Commissiur~ Cut Core #8, 9058' -9067', 9067' -9098', 9098' -9114', recovered 56'. Cut Core #9, 9114' -9146', recovered 29'. Cut Core #10, 9146' -9174', 9174' -9176'. Well took kick. Fin cutting core #10, 9176'-9186', 9186'-9190'. Well taking fluid. Spot LCM pill on btm. Recover 43' Core #10. Cut Core #11, 9190'-9207'. Spot LCM pill, pump dry job. Recover 16.6' Core #11. Cut Core #12, 9207'-9248', recover 38'. Cut Core #13, 9248'-9273', recover 21-1/2'. Spot 50 bbls coarse LCM pill followed by 50 bbl coarse kwik seal LCM pill 9273' -8148'. Cut Core #14, 9273' -9312', recovered 36'. Cut Core #15, 9312' -9372', recovered 60'. Cut Core #16, 9372'-9409', recovered 37'. Cut Core #17, 9409' -9460', recovered 47'. Cut Core #18, 9460' -9518', recovered 58'. Cut Core #19, 9518' -9546', recovered 28'. Wash 9505' -9546'. Cut Core #20, 9546' -9588', recovered 42'. Wash & ream 9548' -9588'. Cut Core #21, 9588' -9648', recovered 59'. Wash & ream 9633' -9648'. Cut Core #22, 9648' -9685', 9685' -9708'. Spot LCM pill. Recover 60' Core #22. Cut Core #23, 9708' -9767', recovered 59'. Cut Core #24, 9767' -9820', 9820' -9827', recovered 58.5'. Cut Core #25, 9827' -9843', 9843' -9883', 9883' -9886', recovered 59'. Cut Core #26, 9886' -9905', 9905'-9946', recovered 60'. Wash 9905' -9946'. Cut Core #27, 9946' -9978', 9978' -9997', recovered 51'. Wash & ream 9910' -9997'. Cut Core #28, 9997'-10014', 10014'-10027', pipe stuck below jars. Jarred pipe, spot SFT pill. Ran free pt, pipe free @ 9905'. Perform acid job while jarring. Pipe free. Circ & work pipe. Recovered 30' Core #28. RIH w/RTTS & storm choke, set RTTS @ 5000'. Chng seals on btm BOP ram. Test seal - ok. Rel RTTS. Pump dry job. Ream 150' to btm. Cut Core #29, 10027' -10086', recovered 55'. Cut Core #30, 10087' -10102', recovered 15'. Cut Core #31, 10102' -10161', recovered 59'. Cut Core #32, 10161'-10208', recovered 47'. Cut Core #33 10208' -10263'; recovered 55'. Cut Core #34 10263' -10296', 10296' -10301'. Pipe stuck while attempting to PU for connection. Fish consists of 6-1/2" core bit, 2 core bbls, XO, 2 monel, stab, monel, 7 steel DCs, jars, 14 steel DCs, 20 jts 3-1/2" DP. Top of fish @ 8827'. MU several fishing strings and work overshot past fish, did not recover fish. RIH w/sinker bar assy, assy dropped dwn 3-1/2" DP. Attempt to back off tool jt, did not back off. TIH w/string shot, backed pipe off @ 8732'. Work washover shoe over TOF, part of washover shoe left in hole. TIH w/fishing assy #9, recovered 191' of 3-1/2" DP. TIH w/fishing assy #10, latch onto fish w/overshot and grapple. Jar & work string. Ran free pt, pipe stuck @ 9900'. Attempt backoff @ -/ '5885'; failed. Latch onto fish, jar & work fish. Ran backoff shot, backed off @ 9885'. Pull WL & back off tools, pull 15 stds. TOH w/fish. Recovered 16 jts DP & 13 DCs. TIH w/fishing assy #12, screw in TOF @ 9851'. Circ & jar fish· Displ & spot 500 gals Hcl acid, cont'd jarring, did not recover fish. Ran free pt, pipe stuck @ 9995'. Backoff shot @ 9979'. Pull WL, pull 15 stds, TOH & LD fish· Recovered 3 DCs, I set jars, TOF @ 9974'. Wash over fish. Screw onto fish, recover 5 steel DCs & I monel. TOF @ 10159'. RIH w/overshot, tag fish, work overshot on fish. RIH w/fishing assy #16, dress TOF. POOH, work overshot onto fish @ 10159'. Jar on fish. RIH w/impr blk (used as a blind box), tag up @ 10167'. RIH w/string shot, irratic CCL operation prevented tie-in; chng CCL. Tie in, shot, no backoff. Mill over stab blades. Wash over pipe. Work overshot onto fish, jar on fish, no movement. RIH w/string shot, would not back off. Second shot would not back off. Attempt to release overshot, would not release. RIH w/grapple, would not latch. RIH w/impr blk, no impr made. Reran, tool stuck @ 9945'· Jar loose. Lead plug fr/impr blk left in hole, drive to top of WL fish. Pump on DP to wash out overshot, pipe came loose during pickup. LD fishing string. Ran DIL/MSFL/GR 10134'-8700'; LDT/CNL/NGT/Caliper 10134'-8700'; LSS/GR 10135'-8700'; LSS/GR tool failed. Ran LDT/EPT/GR 10135'-8700', LDT failed. Ran DIL/BHCS/GR 10135 '-8700'; FDC/GR 10135'-8700'. Ran PHTU, tool failed. Ran dipmeter 10135'-8700'. Reran PHTU, tool failed. Ran RFT. Ran 47 jts 5" 18# S-140 SFJP lnr fr/8484'-10150'. Cmt 5" lnr w/300 sx Class G cmt. Drl cmt to 10112'. Tst csg to 3000 psi. Chng out drlg mud w/9.8 ppg NaCl. Ran CBL #1 fr/10092'-8400' & CBL #2 fr/10092'-8400'. Ran CET fr/10100'-8396'. Ran VSP. Ran GR/CCL 9300'-9800'. Set RTTS. Run GR/CCL to confirm setting depth· Displ fluid in DP w/N2. Bar dropped· Vann Guns did not fire on DST 1, Run#1. TIH w/overshot & recover bar. Unseat RTTS. TIH for DST 1, Run #2. Ran GR/CL for correlation. Set RTTS. Ra'n GR/CL. Press DP w/N2. Load firing bar, drop bar, guns fired. SI well. Take WL sample. Rel RTTS. Set ret @ 9900'. Stab into ret POH Sqz into perfs w/112 sx Class G cmt CO cmt to 10021'. Press tst csg to 2000 psi. Displ well w/lO.O ppg NaC1/NaBr. ~-.~ Set ret. Ran CET 10012'-8450'. Press tst csg to 3000 psi. TIH w/DST tools~ ~,-:~ for DST #2 .... Ran GR/CCL (depth check) Set pkr @ 9858' Rerun GR/CCL Drop bar, gun fired, shot 9930'-9980' w/1 spf. SI for 10 hr build-up.%~? Perform acid job. Flow well & swab. MU DST tools. Set pkr @ 9859', C~ tailpipe @ 10,009'. Displ diesel in coil tbg w/nitrogen. Flow well to surf. Well SI. Run GR/CCL, temp tool, HP, & fluid sample catcher. Sqz'd perfs (9930'-9980') w/112 sx Class G cmt. TIH for DST #3, drop bar, shot 9628'-9730' w/1 spf. SI for 10 hr buildup. Sqz perfs (9628'-9730') w/162 sx Class G cmt. Perf 9204'-9206' w/4 spf, sqz'd w/lO0 sx Class G cmt. Perf 9084'-9086' w/4 spf; sqz'd w/160 sx Class G cmt. Milled ret 9050'-9170'. Drl ret @9170'. Drl cmt fr/9176'-9215'. Ran CBL 9400'-8434'. TIH for DST #4, drop bar, shot 9118'-9198' w/1 spf. SI for 10 hr buildup. Acidize perfs. Run swab. Flow well for 28 hrs. SI for buildup. Hole taking fluid. Pump 6 Bridge-Sal pills & 2 Mixical plugs. Lost approx 1488 bbls fluid to form. Tst csg, found leak at perfs 9084' -9086'. Perf 8988' -8990' w/4 spf. Stab in, attempt to estab breakdown rate. RIH w/jnk bskts, work thru tight spots in 5" lnr. Sqz perfs (8988'-8990' & 9084'-9086') w/175 sx Class G cmt. CO. Resqz perfs (8988'-8990') w/150 sx Class G cmt. Drl cmt to 9108' PBTD. Ran CET 9108'-8484'. TIH for DST #5. Work jnk bskts, recovered jnk. Shot DST #5 8996'-9046' w/1 spf. SI for buildup. Work DST tools out of 5" lnr. Tst csg to 3000 psi, ok. TOH f/DST tools as of 07/31/83. CSM/DH20.tw 08/10/83 ARCO Alaska, Inc. Extension Exploration TRANSMITTAL To: Bill VanAlen Alaska State of Oil&Gas From: Extension/Exploration Date: August 11,1983 Transmitted herewith are the following- One Copy Each (BL. & Sepias) ARCO: 4-11-83 4-15-83 6-15-83 4-11-83 4-15-83 6-15-83 6-15-83 6-15-83 6-15-83 6-15-83 4-15-83 6-21-83 6-14-83 6-29-83 7-7-83 6-21-83 4-19-83 6-15-83 6-14-83 6-14-83 . -South Point State #1 DIL 2" 5" Run 1,2,3 BHC S 2" 5" Run 1,2,3 LDT-EPT-CNL-GR(RAW DATA) 2" 5" LDT-EPT-CNL-GR(POROSITY) 2" 5" Density GR(RAW & POROSITY) 2" 5" EPT 2" Density-Neutron-GR(POROSITY & RAW) Cement Bond Log/VD Dual Laterlog MSFL GR CET Computer Processed(Coriband) Cement Evaluation Tool CBL With Variable Density Repeat Formation Tester Long Spaced Sonic-GR LSS Wave Forms(12" Signal) Receipt Acknowledgment: Return Receipt~ to- ARCO Alaska, Inc. Extension Exploration P. O. Box 100360 Anchorage, AK 99510 5~! 2" 5" 5" 5" 5" 5" 2" 5" 5" Run 3 Run 3 Run 3 Run 3 2" 5" Run 2 Run 3 Run 3 Run 3 Run 3 Run 2 ~ Run 3 Run 3 Run 3 Attn: V. Marxen ATO 1046 ARCO Alaska, Inc. Extension Exploration TRANSMITTAL To' Bill VanAlen Alaska State of Oil&Gas From: Extension/Exploration August 11,1983 Date' Transmitted herewith are the following' One Copy Each(BL. & Sepias) ARCO' 'South Point. State #1 4-15-83 Cyberlook 5" Run 2,3 6-16-83 6-14-83 SHDT 5" Run 3 6-15-83' Electro. Prop, Log 5" Run 3 6-15-83 Natural GR Spec. 2" 5" Run 3 6-14-83 Cyberd~P- 5" Run 3 Receipt Acknowledgment' Return Receipt' to' ARCO Alaska, Inc. Extension Exploration P. O. Box 100360 Anchorage, AK 99510 Processed by' Vadjdieh Marxen Attn' V. Marxen ATO 1046 'ARCO A~aska; ,n~ Post offic ;.:i.F o360 Anchorage-Alaska 995i " Telephone 907 276 1215 July 13, 1983 Mr.'-C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly 'Report of Drilling & Work. over Operations Dear -Mr. -Chatterton: Enclosed are Monthly Reports of Drilling and Workover Operations for the fol lowing- 'Ds 14-23 DS 14-24 DS 13-27 DS 3-19 Pi ngut State #1 and Well Completion or Recompletion Reports and Logs for: DS 7-24 DS 13-28 'Also enclosed are revised Well Completion or Recompletion Reports and Logs for: DS '1-25 DS 13-29 DS 7-25 Sincerely, M. A. Major Area Drilling Engineer MAM/CSM34 · sm Enclosures ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany JUl_ Alaska Oil & Gas [:~,nu." '~" ..... A r, '~ ,~ '- STATE OF ALASKA --- ' ALASK ,L AND GAS CONSERVATION AMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERAT 1. Drilling wel~[~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Al( 99510 4. Location of Well atsurface 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 51.5' RKB 11.5' Pad ADL 28321 7. Permit No. 83-47 8. APl Number 50-- 029-20930 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne lO. WelINo. South Point State #1 11. Field and Pool Prudhoe Bay Fie]d/Lisburne Lisburne Oil Pool For the Month of. June ,1983 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2130 hfs, 04/04/83. Drld 17-1/2" hole to 2667'; ran, csg. Drld hole to 879 Sqz Class G 8850'. Cut DST#1 & DST cmtd, & tstd 13-3/8" 12-1/4" hole to 8090'. Ran logs. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" 1' Ran logs. Ran & cmtd 7-5/8" lnr Drld cmt to 8746' set EZSV @ 7601' cmt into lnr lap. Drld cmt & CO to 7717'. Ran CBL. Drld 6-1/2" hole to 34 cores. Pipe stuck, recovered fish. Ran logs. Ran, cmtd & tstd 5" lnr. Ran #2. Sqz perfs. Ran CET. TIH w/DST tools as of 06/30/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 80'. Instld w/2295# poleset foam. 13-3/8" 72#/ft, L-80, Butt csg w/FS ~ 2654'. Cmtd w/2000 sx Fondu & 400 sx PFC cmt. '9-5/8", 47#/ft, N-80, Butt csg w/FS # 8076'. Cmtd w/500 sx Class G. cmt. 7-5/8", 33.7#/ft, S-95, hydril SFJP lnr fr/7712' - 8788'. Cmtd w/293 sx Class G cmt. 5", 18.0#/ft, S140 SFJP lnr fr/8484'-10150'. Cmtd w/300 sx Class G cmt. SEE DRILLING HISTORY 14. Coring resume and brief description See Attached Core Data b~'~?~%a?~w~53'-8081' LDT/CNL w/GR & Cal fr/8792'-8079' CBL fr/8792'-7396' DIL/MSFL/GR fr/10134'-8700' LDT/CNL/NGT/Caliper 10134'-8700' LSS/GR fr/10135'-8700' I 6. DST data, perforating data, shows of H2S, miscellaneous data DST #1 10020'-10038' w/1 spf DST #2 9930'-9980' w/1 spf LDT/EPT/GR fr/10135'-8700' D I L/BHCS/GR fr/10135'-8700' FDC/GR fr/10135'-8700' GR/CCL 9300'-9800' CET fr/10012'-8450' CBL #1 10092'-8400' CET fr/10100'-8396' Sqz'd perf w/l12 sx Class G c~ ~ , ,, r-~ .... , '" i:cm:;':i~:;~[;~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate C 0 R E C. ORL=- C 0 F..' E CORE CORE C 0 R Ii!: CORF t'"' '--' t': ~- ,., ~.J ?-. C: [i R l:i: CORE ,..(" 0 R E C 0 F'-:. ii"' CORE :'" F'~ r.;-' · '-' ~'~ P F: CORE ;" Fi F;." F: I.: C [] F,' !.::' i~' ~"~ ~.'~ r- COR. E C 0 R. E C 0 R ii"' i'" f'~ F: r" f" -"" V: i'" C 0 R E ~': i'"' r'~ r" ~--- g !~ i"" (~ r.': c:' CORE U*' '-'~ r'~ r" L.. [.) I'"-. r:. :: 11 :~,: ~ :C-' '7.-' :~: i :5 ~'~6 · ~' ~;. '~ .H. ~ ~') ~' ~.. ~. ~26 · --~;: ~ .fl. '? 'F ~ ~;,4 S 0 U T !'-I P 01 N T C 0 F;,' E D A'¥ A CORE DAI'A 8 :iii 5: 0'- 8862; F;.'.t!'" C 0 V E F;,' 88 -' ~-" c, ,.':> ,=:'-'.". '"' '" :"'"':: F;:. o , ( _>-" ,.., ~,; _:;r'-. t::. u, ,_.~ ~ E: ~..C:' _i") ,.., _......"') :!'""~ .... !=-': i_.'[ C 0 V ~:: F;.'. Ii'" D '.i'.'; 9 ' :>,::~";: '.S .... 8?5:4 .; ,.. 89 '=.': '" ::"i: 99 S I:;,'E C 0 V El F;.'. EE D .=~' · ~-. ~" .~ . 899 ~?.;- q:', ,."a.~ 'i. "~ R E C 0 V E F;..' ii-- D i ..;.':= 2 ' .*."...~ 9 £:, i ?T-',--- ,:.:, c-, ':,- ,:;~ F;: E C 0 V El R E:' '."'~_ 2 ~ .?'= ' '"" '-"'-f""':' '""~'" ..8' ,;:),:.' oo' !:;: E' F: 0 V F' I':: r.:' I) 5:6' ~ _-' ,..~- : '~ i 4 .~ .......... 9 i "i 4- 9 ~ ""' '< ~' !::' I"' ;"~ ,'~ o,".; F;,' E (."; Ei;~ E' F;: E:' 0 :~ i 46-9 i: ,.. ,.' ........ "'~:~' ";:.-: ~;-"~ i:~., .... '::',- ':~_._ ...... ,' .", ,: R E C "*: .... : '": ";' . F': I'" I'~ ~" : I r .... ~ "': .... : I ':/:-=';~:- 9¢,i'.'.-]; :.,,~:.u;,_)'~:.l',.E~L~ .... · ~. ,.% 9Si 2 .... 9.3 ,',-- .~ RECO¥1i':I:::.Ei) 60 :., ,:, ..- ~.- 946.', 9 .~ R E C 0 V El:;.: E D :':': 7 94(-)':?-- 9460; RI:':-COVIi':RI!:-D 47 c;, :?../;:::_ 9"i: '~ 8; F;.'..'=: (') Fi V E' F,' E:' I'~ '::' ;" : ..._..... . . ............. 95 i :iii:- o,~ '. ~._ ,_, _ ,- _ .q- 6 .~ R E C 0 V I?. R E I)":' o · .'-,~..u u ¥ E..I',E .... 9'546 -" 9"": 8 '"' r:, I:: ..... ". ;' ':' :" :' i'", ,'~ ~/ C) .~ .,'.. '-' V, t:= (" ('i -'. ! !:7 I=, I'." i"-, *:~ (:', 9588- 9648.~ !::. ,.., d '-.' E:. I", E- !.,' 60 q;'A4F~- ...... 9"?0o,.:,; j:;.'. '"~"'* ......... ' ..... 9 ..... ? ,.':) F: .... 976 '7 ,.' R E C 0 V E R Ii:' D ..,':'= o: 976?- 9F::2]" .~ ,R'EF':;:VE'I=<F ~'.'-, ......... "uF~,. ~'.,, '.:S' · - -"- ::' t-I ! "~::- o_.-..° :~, 7' -" "'::: ~ d 6; R I'=: C 0 ",/E R E= D ...~ '.:. 9886 .... '-'"'" : ~:'(',f':::~:'~.:,~:"f) ,,:':,.'z~, ':?946- ....999 ,'; 9997 - i 6':: ...:~ .....""' "~ "~,, .:. ............. I:;." ,';; 0'::"7 - ~ 00 ''':~ 6 .~ ,~,,:. ,_.,.; :, E: I's I:: :., · .' :. ~. I .. L~.I · _. r~. E C 0 V E: R F i) i 5 ' 0i02 .... '~Oi6i; iq Ii"COVERED 59' : . r'- ~- .-": i'-'~ ~ . ':=':'i6i .... ~':.:.:'2f~8~ :<=:.:,,_,vE:',,EO 4,' · -' , 0208 .... ~ ::=)26.~ ~ R, .....).? LI.,L~., ~ ~.L.~ . South Point State #1 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 2130 hrs, 4/4/83. Drld 17-1/2" hole to 2667'. Ran 72 jts 13-3/8" 72#/ft, L-80 Butt csg w/FS @ 2654'. Stab into FC w/stab-in tool @ 2566'. Pump 100 bbls ligno pill. Cmt 13-3/8" w/2000 sx Fondu followed by 400 sx PFC. ND 20" hydril & diverter system. NU & tstd 13-5/8" BOPE @ 5000 psi. Drld FC, cmt & FS. CO to 2667', 10' new hole. Perform shoe tst, held 11.2 ppg EMW. Drld 12-1/4" hole to 5841'. Wash & ream 5721-5841'. Drld to 6644'. Wash & ream 6600-6644'. Drld to 8090' (4/11/83). Ran OH logs - DIL/BHCS/GR/SP fr/2653-8021'. Ran 194 jts 9-5/8", 47#, N-80 Butt csg w/FS @Jt~0~76'. Cmtd 9-5/8" csg w/500 sx Class G. Tst csg to 3000 psi. Drld FC & cmt. Drld cmt, FS & 10' new hole. Perform form leak-off tst, held 16.4 ppg EMW. Drld to 8240', fighting sloughing shale & gas. Ream 8195-8240'. Drld~ 8-1/2" hole to 8791' (4/14/83). Ran DIL/BHCS w/SP & GR fr/8790-8079', LDT/CNL w/GR & Cal fr/8792-8079'. Perform Arctic Pack dwnsqz w/300 sx PFC followed by 131 bbls Arctic Pack. Ream 30' to btm. Ran 25 jts 7-5/8" 33.7# S-95 hydril SFJP inr w/float equip & mechanical hngr w/tieback sleeve. Cmt 7-5/8" w/293 sx Class ."G" fr/7712-8788'. TOH w/5" DP & lnr setting tool. Set tst plug, chng top rams to 3-1/2". TIH & LD HWDP. TIH w/8-1/2" bit & csg scrpr. No cmt on TOL. LD 80 jts E DP, 6-1/4" DC & scr~r & bit. TIH w/6-1/2" bit. PU 3-1/2" DP. TIH w/CO assy on 5" DP. Drld cmt to 8746'. Press tst lnr lap - lap leaked. TOH w/CO assy. TIH w/EZ drl on 5" DP, PU 5" DP. Set EZ drl SV @ 7601'. Stab into EZSV, unsting. Sqz 200 sx Class G into lnr lap. Tst csg to 3000#. Drl cmt to 7594'. Drl EZ Drl fr/7594-7600'. CO cmt 7600-7712'. TIH w/6-1/2" bit, CO cmt 7712-7717. Tst csg, found leak on vlv on tbg spool, chng out. CO cmt, Drl FS & 7' new hole. Perform leak-off tst to 12.3 ppg EMW. Ran CBL fr/8792-7396. LD excess 5" DP. Displ ligno mud w/50 bbls hi vis pill followed by bland mud. Drld 6-1/2" hole to 8850'. TIH w/coring assy. Cut core #1 8850-8862, recover 9'. Cut core #2 8875-8895, recover 8.2'. Wash & ream 8860-8895'. Cut core #3 8895-8945', recover 59'. Wash & ream 8904-8954'. Cut core #4 8954-8980' recover 39'. Tst BOPs. Wash & ream 8943-8993'. Cut core #5 8993-9010' (coring break 9004-9008'), stopped coring, cont coring 9010-9012'. Took formation kick. Circ out ann gas bubble & oil & gas cut contam bland mud. Lost 69 bbls mud to form. Incr MW, lost 58 bbls to form, lost 44 bbls during circ/mixing cycle. Recover 15.2' core #5. Chng well over to new bland mud. Cut core #6 9013-9020' recovered 2-1/2' Cut core #7 9(~0,'9032~!,Y-9~032 9058' recovered 28'. ~ ~ ~ ~.~ ~. Cut Core #8, 9058'-9067', 9067'-9098', 9098'-9114', recovered 56'. Cut Core #9, 9114' -9146', recovered 29'. Cut Core #10, 9146' -9174', 9174' -9176'. Well took kick. Fin cutting core #10, 9176'-9186', 9186'-9190'. Well taking fluid. Spot LCM pill on btm. Recover 43' Core #10. Cut Core #11, 9190'-9207'. Spot LCM pill, pump dry job. Recover 16.6' Core #11. Cut Core #12, 9207'~9248', recover 38'. Cut Core #13, 9248' -9273', recover 21-1/2'. Spot 50 bbls coarse LCM pill followed by 50 bbl coarse kwik seal LCM pill 9273' -8148'. Cut Core #14, 9273' -9312', recovered 36'. Cut Core #15, 9312'-9372', recovered 60'. Cut Core #16, 9372' -9409', recovered 37'. Cut Core #17, 9409' -9460', recovered 47'. Cut Core #18, 9460' -9518', recovered 58'. Cut Core #19, 9518'-9546', recovered 28'. Wash 9505'-9546'. Cut Core #20, 9546' -9588', recovered 42'. Wash & ream 9548' -9588'. Cut Core #21, 9588' -9648', recovered 59'. Wash & ream 9633' -9648'. Cut Core #22, 9648' -9685', 9685' -9708'. Spot LCM pill. Recover 60' Core #22. Cut Core #23, 9708' -9767', recovered 59'. Cut Core #24, 9767' -9820', 9820'-9827', recovered 58.5'. Cut Core #25, 9827'-9843', 9843'-9883', 9883' -9886', recovered 59'. Cut Core #26, 9886' -9905', 9905' -9946', recovered 60'. Wash 9905' -9946'. Cut Core #27, 9946' -9978', 9978' -9997', recovered 51'. Wash & ream 9910' -9997'. Cut Core #28, 9997'-10014', 10014'-10027', pipe stuck below jars. Jarred pipe, spot SFT pill. Ran free pt, pipe free @ 9905'. Perform acid job while jarring. Pipe free. Circ & work pipe. Recovered 30' Core #28. RIH w/RTTS & storm choke, set RTTS @ 5000'. Chng seals on btm BOP ram. Test seal - ok. Rel RTTS. Pump dry job. Ream 150' to btm. Cut Core #29, 10027'-10086', recovered 55'. Cut Core #30, 10087 '-10102', recovered 15'. Cut Core #31, 10102' -10161', recovered 59'. Cut Core #32, 10161'-10208', recovered 47'. Cut Core #33 10208' -10263'; recovered 55'. Cut Core #34 10263' -10296', 10296' -10301'. Pipe stuck while attempting to PU for connection. Fish consists of 6-1/2" core bit, 2 core bbls, XO, 2 monel, stab, monel, 7 steel DCs, jars, 14 steel DCs, 20 jts 3-1/2" DP. Top of fish @ 8827'. MU several fishing strings and work overshot past fish, did not recover fish. RIH w/sinker bar assy, assy dropped dwn 3-1/2" DP. Attempt to back off tool jt, did not back off. TIH w/string shot, backed pipe off @ 8732'. Work washover shoe over TOF, part of washover shoe left in hole. TIH w/fishing assy #9, recovered 191' of 3-1/2" DP. TIH w/fishing assy #10, latch onto fish w/overshot and grapple. Jar & work string. Ran free pt, pipe stuck @ 9900'. Attempt backoff @ 5885'; failed. Latch onto fish, jar & work fish. Ran backoff shot, backed off @ 9855'. Pull WL & back off tools, pull 15 stds. TOH w/fish. Recovered 16 jts DP & 13 DCs. TIH w/fishing assy #12, screw in TOF @ 9851'. Circ & jar fish. Displ & spot 500 gals Hcl acid, cont'd jarring, did not recover fish. Ran free pt, pipe stuck @ 9995'. Backoff shot @ 9979'. Pull WL, pull 15 stds, TOH & LD fish. Recovered 3 DCs, 1 set jars, TOF @ 9974'. Wash over fish. Screw onto fish, recover 5 steel DCs & I monel. TOF @ 10159'. RIH w/overshot, tag fish, work overshot on fish. RIH w/fishing assy #16, dress TOF. POOH, work overshot onto fish @ 10159'. Jar on fish. RIH w/impr blk (used as a blind box), tag up @ 10167'. RIH w/string shot, irratic CCL operation prevented tie-in; chng CCL. Tie in, shot, no backoff. Mill over stab blades. Wash over pipe. Work overshot onto fish, jar on fish, no movement. RIH w/string shot, would not back off. Second shot would not back off. Attempt to release overshot, would not release. RIH w/grapple, would not latch. RIH w/impr blk, no impr made. Reran, tool stuck @ 9945'. Jar loose. Lead plug fr/impr blk left in hole, drive to top of WL fish. Pump on DP to wash out overshot, pipe came loose during pickup. LD fishing string. Ran DIL/MSFL/GR 10134'-8700'; LDT/CNL/NGT/Caliper 10134'-8700'; LSS/GR 10135'-8700'; LSS/GR tool failed. Ran LDT/EPT/GR 10135'-8700', LDT failed. Ran DIL/BHCS/GR 10135'-8700'; FDC/GR 10135'-8700'. Ran PHTU, tool failed. Ran dipmeter 10135'-8700'. Reran PHTU, tool failed. Ran RFT. Ran 47 jts 5" 18# N-80 S140 SFJP lnr fr/8484'-10150'. Cmt 5" lnr w/300 sx Class G cmt. Drl cmt to 10112'. Tst csg to 3000 psi. Chng out drlg mud w/9.8 ppg NaC1. Ran CBL #1 fr/10092'-8400' & CBL #2 fr/10092'-8400'. Ran CET fr/10100'-8396'. Ran VSP. Ran GR/CCL 9300'-9800'. Set RTTS. Run GR/CCL to confirm setting depth. Displ fluid in DP w/N2. Bar dropped. Vann Guns did not fire on DST 1, Run#1. TIH w/overshot & recover bar. Unseat RTTS. TIH for DST 1, Run #2. Ran GR/CL for correlation. Set RTTS. Ran GR/CL. Press DP w/N2. Load firing bar, drop bar, guns fired. SI well. Take WL sample. Rel RTTS. Set ret @ 9900'. Stab into ret, POH. Sqz into perfs w/112 sx Class G cmt. CO cmt to 10021'. Press tst csg to 2000 psi. Displ well w/lO.O ppg NaC1/NaBr. Set ret. Ran CET 10012'-8450'. Press tst csg to 3000 psi. TIH w/DST tools as of 06/30/83. CSM/DH13 07/07/83 )IORTH SLOPE D]SIRICi · · ! _~ei_p~nowle~ge' : -&~rreceipt to: · · o. Atlantic Richfield Con?any Ilovth.S]ope D~str~ct Attn: --~ -_ . '- Processed ARCO Alaska, Inc. Post Office Box ,v0360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 13, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine' Drive Anchorage, AK 9950! SUBJECT' ~Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton' Enclosed are Monthly Reports of Drilling and Workover Operations for the following- DS 7-24 DS 14-23 DS 13-28 DS 13-29 DS 13-27 South Point State #1 Pingut State #1 Sincerely, M. A -Major Area Drilling Engineer, MAM/CSM' tw CSM/31 Enclosures P,So Also enclosed are Well Completion or Recompletion Report and Log for the following wells' DS 1-25, DS 13-29, and DS 7-25. RECEIVFD ARCO Alaska, J~- - i,; <3 Subsidiary of A!l_anlicRichfie~d¢;nmp~ny Alask.~ Oil & Gas ., ~--~ STATE OF ALASKA ,~--... (~ ~ " ' : ALASKA (. AND GAS CONSERVATION CC ;ISSION MONTHLY: REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~]X Workover operation [] ~~... 4. Location of Well 1320' at surface 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-47 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20930 9. Unit or Lease Name FSL, 1320' FWL, Sec. 18, T11N, R15E, UM Prudhoe Bay Unit/Lisburn. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 51.5' RKB 11.5' Pad ADL 28321 For the Month of. May ,19 83 12.Depthatend~fm~nth~f~~tagedril~ed~fishingj~bs~directi~na~dri~~ingpr~blems~spuddate~remarks Spudded well @ 2130 hfs, 04/04/83. Drld 17-1/2" hole to 2667'; 13-3/8" csg. Drld 12-1/4" hole to 8090'. Ran logs. Ran, lO. WelINo. South Point State #1 11. Field and Pool Prudhoe Bay Field/Lisburn, Lisburne 0il Pool ran, cmtd, & tstd cmtd & tstd 9-5/8" csg. Drld 8-1/2" hol EZSV ~ 7601 ', 6-1/2" hole to SEE DRILLING HI e to 8791' Ran logs Ran & cmtd 7-5/8" lnr Drld cmt to 8746' Sqz Class G cmt into lnr lap. Drld cmt & CO to 7717'. Ran CBL. 8850'. Cut 32 cores as of 05/31/83. STORY set Drld 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 80'. Instld w/2295# poleset foam. 13-3/8" 72#/ft, L-80, Butt csg w/FS ~ 2654'. Cmtd w/2000 sx Fondu & 400 sx PFC cmt. 9-5/8", 47#/ft, N-80, Butt csg w/FS # 8076'. Cmtd w/500 sx Class G. cmt. 7-5/8", 33.7#/ft, S-95, hydril SFJP lnr fr/7712' - 8788'. Cmtd w/293 sx Class G cmt. SEE DRILLING HISTORY 14. Coring resume and brief description Core #1 recovered 9' Core #2 Core #3 Core #4 Core #5 Co re #6 885O 8875 -8862'; -8895'; 8895 -8945'; 8954 -8980'; 8993 -9010'; 9013 -9020'; recovered 8.2' recovered 59'~ recovered 3 9 '~Z~ 9010'-9012'; recovered 15.2' recovered 2.5' Core #7 150 F~g/~n~°/%~he~%~u~65 3 ' -8081 ' LDT/CNL w/GR & Cal fr/8792'-8079' CBL fr/8792'-7396' ~OOl~ data, perforating data, shows of H2S, miscellaneous data 9020'-9032'; 9032'-9058'; recovered 28' Core #8 9058'-9114'; recovered 56' Core #9 9114'-9146'; recovered 29' Core #10 9146'-9176'; 9176'-9190'; recovered 43'(See Attachment) RECEIVED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'~~~~- Area Drilling Engineer SIGNED~ / /'~-=- ~~. TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alas'ka Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate ATTACHMENT 1 SOUTH POINT STATE #1 MONTHLY REPORT Item No. 1 Core #11 Core #12 Core #13 Core #14 Core #15 Core #16 Core #17 Core #18 Core #19 Core #20 Core #21 Core #22 Core #23 Core #24 Core #25 Core #26 Core #27 Core #28 Core #29 Core #30 Core #31 Core #32 4: 919 920 924 927 931 937 940 946 951 954 958 964 970 976 982 988 994 999 100 100 0'-9207 7'-9248 8'-9273 3'-9312 2'-9372 2'-9409 9'-9460 0'-9518 8'-9546 6'-9588 8'-9648 8'-9708 8'-9767 7'-9827 7'-9886 6'-9946 ; recovered 16.6' ; recovered 38' ; recovered 21.5' ; recovered 36' ; recovered 60' ; recovered 37' ; recovered 47' ; recovered 58' ; recovered 28' ; recovered 42' ; recovered 59' ; recovered 60' ; recovered 59' ; recovered 58.5' ; recovered 59' ; recovered 60' 6'-9997 ; recovered 51' 7'-10027'; recovered 30' 27'-10086'; recovered 55' 87'-10102'; recovered 15' 10102'-10161'; recovered 59' 10161'-10208'; recovered 47' CSM/MRllA RECEIVED South Point State #1 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 2130 hrs, 4/4/83. Drld 17-1/2" hole.to 2667'. Ran 72 jts 13-3/8" 72#/ft, L-80 Butt csg w/FS @ 2654'. Stab into FC w/stab-in tool @ 2566'. Pump 100 bbls ligno pill. Cmt 13-3/8" w/2000 sx Fondu followed by 400 sx PFC. ND 20" hydril & diverter system. NU & tstd 13-5/8" BOPE @ 5000 psi Drld FC cmt & FS CO to 2667' 10' new hole Perform shoe tst, held 11.2 ppg EMW. Drld 12-1/4" hole to 5841'. Wash & ream 5721-5841'. Drld to 6644'. Wash & ream 6600-6644'. Drld to 8090' (4/11/83). Ran OH logs - DIL/BHCS/GR/SP fr/2653-8021'. Ran 194 jts 9-5/8", 47#, N-80 Butt csg w/FS @ 8076'. Cmtd 9-5/8" csg w/500 sx Class G. Tst csg to 3000 psi. Drld FC & cmt. Drld cmt, FS & 10' new hole. Perform form leak-off tst, held 16.4 ppg EMW. Drld to 8240', fight~loughing shale & ~s. Ream 8195-8240'. Drld 8-1/2" hole to 8791' (4/14/83). Ran DIL/BHCS w/SP & GR fr/8790-8079', LDT/CNL w/GR & Cal fr/8792-8079'. Perform Arctic Pack dwnsqz w/300 sx PFC followed by 131 bbls Arctic Pack. Ream 30' to btm. Ran 25 jts 7-5/8" 33.7# S-95 hydril SFJP lnr w/float equip & mechanical hngr w/tieback sleeve. Cmt 7-5/8" w/293 sx Class "G" fr/7712-8788'. TOH w/5" DP & lnr setting tool. Set tst plug, chng top rams to 3-1/2". TIH & LD HWDP. TIH w/8-1/2" bit & csg scrpr. No cmt on TOL. LD 80 jts E DP, 6-1/4" DC & scrpr & bit. TIH w/6-1/2" bit. PU 3-1/2" DP. TIH w/CO assy on 5" DP. Drld cmt to 8746'. Press tst l nr lap - 1.ap !gaked. TOH w/CO assy. TIH w/EZ drl on 5" DP, PU 5" DP. Set EZ drl SV @ 7~01'. Stab into EZSV, unsting. Sqz 200 sx Class G into lnr lap. Tst csg to 3000#.? Drl cmt to 7594'. Drl EZ Drl fr/7594-7600'. CO cmt 7600-7712'. TIH w/6-1/2" bit, CO cmt 7712-7717. Tst csg, found leak on vlv on tbg spool, chng out. CO cmt, Drl FS & 7' new hole. Perform leak-off tst to 12.3 ppg EMW. Ran CBL fr/8792-7396. LD excess 5" DP. Displ ligno mud w/50 bbls hi vis pill followed by bland mud. Drld 6-1/2" hole to 8850'. TIH w/coring assy. Cut core #1 8850-8862, recover 9'. Cut core #2 8875-8895, recover 8.2'. Wash & ream 8860-8895' Cut core #3 8895-8945' recover 59' · Wash & ream 8904-8954' Cut core #4 8954-8980' recover 39'.~" Tst BOPs. Wash & ream 8943-8993'. Cut core #5 8993-9010' (coring break 9004-9008'), stopped coring, cont coring 9010-9012'. Took formatio~n..kic~k. Circ out ann gas bubble & oil & gas cut contam bland mud. Lost 69~bbls mud to form. Incr MW lost 58 bbls to form lost 44 bbls during circ/mixing cycle. Recover 15.2' core #5. Chng well over to new bland mud. Cut core #6 9013-9020' recovered 2-1/2' Cut core #7 9020-9032' 9032-9058' recovered 28'. CSM' 1 tc MO3 Cut Core #8, 9058'-9067', 9067'-9098', 9098'-9114', recovered 56'. Cut Core #9, 9114'-9146' recovered 29' Cut Core #10, 9146'-9174' 9174'-9176' Well took kick. Fin cutting core #10, 9176'-9186', 9186'-9190'. Well taking fluid. Spot LCM pill on btm. Recover 43' Core #10. Cut Core #11, 9190'-9207'. Spot LCM pill, pump dry job. Recover 16.6' Core #11. Cut Core #12, 9207'-9248', recover 38'. Cut Core #13, 9248'-9273', recover 21-1/2'. Spot 50 bbls coarse LCM pill followed by 50 bbl coarse kwik seal LCM pill 9273' -8148'. Cut Core #14, 9273' -9312', recovered 36'. Cut Core #15, 9312'-9372' recovered 60' Cut Core #16, 9372'-9409' recovered 37' Cut Core #17, 9409'-9460' recovered 47' Cut Core #18, 9460'-9518' recovered 58' Cut Core #19, 9518'-9546' recovered 28' Wash 9505'-9546' Cut Core #20, 9546'-9588', recovered 42'. Wash & ream 9548'-9588'. Cut Core #21, 9588'-9648' . Wash & ream 9633'-9648' , recovered 59' . Cut Core #22, 9648'-9685', 9685'-9708'. Spot LC.~!__pill. Recover 60' Core #22. Cut Core #23, 9708'-9767' recovered 59' Cut Core #24, 9767'-9820' 9820'-9827' recovered 58 5' Cut Core #25, 9827'-9843' 9843'-9883' 9883'-9886' . Cut Core #26, , , , recovered 59' 9886'-9905' 9905'-9946' recovered 60' Wash 9905'-9946' Cut Core #27, 9946'-9978' 9978'-9997' recovered 51' Wash & ream 9910' 9997' Cut Core #28, 9997' 10014' 10014'-10027', pip stuck below jars. Jarred pipe, spot SFT pill. Ran free. pt, pipe free @ 9905'. Perform acid job while jarring. Pipe free. Circ & work pipe. Recovered 30' Core #28. RIH w/RTTS & storm choke, set RTTS @ 5000'. Chng seals on btm BOP ram. Test seal - ok. Rel RTTS. Pump dry job. Ream 150' to btm. Cut Core #29, 10027'-10086', recovered 55'. Cut Core #30, 10087'-10102' . Cut Core #31, - , , recovered 15' 10102' 10161' recovered 59'. Cut Core #32, 10161'-10208', recovered 47' as of 05/31/83. CSM/DH13 RECEIVED ARCO Alaska, Inc. ARCO Explora..,n - Alaska Operations Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 27.7 5637 HAND CARRIED SAMPLE TRANSMITTAL SHIPPED. TO' STATE OF ALASKA DATE' ALASKA OiL & GAS CONSEVATION COMMISSION 3001 PORCUPINE DR. ANCHORAGE, ALASKA 99501 ATTN' MR. BILL VAN ALEN M_AY 24, 1983 OPERATOR' ARCO SAMPLE TYPE: DRY DITCH SAMPLES SENT: L~,~ a 6,[~vq~-~) NAME' SOUTH POINT STATE #1 NUMBER OF BOXES: 2 TWO BOXES 2670-5730 - · 8230 573o- < ~ .._ - .~.,'~ ~'o'-u'"1' '. "~(" L _~r , .(~ ~ K~~ ., ~'.~ ~1' / SHIPPED BY:~ .. PALEO ~B TECH CEIPT OF THESE S~PLES, ,PLEASE NOTE ~Y DISCREP~ClES AND ~IL A SIGNED &~op~ oF T~S FOm TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: R. L. BROOKS RECEIVED BY: Alaska 0il & G'as L;0,o. bommisslor~ DATE' Anchorags ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post office BoA 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ~3y 11, 1983 Mr. C. V. Chatterton Commissioner State 'of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive ~Anchorage, Alaska 99501 Subject' ~nthly Report of Drilling & Workover Operations Dear Sir' Enclosed find Monthly Reports of Drilling and Workover Operations for the .following' _.'..'DS 7-26 DS '7-25 DS 7-24 DS 1-26 DS 13-29 s-ll NGI #7 S. Point State #1 Sincere ly, M. A. Major Area Drilling Engineer MAM/CSM:tw Attachments RECEIVED Aiaska Oil & Gas Cons. Anchorage ARCO Alaska. Inc. is a subsidiary o! Allant, -':'-,.-.hfi~:.ldCompany ~ . ' ~-"' STATE Or: ALASKA ---~, · ~ ALASKA ~AND GAS CONSERVATION C~ AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 11. Drilling well~[~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of Well atsurface 1320'FSL, 1320'FWL, .Sec 18, T11N, R15E, UH 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 51.5' RKB 11.5' PadI ADL 28321 7. Permit No. 83 -47 8. APl Number 50_029-20930 9. Unit or Lease Name rudhoe Bay Unit/Lisburne 10. Well No. South Point State #1 11. Field and Pool rudhoe Bay Field/Lisburne Lisburne 0il Pool For the Month of April ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud ~ 2130 hfs, 4/4/83. Drld 17-1/2" hole to 2667'; ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 8090'. Ran logs. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8791'. Ran logs. Ran & cmtd 7-5/8" lnr. Drl cmt to 8746', set EZSV ~ 7601'. Sqz Class G cmt into lnr lap. Drld cmt & CO to 7717'. Ran CBL. Drld 6-1/2" h'ole to 8850'. Cutting core #8 as of 4/30/83. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, Weld conductor set ~ 80'. Instld w/2295# Polyurethane foam. 13-3/8", 72#/ft, L-80, Butt csg w/FS @ 2654'. Cmtd w/2000 sx Fondu & 400 sx PFC cmt. 9-5/8", 47#/ft, N-80, Butt csg w/FS ~ 8076'. Cmtd w/500 sx Class G cmt. 7-5/8", 33.7#/ft, S-95, hydril SFJP lnr fr/7712' - 8788'. Cmtd w/293 sx Class G cmt. 14. Corino resume and brief description Core #1 8850-8862'; recovered 9' (75%) Core #2 8875-8895'; recovered 8.2' (41%) Core #3 8895-8945'; recovered 59' (100%) Core #4 8954-8980'; recovered 39' (100%) Core #5 8993-9010', 9010-9012'; recovered 15.2' (80%) Core #6 9013-9020'; recovered 2-1/2" (36%) Core #7 9020-9032', 9032-9058'; recovered 28' (74%) NOTE: A detailed core description will be submitted with the Well Completion Report Logs run and depth where run L/BHCS/GR/SP fr/2653-8081 ' LDT/CNL w/GR & Cal fr/8792-8079' CBL fr/8792-7396' 6. DST data, perforating data, shows of H2S, miscellaneous data None c,¢,~.,. 5ommissiop Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Area Dri 11 ing Engi neet DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate South Point State #1 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 2130 hrs, 4/4/83. Drld 17-1/2" hole to 2667'. Ran 72 jts 13-3/8" 72#/ft, L-80 Butt csg w/FS @ 2654'. Stab into FC w/stab-in tool @ 2566'. Pump 100 bbls ligno pill. Cmt 13-3/8" w/2000 sx Fondu followed by 400 sx PFC. ND 20" hydril & diverter system. NU & tstd 13-5/8" BOPE @ 5000 psi. Drld FC, cmt & FS. CO to 2667', 10' new hole. Perform shoe tst, held 11.2 ppg EMW. Drld 12-1/4" hole to 5841'. Wash & ream 5721-5841'. Drld to 6644'. Wash & ream 6600-6644'. Drld to 8090' (4/11/83). Ran OH logs - DIL/BHCS/GR/SP fr/2653-8021'. Ran 194 jts 9-5/8", 47#, N-80 Butt csg w/FS @ 8076'. Cmtd 9-5/8" csg w/500 sx Class G. Tst csg to 3000 psi. Drld FC & cmt. Drld cmt, FS & 10' new hole. Perform form leak-off tst, held 16.4 ppg EMW. Drld to 8240', fighting sloughing shale & gas. Ream 8195-8240'. Drld 8-1/2" hole to 8791' (4/14/83). Ran DIL/BHCS w/SP & GR fr/8790-8079', LDT/CNL w/GR & Cal fr/8792-8079'. Perform Arctic Pack dwnsqz w/300 sx PFC followed by 131 bbls Arctic Pack. Ream 30' to btm. Ran 25 jts 7-5/8" 33.7# S-95 hydril SFJP lnr w/float equip & mechanical hngr w/tieback sleeve. Cmt 7-5/8" w/293 sx Class "G" fr/~7~_12-8788'. TOH w/5" DP & lnr setting tool. Set tst plug, chng top rams to 3-1/2". TIH & LD HWDP. TIH w/8-1/2" bit & csg scrpr. No cmt on TOL. LD 80 jts E DP, 6-1/4" DC & scrpr & bit. TIH w/6-1/2" bit. PU 3-1/2" DP. TIH w/CO assy on 5" DP. Drld cmt to 8746'.. Press tst lnr lap - lap leaked. TOH w/CO assy. TIH w/EZ drl on 5" DP, PU 5" DP. Set EZ drl SV @ 7601'. Stab into EZSV~~ i~i.:i~ Sqz 200 sx Class G into lnr lap. Tst csg to 3000#. Drl cmt to 7594'. Drl EZ Drl fr/759417600'. CO cmt 7600'-7712'. TIH w/6-1/2" bit, CO cmt 7712-7717. Tst csg, found leak on vlv on tbg spool, chng out. CO cmt, Drl FS & 7' new hole. Perform leak-off tst to 12.3 ppg EMW. Ran CBL fr/8792~-7396: LD excess 5" DP. Displ ligno mud w/50 bbls hi vis pill followed by bland mud. Drld 6-1/2" hole to 8850'. TIH w/coring assy. Cut core #1 8850~-8862, recover 9' (75%). Cut core #2 8875-8895., recover (41%). Wash & ream 8860£8895'. Cut core #3 8895-8945', recover 59' (100%). Wash & ream 8904'-8954'. Cut core #4 8954[8980' recover 39' (100%). Tst BOPs. Wash & ream 8943S8993'. Cut core #5 8993'-9010' (coring break 9004-9008'), stopped coring, cont coring 9010-9012'. ~ Circ out ann gas bubble & oil & gas cut contam bland mud. Lost 69 bbls mud to form.. Incr MW, lost 58 bbls to form, lost 44 bbls during mixing cycle. Recover 15.2~(80%) core #5. Chng well over to new bland mud. Cut core #6 9013'-9020', recovered 2-1/2' (36%). Cut core #7 9020~-9032' 9032'-9058' recovered 28'~(]7'~)~ ~~ ~'~ ~"iTILH to cut core //8 as of 4/30/83. CSM'ltc ~.~.~ ~ ' ' MO3 ai,,~s~ Oii ~: G~s, (3.o~'~-;- ..... ~TI',OM .HCbF~ b¢,¢'.; SSC,. T, L_lq __. PATE-: .... PROFb-~. Et-> ' ~ I ! =--il i~-ili=lll_~ : 7~IL f~ 5~j SeT A'r ~'o~'3 ' 'r,P.'AT ' ~ o~iSl' k~r. J. R. Knepler Regional Engineer ARCO Alas ka, Inc. P. O. Box 100360- Anchorage, Alaska 99510 Dear Mr. Knep!er: The Alaska Oil and Gas Conservation Commission has received your r~est, dated April 29, 1983, to flare gas during an extended test of the Ltsburne Reservoir, Prudhoe Bay Unit, in the So~__h~_J~~tate No. i well. The referenced well te~t will provide data needed to evaluate the ~otential of the Ltsburne Reservoir. It is under~tood that the test will take about, two months and that ak~u~c !20,000 STB of oil and 240 MSSCF of g~s will be produced. It iL further understood that a flowline will be installed bergen the well site and Drill Site No. 18 to handle the gas coming from the test separator which will, by necessity, be operated at pressure above 800 psiS. By this plan, aleut 4[, ~SCF of gas which cannot be put into the flow line will have to be flared. By this letter., the Alaska Oil and Gas Conservation Commission hereby permits ARCO Alaska, Inc. to flare up to 40 t,]~SCF of gas during a two month period, the exact dates yet to be determined, in the testing of the Lisburne Reservoir in the South Point State No. i well. The testing will be conducted in a manner to keep the flared volumes at a minimum. The Commission will be ke.r-.t a~vtse~ of the progress of the test by adequate reports. The C~mission is also deeply interested in the development potential of this reservoir and we hope you have a very successful an~ informative operation in the South Point State No. I well. Yours very truly, /.-'" / .. ~arry ~q. Eugler Commiss loner BY OgDER. OF TRE COMMISSIO~ ARCO Alaska, Inc Post Office b_,< 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 18, 1983 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat South Point State No. 1 Dear Elaine: Enclosed is an as-built location plat for the subject well. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG2L56: sm Enclosure ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany I I I I I · P PRUDHOE BAY l~ :! SO. STATE PT.! --/~i~ SO. STATE · __ stole: ~' ~ VICINITY MAP I"=lmile I NOTES: I. ALL COORDS ALASKA STATE PLANE ~ ZONE 4. ,/~~..> EL DISTANCES ARE GEODETIC. i / CONDUCTOR LOCATION ! , Y= 5~963~221.018 13 18 x= 693~021.337' i 24 19 PROTRACTED SEC. 18, LAT.= T II Ny RI~E~ U.M. LONG.= 148°26' 10'661" ' SC, ALE: I = 200' ..... E~ LEV.= 13,4~ ~.'.z~ ~,..~..:_:~ I HEREBY CERTIFY THAT I AM P~OPE~LY ~EGISTE~ED AND ..' ~:. T~ .~, , ~ ~. LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF A~SKA AND THAT THIS P~T . REPRESENTS AN AS-BUILT SURVEY 7~ ~.~'~ >~c. s~.2~-s '"-~ ~ MADE BY ME, AND THAT ALL :; ~-?.~ '.... .... .-"~?". DIMENSIONS AND OTHER DETAILS "{:-'~. '-?';-: :.-::~ '.-~~ ARE CORRECT, AS OF: SWAN ~ ~ ~ i ~ - / SOU~ STATE POINT NO. I AS-BUILT SURVFY ARCO OIL and GAS COMPANY ,. ,, . ARCO Alaska, Inc. Post Office BoL ~d0 Anchorage, Alaska 99510 Telephone 907 277 5637 March 16, 1983 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Con~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Flare Request -%South Point State No. 1~~, Dear Mr. Chatterton: ARCO Alaska, Inc. reg~. eats a permit to flare hydrocarbon gas during_ an extended production test of the Prudhoe Bay Unit - Lisburne reservoir in the South Point State No. 1 well. The spud date for the well is late March, 1983 with the testing to take place during the second and third quarters of 1983. %he well will be located near Drill Site No. 18. %he test will provide data needed to evaluate the development potential of the Lisburne reservoir. %he test is expected to take about tvxp months. %he purpose of the test is to confirm the well performance seen in the long-term pro- duction test of the Lisburne reservoir at West Bay State No. 1. Sustainable oil rates and GOR performance are of particular concern. The average oil rate over the t~o-month test period is expected to be 2000 BOPD. %he GOR is expected to increase from approximately 1000 SCF/Bbl to 3000 SCF/Bbl, averaging 2000 SCF/Bbl. Total production from the test is expected to be 120,000 STB of oil and 240,000 MSCF of gas. 5his is based on the well performance seen in the West Bay State No. 1 test. Due to the relatively short length of the test, and considering the extensive testing_ planned for other 1983 Lisburne wells, installation of a flowline to handle the test production is not economically feasible. Also, from an environmental standpoint, we cannot justify the summer-time, off-road travel which would be required to install such a line. Current plans are to truck the oil to Flow Station No. 1 and flare the gas, as was done during the West Bay test. The extensive testing, performed at West Bay State NO. 1 in 1982 was the first "long-term" production testing done in the Lisburne reser- voir. Although encouraging well _performance was seen during the test, many .questions remain unanswered. A major concern at this time is the areal continuity and homogeneity of the productive intervals tested at West Bay State No. 1. Additional Lisburne wells and tests are needed to confirm the West Bay Test results and determine the viability of full-field Lisburne develot~nent. It is hoped that South Point State No. 1, in conjunction with other 1983 Lisburne wells, will provide the data necessary to make this evaluation in a timely fashion. ~,..~ C ~ ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany .&laskri Oi! ~', Gas (-;u;~:;. r-;o~r~mlssior, C. V. Chatterton March 4, 1983 Page TWo If you have any questions of comments, please call me at 265-6193. Very truly yours, J. R. Knep±er ~ Regional Engineer JRK:JBR:ml ~arch 15, 1983 Mr. Mark A, Major Area Drilling Engineer ARCO Alaska, Inc. P, O. Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit South Point State No. I ARCO Alaska, Iuc. Permit No. 83-47 Sur. Loc. 1320'FSL, 1320'FWL, Sec. 18, TtlN, RISE, Btmhole Loc. $ A M E. Dear Mr. Major: Enclosed is the approved applieatiom for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required, Samples of well cuttings and a mud log are required. An inclination survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on ail logs for copying except experimental legs, velocity surveys and dtpmeter surveys. Many rivers in Alaska and their drainage ~ystemm have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are zubject to AS 16,05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may. be contacted by a~representat£ve of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout ~r. ~ark i. Major -2- Prudho~ 'Bay Unit South Point State No. I ~arch 15, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casin§ shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may vitness testing before drilling belov the shoe of the conductor pipe. · In-the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Chairman of BY ORDER OF Alaska Oil and Gas Conservation Enclosure Department 'of Fish & Game, Habitat Section w/o encl, Department of Environmental Conservation w/o enclo ARCO Alaska, Inc. / -. Post Office B, $60 .. Anchorage, Alaska 99510 Telephone 907 277 5637 Harch 4, !983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- South Point State #1, Permit to Drill Dear Mr. Chatterton- Enclosed is our application for Permit to Drill South Point State #1 and the required $100 filing fee. Attachments to the application include a sketch and description of the proposed pad and access road; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. We will spud this well approximately April 4, 1983. If you have any questions, please call me at 263-4965. Sincerely, M. A. Major Area Drilling Engineer MAM/JG2L21'sm Enclosures Alaska OiJ E< GaS Co~ls. ¢",- ~ - · ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION CO~,.,vllSSlON PERMIT TO DRILL ~0 AAC 2~.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UH At top of proposed producing interval 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UN At total depth 1320' FSL, 1320' FWL, Sec. 18, T11N, R15E, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 51.5' RKB, 11.5' PAD ADL 28321 9. Unitorleasename Prudhoe Bay Unit/Lisburne 10. Wellnumber South Point State #1 11. Field and pool Prudhoe Bay Field/Lisburne Lisburne 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 7 mi NW of Deadhorse miles 1320 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10951 ' (MD=TVD) feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT None feet. MAXIMUM HOLE ANGLE 0 oI (see 20 AAC 25.035 (c) (2) Amount $500,000 ll 5. Distance to nearest drilling or completed 18-10 well 2391' @ Surface feet 18. Approximate spud date 4/04/83 :~660 psig@ Surface 4?)00 psig@ lOqC, 1 ft. TD (TVD) 21 SIZE Casing Weight 20" 94# 13-3/8" 72# Hole ~7-1/2" h2-1/4" 8-1/2" 6-1/8" 9-5/8" 47# 7-5/8" 33.7# 5" 15# Proposed Casing, 22. Describe proposed program: CASING AND LINER Grade Coupling u- 0 I I L-80 J BUTT I L-80 /BUTT J S-95 SF~JP/HYDR I Ir N-80 JAB MOD/I FL 4S Length 85' 35' I 35' I 34' 34' 2666' 8083' 1015' 2420' iner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD (include stage data) 33' ~ 33' 7816' I ~7816' 8531 ' 18531 ' I MD BOTTOM TVD 120' 120' 2700'I 2700' 8116'1 8116' 8831'1 8831' 10951'110951' 1925# Pol eset 2300 sx Fondu+400 sx PF 500 sx G&300 sx PF1 400 sx Class G cement 250 sx Class G cement ARCO Alaska, Inc., proposes to drill this vertical hole to 10951' (MD=TVD) to core and test the Lisburne zone. Logs will be run across selected intervals from the 13-3/8" casing shoe to TD. A surface diverter will be used on this well. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A mud logger will be used from surface to TD. The entire Lisburne zone, +2000,~ is scheduled to be cored. Six Lisburne cased hole DSTs are planned. This well will be completed with a packer above the Lisburne and produced through tubing for a long-term Production test. No close wellbore crossings will be encountered downhole. All intervals perforated while the rig is on the hole will be reported as applicable. A separate Sundry Notice will be submitted for perforating work done after rig release. i, E ! V E!" 23. I hereby certify that the foregoing is true and correct to the best of my knowledge · SIGNED ~ ~ TITLE Area Drilling EngineeJ~AR~ ~/~':'~;~/~. :~ The space below for Commission use CONDITIONS OF APPROVAL Samples required ~YES []NO Permit number APPROVED BY Mud log required (~YES []NO Approval date ,, Alaska 0iic.: ° .,c'*°...,, Cons. C¢!'nmJssi0n Directional Survey required I APl number I--JYES eNO I 50--O ?.~' - SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Ma~c~ 15, 1983 by order of the Commission Submit in triplicate Form 10-401 GRU2/PD8 SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INC. SCHEMATIC ~0" HYD. OPR. BALL VALVE WELL BORE (SEE DETAIL) I0" HYO. OPR. BALL VALVE ALL 90° TURNS ARE "TEE" - - !' "" I ' ' ' RESERVE PIT AREA NOTE' FLOWLINE DR ILL RISER 20" 2000 PSI WP ANNULAR PREVENTOR IO" HYDRAULIC OPERATED BALL VALVES '-IO" DIVERTER LINE -- DR ILL ING SPOOL 'Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 20260 13-5/8" BOP STA£~ DIAGRAm ANNULAR PREVENTER --J~BLIND RAMS Accumulator Caoacit7 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' simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" 80P Stack Test Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a. 250 psi low pressure test for a minimum of 3, minutes, then test at the high pressure. 5. I~crea~e presure to 3000 psi and hold for a .minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close.bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of holeo Close blind rams and test to 5000 psi for at least 3 minutes° 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13o Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside 80P to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete 80PE test once a week and functionally operate BOPE daily. Rev. 5/13/81 535' 2~5' 20' 20' /2, ACREAGE.: PAD: 5.45 ACPES ROAD: 2.85 ACRE.S ¥O;_UME: PAD: 36, OOO C.Y. ROAD; 14, OOO C.Y. (APPROX.) LOSAT]ON: 1~20' FSL, 1320' F~, SECT]ON 18, TI IK~RISE, Pu.<~-~E: L F]_LD DEVEL~N7 ADJACEr;7 LA',O O'~r;E~: SLATE ELE AT'r ' A~ PAD SuPFACE: II 5' KLL~' U. LC lDO° SCALE: i" - 125' PROPOSED SOUTH POINT STATE PAD AND ACCESS ROAD PRUDHOE BAY UNiT N,.ORTH SLOPE BO~,OLJGH STATE C>r- ALASKA PROPOSED SOUTH PT, 'STATE PAD DS- 8 Aia~k~ Oil ? ~' [~ .E×iST3NG [] PROPOSED ['_"J COt,~EPTUAL (FUTURE) T! IN- T I IN- LAT.: ?O*lB' 14.39' RI4E RISE L~.'qG,: 148026' I I, 2-/'5' ACREAGE: PAD: 5.45 ACRES R'OAD: 2.85 ACRES vC~...u),"E: PAD: 36. 000 C.Y. ROAD: 14. 000 C.Y. (:APP~OX.) LOCATION: 1320' FSL. 1320' FWL. SECT]ON 18,, T~I',~-R~5E. PURPOSE: OIL FIELD DEvELOP~'~NT ADJACrNT LAND Obi,.'--R: STATE OF ALASKA ELEvA'r]oN AT PAD SURFACE: 11,5'. t',,'LLW 4 0 400C · i I ..... r -~--r i ' SCALE IN FEET PROPOSED SOUTH PO]IHT STATE PAD AND ACCESS ROAD PRU~HOE BAY UNIT NORTH SLOPE BOROUGH STATE OF ALASKA .~c~ I ~3 ~t£, DEC. '82 CHECK LIST FOR NEW WELL PERMITS, Company Lease & Well No. f /f, ~¥ ITEM APPROVE DATE (1) Fee (2) Loc .~×2 thru 8) YES NO 1 Is the permit fee attached 2. Is well to be located in a defined pool .., ........................... 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ............... 7. 'Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... (3) Ad rain /~>'f". ~ / / ~ ] 9. (9/ thru 11) 10. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Casg ,4~.~,/~M/ ~-/g/-~ (4) (12 thru 20) (5) BOPE,~///~'~ ;~'-T¢'-fJ (21 thru 24) Does operator have a bond in force ................................... ~-~_ Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... z~, Will cement tie in surface and'intermediate or production strings ... ~ Wil Wil Wil Is Is Is 1 cement cover all known productive horizons ..................... ~ 1 surface casing protect fresh water zones ..................... ~, 1 all casing give adequate safety in collapse, tension and bu[st ·z~, this well to be kicked off from an existing wellbore ..... ,. ....... old wellbore abandonment procedure included on 10-403 ............ adequate well bore separation proposed ........................... ,~ REMARKS Is a diverter system requireddiver;;~.;~ ................ ~ ''':'' ': ;;t;ghed ..1...,~ Are necessary diagrams of equlpmen[ Does BOPE have sufficient pressure rating -Test to ~"LPLPC) psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. (6) Add: ~,~.~?~//. ~-//'Y'~3 25. Additional requirements ............................................. ~z Additional Remarks: o ~z o~ o~ Geology: Engin~eer ing :/ ~{WK L~ S ~-~,, ~BE%~ ~ ,-.~VA ~_ JKTJ~-~ HJH / 3AL · MTM ~ 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information, -: · ,o ' - I © © . ? ~ _ _ . -24 .~ ~ -. _~... · _ i_)7 _- - . . . -' .~ 0 0 : ! 1 I I . . ..~.. ..~' _ _ _ © © I I~ I1]iil iT:J Zi [;.12! ~ ~ ~ _ 1,:~-~ ,~ ? .X,_~ ''~ 2c~., i ~, ~; '~., ..i .~ . . ~ ~,.I .. /~,_, _ . {~ . ~ · _ .. ~. - . : ~ ~ ' y. ~:~ ~ .- .~ - 0 0 I ' I ~:~:. .~: ...- . - . . . :. . ..~ ~ ~ ~ .- : - . 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