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189-010
RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMIPION JUL 1 7 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations Li Perforate U Other Lj Bright Water Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Developments Exploratory ❑ 189-010-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service © 6.API Number: Anchorage,AK 99519-6612 50-029-21909-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028330 PBU 12-33 . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): '10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL' 11.Present Well Condition Summary: Total Depth measured 9980 feet Plugs measured None feet true vertical 9230.85 feet Junk measured 9647 feet Effective Depth measured 9933 feet Packer measured See Attachment feet true vertical 9186.93 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 33-113 33-113 1490 470 Surface 3541 13-3/8"68#L-80 32-3573 32-3503.26 5020 2260 Intermediate None None None None None None Production 9612 9-5/8"47#L-80 31 -9643 31-8915.68 6870 4760 Liner 635 7"29#L-80 9344-9979 8638.46-9229.91 8160 7020 Perforation depth Measured depth 9642-9646 feet 9646-9661 feet 9740-9750 feet 9750-9756 feet 9762-9790 feet 9794-9807 feet True Vertical depth 8914.75-8918.48 feet 8918.48-8932.49 feet 9006.35-9015.71 feet 9015.71-9021.33 feet 9026.95-9053.16 feet 9056.91 -9069.09 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: NUV 0 6 2013 scAtitiED 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 5 ' Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPIU GSTOR ❑ WINJ 0' WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 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 Nita Summerhays Email Nita.Summerha"--• P.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signat --4//'l ��' ice/�,_=���. Phone 564-4035 Date 7/16/2013 WOVI/r RBDMS JUL 23 20 ?"//ti Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028330 T/I/0=360/850/100 emp=HOT(RESEVIOR SWEEP MOD) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 208 gal. EC9360A(Surfactant) Average of 18.9 gph for 11 hrs. Pumped a total of 208 gal. since start of project. Pumped 1533 gal. EC9378A( Polymer) Average of 139 gph for 11 hrs. Pumped a total of 1533 gal. since start of project 6/15/2013 ***Job continued to 5-16-13 WSR*** ***Job continued from 6-15-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 607 gal. EC9360A(Surfactant) Average of 25.2 gph for 24 hrs. Pumped a total of 815 gal. since start of project. Pumped 2938gal. EC9408A( Polymer) Average of 122.4 gph for 24 hrs. Pumped a total of 4471 gal. since start of project 6/16/2013 ***Job continued to 5-17-13 WSR*** ***Job continued from 6-16-13 WSR*** (Brghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 658 gal. EC9360A(Surfactant) Average of 27.4 gph for 24 hrs. Pumped a total of 1473 gal. since start of project. Pumped 3000 gal. EC9408A( Polymer) Average of 125 gph for 24 hrs. Pumped a total of 7471 gal. since start of project ***Job continued to 6-18-13 WSR*** 6/17/2013 ***Job continued from 6-17-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 699 gal. EC9360A(Surfactant) Average of 29 gph for 24 hrs. Pumped a total of 2172 gal. since start of project. Pumped 3212 gal. EC9408A( Polymer) Average of 133 gph for 24 hrs. Pumped a total of 10683 gal. since start of project ***Job continued to 6-19-13 WSR*** 6/18/2013 • Daily Report of Well Operations ADL0028330 ***Job continued from 6-18-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 71 gal. EC9360A(Surfactant) Average of 23 gph for 3 hrs. Pumped a total of 2243 gal. since start of project. Pumped 326 gal. EC9408A ( Polymer) Average of 108 gph for 3 hrs. Pumped a total of 11009 gal. since start of project Final Valve postions SV=closed, SSV, WV MV=open, IA/OA=OTG FWHP 360/770/30 6/19/2013 FLUIDS PUMPED GALS 2243 EC-93609A SURFACTANT 11009 EC-9408A POLYMER 13252 TOTAL Casing / Tubing Attachment ADLOO2833O Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 33 - 113 33 - 113 1490 470 LINER 635 7"29# L-80 9344 - 9979 8638.46 - 9229.91 8160 7020 PRODUCTION 9612 9-5/8"47# L-80 31 - 9643 31 - 8915.68 6870 4760 SURFACE 3541 13-3/8"68# L-80 32 - 3573 32 - 3503.26 5020 2260 TUBING 9092 4-1/2" 12.6# L-80 30 - 9122 30 - 8435.97 8430 7500 TUBING 70 5-1/2" 17# L-80 9134 - 9204 8446.84 - 8510.44 7740 6280 TUBING 29 5-1/2" 17# L-80 9685 - 9714 8954.92 - 8982.03 7740 6280 . • • • Packers and SSV's Attachment ADL0028330 SW Name Type MD ND Depscription 12-33 PACKER 9034 8282.55 4-1/2" Baker S-3 Perm Packer 12-33 PACKER 9162 8398.25 5-1/2" Baker SB-3 Packer 12-33 PACKER 9685 8880.92 4-1/2" Brown 2-B Packer _ CIYV • -ANY NOTES:H2S READINGS AVE RAW 125 ppm ACTUATOR BAKERY 12-33.�._ _._ _ . � wHaa ON ML WELL REQUIRES ss5trt�ev ON ACTUATOR- BAKER C ELE 74' ML °RENAL 03/15/89 TBG TALLY IS OFF BY-103'. !VIAL KB. _ B_EV_ _.._ _ g CORRFCTIONS ARE SHOW.''CHROMENPPLI33*** H I]KOP= 2500' Max Angie= 33°@ 630D 1 1 I 2026' H4-1/2"F ES X NP(9-CR),ID=3.813' Datum MD= 9598' Datum TVD= 8800'SS 13-3/8'CSG,68#,L-80/K-55,13=12.415" -j 3573' I I 1 9003' H4-12"HES X NP(9-CR),D=3.813" I Minimum ID = .80"@ 9069' 4-112" DOWNHOLE CHOKE ><, ►mo t 9034' I—Ie 51s X4 12"BKRS 3 RCF�D=3.870" IIII 9069' H4-112"HES X NP(9-CR),D=3.813" I 9069'7—+4-12"X LOCK CHOKE,D=.80"(06104/13) 4-1/2"TBG,12.6#,1.80 TAI, -I 9122' ' I 9133' F-14-112'X 5-1/2"XO I .0152 bpf,D=3.958" 1 9148' H9-5/8"X 5-12"MOUE OVERSHOT 5-1/2"TBG STIi$(11125/08) H 9134' I 9162' 1--19-518'X 5-1/7 BKRSB-3A RCR,D=4.875" 1 5-1/7 TBG,17#,L-80,.0232 bpf,ID=4.892' H 9182' I--'— 9182' H5-1/7 X 4-12"XO I 4-1/7 TBG,12.6#,180,.0152 bpf,D=3.958" H -9204' 1-- -9204' -BAD OF 4-1/2"PARTED 1BG(12/04/08) ITOP OF 7'1PR H 9344' (LKaY"UNSC17EWED°NSTEA0OF"PARTED') -9647' I-F6 4-1/2"TBG TAL(12/04108) LKELY IIES FASDRLL Sill N NFR.E 19-5/8'CSG,47#,1-80,D=8.681" H 8643' I-4 tt El Z L 96w H7-X 4-12-BROYUN 2-B Fi02,D=4.00" 4-1/2'TBG,12.6#,L80,.0152 bpf,I)=3.958' H 9714' ' ' I 9710' H4-12"OTIS XN NP,13=3.725' PERFORATION SUMMARY REF LOG: 81-CS on 02/11/89 ANGLE AT TOPPERF: 21°@ 9642' / \ I 9714' H4-12"WLEG,D=3.958' I Note:Refer to foduction CB for historical pert data SIZE SR= 9013 VAL Opn/Sqz SHOT SOZ 9721' -I MILD TT LOGGED 10126189 I 3-3/8" 4 9642-9646 0 11/28/90 a 3-3/8' 8 9646-9661 0 06/03/89 3-3/8" 1 9740-9750 0 1128/90 3-3/8" 3 9750-9756 0 1128/90 3-3/8" 2 9762-9790 0 06/03/89 3.3/8" 2 9794-9807 0 06/03/89 FETID -I 9933' ••1•1•1•1•1•1•• 11111111 11111111 7'LNR,29#,1-80,.0371 bpf,D=6.184" H 9979' , 1 V f 1 f c c •1111111111111• TD -I ' 1 11111111 ATE REV BY OOMbBJTS DATE REV BY OOM ENTS PRUDHOE BAY I. HT 03/15189 ORIGINAL COMPLETION 01/13/12 TMNYJMO A013E0 1-25 SAFETY NOTE WELL 92-33 11/30/08 016 RWO w/ORIG COMP CORK 06/12/13 WKFTJMD ADDED DH CHOKE(06/04/13) R RMT t'b:8189010 12/08/08 SEW/SV FISH(12/04/08) AR No: 50-029-21909-00 06/13/09 KNC/TLH TT FISH&FASDRLL CORRECTIONS 06/15/09 l-8/.10 DRLG DRAFT CORRECTIONS SEC 18,TON,R15E,168'FSL&692'FB 02109/11 1411JM3 ADDED SSSV SAFETY NOTE BP Exploration(Alaska) STATE OF ALASKA ' A OIL AND GAS CONSERVATION CO SION l 2vl~REP RT OF SUNDRY WELL OPE~TIONS ~~w~" ~I 1 ~~~?-O~ 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 189-010 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21909-00-00 7. KB Elevation (ft): 74 0' ~ 9. Well Name and Number: PBU 12-33 8. Property Designation: 10. Field /Pool(s): ADL 028330 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9980 - feet true vertical 9231 ~ feet Plugs (measured) None Effective depth: measured 9933 feet Junk (measured) -9647' true vertical 9187 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3573' 13-3/8" 3573' 3503' 4930 / 3700 2670 / 2230 Intermediate Production 9643' 9-5/8" 9643' 8916' 6870 4760 Liner 635' 7" 9344' - 9979' 8638' - 9230' 8160 7020 Perforation Depth MD (ft): 9642' - 9807' Perforation Depth TVD (ft): 8915' - 9069' 4=1/2" x 5-1/2", 12.6# / 17# L-80 -9204' Tubing Size (size, grade, and measured depth): a-~/2° ~2 R# I -go Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker S-3 Packer; 9034' 9-5/8" x 5-1/2" Baker SB-3A Packer; 9162' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull Tubing from 9134'. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 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 Hank Baca, 564-544a 308-310 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Sig ature Phone 564-5743 Date Sondra Stewman 564-4750 Form 10-404 Revised 04/200- ~ Submit Original Only _. . , ~ ~__i (.... ~~~ ~ `(lam i ~ ®,r~ r~ WELLHEAD= MCEVOY ACTUATOR= AXELSONI KB. ELEV = 74' BF. ELEV....- KOP = Max Angle = ?500'; 33 ~ 6300' Datum MD = 9538' DatumTVD-.... ....._.8800' SS Q 13-3/8" CBG, E8# L 80/K 55, ID = 12.415" ~ 3573' Minimum ID =3.72''' a~7 9T'IE~` 4-1/2" UTIS XN NO-G(3 NlPPLE 4-1!2" TBG, 12.6#, L-80,....0152 bpf, ID =3.958" 9122` ....__ -112" Tt1Blrlt~. ~ IE3 (11:251t18) 9134' 5-1,2" TBG, 17#/, L-8t?, .fl232 bpf, = 4..892:,` 9182`.. 4-112" TBG, 12,6#, L-80, .0152 bpf, iD =3.958" °9204 ITOPOF7"LR [ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9643' TOP OF 4-1 /2" TBG 9685' 4-1/2" TBG, 12.6#, L80, .0152 bpf, ID = 3.958" ~ 9714' PERFORATION SUMMARY REF LOG: BHCS on 02/11/89 ANGLEATTOPPERF: 21 @9642' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9842-9646 O 11/28/90 3-3/8" 8 9646-9661 O 06/03/89 3-3/8" 1 9740-9750 O 11/28/90 3-3/8" 3 9750-9756 O 11/28/90 3-3/8" 2 9762-9790 O 06/03/89 3-3/8" 2 9794-9807 O 06/03/89 PBTD 9933' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9979' TD X9980' S NOTES: ORIGINAL 3/15/89 TUBING TALLY 12 -3 3 IFO Y~103'. CORRECTIONS ARE SHOW N. ?e~.,~ ~~~' ~---~:- i t ~dz~ IL) =8.818" 903' -j4-1i2" X NIP, ]D = 3.813" 9934' 9-518'° X 4-1i2" BKR S-3 PKR, ID = 3.870" 9069' 4-112" X NiP, iD = 3,813" ~-" ;~`~' -~, ~~- ~' ~ ~,:R `:~ ,-3A tr~~.R, ID = x_875" -9204' END OF 4-112" PARTED TBG (12104/08) ^°9647" FISH: 4-112" TBG TAIL (12f04/08) 9685' 7" X 4-1/2" BROWN 2-B PKR, ID = 4.00" 9710' 4-1/2" OTIS XN NO-GO NIP, ID = 3.725" 9714--~4-1/2" WLEG, ID=4.00" 9721' ELMD TT LOGGED 10/26/89 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/15/89 ORIGINAL COMPLETION 11/30/08 D16 RWOw Orig Comp Corr 12/08/08 SEW/SV FISH (12/04/08) PRUDHOE BAY UNft WELL: 12-33 PERMfT No: 189-010 API No: 50-029-21909-00 Sec. 18, TION, R15E 2459.39 FEL 2531.48 FNL BP F~cploration (Alaska) • a BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: 12-33 Common Well Name: 12-33 Spud Date: 1/27/1989 Event Name: WORKOVER Start: 11/3/2008 End: 11/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/30/2008 Rig Name: DOYON 16 Rig Number: Date From - To 'Hours I, Task Code NPT Phase Description of Operations 11/20/2008 12:00 - 16:30 4.50 MOB P PRE Move Rig off of 12-19i Well Slot. 16:30 - 00:00 7.50 MOB N WAIT PRE Waiting on Well House and Flowline to be removed. Waiting on dirt work to build up pad for Rig. Maintain Rig and Equipment. 11/21/2008 00:00 - 18:00 18.00 MOB N WAIT PRE Continue waiting on Pad prep work. Maintain Rig and Equipment. Work on Pipe Skate. Work on Hazard Hunt list. General house keeping. 18:00 - 00:00 6.00 MOB N WAIT PRE Continue waiting on Pad prep work. Maintain Rig and euipment. Painting the Pump and Pipe Shed floors. Fix misc hydraulic leaks. Tighten drum sprocket on Draw Works. 11/22/2008 00:00 - 06:00 6.00 MOB N WAIT PRE Continue waiting on Pad Prep. (Good progress made during the night). 1000-hours, bring in a compactor to work the pad. Continue with work on Pipe skate. Baker Machine has the pin and ram end from one of the Off-driller side Pipe Skate elevator rams that need to be repaired, but the North Slope Borrough electrical power distribution system has been down since early yesterday. Baker has a priority on Doyon 16 repairs and have enough electrical power to operate two of their smaller machines as of 1100-hours. 06:00 - 16:00 10.00 MOB N WAIT PRE Continue to maintain Rig and Equipment while waiting on completion of pad prep. Compleet several modification projects to rig equipment and house keeping projects. 16:00 - 18:00 2.00 RIGU P PRE PJSM. Lay Herculite and mat boards. Prep to move Rig. Order out hot Sea Water. 18:00 - 19:00 1.00 RIGU P PRE Move, spot, and shim Rig on 12-33i Well Slot. 19:00 - 00:00 5.00 RIGU P PRE Berm Rig. Install double valves on IA and OA. Prep to spot equipment modules. Rig up cellar to circulate. 11/23/2008 00:00 - 02:30 2.50 RIGU P PRE Finish rigging up cellar. Spot #2 Pump module and #4 Generator. Spot Slop Tank. Continue to fill Pits with hot Sea Water. 02:30 - 03:00 0.50 RIGU P PRE Pad Operator remove LO-TOs on Tree Valves and pump open SSV. 03:00 - 05:00 2.00 PULL P DECOMP Plck-u~Lubricator and test to 500 psi. Pull BPV Lay down same. TP = 200 psi. IAP = 200 psi. OAP = 0 psi. Test lines at 250/3,500 psi. Bleed Tbg and IA to Slop Tank. 05:00 - 08:30 3.50 KILL P DECOMP PJSM. Mix and pump a 20 bbl HI-Vis sweep. Circulate Well with hot Sea Water at 5.5 bpm/480 psi. Monitor well and well is dead. Blowdown lines. 08:30 - 12:00 3.50 WHSUR P DECOMP PJSM. DSM P/U ISA BPV and dnr-rod it into hanger. PT from the bottom to 1000-psi, twice with no happiness.. R/U DSM lubricator and POH with ISA BPV, seeing no pressure under the BPV. Examine BPV and find O-ring damaged. Replace BPV with second BPV and RIH. PT from the bottom and it held 1000- siforl0-minutes recorded. 12:00 - 13:30 1.50 WHSUR P DECOMP PJSM. Blowdown and R/D lines. N/D Tree and adaptor flange. 13:30 - 17:00 3.50 BOPSU P DECOMP N/U 11" x 13-5/8" DSA, N/U BOPE and R/U lines for initial BOPE test on 12-33i. 17:00 - 00:00 7.00 BOPSU P DECOMP Test BOPE to~50-psi low and 4000-psi high using 4" and 5-1/2" test joints. Test Hydril 250-psi low and 3500-psi high with 4" test joint, only. AOGCC's right to witness the test was waived by C. Sheve. Note: The Manual Kill Line valve failed the low pressure test. Replace valve. 11/24/2008 00:00 - 03:00 3.00 BOPSU P DECOMP Complete replacement of the Manual Kill Line Valve. Test Printed: 12/18/2008 1:24:27 PM • • BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: 12-33 Common Well Name: 12-33 Spud Date: 1/27/1989 Event Name: WORKOVER Start: 11/3/2008 End: 11/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/30/2008 Rig Name: DOYON 16 Rig Number: Date From - To '~ Hours Task Code NPT Phase Description of Operations 11/24/2008 00:00 - 03:00 3.00 BOPSU P DECOMP valve at 250/4,000 psi. Good test. Rig down test equipment. Blow down lines. 03:00 - 04:15 1.25 BOPSU P DECOMP Plck-up Lubricator and test. Pull blanking plug and BPV. Lay down same. 04:15 - 05:00 0.75 PULL P DECOMP Pick-up landing joint. BOLDS. dull Tubing Hanger to floor with no problems (180K). 05:00 - 06:00 1.00 PULL P DECOMP Circulate well at 7.0 bpm/140 psi. Monitor well. 06:00 - 06:30 0.50 PULL P DECOMP PJSM with crew, Schlumberger spooler operator, Tool Pusher, and WSL to POH and UD tubing. 06:30 - 07:00 0.50 PULL P DECOMP Cut SS Control Lines, wrap sash cord around lines and tie off to spooler. B/O and UD hanger. 07:00 - 09:00 2.00 PULL P DECOMP POH and UD 5-1/2" 8rd AB Mod tubing and spool up two 1/4" SS Control Lines. Stop to CBU with 30-joints POH. 09:00 - 11:00 2.00 PULL P DECOMP Stop to circulate bottoms u .Have wron crossover for the 5-1/2" being pu ed. a led Tool Services and Stores to verify which thread was on the original completion. It was 5-1/2" LTC 8rd which was shown as 5-1/2" AB Mod on the original running summary in the Handover Folder and shown as BTC in the RWO program. The CBU produced nothing but our well-kill circ-out seawater in the returns. 11:00 - 19:30 8.50 PULL P DECOMP Resume POH and UD 5-1/2", LTC 8rd tubing. UD the SSSV at 1300-hours. UD #75 C~ 1400-hrs. #95 @ 1450-hrs. #120 ~ 1525-hrs. #160 @ 1655-hrs. Finish POOH with 5 1/2" completion. Recovered 233 Joints and a 21.10' cut-off stub. Normal flare = 6 1/4". (Note: Found small in hole in joint #98. Also recovered both SSSV control lines and all 58 bands). 19:30 - 20:30 1.00 PULL P DECOMP Rig down 5 1/2" hndling equipment. Clear and clean floor. 20:30 - 21:30 1.00 CLEAN P DECOMP Rig up to pick-up Drill Pipe. Install Wear Bushing. 21:30 - 23:30 2.00 CLEAN P DECOMP Make-up BHA #1 as follows: 8 1/2" x 5 9/16" Mill Shoe, WP Ext, WP Ext, WP Ext, (5 1/2" Inner Dress Mill), Boot Basket, Double Pin Sub, 9 5/8" Casing Scraper, Bit Sub, Bumper Jar, Oil Jar, XO, 6 ea 4 3/4" Drill Collars. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH with BHA #1. Single in with 4" Drill Pipe from Pipe Shed. 11/25/2008 00:00 - 07:30 7.50 CLEAN P DECOMP Continue RIH with BHA #1 with 4" Drill Pipe from Pipe Shed. 07:30 - 08:00 0.50 DHB P DECOMP PJSM to P/U and RIH with RTTS/Storm Valve, and N/D BOP, R&R 9-5/8" packoff, R&R Tubing Head. 08:00 - 09:00 1.00 DHB P DECOMP P/U and M/U RTTS/Storm Valve, RIH and set one stand below Rig Floor. Test to 1000-psi for 10chart-recorded minutes. 09:00 - 14:00 5.00 BOPSU P DECOMP Pull Wear Ring, N/D BOP stack at the DSA, N/D 11" x 13-5/8" Tubing Spool, pull packoff, install new packoff, N/U new 13-5/8" x 13-5/8" Tubing Spool. Test Pack of at 5,000 psi x 30 minutes. Good test. 14:00 - 15:00 1.00 BOPSU P DECOMP Nlpple up BOP Stack. 15:00 - 16:00 1.00 BOPSU P DECOMP Install test plug. Test BOP bod break at 250/4 000 si. Good test. State's right to witness test was waived by C. Sheve. Pull test plug. 16:00 - 16:30 0.50 DHB P DECOMP RIH with 1 stand and release Halco 9 5/8" Storm Packer. POOH and lay down acker. ecovere comp ete. 16:30 - 18:00 1.50 CLEAN P DECOMP Continue IH with BHA #1 and remainder of 4" Drill Pipe from Pipe Shed. Tagaed -100' high (9,134' dmd). Solid set-down. No over pull on pick-up. Bring pump on line and attemp to make hole. Double check pipe tallies and joint counts. Re-run pipe tally on a different program and came up with the same PflntBtl: 12/18/zoos 1:24:27 NM • • BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: 12-33 Common Well Name: 12-33 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To ', Hours ' Task Code NPT 11/25/2008 16:30 - 18:00 1.50 CLEAN P 18:00 - 19:00 1.00 CLEAN P 19:00 - 22:00 3.00 CLEAN P 22:00 - 22:30 I 0.501 CLEAN I P 22:30 - 00:00 ~ 1.50 ~ CLEAN ~ P 11/26/2008 100:00 - 01:30 I 1.501 CLEAN I P 01:30 - 02:30 1.00 CLEAN P 02:30 - 06:00 3.50 CLEAN P 06:00 - 07:30 I 1.501 CLEAN I P 07:30 - 09:00 I 1.50 I CLEAN I P Spud Date: 1 /27/1989 Start: 11 /3/2008 End: 11 /30/2008 Rig Release: 11 /30/2008 Rig Number: Phase Description of Operations DECOMP depth. Discuss plan forward with Anchorage Engineering. DECOMP CBU ~ 10 BPM with 1890 psi. Shut down and monitor well. DECOMP POOH with BHA #1 standino back 4" Drill pipe in derrick. Monitor well on last stand of DP. Constant hole fill on trip out. DECOMP UD BHA #1. Observed wear marks inside mill shoe 3" up. Discussed running Lead impression block with Anchorage engineering. DECOMP Hold PJSM with rig crew and SWS for rigging up slick line. Install dutch riser and R/U slick line with 6-1/2" Lead impression block. DECOMP RIH with 6-1/2" lead impression block on slick line. Ran in to 9144' slick line measurement and to ed. POOH and sa tubing stub impression on lead block. DECOMP PJS slickline and dutch riser. DECOMP Make up cleanout BHA and RIH with 4" DP from derrick to dress 5-1/2" tubing stub ~ 9134' Drillers measurement. DECOMP Ta to of 5 1/2" tubing slum at 9 134.5'. Establish parameters as follows: PUW = 192K. SOW = 155K. ROTW = 174K. Pump#1 = 3 bpm/180 psi. RPMs = 40. Dress off top of 5 1/2" Stump with no problems. Swallowed stump 3 time after dress off without rotati~ Swallow depth of shoe = 9,148.5. Final top oTstump depth = 9,135' dpm. DECOMP Mix and pump a 20 bbl Hi-Vis sweep. Chase to surface with -625 bbls sea Water at 11 bpm/2150 psi. Monitor Well. Pump dry job. Blow down top Drive. 09:00 - 13:00 4.00 CLEAN P DECOMP ~ h Drill Pi e a nick. Noticed some chatter on weight indicator coming off bottom for several stands. Stop will 10 stands in Derrick. Driller and WSL monitor fluid in well at a static condition. Continue with POOH. 13:00 - 13:30 0.50 CLEAN P DECOMP Finish POOH. Lay down BHA #1. Good wear pattern on inside of Shoe and face of Dress-off Mill. Recovered some shavings in Boot Basket. Clear floor. 13:30 - 14:00 0.50 CLEAN P DECOMP Rig up floor to handle and run 2 7/8" PAC Drill Pipe and next 14:00 - 15:00 I 1.001 CLEAN I P 15:00 - 17:30 I 2.50 I CLEAN I P 17:30 - 20:00 2.50 CLEAN P 20:00 - 21:30 1.50 CLEAN P 21:30 - 00:00 2.50 CLEAN P 111/27/2008 100:00 - 00:30 I 0.501 FISH I P DECOMP Have a mini safety stand down and general safety discussion with Crew, RLG, Tool Pusher, WSL, Snake, and Allen Graff. Also hold PJSM before picking up BHA #2. DECOMP Make up BHA #2 as follows: 8 1/2" Guide Shoe, 8 1/8" TS WP Ext, 5 3/4" TSWP Ext, Shear Pin Guide, (after shear), 3 5/8" Junk Mill, Bit Sub, 20 Jts 2 7/8" PAC Drill Pipe, XO, Bumper Sub, Oil Jar, Pump out Sub, XO, 6 ea 4 3/4" Drill Collars. DECOMP RIH from 827' to 9070' with BHA #2 with 4" DP from derrick. DECOMP Slip and cut 84' of drilling line. DECOMP M/U top drive and establish perameters 150 DN 187 UP 169 RT ~ 30 rpm and 4k TO 4 BPM with 580 PSI. Set 1 k WOB down on fasdrill ~ 9244' and plug feel. RIH and tagged ~ 47' rotated ~ 30 rpm 4-5k TO 56PM 820 PS' I to 965' Stopped drilling at 9651' had 4-5k WOB 6k TO not making any hole. Talked to Anchorage engineering. We are below 4-1/2" W LEG @ 9275' and above top of 7" packer ~ 9685'. DECOMP Observed a 20 bbl pit gain while CBU ~ 8 BPM 2330 psi. Shut off pump and monitor well. (Well was flowing) Open choke and close annular. Shut in p 40 psi u in casing Printed: 12/18/2008 1:24:27 PM • • BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: 12-33 Common Well Name: 12-33 Spud Date: 1/27/1989 Event Name: WORKOVER Start: 11/3/2008 End: 11/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/30/2008 Rig Name: DOYON 16 Rig Number: Date From - To 'Hours Task Code NPT Phase Description of Operations 11/27/2008 00:00 - 00:30 0.50 FISH P DECOMP 110 psi. Notified Anchorage engineer, Jim Willingham, AOGCC. Called for extra vac trucks with 8.5 ppg seawater. 00:30 - 03:30 3.00 KILL C DECOMP Shut in casing pressure built to 150 psi. Hold PJSM with rig crew and Vac truck drivers. Once vac trucks with fluid on location start bullheading fluid down DP and Annulus @ 6BPM 240 psi ICP bring pumps up to 8 BPM 620 psi FCP. Bullheaded 955 bbls of 8.5 ppg seawater. 03:30 - 04:00 0.50 KILL C DECOMP Shut down pump and monitor well. (No flow) 04:00 - 06:00 2.00 FISH P DECOMP Open annular and blow down choke, drain gas buster. CBU ~ 6 BPM 1367 psi pumped 65 bbls before we saw returns to surface. Resume milling (with care) on un-Inown obstruction at 9,647' - 9,651'. No progress made. 06:00 - 08:00 2.00 FISH P DECOMP Stop milling operations. Discuss plan forward with several Anch Engs. 08:00 - 09:30 1.50 FISH P DECOMP End further attemps to mill through problem area in the 7" Liner. Lay down Drill Pipe from 9,643' - 9,102'. Park Mill just above the 9 5/8" Packer. Shut down for some extra time for both crews to enjoy their Thanksgiving meal. 09:30 - 14:00 4.50 FISH P DECOMP Thanksgiving meal and safety moments for both Crews. Pit watcher, Tool Pusher, and WSL monitor constant hole fill. TIW Valve installed in Drill Pipe. Maintain boliers and fluid transfers with Vac Trucks. Fluid loss = 120 bbls/hr. 14:00 - 22:00 8.00 FISH P DECOMP Resume operations. PJSM. Continue to single down 4" Drill Pipe in Pipe Shed from 9102' to 827'. Fluid loss remains at 120 bbl/hr. Constant hole fill. 22:00 - 00:00 2.00 FISH P DECOMP UD BHA #2 Milling BHA From 827' to 100'. 11/28/2008 00:00 - 00:30 0.50 FISH P DECOMP Continue laying down BHA #2. Observed wear marks on shoulder of mill none on bottom. 00:30 - 01:30 1.00 FISH P DECOMP Clean and clear rig floor of Baker tools. 01:30 - 02:30 1.00 FISH P DECOMP Pull wear ring and hold PJSM for testing Annular and valve #5 on choke manifold. 02:30 - 05:30 3.00 FISH P DECOMP Tested valve #5 on choke manifold 250 psi low 4000 psi high 5 minutes each. Attempt to test annular with 4-1/2" donut test joint and pressure bleeding off, pull test plug and inspect Cameron service hand RILDS on test plug. Tested annular to 250 psi low and 3500 psi high for 5 minutes each. (good test) 05:30 - 08:30 3.00 BUNCO RUNCMP Rig up floor to handle 4-1/2" L-80 TC-II completion. Rig up Torque Turn Equipment. Perform final jewelry inspection. 08:30 - 16:30 8.00 BUNCO RREP RUNCMP Problems with TR valve (pressure regulator) on Koomey Unit. Attemppt to repair. Search for more parts or a replacement valve. Maintain constant hole fill. FL = 120 bbl. 16:30 - 18:00 1.50 BUNCO RUNCMP Repairs complete. Resume planned operations. Pick up com letion 'ewelry as follows: 9 5/8" x 5 1/2" Unique Overshot, 1 Joint 4 1/2" 12.6 Ib/ft L-8 TCII Tubing, X-Nlpple Assy w/RHCM, 9 5/8" x 4 1/2" Baker S-3 Packer, X-Nipple Assy. All connections below Packer were Baker-Loc'd. Start to single in with 4 1/2" 12.6 Ib/ft L-80 TCII Tubing from Pipe Shed. Used Jet Lube Seal pipe dope and torqued connections at 3,850 fUlbs using Torque Turn Services. 18:00 - 00:00 6.00 BUNCO RUNCMP Continue running 4 1/2" completion as designed. Have 124 joints in at midnight (5,390') 11/29/2008 00:00 - 04:00 4.00 BUNCO RUNCMP Continue running 4 1/2" completion as designed. PUW = 145K. SOW = 130K. Printetl: 12/18/2008 1:'L4:2/ F'M • BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: 12-33 Common Well Name: 12-33 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date II From - To Hours ~ Task Code NPT 11 /29/2008 04:00 - 05:00 1.00 05:00 - 06:00 1.00 06:00 - 10:00 4.00 10:00 - 12:30 2.50 12:30 - 14:00 1.50 RU 14:00 - 16:00 2.00 RU 16:00 - 17:00 17:00 - 18:00 18:00 - 20:00 20:00 - 00:00 11/30/2008 00:00 - 01:00 01:00 - 02:30 1.001 RUN 1.001 BOPSURP Spud Date: 1 /27/1989 Start: 11 /3/2008 End: 11 /30/2008 Rig Release: 11/30/2008 Rig Number: Phase Description of Operations RUNCMP Pick up Joint #213 and start to swallow 5 1/2" Tubing stump. Saw first set of pins shear. Did not see second set. No-Go on stump at expected depth. Re-tag to confirm. Lay down Joint # 213. Make up Tubing Hanger assembly. Land Tubing Hanger with Unique "No-Go" 3' above stump (Unique Overshot swallow stump = 10.84'). RILDS. Lay down landing joint. RUNCMP Rig up to circulate. Test lines at 4,000 psi. Spot Vac Trucks and R/U to #1 Pump. RUNCMP Reverse Circulate in 125 bbls of 120 deg SW followed by 500 bbls of 120 deg SW with Corrosion Inhibitor, 3 bpm at 230 psi. RUNCMP R/U Little Red to Circulating Manifold. PT lines to 4500 psi. Reverse Circulate in 125 bbls of 80 deg diesel at 2 bpm and 200 psi. Catch up to fluid level at 80 bbls away. Shut-in annulus and swap over to pump down tubing. Bullhead 30 bbls of diesel down tubing at 2 bpm and 100 psi. Required 10 bbls to catch fluid. RUNCMP Shut-in Tbg and Suck Back lines. Drop Ball and Rod, let fall for 10 mins. Bring on Little Red with diesel pumping at 1 bpm, caught fluid after -2 bbls. ressure Up to 3500 psi and hold f r 5 mins to set acker. Bee own pressure o 5QtT'p'~i T~- bleed off trapped air and pressure up to 4000 psi for tbg test. Pressure Test Tubin to 4000 si for 30 mins on chart - pod test. RUNCMP Blled Down Tbg to 1500 psi and shut -in. Swap over to pump down IA, bring on Little Red with diesel pumping at -2 bpm. Catch fluid after pumping 16 bbls. Pressure Test IA to 4000 si for 30 mins on chart - pod test. No pressure seen on A during Tbg or IA pressure tests. RUNCMP Bleed down IA and Tbg Pressures to zero. Suck back lines and rig down Little Red. Drain BOP Stack. RUNCMP Cameron Wellhead Tech set TWC in Wellhead. Pressure 2.00 BOPSU P RUNCMP Suck out BOP stack. Blow down lines. Nlpple down BOP stack and set back on stump. 4.00 WHSUR P RUNCMP Prep wellhead. Nlpple up Adaptor Flange. Test at 5,000 psi x 30 minutes. Good test. Nipple up Injection Tree. Test at 5000 psi. 1.00 WHSUR P RUNCMP Complete 5000 psi x 30 minute tree test. Good test. 1.50 WHSUR P RUNCMP. Pick up lubricator and test. Pull TWCV. Lay down same. Install back pressure valve. Install Jewelry on Tree. Secure Tree and cellar. Release Rig at 02:30 hrs. Nrmtea: iznwzuua i:za:~i rnn -.J Well History Well Date Summary 12-33 10/16/2008 ***CONT. JOB FROM 10/15/08 WSR***[pre rwo] PULLED 4 1/2" XX PLUG F~ROM~TT~ 9255' SLM. ***RDMO. LEFT ~11EC~SII~DRNED WELT~DEFF~ T`O DSO*** 12-33 10/25/2008 T/V0= 790/125/0+. Temp= SI. Monitor WHPs (pre Eline). T FL @ 2545' (59 bbls). IA FL @ 800' (35 bbls). SV,WV,CV=C. SSV,MV=O. IA,OA=OTG. NOVP. 12-33 10/27/2008 T/V0= 800/100/0 Assist E-line.( RWO prep.) Job postponed due to tubing obstruction. Fnal WHP= 800/100/0 12-33 10/27/2008 WELL SI ON ARRNAL. INITIAL T/V0= 800/125/0 RIH WTTFi 4-1/2" HES FASDRILL COMPO E PLUG AND SAT DOWN AT 368 ' RECOVERED SAMPLE OF-`SCHMO N TOOL STRING. JOB INCOMPLETE WELL LEFT SHUT IN, SSV OPEN, VALVES OPEN TO GAUGES, DSO NOTIFIED. FINAL T/VO = 800/125/0. 12-33 10/29/2008 ***WELL S/I ON ARRNAL*** (pre -rig) 5" x 4.5" XO ITFI 5.5" BRUSH & 4.5" GAUGE RING. RAN KJ, 4.5" BRUSH W/3.75" GAUGE RING, BRUSHED FROM 9177-9400'SLM. (TAR ET DEPTH FOR FASDRIL ~ 9350') '**LEFT WE1L S/I*** 12-33 10/29/2008 ***WELL SHUT-IN ON ARRNAL*** INITIAL T/VO 200/200/0. ELINE RU TO SET 4 1/2" HES FASDRILL THEN JET CUT TUBING. ***JOB CONTINUED 30-OCT-2008*** 12-33 10/29/2008 T/V0=800/120/20 Temp=S/I Assist Slickline w ith brush & flush (RWO prep) Pumped 235 bbls of 190*F diesel dow n Tbg w hile Slickline brushed. FWHPs=300/220/0. Slickline on w ell upon LRS departure. 12-33 10/30/2008 T/V0= 200/200/0. Temp= SI. Bleed IA and OA to 0 psi. IA FL near surface. Bled IAPfrom 200 psi to 4 psi in 2 hrs 45 min. Monitor for 30 min. TP, IAP, OAP remained unchanged. Fnal WHPs= 4/4/0. E line has control of valves. 12-33 10/30/2008 T/V0=140/200/20 Assist E line, CMIT TxIA PASSED to 4000 psi. (RWO prep) Pumped 3 bbls methanol followed by 46 bbls diesel down g. a ow n pressures ue to casing spool leak.***AWGRS continued by LRS 70*"* 12-33 10/30/2008 ***JOB CONTINUED FROM 29-OCT-2008*** ELINE SET 3.66" HES FASDRILL IN 4-1/2" TUBING AT 9350 FT. LRS MIT-T TO 1000 PSG FAIL - IA CKING, SEE L PU CMIT TO 4000 PSI, RING GASKET BETWEEN CASING HEAD AND TUBING HEAD LEAKING. DHD AND FMC TREE CREW REPAIR LEAKING RING GASKET. CONTINUED WITH CMIT TX1A TO 4000 PSI -PASS, SEE LRS PUMP REPORT. T/VO BLED BACK TO 50/50/0. RIH WTfH 4.15" JET CUTTER ***JOB CONTINUED 31-OCT-2008*** 12-33 10/30/2008 T/V0=0/0/0 Assist E Line, CMTT TxIA PASSED to 4000 psi. (RWO prep) Pumped 39.9 bbls diesel dow n Tbg to reach test pressure. T/I lost 80/80 psi in 1st 15 min and 40/40 psi in 2nd 15 min for a total loss of 120/120 psi in 30 nin. Bled dow n pressures. FWHPs=60/60/0. Annulus casing valves tagged and left open to gauges. E Line on w eil upon LRS departure. 12-33 10/30/2008 T/V0=0/0/0, Temp=Sl. PPPOT-IC (PASS), repair leaking ring gasket. Ring gasket leaking between Casing head and Tubing head. DHD bled WHPs to 0 psi. Opened sloted bleeder screw to verify 0 psi in test void. FMC tree crew torqued flange to spec. Removed internal check and installed external check in test port. RU to packing port and re-energized secondary Y seal w ith plastic (1 J stick). R-essured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 12-33 10/31/2008 ***JOB CONTINUED FROM 30-OCT-2008*** JET CUT 5-1/2" TUBING WITH 4.15" JETCUTTER AT 9237 FT, MIDDLE OF FIRST FULL JOINT A VE PA K INAL T = 200/80/0 ***JOB COMPLETE'** 12-33 11/4/2008 T/V0= 200/200/20 Temp= SI Circ-Out (RWO prep) MIRU, PJSM Standby for grease crew, PT surface line to 4500 psi. ***WSR Continued to 11-05-08*** Print Date: 12/18/2008 Page 1 of 3 Well Date Summary 12-33 11/5/2008 ***WSR Continued from 11-04-08*** Temp= SI Circ-Out, CMff TxIA PASSED to 4000 psi, MIT OA FAILED to 2000 psi. (RWO Prep) Pumped 5 bbls meth followed by 1126 bbls 110*F 1 % KCL and capped wit s iesel dow n Tbg taking returns up IA through hardline and casasco valve dow n flow line of w ell 12-35. Freeze protect hardline to 12-35 w ith 3 bbls meth. U-tube TxIA for 1 hr. Pressured up TxIA to 4000 psi w ith 8.2 bbls diesel for CMIT. T/IA lost 40/40 psi in 1st 15 min and 20/20 psi in 2nd 15 min for a total loss of 60/60 psi in 30 min test. Bled back 12 bbls diesel. Pressured up OA to 1700 psi w ith 16 bbls crude to attempt MITOA. Established LLR= 4 bpm @ 1700 psi for 10 bbls w ithout change (40 bbls total). Bled back 2 bbls crude .Final WHPs= Vac/Vac/Vac. Operator notified of valve positions: Swab, Wing, SSV= closed, Master= open, IA and OA open to gauges upon LRS departure. 12-33 11/6/2008 T/VO=SSV/VAC/VAC, Temp=Sl. PPPOT-T (PASS) . Pre RWO. PPPOT-T: External check installed. Stung into test port (0 psi). Functioned LDS (2.25"), all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Tested good 10-30-08 see AWGRS. Functioned LDS (2.50"), all moved freely. 12-33 11/8/2008 T/V0=0/0/0; Set 5-1 /8" FMC ISA BPV #538 thru tree for Doyon16 Re-rig; 1-2' ext. used, tagged @ 98"; ***Complete*** (Best/Fra er 12-33 11/11/2008 T/VO =SSV/80/0. Temp = SI. WHPs post OA load. BPV in hole. IA and OA FL @ surface. MI line is blinded. SV, WV, SSV, MV =Closed. IA, OA = OTG. NOVP. 12-33 11/12/2008 T/VO=SSV/130/0. Temp=Sl. Bleed IAPto 0 psi (PRE RWO). BPV set. Va FL @ surface. Bled IAPfrom 130 psi to 0 psi in 20 min, (all fluid). Bled back 46 gallons of diesel. Monitored for 30 min, IAP unchanged. Fnal WHPs=SSV/0/0. SV,WV,SSV, MV=Closed (Safed out). IA & OA=OTG. NOVP. 12-33 11/13/2008 T/VO =SSV/41/0. Temp = SI. Monitor WHPS post IA bleed. IAP increased 41 psi overnight. Bled to a bucket (all fluid). Fnal WHPs =SSV/0/0. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 12-33 11/19/2008 T/VO = BPS//230/0+. Temp = SI. Monitor WHPs (pre RWO). No AL. WAG. SV, WV, SSV, MV =closed. IA, OA = OTG. NOVP. 12-33 11/19/2008 T/V0= SSV/280/50. Temp SI. Bleed VaPto 0 psi. (pre rig). IA FL @ surface. OA FL near surface. Bled IAP from 280 psi to 0 psi in 35 rrin to a slop oil trailer (All liquid). Bled OAP from 50 psi to 0 psi in <1 min (All gas). Monitored for 1 hour. No change. Final WHPs=SSV/0/0. SV,WV,SSV,MV=posed. IA,OA= OTG. NOVP. 12-33 11/20/2008 T/V0=6PV/30/0+. Terre=Sl. Monitor WHP, bleed if needed (pre-RWO). No A/L. IAP increased 30 psi. Tie in crew still on w ell. SV, WV, SSV, MV=Closed. Va&OA=OTG. NOVP. 12-33 11/23/2008 T/V0=180/180/0. Pull 5" FMC IS-A BPV thru tree. Doyon 16 move on well 12-33 11/23/2008 T/VO = 0/0/0 Set 5-1/8" FMC ISA from rig floor w ith T-bar (Doyon 16) RKB=21.90. Pressure tested to 3500 from below ...pug ea a y. a with Iubricator.Set another 5-1/8" FMC ISA BPV thru tree, tag @ 108" pressure tested to 1000 PSI no pressure loss. 12-33 11/24/2008 T/V0=250/0/0. Pull 5" FMC IS-A BPS/ thru BOPE after Doyon 16 test. 12-33 11/25/2008 ***ASSIST DOYON 16*** R/U SLICKLINE #4516 CURRENTLY PoH W/ 6.00" LIB ***CONTINUE WSR ON 11-26-08*** 12-33 11/26/2008 ***CONTINUE WSR FROM 11-25-08**** (ASSIST DOYON 16) TAG TUBING STUB W/ 6.00" LIB @ 9144' SLM (IMPRESSION OF TUBING STUB), ***TURN OVER TO DOYON 1 ~ 12-33 11/30/2008 T/V0=0/0/0. Pull 4-1/16" CNV H TWC thru tree, post tree test. 1-2' ext used, tagged @ 104". No problems. 12-33 12/3/2008 T/V0=0/0/0; Pulled 4-1/16" CNV "H" BPS/ #145 thru tree Post Doyon 16; 1-2' ext. used, tagged @ 102"; ***Complete*** (Best/Fraker) 12-33 12/3!2008 ***WELL S/I ON ARRNAL*** (post rig) PULLED BALL & ROD AND 4 1/2" RHC PLUG BODY FROM 9071' SLM. ***CONT. J B N 1 ~768~P5'R~'~ Print Date: 12/18/2008 Page 2 of 3 Well Date Summary 12-33 12/4/2008 '**CONT JOB FROM 12/04/08 WSR*** (post rw o) RAN 3.625" CENT., T.EL, SAMPLE BAILER...UNABLE TO LOCATE TBG TAIL IN THE AREA OF 9282' ELMD. SD @ 9590' SLM, ABLE TO WORK THRU TO @ 9661' SLM..UNABLE TO WORK PAST. LOCATE WHAT APPEARS TO BE TBG TAIL @ 9210' SLM, INDICATING -71' OF PARTED TBG SETTING ON T RECOVERED SAMPLE OF WHAT APPEARS TO BE DRILLING MUD. RAN 3.78" CENT., 3.75" LIB TO OBSTRUCTION @ 9590' SLM...LIB SHOWS IMPRESSION OF WHAT APPEARS TO BE PARTED TBG. ***LEFT WELL S/I, TURNED WELL OVER TO DSO*** Print Date: 12/18/2008 Page 3 of 3 20 BBI gain on D-16 @ DS 12 -33i Page 1 of 1 Regg, James B (DOA) ~`~ t~`~~-o~~ From: Hinkel, Lee (ORBIS) [Lee.Hinkel@bp.com] ~ tt~~~~~~ Sent: Thursday, November 27, 2008 6:56 AM ~( To: Regg, James B (DOA); Willingham, James M; Rossberg, R Steven Subject: 20 BBI gain on D-16 @ DS 12 -33i At 0000 hrs on 11-27 driller was CBU and observed 20 bbl pit gain. Driller shut down pump and observed well flowing, he opened choke and closed annular. The well had 40 psi on DP and 110 psi on casing. Anchorage engineer, Jim Willingham, Day WSL and AOGCC on north slope were notified @ 0015 hrs on 11-27. Two CH2MHill trucks were on location 1) had 120 bbls and 1) had 290 bbls of 8.5 seawater. Called CH2MHill dispatch and requested 2 additional trucks with 8.5 ppg seawater. When additional fluid was on location we bull headed 955 bbls (1 1/2 hole volume) into well going down DP and annulus at 8 BPM. Monitored well for 30 minutes and opened annular. Pumped 65 bbls before returns to surface. Circulated bottoms up. Well is taking approximately 120 bbls per hour. We had just finished drilling the fasdrill out and well was taking 100 bbls per hour when flow was observed. When we get out of hole we will test annular and all assosiated valves used during bull head operations. Thanks, O'Neal Coyne WSL Doyon 16 11/28/2008 • • , 4 ~ ~ ~s f ~ ~ ~ ~ ' ~`` ^ ~ v ~ ~ .. F ~ ~, 'V d ~ ~ ~x I ~ ~~ ` + ~ a ~ SARAH PALIN GOV . ._ _.s ~ ~ j ~? i ~~ ~ ~~ ~ ~ , ERNOR - '-"""~"~~ ~~ ~ t7ras7 r 333 W 7th AVENUE S C011TSERQATIOrIT COl-II1IIS51O1~T ~ . , UITE 100 />NCHORAGE, ALASKA 99501-3539 // PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~~~~N~~ ~~~ ~ ~ Zd~B Anchorage, AK 99519-6612 - ~ p, d ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-33 Sundry Number: 308-310 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. Sincerely, ~~ Cathy P. Foerster Commissioner DATED this ~ ay of September, 2008 Encl. e ~~ pp t.:,. Save g r~ STATE OF ALASKA ~ ~' UG 2 9 ZOQB ~ ALA OIL AND GAS CONSERVATION COMMIS I N ` n~i ~ roo APPLICATION FOR SUNDRY APPROVAL ~=~ Gas Cons. Commis, 20 AAC 25.280 ' "`~•`_~ ~^e ~ 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 189-010 3. Address: ®Service- ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21909-00-00~ 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 12-33 Spacing Exception Required? ^ Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028330 ' 74.0'- Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9980 9231- 9933 9187 9366 N/A in L n th i MD ND ur Ila se ru tural n r 1 4 Surfa 7 ' 1 -3/8" 7 ' 0 ' 49 0 / 7 67 / 2230 In ermediate P i 4 ' 1 47 Liner 63 ' 7" 9344' - 997 ' 38' - 92 1 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): (Below Pluq) 9646' - 9807' (Below Pluq) 8918' - 9069' 5-1/2" x 4-1/2", 17# / 12.6# L-80 9378' Packers and SSSV Type: 9-5/8" x 5-1 /2" Baker SB-3A Packer; 7" x 4-1 /2" Brown 2-B Packers and SSSV MD (ft): 9265'; 9685 ; Pakker and 5-1/2" Cam Bal-O SSSV 2178' 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: September 15, 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 Hank Baca, 564-5444 Printed Nam David Reem Title Engineering Team Leader Prepared By NameMumber: Signature cj Phone 564-5743 Date g ~,~ ~$ Sondra Stewman, 564-x750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness `' ` ~~ l~, o ^ Plug Integrity ~OP Test ~Aechanical Integrity Test ^ Location Clearance ~~ ~ ~~~~ ' ~~~ Other: ~..~iJ -` ~ Subsequent Form Required: ~~ APPROVED BY s ~ ~~ ^~ A roved B : COMMISSIONER THE COMMISSION Date U Form 10-403 Revised /20 Submit In Duplicate ;~~ • • by c,,~~,, 12-33i Rig Workover (Injector tubing swap TxIA communicaton) Scope of Work: Remove 5.5" tubing and run 4.5" L-80 stacker packer completion. Engineer: Hank Baca MASP: 3360 psi Well Type: Injector Estimated Start Date: September 15th, 2008 S 1 Pull XX lu ~ 9366'. Drift for 'et cut/4.5" Fasdrill. E 3 Set Fasdrill C«~ 9350' & pressure test tubing to 1000 psi for 10 minutes. If tubing tests, Power Jet cut @ 9232'. Reference tubing tally 3/15/89. Cut desired to be midway down 1St full joint above acker. F 2 CMIT TxIA to 4000 si for 30 charted minutes. MIT OA to 2000 si for 30 charted minutes O 4 PPPOT-T, -IC, check all LDS. Prouosed Procedure 1. MIRU. ND tree. NU and test ROPE to 250 psi low/ 4000 psi high fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5.5" tubing to the cut C~1 9232'. 3. Dress 5.5" stub 4. Run 4-~h" L-80 completion with Baker S-3 packer. 5. Displace the IA to packer fluid and set the packer. 6. Test tubing and IA to 4000 psi. Freeze protect to 2,200' MD. 7. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. Circulate out freeze protection RDMO. TREE = MCEV OY GEN 4 WELLHEAD = MCEVOY ACTUATOR= AXELSON KB. ELEV = 74' BF. ELEV = KOP = 2500' Max Angle = 33 @ 6300' Datum MD = 9598' Datum TVD = 8800' SS 13-3/8" CSG, 68#, L-80/K-55, ID = 12.415" I 3573' Minimum ID = 3.725" @ 9710' 4-1/2" OTIS XN NO-GO NIPPLE 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 9285' TOP OF 4-1/2" TBG ~ 9285' TOP OF 7" LNR ~-i 9344' 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 9378' 9-518" CSG, 47#, L-80, ID = 8.681" 9643' TOP OF4-1/2"TBG 9685' 1 4-1/2" TBG, 12.6#, L80, .0152 bpf, ID = 3.958" 1 PERFORATION SUMMARY REF LOG: BHCS on 02/11/89 A NGLE AT TOP PERF: 21 @ 9642' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9642-9646 C 11/28/90 3-3/8" 8 9646-9661 C 06/03/89 3-3/8" 1 9740-9750 C 11/28/90 3-3/8" 3 9750-9756 C 11/28/90 3-3/8" 2 9762-9790 C 06/03/89 3-3/8" 2 9794-9807 C 06/03/89 PBTD 9933' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9979' TD 99$0' SAFETY NOTES: 12 -3 3 • 2178' 5-1/2" CAM BAL-O SSSV NIP, ID = 4.562" 9265' -~ 9-5/8" X 5-1 /2" BKR SB-3A PKR ID = 4.875" 9285' S-1/2" X 4-1/2" XO { 9366' 11 4-1/2" OTIS X NIP, ID = 3.813" 1 9366' 4-1/2" XX PLUG (12/15/07) 9378' 4-1/2" TUBING TAIL, ID = 4.00" 9282' - ~ MD TT LOGGED 10/26/89 9685' 7" X 4-1/2" BROWN 2-B PKR, ID = 4.00" 9710' 4-1/2" OTIS XN NO-GO NIP, ID = 3.725" 9774' 4-1/2" WLEG, ID = 4.00" 9721' EMLD TT LOGGm 10/26/89 DATE REV BY COMMBYfS DATE REV BY COMMENTS 03/15/89 ORIGINAL COMPLETION 12/17/00 SIS-SLT CONVERTED TO CANVAS 02/26/01 SIS-LG FINAL 10/07/01 RN/KAK CORRECTIONS 01/15/08 JLM/SV SET PLUG (12/15/07) PRUDHOE BAY UNff WELL: X12-33 PERMff' No: 189-010 API No: 50-029-21909-00 Sec. 18, TION, R15E 2459.39 FEL 2531.48 FNL BP Exploration (Alaska) TREE = MCEVOY GEN 4 WELLH D = MCEVOY ~ ~ ~ ~~ ~ ~I SA FEN NOTES: I ACTUATOR = AXELSON KB. ELEV = 74' PROPOSED BF. ELEV = KOP = 2500' Max Angle = 33 @ 6300' Datum MD = 9598' DatumND= 8800'SS 2000` 4.5" Otis X nipple, ID 3.813" 13-3/8" CSG, 68#, L-80/K-55, ID = 12.415" 3573' 4.5" Otis X nipple, ID 3.813" I a-1/2" TBG, 12.6#, L80, .0152 bpf, ID = 3.958" I 4.5" X 9.625" Baker S-3 Packer Minimum ID = 3.725" @ 9710' 4.5" Otis X nipple, ID 3.813" 4-1/2" OTIS XN NO-GO NIPPLE Unique Machine Overshot 9265' 9-5/8" X 5-1 /2" BKR SB-3A PKR, ID = 4.875" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 9285' ' 9285' 5-112" X 4-1/2" XO TOP OF 4-1/2" TBG 9285 TOP OF 7" LNR 9344' 9366' 4-1/2" OTIS X NIP, ID = 3.813" 9366' 4-1/2" XX PLUG (12/15/07) 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9378' 9378' 4-1/2" TUBNVG TAIL, 1D = 4.00" 9282' ELMD TT LOGGED 10/26/89 9-5/8" CSG, 47#, L-80, ID = 8.681" 9~' " ' TOP OF 4-1/2 TBG 9685 Jfi85' 7" X 4-1/2" BROWN 2-B PKR ID = 4.00" 4-1/2" OTIS XN NO-GO NIP, ID = 3.725" 9714' ~4-1/2" wLEG, ID = 4.00" 4-1/2" TBG, 12.6#, L80, .0152 bpf, ID = 3.958" 9714' 9721' EMLD TT LOGG® 10/26/89 PERFORATION SUMMARY REF LOG: BHCS on 02/11/89 ANGLE AT TOP PERF: 21 @ 9642' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9642-9646 C 11/28/90 3-3/8" 8 9646-9661 C 06/03/89 3-3/8" 1 9740-9750 C 11/28/90 3-3/8" 3 9750-9756 C 11/28/90 3-3/8" 2 9762-9790 C 06/03/89 3-3/8" 2 9794-9807 C 06/03/89 PBTO 9933' ( 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I I 9980' I DATE REV BY COMMBVTS DATE REV BY COMMENTS 03/15/89 ORIGINAL COMPLETION 12/17/00 SIS-SLT CONVERT® TO CANVAS 02/26/01 SIS-LG FINAL 10/07/01 RWKAK CORRECTIONS 01/15!08 JLM/SV SET PLUG (12/15/07) PRUDHOE BAY UNfT WELL: X12-33 PERMfT No: 189-010 API No: 50-029-21909-00 Sec. 18, TION, R15E 2459.39 FEL 2531.48 FNL BP F~cploration (Alaska) Hello Jim, Well 12-33 (PTO #1890100) failed an MITIA with a LLR of 2.0 bpm at 2200 psi on 01/18/07. The well has been shut-in and further diagnostic work will be performed. Recent events: > 03/31/05: Bled lAP to 0 psi, re-pressured to 240 psi in 2 days. > 04/17/05: MITIA Passed to 3000 psi > 01/18/07: MITIA Failed; LLR = 2.0 BPM @ 2200 psi Plan forward: 1. SL: Caliper 2. EL: Perform LOL 3. WIE: Eval for tubing patch &CAttED JAN 2 i 2007 A wellbore schematic and TIC plot have been included for reference. In addition, the MIT form is attached. «12-33 TIC Plot.ZIP» «12-33.pdf» «MIT PBU 12-33 01-18-07.xls» Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 12-33 no Plot.ZIP 12-33 TIO Plot. ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 lof2 1/19/2007 1:59 PM . . Content-Description: 12-33.pdf 12-33.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: MIT PBU 12-33 01-18-07.xls MIT PBU 12-33 01-18-07.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 Ji19/2007 1:59 PM TREE = II£EVOY GEN 4 W8..LHEAD = MCEVOY ACTU'I. TOR = AX8..S0N ¡ KB. ELEV = 74' BF. ELEV = KOP- Max Angle - DatumMD- Datu m TVO - 2500' 33 @ 6300' 9598' 8800' SS 13-3I8"CSG, 68#, L-80/K-55, 10= 12.415" I Minimum 10 = 3.725" @ 9710' 4-1/2" OTIS XN NO-GO NIPPLE 5-1/2" TBG, 17#, L-80, .0232 bpf, ID -4.892" TOP OF 4-1/2" TBG TOPOF 7" LNR H 9344' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 9378' 9-5/8" CSG. 47#, L-80, ID = 8.681" TOP OF 4-1/2" TBG H 9685' 4.1/2"TBG, 12.6#, L80, .0152 bpf,lD = 3.958" I 9714' PERFORATION SUMMARY REF LOG: BHCSon02/11/89 ANGLE AT TOP ÆRF: 21 @ 9642' Note: Refer to Production DB for historicai perf data SIZ E SPF INTERV AL Opn/Sqz DCI TE 3-3/8" 4 9642-9646 0 11/28190 3-3/8" 8 9646-9661 0 06/03/89 3-3/8" 1 9740-9750 0 11/28190 3-3/8" 3 9750-9756 0 11/28190 3-3/8" 2 9762-9790 0 06/03/89 3-3/8" 2 9794-9807 0 06/03/89 9933' 7" LNR, 29#, L-80, 0371 bpf, ID 6.184" 9979' 9980' DATE 03/15/89 12/17100 02/26/01 10/07/01 REV BY COMMENTS ORIGINAL COMPLETION SIS-SLT CONVERTED TO CANVAS SIS-LG RNAL RN/KAK CORRECTIONS DATE REV BY 12-33 . COI\iMENTS . I SAFETY NOTES 2178' -j 5-1/2" CA.M BAL-O SSSV NIP, ID = 4.562" 9265' - 9-5/8" X 5-1/2" BKR SB-3A PKR, ID = 4875" I 9285' 9366' -14-112" OTIS X NIP, 0 =3.813" I 9378' 4-1/2" TUBING TAIL, 10 - 4.00" 9282' H ELMD TT LOGGED 10/26/89 I 9685' - 7" X4-112" BROWN2-B PKR, 10 =4.00" I 9710' -14-1/2" OTIS XN NO-GO NIP, 10= 3.725" , 9714' - 4-1/2" WLEG, ID = 4.00" I 9721' H EMLD TT LOGGED 1 0/26/89 PRUDHOE BAY UNrr WELL 12-33 ÆRMTNo 189-010 API No 50-029-21909-00 Sec. 18, TION, R15E 2459.39 F8.. 2531.48 FNL BP Exploration (Alaska) . ~ . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO~ Mechanical Integrity Test , ",L-i\ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckensteìn@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us .. OPERA TOR: FIELD / UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: \\ \G\ \01 BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / DS 12 01/18/07 Andrea Hughes Packer Oepth Pretest Initial 15Min. 30 Min. Well 12-33 I Type Inj. I W TVO I 8,566' Tubing 325 325 IntervalL 0 P.T.D. 1890100 I Typetest I P Test psi! 3000 Casing 350 2,200 PIF P Notes: MIT-IA for AA request. LLR = 2 bpm. OA 0 0 .-. Weill I Type Inj. I I TVO I Tubing I I J Interval I. PTo.1 I Type test I I Test psi! Casing J PIFI. Notes: OA I Weill I Type Inj.1 I TVD I Tubing Interval I PT.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVO I Tubing Interval PTD.I I Type test I I Test psi Casing PIF Notes: OA Weill I Type Inj.¡ I TVO I Tubing Interval p.T.D.1 I Type test I I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M =: Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A :: Temperature Anomaly Survey D = Differentíal Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T:: Test during Workover 0= other (describe in notes) MIT "BU 12-33 01-18-07xI5 t ~9--(}Uì (// .:. ... (19.{ () 7 ') I ~e11 . . .... Tbg -11- IA -.10:- OA OOA --12=33-TlO'Plõf 4,000 Iii ['111\ 1 3,000 2,000 Jim and Bob, Attached are the missing MIT forms questioned in your emailo past due; (PTO 1890100 MITIA performed on 04/17/05 (?TO 20214~0) MITIA performed on 11/10/03 Z-33A (PTO 1890050 MITIA 05/09/03 12-30 (PTO 1831420) MITIA 12/04/04 2. MITs done; 12 23 (PTO 1 3 4 58 3 - 2 2 (?TO 182 77 [vlITOA 07/29/06 MITOA 08/26/06 Please lee me know If you need further information. ThanK you, ¿::\.:-'ldrea s Wel Office: Pager: ty Coordinator (907) 659-5102 907) 659-5100 x1l54 -----Original Message----- From; James Regg reaL 1 t : ' Sent: Thursday, January 11, 2007 1;17 PM To; NSU, AOW Well Integrity Engineer ect; Missing MITs !fle have eted a reVl2W of the MITs due December 2006) and due in October 1. MITs that appear to be past due *PBU 12-33* (PTD 1890100); MIT due 10/20/2 PSI-01* (PTD 2021450); MIT due 11/2/2006; FTD 189 rJ50); MIT due 10/19/2006; status 06; status - scatus - lnlec': 2. MITs done based on eecor int Commission ~ecord of the rCQ~' *PBU 12-23* PTD 184 580;; annual MIT02\ done 132 7 ; a~nual ITOA done 8/26/2 ~ tne past quarter Several lists below: ect * PEtJ ecting *PBU Z-33A* ty report) ; Y' .^" .L.L--J 7//29,/20 6 *PBTJ PTD ?lease complece MITs and provide miss reDor::s 13-22* Ja2uary 311 2 7 - 2':::::C. i:-':.'0 3. ITs durin,; Jar:uar--y 2 7 accordlng data: *M?U C-36* ?TD 193 10); due 1/17/2 7; status - inJect PTD PiG 198193 ; due 1/17/2 7; status 98179 dL2 1/ /2 7; st~cus e,::t lCg ; --t. Shut lTI wells apprcashing MIT anniversa I of2 * IVI PU F - 92* *:V1?U F-95* dace; l, 13 accep[ao~e 16/2007935 AiVl . . to defer testing these until they recommence injection: *PBU WB-06* (PTD 1982210); due 1/13/2007; status - 81 since 9/2003 *PBU PWDW2-1* (PTD 1760630); due 1/27/2007; status - 81 since 3/2003 Call if you need to discuss. Jim Regg AOGCC Content-Description: MIT PBU 12-30,33 12-04-04,xls MIT PBU 12-30,33 12-04-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU PSI-01 11-10-03 (2).xls MIT PBU PSI-0111-10-03 (2).xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU Z-33A 05-09-03.xls MIT PBU Z-33A 05-09-03.xls Content-Type: application/vnd,ms-excel Content-Encoding: base64 Content-Description: MIT PBU 12-23 07-29-06.xls MIT PBU 12-23 07-29-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 13-22 08-26-06.xls MIT PBU 13-22 08-26-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 lil6í2007 9:35 AM . . . v1 If:?...... '1/ . ./f Ci (f-i'q l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / OS-12 12/04/04 Joe Anders W Packer Depth TVD 8,509' Tubing o P o ,/' P Well PTD Notes: Well PTD. Notes: Well P.T.D. Notes: Test Details: AOGCC inspector Chuck Scheve declined witness. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUNey A = Temperature Anomaly SUNey 0= Oifferential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank MIT Report Form Revised: 06119102 MIT PBU 12-30.33 12-04-04-1 xis AIfASIiA. OIL AlQ) GAS CONSERVATION COMMISSION e FRANK H. MURKOWSKI, GOVERNOR Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 \lh<tO\O Re: Prudhoe Bay Field, 12-33 Sundry Number: 306-045 ~A~~~tFi[ (, Dear Ms. Julian: 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. Sincerely, Daniel T. Seamount Jr. ý1.... Commissioner DATED this? day of February, 2006 Encl. .. _L 1. Type of Request: Abandon U Suspend D Operational shutdown U Perforate U Waiver U ·"Other U Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developm ent 0 Exploratory 0 189-0100/ 3. Address: P.O. Box 196612 0 /S . ~ 6. API Number: Stratigraphic ervlce Anchorage, AK 99519-6612 50-029-21909-00-00 / 7. KB Elevation (ft): 9. Well Name and Number: 74 KB 12-33 ,/ 8. Property Designation: 10. Field/Pools(s): ADL-028330 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): rota I Depth TVD (ft): IEffective Depth MD (ft): Effective Depth TVD (ft): I Plugs (measured): IJUnk (measured): 9980 9230.85 9933 9186.93 None None Casing Length Size MD / TVD Burst Collapse Conductor 80 20" 91.5# H-40 33 . 113 33 113 1490 470 Surface 3541 13-3/8" 68# L -80 32 3573 32 3503 4930 2270 Production 9612 9-5/8" 47# L-80 31 9643 31 8916 6870 4760 Liner 635 7" 29# L-80 9344 9979 8638.46 9230 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9642 -9807 / 8914.75 - 9069.09 5-1/2" 17# / L-80 31 - 9285 4-1/2" 12.6# L-80 9285 - 9378 / 4-1/2" 12.6# L-80 9689 - 9714 Packers and SSSV Type: 5-1/2" Baker SB-3 Packer Packers and SSSV MD (ft): 9265 4-1/2" Brown 2-B Packer 9685 " 12. Attachments: Descriptive Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service ~ 14. Estimated Date for ~06 15. Well Status after proposed work: Commencing Operations: Oil 0 Gas 0 Plugged D Abandoned 0 (' 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ ~ WDSPL 0 Commission Representative: Prepared by Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jennifer Julian Printed Na<::) Jenni¡er Juljeq . Title Wells Engineer Signature 11 NlJ\/\ ¡ .... . \...J. I . Phone 564-5663 Date 2/3/2006 (7 (j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: :5)LP - 045 Plug Integrity 0 BOP Test D Mechanical Integrity Test [Ø"" Location Clearance D Other: MI.T "'Õu.i.~A . Subsequent Form Required: l c? - 4- D 't . RBDMS BFl FES 6 9 .2006 ,01V/ APPROVED BY 2(¡/~ Approved by. '~rr COMMISSIONER THE COMMISSION Date: v ,. / vrtr~-!J -ðJ, _ STATE OF ALASKA _ AL~ OIL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 w~'wtt4U1cEJJ FEB 0 7 7.006 Alaska Oil & Gas Cons. Commission Form 10-403 Revised 7/2005 ORIGINAL Submit in Duplicate '.. ,I «I I . .. ".__ e e To: J. Bixby/ D. Cismoski Well Operations Team Leader From: DeWayne R. Schnorr, Design Engineer Date: January 31,2006 Est. Cost: ~ lOR: injector Subject: 12-33; OA Cement DownsQueeze Procedure PBD12WL33-N Please downsqueeze the OA as described in the following procedure. This procedure . I d th f II . t Incu es e 0 oWing s eps: Step Type Procedure 1 DHD Depress OA FL w/ AL 2 F OA cement downsqueeze 3 F MIT OA cement downsqueeze 2400 after WOC. MIT IA. /' 4 WAV Write up Waiver for TxlA / 12-33 is a water injection well. Last injection rate was 6500 BWPD @ 181 psi on 01//29/2006. Well failed an MIT-OA (11/13/2005.) OA fluid level is at surface. MIT-IA _ passed to 3000 psi (04/17/2005.) MIT-OA failed on 11/13/2005 with a LLR of 2.8 bpm at 2400 psi. An OA downsqueeze is recommended so a waiver can be pursued. A waiver will require annual testing of the production casing as the primary barrier, (MITIA passed to 3000 psi on 04/17/2005) and surface casing as the secondary barrier surface casing. This program is designed to depress FL w/ AL to determine leak depth. Following the fluid depress, pump a column of cement from the shoe to approximately 500' above the shoe. The procedure includes the following major steps: 1. DHD Depress OA FL w/ AL. 2. DHD Shoot fluid levels and record WHP's. 3. DHD Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as required. OA Downsqueeze / MIT OA after waiting on cement. 4. 0 5. 0 If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (W), 274-0929 (H), or 240-8037 (C). cc: w/a: Well File e e JOB PLANNING DETAILS: Please contact Jennifer if FL was not depressed to shoe. 11/13/2005: MIT-OA failed with a LLR of 2.8 bpm at 2400 psi. Well has TxlA communication. OA= 13-3/8" 68# L-80/K-55 Note: one joint of K-55 (top joint of surf casing) - 3480 psi burst strength. Do not PT above 2780 psi. /' IA= 9-5/8" 47# L-80 Shoe at 3573' OAxIA Annular Capacity=.0597 bbls/ft Volume to shoe = 214 bbls 500' of cement = 30 bbls Displacement= 214 -5 (H20 spacer) - 30 (cement) - 5 (H20 flush) = 174 bbls Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 400 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 174 bbls at 30-60 degree F Crude: (volume needed to load OA) OS CW1 01: 1.Q bbls Arctic Set 1 Cement (15.7 ppg): 30 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsQueeze): DHD/FB: 1. Depress OA FL w/ AL. 2. Shoot FLs and record WHPs. 3. The day prior to the downsqueeze, bleed the OAP to +/- 200 psi. 4. Fluid Pack the OA with crude. CEMENTING OPERATIONS: FB Pumping 1. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 2. If well has IA x OA communication (well has not shown this communication to date), the IA pressure must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. Tie into the IA with a LRS or pump. e e 3. Flood lines with warm fresh water and pressure test lines to 3000 psi. 4. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent .........-- times during the displacement. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of OS CW1 01 surfactant (optional) c. -320 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) d. 5 bbls of fresh water spacer e. 30 barrels of 15.7 ppg Arctic Set 1 cement f. 5 bbls of fresh water flush g. 174 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 164 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 5. Shut down pumps and leave the well SI. Please DO NOT try to achieve a SQueeze or to build SQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. /' 6. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post SQueeze: FB: 7. Have a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. 8. MIT-OA to 2400 psi. Establish LLR if MIT-OA fails. / e e WELL SERVICE REPORT WELL JOB SCOPE 12-33 PRESSURE TEST (MAl NT) DATE DAILY WORK 11/13/2005 AC-MITOA COST CODE PLUS KEY PERSON PBD12WL33-M LRS-SSMITH MIN ID DEPTH 0" 0 FT UNIT LRS 46 DAY SUPV APPLEHANS NIGHT SUPV UNKNOWN TTL SIZE 0" DAILY SUMMARY T/I/O= (Pressure Test MIT OA Failed to to establish a LLR of 2.8 b m 2400 si. FWP= 460/400/150 LOG ENTRIES Init-> \46O~20 ~ TIME BPM I BBL,;-fLUID I TEMPJ~ IA -C COMMENTS_~ _ ____ ___ L~~~~~ -~Ir= - ~=~ ==~= -~- ~~ I -== ~~:~d~~k:~ S~~g river briéig~ for securit~c<?rt - == ~-~ I 07:25~~ ~ _ ~_ ~I I ~J ~~i~~ on location, DSO signed permit, MIRU to OA, PJSM, I 08:33 1 start diesel 40* 4601 320 hjOO Start down r08:36 ~ 1.5 ~ 3T ~- ~I "~460~ - ~320 350 Increase I 08:3~7 1.5~~-{q~ "~~ ';-~460T 320 100Õ- I ~~:~;J1.; C1: I ~::[ ~i:~~ I ~~~ L~~~~~:~::~~er:~kedropped from 2000 psi I ~~§~ 1- m- ~~l= :I-)~~~~ I-~~~~'~~::::-~¡f--- ----- ~~!iit=21~4f~·F--'r46§[~~l2±OOI :~:~hed aLLR=-L~b~m @~4Ö~~~ ~-- _~== Final 460 400 150 > JOB COSTS SERVICE COMPANY - SERVICE DAILY COST ~"",.,~_..,~,..,.~_." ,--,.".,--~-,."...,_.~. LITTLE RED WAREHOUSE TOTAL FIELD ESTIMATE: CUMUL TOTAL ~- ----~-$1:250 _.'-~~~"'~ .'.". $2'2"7 $1,477 FLUID SUMMARY 45 bbls diesel TREE = MCEVOY GEN 4 WELLHEAD = MCEVOY ACTUA TOR = AXELSON KB. ELEV = 74' BF ELEV K M D D 12-33 SAFETY NOTES = OP= 2500' ax Angle = 33 @ 6300' atum MD = 9598' atumTVD = 8800' SS €) 2178' I· 113-318" CSG, 68#, L-80/K-55, ID = 12.415" I 3573' -µ ~ Minimum ID = 3.725" @ 9710' 4-1/2" OTIS XN NO-GO NIPPLE :g ~ 9265' I· ..::::..::::. 15-1/2" TBG, 17#, L-80, .0232 bpf, ID =4.892" 9285' I 9285' 1· TOP OF 4-1/2" TBG 9285' 1 I TOP OF T' LNR H 9344' I . 9366' I· 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D =3.958" I 9378' I 9378' 1- J I 9282' I 9-5/8" CSG, 47#, L-80, ID = 8.681" 9643' J------:. lilt. I TOP OF 4-1/2" TBG H 9685' Ið 9685' I· ¡.:::::::. I I . I 9710' I· 4-1/2"TBG, 12.6#, L80,.0152 bpf, ID =3.958" I 9714' I I 9714' 1- [ I 9721' PERFORATION SUfvfv1ARY [ REF LOG: BI-CSon02/11/89 ANGLE AT TOP ÆRF: 21 @ 9642' I\bte: Refer to Production DB for historical perf data SIZE SPF INrERV AL Opn/Sqz DATE 3-3/8" 4 9642-9646 0 11/28190 3-3/8" 8 9646-9661 0 06/03/89 3-3/8" 1 9740-9750 0 11/28190 3-3/8" 3 9750-9756 0 11/28190 3-3/8" 2 9762-9790 0 06/03/89 3-3/8" 2 9794-9807 0 06/03/89 IFBTDI 9933' I T' LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9979' I ~ 9980' --15-1/2" CA M BAL-O SSSV NIP, ID = 4.562" -19-5/8" X 5-1/2" BKR SB-3A PKR, ID = 4.875" I --15-1/2" X 4-1/2" XO I --14-1/2" OTIS X NIP, D =3.813" I -14-1/2" TUBING TAIL, ID= 4.00" I --I ELMD TT LOGGED 10/26/89 I -1 T' X 4-1/2" BROWN 2-B PKR, ID = 4.00" I -14-1/2" OTIS XN NO-GO NIP, ID= 3.725" I --14-1/2" WLEG, D= 4.00" I H 8v1LD TT LOGGED 10/26/89 DATE 03/15/89 12/17/00 02/26/01 10/07/01 REV BY COMMENlS ORIGINAL COMPLETION SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL RN/KAK CORRECTIONS DATE RBI BY CO fvfv1 ENTS PRUa-iOE BAY UNIT" WELL: 12-33 ÆRMlTNo: 189-010 APII\b: 50-029-21909-00 Sec. 18, TION, R15E 2459.39 FEL 2531.48 FNL BP Exploration (Alaska) Injector 12-33 (PTD 1890100) Slow TxIA comm ) ) Subject: Injector 12-33 (PTD 1890100) Slow TxIA comm From: "Anders, Joe L" <anders22@BP.com> I~"" 0 10 Date: Sat, 09 Apr 2005 15:24:37 -0800 \I To':: "AOGCC - Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC - Winton Aubert (E~mail)" <winton _aubert@admin.state.ak.us> CC: "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "N~U, ADW .WeU Integrity Engineer" <NSUADWW ellIntegrityEngineer@BP.com>, "Reeves, D<.1naldF" <ReevesDf@BP.com>, "Dube, AnnaT" <Anna.Dube@BP.com>, "GPB, FSl DS Ops Le~d" <GPBFSIDSOpsLead@BP.com>, "GPB, FSl/SIP/STP AreaMgr" <GPBFSITL@BP.com>, "Gerik, B<;>b G (PRA)" <GerikBG@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Engel, Hahy R" <EngeIHR@BP.com> Hello all. Well 12-33 (PTO #1890100) appears to have slow TxlA communication. The IA was bled from 260 psi to o psi on 3/31/05 and repressured to the tubing pressure of 240 psi in 2 days. Recent events: > 12/04/04: MITIA Passed to 2250 psi > 03/31/05: Bled lAP to 0 psi, re-pressured to tubing pressure of 240 psi in 2 days. Current plan is to conduct an MITIA and evaluate for an Administrative Action. Attached is a wellbore schematic, please call with any questions. «12-33.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom Content-Description: 12-33.pdf Content-Type: application/octet-stream Content-Encoding: base64 :;,;;c· ~II ~i,·I"U¡¡::r\ ',n '"': "" ~. ("1[1'"- ,~ ~/.r-1n ,niJ~" c.i h ¡~ ¡~ ".: ,. / 1 P·.·.I t...... ....'" c...~ 0." ....... '- 1 of 1 4/13/2005 2:45 PM ') TREE = Iv1CEVOY GEN 4 WB..LHEAD = IVicEVÖY ACTUA. TOR = AXa.SON KB. ELEV = 74' BF. ELEV = KOP= ïviaX..ÄiïiiJë··;.... 'öäfuï:ritv1D =" ö"äfÚn:ï TVÖ; . 2500' ....3S·..@)·"6"sÖ·Öi . ... . 9598;" "8"800' s's 113-3/8" CSG, 68#, L-80/K-55, ID = 12.415" l-i 3573' Minimum 10 = 3.725" @ 9710' 4-1/2" OTIS XN NO-GO NIPPLE 15-1/2" TBG, 17#, L-80, .0232 bpf, ID =4.892" - ITOPOF 4-1/2" lEG - 9285' 9285' ITOP OF 7" LNR l-i 9344' 14-1/2" 1BG, 12.6#, L-80, .0152 bpf, D = 3.958" 1-1 9378' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" H 1 TOP OF 4-1/2" lEG l-i 9643' 9685' 14-1/2" TBG, 12.6#, L80, .0152 bpf, ID = 3.958" 1--1 9714' PERFORATION SUMv1ARY REF LOG: BHCS on 02/11/89 ANGLE AT TOP ÆRF: 21 @ 9642' t>bte: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz 06. TE 3-3/8" 4 9642-9646 0 11/28/90 3-3/8" 8 9646-9661 0 06103/89 3-3/8" 1 9740-9750 0 11/28/90 3-3/8" 3 9750-9756 0 11/28/90 3-3/8" 2 9762-9790 0 06103/89 3-3/8" 2 9794-9807 0 06103/89 I AnD H 9933' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 9979' ~ 9980' DATE 03/15/89 12/17/00 02/26/01 10/07/01 REV BY COMWENTS ORIGINAL OOrvPLETlON SIS-SL T 00 NVERTEDTO CANVAS SIS-LG ANAL RN/KA K CORRECTIONS 12-33 - ~ ") I SAFETY NOTES 2178' 1-15-1/2" CAM BAL-O SSSV NIp, ID = 4.562" ~ z \ z--..i 9265' 1-19-5/8" x 5-1/2" BKRSB-3A PKR, ID =4.875" 1 ! 1 9285' 1-15-1/2" X4-1/2"XO 1 11 I l ~ ~ Oã. Z5: :g: l ~ ~ 11 I .. ~ I DATE RBI BY CO Mv1 B>.ITS 9366' 9378' 9282' 9685' 1--14-1/2" OTIS X NIP, D = 3.813" 1 1-14-1/2" TUB ING TA IL, ID = 4.00" 1 1--1 ELMD TT LOGGED 10/26/89 1 1-17" X 4-1/2" BROWN 2-B PKR, ID = 4.00" 1 9710' 1-14-1/2" OTIS XN NO-GO NIP, ID = 3.725" 1 9714' 1--14-1/2" WLEG, ID= 4.00" 1 9721' H BVlLD TT LOGGED 10/26/89 PRUŒiOE BA Y UNrr WELL: 12-33 ÆRMTNo: 189-010 API No: 50-029-21909-00 Sec. 18, TION, R15E 2459.39 FB.. 2531.48 FNL BP Exploration (Alaska) ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test } Z, (i'" ¡ bit ~e..-~ -q Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us \~~¥'~t() OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU /OS-12 12/04/04 Joe Anders Packer Depth Pretest Initial 15 Min. 30 Min. Well 12-30 Type Inj. WAG TVD 8,509' Tubing 600 600 600 600 Interval P.T.D. 1881420 Type test P Test psi 4,000 Casing 420 4,000 3,980 3,980 P/F Notes: MITIA to 4000 psi pre-MI swap. This is the second test, first test IA lost 100/60, so it was repressured and repeated. 0 P /' Well 12-33 Type Inj. WAG TVD 8,566' Tubing 480 480 480 480 Interval 0 / P.T.D. 1890100 Type test P Test psi 2,250 Casing 300 2,250 2,200 2,180 P/F P Notes: MITIA to evaluate high IA pressure. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Typelnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: AOGCC inspector Chuck Scheve declined witness. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) Notes: If the test was not AOGCC witnessed,leave the "AOGCC REP:" box blank. SC/-\NNEr' DE C 2 1. ZODt MIT Report Form Revised: 06/19/02 MIT PBU 12-30,33 12-04-04.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor /,~,~ DATE: October 20. 2002 Chairman ~~/~, SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BP× P.I. Supervisor ~~/~ \O!'~'/ DS12 PBU FROM: Chuck Scheve Prudhoe Bay Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 12-19 I Typelnj. I S J T.V.D. J 8403 I Tubing 11850 J 1850 I 1050 J 1850 J lntervalI 4 P.T.D.I 182-198 Type testI P I TestpsiI 2101 I CasingI 250 I 23001 23001 23001 P/FI P Notes: WoIIJ 12-33 I Type,nj.J S I T.V.D. 18450 J Tubing 11600 J1600 J1600 J lntervalI 4 P.T.D.I 189-010 ITypetestJ P ITestpsil 2115 ICasingI 100 I 22501 22501 2250l P/F I P Notes: WellI P.T.D.I Notes: P.T.D.I Notes: WellI P.T.D.I Notes: Type Inj. Type test Type Inj. Type test IType I nj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 12 and witnessed the 4-year MIT on wells 12-19 and 12-33. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all both wells demonstrating good mechanical integrity. M.I.T.'s performed: _2 Attachments: Number of Failures: 0 Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. MIT PBU DS 12 10-20-02 CS.xls 10/25/2002 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 P C:LORlhMFILM.DOC E E L E W A T E R IA L U N D ER THIS MARKER i i --~ STATE Of ALASKA ALASKA C,_ AND GAS CONSERVATION CObi,,,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X~ Plugging Perforate ~ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 169' FSL, 692' FEL, Sec 18, T10N, R15E, UM. At top of productive interval 2478' FNL, 2386' FEL, Sec 19, T10N, R15E, UM. At effective depth 2522' FNL, 2438' FEL, Sec 19, T10N, R15E, UM. At total depth 2533' FNL, 2451' FEL, Sec 19, T10N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 74' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-33i 9. Permit number/approval number 89-10 10. APl number 50 - 029-21909 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Sudace 9980 feet 9231 feet Production Liner Plugs(measured) PBTD Tagged @ 9883' MD (8/4/96). 9883 feet 9111 feet Junk(measured) Length Size Cemented Measured depth True vertical depth 80' 20" 2150# Poleset 110' 110' 3539' 13-3/8" 2000 Sx CS III, 600 Sx CI G, 3573' 3503' & Top Job: 396 Sx CS 9611' 9-5/8" 500 Sx Cl G 9643' 8915' 635' 7" 300 Sx Cl G 9979' 9231' Perforation depth: measured 9642 - 9661'; 9740 - 9756'; 9762 - 9790'; 9794 - 9807' true vertical 8841 - 8858'; 8932 - 8947'; 8953 - 8979'; 8983 - 8995' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 9285' MD; 4-1/2", 12.64t, L-80, Tbg @ 9378' MD; 4-1/2", 12.64¢, L-80, Tbg @ 9685 - 9714' MD. Packers and SSSV (type and measured depth) Baker SB-3A Packer @ 10790' MD; Brown 2-B Packe ~;~2!'~;~ar~c(~.~aI-O SSSV @ 2189' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Avera0e Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 52OO 14181 Tubing Pressure 3540 3500 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil__ Gas__ Suspended m Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~ '~. ~ Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 cc: JWP. SUBMIT IN DUPLI(~ATE 12-33i DESCRIPTION OF WORK COMPLETED DIESEL/XYLENE PERFORATION WASH & SQUEEZE 8/1/96: RIH & tagged PBTD at 9773' MD. 8/2/96: MIRU CTU & PT equipment. RIH w/CT nozzle jet washing down tubing w/317 bbls 1% KCI Water, then pumped 80 bbls biozan to jet a fill cleanout to 9850' MD. Swept biozan from the well circulating 1% KCl Water, then swapped to reciprocating 60% Diesel/40% Xylene across the perforation intervals located at: 9642 - 9661' MD (Sag) 9740 - 9756' MD (Z4) 9762- 9790' MD (Z4) 9794 - 9807' MD (Z4) Ref. Log: BHCS 2/11/89. Washed 50 bbls of 60% Diesel/40% Xylene across the perfs, then shut in the well & squeezed the fluids into the formation w/1200 max whp. Opened choke & jetted OOH w/1% KCl. RD. 8/4/96: RIH & tagged PBTD at 9883' MD. Returned the well to miscible gas injection & obtained a valid injection rate. STATE OF ALASKA ALASKA ~"~' AND GAS CONSERVATION CC-'~"~lISSlOl~ ~ i {~A 1. REPORT SUNDRY WELL OPF_.rIATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 169' FSL, 692' FEL, Sec 18, T10N, R15E, UM At top of productive interval 2478' FNL, 2386' FEL, Sec 19, T10N, R15E, UM At effective depth 2522' FNL, 2438' FEL, Sec 19, T10N, R15E, UM At total depth 2533' FNL, 2451' FEL, Sec 19, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service X 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-33 9. Permit number/approval number 89-10/91-291 10. APl number 50 - 029-21909 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9980 feet Plugs(measured) true vertical 9231 feet Effective depth: measured 9933 feet true vertical 9187 feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2150 # Poleset 110' 110' Sudace 3539' 13-3/8" 2o0o sx cs iii & 600 sx CL'G'- Top jcl3 w/396 sx CS 3573' 3503' Production 9611' 9-5/8" 500 sx CI 'G' 9643' 8915' Liner 635' 7" 300 sx CL 'G' 9979' 9231' 13. Stimulation or cement squeeze summary 14. Perforation depth: measured 9642-9661'; 9740-9756'; 9762-9790'; 9794-9807' true vertical 8841-8858'; 8932-8947'; 8953-8979'; 8983-8995' Tubing (size, grade, and measured depth) 5-1/2", L-80, PCT w/tail @ 9714' md Packers and SSSV (type and measured depth) Baker SB-3A pkr @ 10790' md, Brown '2B' pkr @ 11242' md, Camco BaI-O SSSV @ 2189' md REC"" EiV Lb/ Intervals treated(measured) MAY 1,5 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. C0r~t~ss~t0tl Representative Daily Average Production or Injection Data, Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure 5604 6347 Tubing Pressure 1000 psi 2181 psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas..__ Suspended ~ Service Injector 17. I hereby certify that the foregoin,gj~ true and correct to the best of my knowledge. Signed ~'~'~(.... 0"'.~/~ Title Senior OperationsEngineer Form 10-404 Rev 06/15/88 ~' CC: S. Wallace/DS Engr/J. W. Peirce Date ~'/~,?/~ ~._---~ SUBMIT IN DUPLICATE 6. Datum of elevation(DF or KB) 74' RKB feet Daily Report of Operations DS 12-33 12/2/91 Switched from SWI to MI injection. WAG conversion complete. RECEIVED I~AY 1 5 Alaska Oil & Gas Cons, commtSs~o~ Anchorage STATE OF ALASKA D ~'1 ~ [ 0 t{ i G I N .~GK/~.~-~.,L AND GAS CONSERVATION CP" MISSION Pull tubing Alter casing ~ Repair well ~== Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 9951O-O36O 4. Location of well at surface 169' FSL, 692 FEL, Sec. 18, T1 ON, R15E, UM At top of productive interval 2478' FNL, 2386' FEL, Sec. 19, T10N, R15E, UM At effective depth 2522' FNL, 2438' FEL, Sec. 19, T10N, R15E, UM At total depth 2533' FNL, 2451' FEL, Sec. 19, T10N, R15E, UM 5. Type of Well Development ---. Exploratory Stratigraphic Service × ' 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-33 9. Permit number/approval number 89-10 10. APl number 50 - 029-21909 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 9980' MD feet Plugs(measured) None true vertical 9231' TVD feet Effective depth: measured 9933' MD feet true vertical 9187' TVD feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 21504t Poleset 110' MD' 110' TVD Sudace 3539' 13-3/8" 2000 sx CS III & 3573' MD 3503' TVD 600 sx Class G - Top job w/396 sx CS 1 Intermediate 9611' 9-5/8" 500 sx Class G 9643' MD 8915' TVD Production 635' 7" 300 sx Class G 9344'-9979' MD e639'-9231' TVD Perforation depth: measured 9642-9661'; 9740-9756'; 9762-9790'; 9794-9807' true vertical 8841-8858'; 8932-8947'; 8953-8979'; 8983-8995' Tubing (size, grade, and measured depth) 5 1/2" L-80 tbg 5 1/2" x 4 1/2" x over 9285', 4 1/2" tbg tail 9721' Packers and SSSV (type and measured depth) Baker 'SB-3A' pkr @ 9265', Brown '2B' pkr @ 9685' & Camco 'Bal-0' SSSV @ 2178' 13. Stimulation or cement squeeze sUmmary _J~ ~C ~ i V ~. D 14. Intervals treated(measured) Treatment description including volumes used and final pressure ~la~lm oil & Gas Cons. Reoresentative Daily Averaoe Produ~ion or Ini~ion Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2200 -- 600 Subsequent to operation 2450 -- 400 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil..._ Gas._. Suspended_._ Service Injector 17. I hereby certify that the foregoing~true and correct to the best of my knowledge. Si~ned ~/~<-'~(--~ ~.~ . ~ Title Form 10-404 Rev 06/15/88 SW/JWP/DS Engr SUBMIT IN DUPLICATE Perforating Well 12-33 Summary of Operations 11/28/90 MIRU. PT BOPS to 3000#. RIH w/gun #1. Perf 9740-9756' MD. POOH. RIH w/gun #2. Perf 9642-9661' MD. POOH RDL. Return well to injection. (All depths reference 2/11/89 BHCS.) RECEIVED STATE OF ALASKA ' ALASKA LAND GAS CONSERVATION CC'-"JISSIO~ APPLICATION FOR SUNDRY APPROVAL G I N 1. Type of Request: Abandon. ,,, Suspend Operation shutdown Alter casing Repair well Plugging , Change approved' program Pull tubing Re-enter suspended well , Time extension Stimulate Vadance Perforate 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service , X, ~ 4. Location of well at surface 169' FSL, 692' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2478' FNL, 2386' FEL, Sec. 19, T10N, R15E, UM At effective depth 2522' FNL, 2438' FEL, Sec. 19, T10N, R15E, UM At total depth 2533' FNL, 2451' FEL, Sec. 19, T10N, R15E, UM Other X 6. Datum of elevation(DF or KB) 74' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-33i 9. Permit number 89-10 10. APl number 50 - 029-21909 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9980 feet Plugs(measured) true vertical 9231 feet Effective depth: measured 9933 feet true vertical 9187 feet Junk(measured) None Casing Length Size Cemented Conductor 80' 20" 2150 # Poleset Su dace 3539' 13-3/8" ~ooo sx CS III & 600 s. CL 'G'- Top job w/396 sx CS I Measured depth True vertical depth 110' 110' 3573' 35O3' Production 9611' 9-5/8" 500 sx CI 'G' 9643' 8915' Liner 635' 7" 300 sx CI 'G' 9979' 9231' Perforation depth: measured 9642'-9661 ';9740'-9756';9762'-9790';9794'-9807' true vertical 8841 '-8858';8932'-8947';8953'-8979';8983'-8995' Tubing (size, grade, and measured depth) 5-1/2",L-80,PCT w/tail @ 9714'md Packers and SSSV (type and measured depth) Baker SB-3A pkr @ 10790'md, Brown '2B' pkr @ 11242'md,Camco BaI-O ssSv @ 2189'md 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation September 1991 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 15. Status of well classification as: Gas Suspended Injector Title Sr. Area Operations Engineer FOR COMMIRRION HRI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity.,, BOP Test Location clearance Mechanical Integrity Test ,, Subsequent form required 10- Approved by order of the Commissioner ORK:i~NAL SIGNED BY RUSSELL A. DOUGLASS Date Form 10-403 Rev 06/15/88 c: SW SUBMIT IN TRIPLICATE DS 12-33i Summary of Proposed Operations API 50-029-21909-00 Permit # 84-10 Conversion from Seawater/Produced Water Injection to Water- Alternating-Gas Injection Service 1) Test surface flowline and valves. 2) Commence Miscible Gas, Alternating with Water on or about October 15, 1991. Note: This well is part of the planned expansion of the Prudhoe Bay Miscible Gas Project (PBMGP). Mechanical Integrity Test of tubing/casing annulus passed and witnessed by AOGCC on 7 / 17 / 91. . ARCO ALASKA, INC. I='.0. BOX ~00360 ANCHORAGE~ ALASKA F,:Ii:'FEF(ENCE' ARCO CASED HOLE FINAI_S 2-2 4-~ 2-9~ COLLAR/F'ERF RUN ~ , "2-~ S S-25-9~ F'I:'(ODUC'FION RUN ~ , 3-5 4-2-9i TBG CUTI'ER I:<UN t , 4-.i .,"z-'~'~-..ot~. . FKDD PROFILE/PITS RUN i, 4-6 3-.24-.9i TEHF'ERAI'UF~E RUN i , 4-24 ~24.-.9t STATIC TENF:'ERATUF~E RUN t, 4--35 3--2t-9i F'II'S RUN t, o 3 4-7-9 PACI, EK' ',' .... ' , P O ,uc'rzo ~-'47 3529-9i. GAMHA/CCL I:~UN i -- 9-48 4-5-9i COLLAR/F:'EI:~'. F" R~N i i2-22 4-i-9i COLI_AR/F'ERF RUN i, g.~ 2-~i ~-2i-9t INJECTION RUN i, I~J 2'-3~ 3-~i--oi INJECI'ION RUN i i 3-98 3"2~-9t FL. tJID I.D. RL]N i , i 4.-i 6 3-i 8-9i F'RODUCTION RUN i , t5-5 2-27-9t PITS RUN i, i ~- ~ .~_ .~ ., .. ~ .=8-.9i FERF BREAKDOWN RUN i, i 6-6 4-i i-gt COLLAR/F'ERF RUN i , 5" .5" 2"&5" .5" 5' ,,,, 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" F:' I... E A S E ~' I G N A N I) R E T U R N T I-'1E A T T A C I..I E D "'~ "" ,., C C. F. ~ A $' R E C E I P"i' 0 I::- I.:, A T A I-?FCI.-':'IVED BY _~__.~ HAVE A NICE DAY! SHARON WILSON A'FO.- i .529 A F' P R 0 V Iii: D ~.. "~ I"RANS:,$ 9 i A i' L. A ,.':,,' C A [i C 0 A T L.. A,S' CAMCO CAMCO C A l,i C 0 C A bi C 0 A'I'LAS I"l t:;:.S' ATI_AS A'T'I_A,S' CAi'iCO C A i',l C 0 HRS, CAMCO H F;.'. $ I-.IRS ~..', IL. AS D I ,~ T R :1: B U l' :1:0 N · "' C F: N T R A !.. I:: t L E S, '"' ~" · ,- ... F:' !-I I I.. L I F:' -,. C H E V R 0 N F'B W E I..i.. I::' I I... E..%' g & I'i R & D · ,,.'"' E: X T E N .S' I 0 N E X F:' I... [) R A l" I 0 N .,.'"' B F:',..~' :~ E X X 0 N '"' · ,- ,~.; 1' A T I.::.: 0 F: A L,'.-h,S' I< A M A R A 1' i"10 N 'l" I."i: X A C 0 · ,.'"' l'i 0 B I L * 1'1"1E C 0 R R E C 1' E D A I::' ARCO Alaska, Inc. Post Office ,.. _,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 4, 1991 Mr. L. Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Revised State reports Dear Mr. Chatterton' Please note the highlighted correction on the attached reports and make these corrections on any reports you have which carry these errors. If you have any questions please feel free to call me at 263- 4618. S~¢~rely, Engineering Aide DW Attachments cc: File W4-3 Binder Distribution .RECEIVED ARCO Alaska, [nc, is a Subsidiary of AtlanticRichfieldCompany ' " STATE OF ALASKA AL,,oKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well *R_._EVISION* ~'" INJECTOR OIL ~ GAS [] SUSPENDED F'-] ABANDONED D SERVICE F~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-10 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21909 4 Location of well at surface 9 Unit or Lease Name 169' FSL, 692' FEL, SEC 18, T10N, R15E UM PRUDHOE BAY UNIT At Top Producing Interval 10 Well Number 2478' FNL, 2386' FEL, SEC 19, T10N, R15E UM DS 12-33 At Total Depth i'i Field and Pool 2533'FNL, 2451'FEL, SEC 19, T10N, R15E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 74'I ADL 28330 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 01/27/89. 02/10/89. 06/03/89*I N/A feet M SLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 9980' MD/9231'TVD 9933' MD/9187' TVD YES ~l NO ~I 2189' feet MD 1900' (approx) 22 Type Electric or Other Logs Run DIL/GR/CAL, FMT/GR, DIL/BHCS/SP/GR, GR/CNIJZ-DEN/CAL, CBL/CEI_/GR/CCL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 SURF 110' 30" 2150# POLESET 13-3/8" 72.0/68.0# L-8O/K-55 SURF 3573' 17-1/2" 2000 SX CS III & 600 SX CLASS G TOP JOB W/396 SX CS I 9-5/8" 47.0# L-80 SURF 9643' 12-1/4" 500 SX CLASS G 7" 29.0# L-80 9344' 9979' 8-1/2" 300 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 9714' 10790' & 11242' 9646'-966 l'MD/8918'-8932'TVD W/4 SPF, 120° PHASING 9762'-9790'MD/9027'-9053'TVD W/2 SPF, 120° PHASING i26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 9794'-9807'MD/9056'-9067'TVD W/2 SPF, 120° PHASING DEPTH INTERVAL IMD) AMOUNT & KIND OF MATERIAL USED N/A 27 N/A PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATF 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. NONE Submit c°re chip~ E ~ E I V ED FEB - 6 1 91 .i~las~ 0il & Gas Cons. *NOTE: DRILLED 2/14/89. TUBING RUN 3/16/89. PERFORATED WELL 6/3/89. ~'J~Jl.~J'~. ~. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 9738' 9004' HOT 9807' 9069' ©WC 9846' 9105' NONE 31. LIST OF ATTACHMENTS NONE 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~l/~/~.LZ/~ Title DRILLING ANALYST Date '~-4-~'I 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 pedinent 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- lng 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 ARCO ALAS~K A F'~ O, BOX ANCHOR'A(;E, AL.A,.~K A 995J I:;: E F: I:Z I=(E N C E ' A I:;: C 0 C A ;'.':,' lie D H 0 L E F: I N A L S' 4 .... 24 · ~ ~ '"' 3- 90 F' E F;,' F F,' [il C 0 R D 4 .... ',! 2. · ~ I .... 9"" 9 ~-) F:' R 0 D l::' l:;,' 0 F' ill L E / F:' ill TS 6 .... ~ 4. ~ 0 .... 2/,-' 9 () F:' Ii:. R F:' l:~'. [il C 0 R D ~i .... 4- ~ .... i~ .... ~;:l(~ F"IT.S' i i --6 ~ 9-. t ':2 .... 9,'?> THI)--BCJI=(AX t t .--I t~ t t '-t 2'--9() F']:T$ i i .... i i' t i '-t,..."~-'°'"'", ,, 'I'BG CC}L.L. AF;,' t 2 "- 2 ' i t "" 2 6 '- 9 £) F' IF:: R F' ~,.) · ~.), ~') ..... , .. 'i ~..."- 1 -. t,.. .... 2{-..on, ,, COL. LAF~/F:'E.i",F'.. "~ ' - 2 8 9 i ~'..'-'.3 ~'5 i i '" (~; F:'li:' F;,' f:' i 4- 2' i i .... i 4 '-' 9 (~ F:'R 0 I) F' R [] F I I... E i 4 .... i (>, i i '"' 9'-' 9 ~.') I... t:=': A K I> Iii: T E C'i" I 0 N i 4 .... i (:'. i i .... "? .... ?'a TBfi. C;OL.L..Ai:;: i 4 ..... :3 3, i i .... i 4 "" 9 ¢~ ['.'- 0 I...I... A F;,' / [:-; F: / C C I... t '.!:,': .... i 6 ' i t .... i 4 .... ':;;'(~ F:' ii!: I:;: F F.:E:C (:'.~F.'.i) i '.5 .... 2 i · i i .... '3 .... ?.";." l::'li.:. F.: F:' i ':~"- '~ i' i i .... '?-"':?":'; F' ]: i'.S'/' T E: H F' .... ,C. ;,' t ,5-6, i i/t ? ..- 2 ¢:) / S: (:, L. EAK DFTECTION · ':'")' ,q "; ;.~, P R 0 I> F:'R 0 F I I... E i ,:::, .... ~-..~-..i i .... i .....-.= .... F:' I... Ii!: A ;!~ Iii ;!~' ]: C; N (:~i'.,l):> Fi: ti.': 'T' U 1:;: N "1' I"lli[ (:'.'T' l" A C I"lli[ I) C 0 F:' Y RUN t, R U~..! t , RI.JN t , RUN t, RUN t , IN:UN t , RLJN t , IR'UN i, RtJN i , RUN ~, F:LJN t, RUN I , RUN t, F;,' U N i , l~,'l..Jt,! S, RUN i , RI. JN2, F,' LIN 2, A ;~' R IE C E i I::' 'IF' 0 F' i) A'i"A, .,/ A I::' F:' I::: C} V Iii: I) .~ .5 ' .5" .5' 5' 5" 5' ~ l .5" 5 ' 5' 2"&5' 5" 5" I:;.' II .! 2"&5' HI...S' C A I'~ C; El HI...S' C A I't C C) FILS' CAHCCI C; A H C 0 HL.$ ~'1'1... A :~; HL.,~ C A H C C) C A ['i C C) C A H C C) I.il....S' !-.I !... ;~;' CAHCO (. A H .., 0 C; A H CCI I) I '3 T R I B U l" I 0 N '"' CEN'¥RAL. F: II..E$ 'Ir ~"~,.CI-iE.' VRO N E:XT'ENSION E:XF'I...C)iRAT I ON EXXON 11' f't A F;,' A 1' H 0 N MOBIL 'Il' ¢ F'H II..L IF'$ F'B WEL_I.. FILE,S' BF'X 'Il' STATE OF ALAS'KA I'[:'XACO RECE VED DEC 1':' 1990 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALA~'KA, ZNC,. F'~O~ BOX i0<~S6~ AiqC;HOF. IAC~E]~ AL.A~,'KA 995~ (.'} DATE · 6,,' ~ S/9(-) F;.'. Iii: I::' Iii: i:;.: E: N C E: ' A F;..' C C) C A 5,' E: D I"t .., - 2:2~ e F;.'. O D O E:'T' ]: 0 N F:' F;,' C] F:' :[ I... [: F;..' ! J i"~. i ':""" 2 .... 2 t 5: '"' 2:2'.'; .... 9,:7.) F' F;.'. O)'.) U C T' :[ t"'~ hi P 1:;..' O f:' :1: L ii':: I:;: I j f'..l i ':~'" ,~ -. . .I ,./ 2 .... 28 ....':".: _.. ,."::' .... ,c: .... ,:;,,, ;:), ...... i"E; i"i F' iE F;.: A t- Li R Iii: ,?i; LJ F;.'. V E: Y f;..' I i iq i , '=':" ,.l. "" 'i ''':'~ ~::' .. "':' ".... "'" ~":'i i"-,I ti:' I")"t" e J:;..' O I::' ]] t... Iii: j:;..' I t [',J. .... ;. ",... e:. '.." :.:: Z :[ 0 N ':~'" *, ,. ........ .I ..,' ' '" ":" ":' !i!.;-' 2'? .... 9 (') .... " 4 ..: ...... 'i" [.:. M P Iii: R A T U R iE t... 06;. i:;.: LJ i"'.~ 'i: '::" ! i .... '7 '.:5"- 26 .... 9 qb I N.J f.'i:fZ:'t" :[ 0 N F' R C)I::' :[ t.. ii:' I::..' L.I N 'i ,'.5:" t 'i .... i 6 '::' '" © ""'::.:'""'" F:' F;.'. O J.) U C.'.'T' ]: 0 f'.~ F:' I:;,.' ri F:' ]: i... iii: I::..' t I i'...~ i '::'" ..,:' -" ·.:.: .';.. " ;' ...... I ,-.:' i i -'i '7 ':< .... 2":'""9':) F:'RC!DI.]CTZC)N I::' F:: i'~ i::' ]: t.. li!: j:;:i ip.I i '::"" 'i,....":' .... S T."!: '!~;. .... ,.:."':' ..,'::" .... (:;'C), C': O 1... ~, ...... A R I:;.: L.t i'-J i , '"",." F't... I.:.': A 5.7 f.i: ;!..." :[ 6:. N A N D R li:.:'T' U F;,' N T i--t E A T'T' A C: I-.I E):) C: O F' Y A $ t:;.:' f.:: C r..i: :1: F:' 'T (3 F:' O A'J" A,. F~.'. iii: CIE :1: V t.:.':'.0 B Y . .......... ~ .......... 'i" I-;,' A N i.: :[ 9(i)22 t Alaska .Oil .& Gas Cons..Go. mmiss[O~ '"' f': F:'N'f' I";.: A C F"' :t: I_ E · 11° . .,..". r":. .... t..t E V t:;.', fi i'..~ ):) & i"i · ,.'"' [..': X 'T' !ii: N .~i: I 0 i'.J. IE X P t... 0 R A 'T' I 0 N · "' EXXON 'Ir H A F;.'. A T I"t O N · "' i'"'i O B :[ i... '1t' ARCO ALASKA, INC F'~O~ BOX i00S60 ANCHORAGE, ALASKA ~995i 0 DATE · REFERENCE' tt-27-89 ARCO CASED HOLE FINALS ~'i-S4 i0-t4-89 PRODUCTION PROFILE 2-o0 t 0-25-89 GAMMA DSN ~'5-i i i-9-89 COLLAR/F'ERF/F'ACKER ~i~ ~-"~7 i i-4-89 CBT ~ 6-3 i i -2-89 FM 'i'EMF' i4 ii-3-89 PRODUCTION PR[)FILE -7A i~-25-89 PRODUCTION PROFILE ~7-i7 i~-25-89 F, RODUCTION PROFILE ~7-'20 ii-6-89 PRODUCTION PROFILE ~-27 ii-4-89 INJECTION F'ROFILE ~-28 i ~ -S-89 PITS ~7-29 i i-4-89 PITS 7-Jrt = ' / ~ i i 5-89 PITS 7-SS ii-5-89 INJECTION F'ROF]:LE/I'EMF' ~'9-9 tn-27-89 PRODUCTION Fl,dF"~'~ .... ILE ~-. ~ 9-ii i0-28-89 LEAK DETECTION 9-28 l 0-S0-89 TEMF'/GR 9-58 ti-5-89 F'ERF RECORI) * ii 5 9-2 89 PERF NE,ORD ~.i-5 t0-27-89 PRODUCTION PROFILE/LEAK **~t2-ii i0-28-89 LEAK DETECTION ~-Si i 0-27-89 CCL/TEMP ~..~ ~l~2-SS i 0-26-89 INJECTION PROFILE ~,,'i 4-4 i i -6-89 COLLAR/F'ERF ,--~iS-tS ii-7-89 TUBING CUTTER 4~" ~ i o TM i 8-~8-89_ TEMF' ~4 5-2~ i i -4-89 CNL ~i7-4 9-8-89 PERF RECORD DEl', RUN i , .,. RUN i , 5" RUN i , ~' · RUb.! i , 5 · RUN t , 5" RUN i , 5" RUN i, _,~-~'" RUN t , 5" RUN t , .~'" RUN t, 5" RUN i, 5" RUN i, '2" &5" RUN i , 5" RUN i, ~""&5" RUN t , 5" RUN i , 5" RUN t, ~."~"&5" RUN t, 5" RUN t, u.='" RUN t, RUN i, RUN i, '2"&5" RUN t , 5" RUN RUN i , 5" RUN t, 5" RLJN i , 2" RUN i RUN PI_EASE SIGN AND RETUj;:N THE ATTACHED HAVE A NICE DAY! NOV 01989 SALLY HOFFECKER A T O- t 5 2 9 Alaska 0ii & Gas Cons. Comm'tSSW[ Anchorage COPY AS I;'.ECEIF'T OF AF'F'ROVED ~__ TRANS~ 89 6 DISTRIBUTION DATA CENTRAL FILES T'~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION T' BF'X EXXON ~- STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL CAMCO HL£ FILS A i'LA£ SCI-t CAMCO CAMCO CAi'riCO CAMC'.O CAMCO C A M fT' ''''~ H R S HRS CAMCO CAMCO CAMCO CAMCO SCH CAMCO CAMCO CAMCO CAMCO ATLAS A'i"LA:S' CAMCO SC~'~ FILS * THE CORRECTED AF'I~ F'OR ii-5 I.S' 50-0':29-20670, ............... -,-,-,-~-r~ ,-,,-,'r~. =,n~:, ~'.~-~ 'tx' 50-029-2060i ,, ARCO At_A3KA, INC F' , 0 ,BOX i ANC!4ORAGE, ALASKA 99510 DATE' 9-t 8-89 REFERENCE' 4-5 4-t9 7'-"28 9-2 9-S2 9-56 t2.-;5t i ")-'~ 3 iS-J4 i4-37 i6-6 i6-i8 t 6-2r3 t 8-20 PLEASE SIG ARCO PRESSURE DATA 8-30-89 BHP--STA'F IC GRADIENT 8-29-89 BIqP--$TA'F lC GRADIENT 8-29-89 BHF'--£'I'AI' I C GRAD IEN'f' 7-5'-89 BHF'--$I'AT I C GRADIENT 9-2-89' BHP--STATIC GRAD IEN'f' 9-2-89 BHP--STATIC 61;,'AD I ENT 8--i 3-89' BHF ..... FLOWING GRADIENT 6-5-89 ~'4HP--SI'AT lC GRADIENT 6-5'-89 ' BHP--$TATiC GRADIEN'[ 8-t e-89 ~ BHP--STA'¥IC GRADIENT 9-2-89 BHP--STATIC GRADIENT 8-iS-89 ' BHP--S'rATIC GRADIENT 8-2t-89 BHP--FLOWING GRADIENT 8-t~-89 BHF'--STATIC GRADIENT 8-tt-89 BHP--STATIC GRADIENT N AND RETURN THE ATTACHED COPY AS RECEIPT OF CAM[:[) CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO HRS CAMCO CAMCO DATA. RECEI'v'ED BY HAVE A NICE DAY! E ~D SALLY HOFFECKER AF'F'ROVEI) ~ ..... ATO-i 529 ~~j~ANS.~ 89~93"'r" Oil & Gas CoDs. Anchorage DISTRIBUTION CENTRAL FILES ~ ,PHILLIPS CHEVRON F'B WELL FILES D&M ~ R&D EXTENSION EXF'LORATION $ BF'X EXXON ~ S'I'AI'E OF ALASKA MARATHON $ TEXACO MOBIL , "~-' STATE OF ALASKA --~' 0 J{ I G I ~ A L ~ ALASk,~ OIL AND GAS CONSERVATION COMMISSION ~'' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] · 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 89-10 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21909 4. Location of well at surface !~T1ON~ 9. Unit or Lease Name 169' FSL, 692' FEL, Sec.18, TION, R15E, UN VERIFi'ED Prudhoe Bay Unit At Top Producin9 Interval ' rf "~/~ "10. Well Number 2478' FNL, 2386' FEL, Sec.19, TION, ELSE, UM .B. FI.-~---'~___(__ 12-33 At Total Depth 'i 1. Field and Pool 2533' FNL, 2451' FEL, Sec.19, TION, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool RKB 74'I ADL 28330 1.2., Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offshore 116. No. of Completions 01/27/89 02/10/89 06/03/89*I N/A feet MSL/ 1 17. TotalDepth(MD+TVD) 18. PIugBackDepth(MD+TVD)i 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafros, 9980'MD/9231 'TVD 9933'MD/9187'TVD YES ~ NO [] 2189' feet MD 1900' (approx) 22. Type Electric or Other Logs Run D I L/GR/CAL, FMT/GR, D I L/BHCS/SP/GR~ GR/CNL/Z-Den/CAL, CBL/CEL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASII~G SIZE! WT. PER FT. GRADE iTOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' . :50" 71c;~)~ Po!eset 13-:5/8" 72.0#/68.0~ L-80/K-55 Surf 3573' 17-1/2" ?nnn ~ c$ ~!! & 600 s> C~.ass G Tn.n jnb w/396 sx CS I 9-5/8" 47.0# L-80 Surf 9643' 12-1/4" 500 sx £1a.~s G 7" 29.0# L-80 9344' 9979' 8-1/2" 3~lil ~× £1~, C; 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) Perforated ~ 120° Phasing 5-1/2" 971~' 10790' & 11242' 9646'-9661 'MD/8918'-8932' w/4 spf 9762 '-9790 'MD/9027 ' -9053 ' w/2 spf "26. ACID, FRACTURE, CEMENT SQUEEZE, ETC." 9794'-9807'MD/9056'-9067' w/2 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHOKE SIZE IGAs'OILRATIO TEST PERIOD I~ ..... Flow Tubing i Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ ,,_ 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ., NoneRECEIVED * Drilled RR 2J14J89. Tublng run 3/16/89. Perforated ~ell 6/3J89, AUG ~ 8]~8-0 (Dani) WC6/057 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit HOT OWC GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 9738' 9807' 9846' 9004' 9069' 9105' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS . Addendum (dated 4/7/89) 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-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM ~"ELL: 2/18/89 3/17/89 12-33 Rn CBL/CEL/GR/Collar Locator combination. Follow cmt evaluation logs w/Gyroscopic Directional Survey log. PBTD @ 9942' ELM - TOL @ 9350' ELM. Logs show good cmt f/PBTD to 9650' ELM. From 9650' ELM to TOL is fair to poor cmt. Est'd TOC @ 8455' ELM. No cmt above 8450' ELM. Continue to log w/GR up to 3500' ELM. MU S/L unit; tst lubr to 1000 psi. Pull BPV. RIH, pull dummy f/SSSV nipple. RIH, pull Otis catcher sub from "X" nipple. Catcher sub full of plastic coating from tbt. RD. R'ECE]VED 2 989 ~ Alaska Oil & Gas Cons. Commisslo. Anchorage $UB.$URFACE DIRECTIONAL ~URVEY I'~UIDANCE I~ONTINUOUS I-~"! OOL Company ARCO ALASKA~ INC. Well Name D.S. 12-33(169' FSL,692' FEL,SEC 18,TION~R15E,UM1 Field~Locatiorl PRUDHOE BAY~ NORTH SLOPE- A~rASKA Job Reference No. 73193 REYNOLDS Date 18-FEB-89 Computed By:. KOHRTNG SCHLUMBERGER GCT OIRECTTONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. D.S. lZ-33 ' PRUDHOE BAY NORTH SLOPer ALASKA SURVEY DATE: 18-FEB-89 ENGINEER: REYNOLOS METHODS OF COMPUTATION TOUL LOC~TION: TANGENTIAL- ~VERAGED DEVIATION AND AZIMUTH LNTERPOL~TION: LINEAR ~ VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH ]6 DbG 45 MIN WEST ARCO ALASKA INC. D.S. 12-33 PRUDHDE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 15-MAR-B9 PAGE 1 DATE OF SURVEY: 1B-FEB-89 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: REYNOLDS ,, INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA 'i COURSE MEASURED VERTICAL VERTICAL D~¥[ATJON AZTMUTH DEPTH DEPTH 0.00 O.Og 100.00 100.05 ZO0.O0 200.05 300o00 300.0~ 400.00 400.04 500.00 500.04 600.00 600.06 100.00 700.04 800.00 800.04 900.00 900.04 DEPTH ,OF- :N OEG MIN -74. O0 N 0 0 E Z6.05 :~! S 37 39 W 126.05 i S 25 10 U 226.04 :". 0'~22'~ S 13 21 W a26.04 ~0 15 S 5 19 E 426.04 0 17 S 7 23 E 526.04 ~ 0 19 S 2 26 E 626.04 0 17 S 8 21 E 726.04 0 I3 S 29 22 E 826.04 0 7 S 69 23 E 1000.00 1000.04 926.04 0 5 llO0.UO I100.04 1026.04 0 8 1ZO0.O0 1200.04 1126.04 0 10 1300.00 1300.03 1226.03 . 0 25 1400.00 1400.03 1326.03 0 16 lbO0.OU 1500.03 14Z6.03 0 1Z 1600.00 1600.03 1526.03 0 11 1700.00 1700.03 1626.03 0 7 1800.00 1800.03 1?26.03 0 3 1900.00 1900.03 1826.03 0 14 N 55 33 E N 30 OW S 71 27 W S 72 18 W S $8 35 W S 63 50 W S 47 47 W S 31 37 W N 35 6 E S 32 45 W VERTICAL DOGLEG RECTANGUL&R CgORDINRTeS HORIZ. DEPARTURE SECTION SEVERITY NORTH/SDUTH E~ST/WEST DIST. AZIMUTH FEET DES/lO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.35 0.43 0.26 S 0.2~ W 1.08 0.10 0.89 S 0.62 W 1.71 0.05 1.52 S 0.83 W 2.15 0.06 2.05 S 0.86 W 2.49 0.09 2.52 S 0.80 W 2.88 0.12 3.03 S 0.74 W 3.31 0.14 3.59 S 0.72 W 3.54 0.33 4.00 S 0.57 W 3.58 0.08 4.20 S 0.36 W 0.00 N 0 0 E 0.36 $ 42 48 W 1.08 S 34 58 W 1.73 S 28 31 W 2.22 S 22 43 W Z.64 5 17 36 w 3.12 S 13 47 W 3.67 S 11 22 W )\ 4.04 S 8 7 W 4.22 S 4 56 W 3.47 0.10 4.19 S 0.19 W 3.33 0.13 4.02 S 0.17 W 3.37 0.38 3.95 S 0.35 W 3.87 0.17 4.16 S 0.91 W 4.43 0.15 4.42 S 1.48 W 4.80 0.06 4.58 S 1.89 W 5.13 0.17 4.78 S 2.17 W 5.41 0.27 4.99 S 2.36 W 5.44 0.15 5.05 S 2.33 W 5.62 0.Z9 5.14 S 2.51 W 4.19 S 2 39 W 4.03 S 2 26 W 3.96 5 5 4 W 4.Z6 S 1Z 17 W 4.67 S 18 32 W 4.96 S 22 Z1 W 5.25 5 24 27 W 5.52 S 25 19 W 5.56 S 24 47 W 5.72 5 26 4 W ZO00.O0 2000.03 1926.03 0 16 2100.00 Z100.03 2026.03 0 28 ZZO0.O0 ZZOO.OZ 2126.02 0 41 Z300o00 ZZgCJ. 90 ZZZS.90 4 12 2400=00 2399.42 2325.42 7 2 Z~O0.O0 2498.30 2424.30 9 33 2600.00 2596.53 2522.53 12 Z700.00 2693.63 2619.63 15 6 Z800.00 2789.50 Z715.50 17 56 2900.00 Z883.91 2809.91 20 15 3000.OU 2971.19 2903.19 Z1 51 3100.00 3069.73 2995.73 22 32 3ZO0.UO 3161.95 3087.95 22 58 3~00.00 3253.86 3179.86 23 3400.00 3345.41 3271.41 23 58 3~00.00 3436.62 3362.62 24 Z1 3600.00 3527.61 3453.61 24 43 3700.00 3618.35 3544.35 24 4~ 3800°00 3709.35 3635.35 24 ZO 3900.00 3800.50 3726.50 24 7 S ~4 5~ E S ~5 4A E S 30 6 E S 16 17 W S 25 40 W S 26 B W S 25 36 W S 26 8 W S 24 17 W S 23 2B W 6.02 0.91 5.59 S 2.57 5.75 0.63 5.83 S 1.81 5.45 3.40 5.94 S 1.16 9.50 2.37 10.47 S 1.87 18.82 3.40 19.35 S 5.54 33.44 1.57 32.71 $ 12.08 51.76 3.63 49.50 $ 20.2l 75.21 Z.66 70.89 S 30.76 103.04 2.90 96.59 S 135.11 1.70 126.79 S S 24 37 W 170.28 1.36 S 23 48 W 207.25 0.49 S 24 34 W 245.00 0.52 S 25 9 W Z83.54 0.70 S 25 43 w 323.00 0.55 S 26 1 W 363.27 0.33 S 26 47 W 404.05 0.80 S 27 26 W 445.49 0.48 . S 27 50 W 486.43 0.10 S 28 14 W 527.09 0.62 6.16 5 Z4 41 W 6.10 S 17 14 W 6.05 S 11 3 W 10.63 S 10 6 W 20.13 S 15 59 W 34.87 S ZO 15 W 53.47 S ZZ 13 W 77.2'3 S 23 27 W 42.86 W 105.68 S 23 55 W 56.01 W 138.61 S 23 49 W 159.61 S 10.85 W 174.63 S 23 56 W 194.23 S 86.28 W Z12.53 S 23 57 W 229.50 S 102.14 W 251.20 S 23 59 W 265.26 S 118.67 W 290.59 S 24 6 W 301.58 S 135.99 W 330.82 S 24 16 W 338.47 S 153.87 W 371.80 5 24 26 W 375.66 S 172.25 W 413.26 S 24 37 W 413.02 S 191.45 W 455.24 S 24 52 W 449.74 S Z10.72 W 496.66 5 25 6 W 486.06 S 230.03 W 537.15 5 25 19 W ARCU ALAS&A INC. U.S. 12-.3.3 PRUDHOE BAY NORTH SLOPEm ALASKA COMPUTATION DATE: 15-MAR-89 PAGE 2 DATE OF SURVEY: 18-FEB-89 KELLY BUSHING ELEVATION: 7~.00 FT ENGINEER: REYNOLDS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASURED VER[ICAL VERTICAL DEPTH DEPTH DEPTH : ,COURSE TION AZIMUTH ;N DEG MIN 4000.00 3891.96 3817.96 4100.U0 .3983°46 3909.46 4200.00 4015.1Z 4001.1Z 4300.00 4,1 66.86 4,092.86 4400.00 4258.85 4184.85 51 4500.u0 ~351.10 4277.10 ':22 36 ~600.00 4,4,43.4,3 4369°43 ~22 28 4700.00 4535.89 44,61.89 ~ 22 28 4800.00 ~628,2~ 4554.24 22 3~4 · 900.00 47Z0.53 4646.53 Z2 37 5000.00 4812.88 4,738.88 22 30 5100,00 4905.31 4831.31 22 22 5Z00.00 4,997.78 4923.78 22 22 5300.00 5090.26 5016.26 22 24 b400.O0 5182,66 5108.66 22 44 5500.00 5274.65 5200.65 23 33 5600°00 5365.8~ 5291.88 24 43 bt'U0. O0 54,56.34 5382.34 25 36 5800.00 5546.32 5472.32 26 14 5900.00 56-45.65 556.t.65 27 13 6UO0.UO 5724.00 5650.00 28 44, 6100.00 5811.10 5737.10 30 1 6200.00 5897.22 5{323.22 31 8 6500.00 5902.16 5908.16 32 3Z 6400.00 6066.32 5992..32 32 30 6500.00 6150.92 6076.92 31 56 6600.00 62-45.99 6161.99 31 26 6100.00 6321.43 6247.43 31 9 6800.00 6q. 07.51 6333.31 30 28 6900.00 6493.6q 6419.54 30 9 7000.00 6580.24 6506.Z4 29 4,7 7100.00 6667.30 6593.30 29 21 ]ZO0.O0 6754.43 6680.43 29 26 7300.00 6841.45 6767.45 29 32 7400.00 6928.40 685 ~+. ~+0 29 38 7500.00 7015.29 6941.29 29 39 7600.00 7102.15 7028.15 29 47 7700.00 7189.01 7115.01 29 36 7 I:10 O. OO fZ76.05 7ZOZ.05 Z9 26- 7900.00 7-463.16 7289.16 29 24 VERTICAL DOGLEG RECTANGULAR COORDIN,~TES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SDUTH EAS'T/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 28 55 W 567.11 S 29 24 W 607.11 S 30 Z W 646.79 S 30 39 W 686.34 S 31 10 W 725.34 S 31 37 W 763.79 S 31 40 W S 31 56 W 839.99 S 32 27 W 878.22 S 32 32 W 916.64 S 32 20 W 954.88 S 33 1W 992.94 S 33 45 W 1030.95 S 34 28 W 106~.96 S 34 38 W 1107.18 S 34 5 W 1146.35 S 32 42 W 1187.22 S 32 40 W 1229.72 S 33 11 W 1273.25 S 33 10 W 1318.13 S 31 Z w 1364.81 S 29 39 W 1413.59 S 29 27 W 1464.03 S 29 10 W 1516.36 S 28 51 W 1569.q7 S 29 8 W 1622.70 S 28 58 W 1674.79 S 2~ 59 W 1726.28 S Z8 53 W 1777.04, S 2° 56 W 1827.03 S 29 § W 1876.58 S 29 20 W 1925.36 S 29 23 W 1974.02 S 29 37 W 2022.91 S 30 3 W 2071.93 S 30 ~Z W 2121.13 S 31 26 W 2170.43 S 32 15 W 2219.79 S 33 1Z W 2268.92 S 33 51 W 2317.94 0.51 0.38 0.32 0.5.4 0.61 0.21 0.33 0.45 0.37 0.32 0.50 0 0.39 0.29 0.61 1 1.06 0 0.90 I .03 2.21 1.10 I .30 0.98 0.58 0.10 0.27 0.45 0.35 O.Z1 521.54 S 249.40 W 578 11:]: !$: 25 33 W 556.78 S 269.06 W 618:39' iS 25 47 W 591.50 S 2~38.87 W 658.271: $ 26 I W 625.83 S 309.00 W 697.96' S ,?.6 16 W 659.48 S 329.13 W 737.05' S 26 31 W 692.43 S 349.27 w 775.53 S 26 46 W 725.10 S 369.43 W 813.79 S 26 59 W 757.49 S 399.50 W 851.'17 S 27 12 W 789.94 S 409.94 W 889.98 S 27 25 W 822.39 $ 430.70 W 928.34 S 27 38 854.81 S 451.19 W 966.58 S Zl 49 W 886.93 S 471.79 W 1004.61 5 28 0 W 918.72 S 492.74 W 1042.52 S 28 IZ W 950.20 S 514.12 W 1080.37 S ZB 24 W 981.68 S 535.84 W 1118.4,0 5 28 37 W 1013.96 S 558.07 W 1157.40 S 28 49 W 1048.21 S 580.52 W 1198.ZZ S 28 58 W 1084.13 S 603.44 W 1240.76 S 29 6 W 1120.73 S 627.19 W 1284.29 S 29 13 W 1158.33 S 651.84 W 1329.14 S 29 22 W 1197.79 S 677.02 W 1375.89 S 29 28 W 1240.3~ S 701.57 W 1425.01 S 29 29 W 1284.55 S 726.65 W 1475.84 S Zg 29 W 1330.57 S 752.49 W 1528.61 S 29 29 W 1377.80 S 778.68 W 1582.62 S 29 28 W 1424.39 S 804.58 W 1635.92 S 29 27 W 1470.33 S 830.13 W 1688.49 S 29 26 W 1515.81 S 855.26 W 1740.45 S 29 25 W 1560.63 S 830.10 W 1791.63 S 29 25 W 1604.80 S 904.49 W 1842.14, S zg 24 W 0.69 0.43 0.33 0.26 0.29 0.24 0.42 0.56 0.35 0;34 ~=~!, .. ',,e · 1648.52 S 928.77 W 1892.14 S 29 23 W 1691.46 S 952.78 W 1941.34 S 29 23 W 1734.21 S 976.86 W 1990.~1 S 29 23 W 1777.11 S 1001.11 W 2039.70 5 29 23 W 1819.96 S 1025.67 W 2089.08 S 29 24 W 1862.67 S 1050.69 W 2138.57 S 29 25 W 1905.12 S 1016.25 W 2188.11 5 29 27 W 1947.21 S 1102.39 W 2237.61 S 29 30 W 1988.62 S 1129.03 W 2286.77 S 29 35 W 2029.54 S 1156.16 W Z335.16 5 29 40 W ARCO ALASKA iNC. D.So 12-33 PRUDHDE BAY NURTH SLOPE, ALASKA COMPUTATION DATE: 15-MAR-89 PAGE 3 O~T~ OF SURVEY: 18-FEB-S9 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: REYNOLDS TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH INTERPOLATEO VALUES FOR EVEN 100 FEET DF MEASIJRED DEPTH COURSE VERTICRL DOGLEG RECTANGULAR COORDENATES HORIZ., DEPARTURE ION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 8UO0.O0 1450.27 7376.27 8100.OO 7537.29 7463.29 8200.00 7624.Z2 7550.22 8300.00 7711.02 7637.02 84OD.OD 7797.93 7723.93 N DEG MIN FEET S 34 33 W 2367.01 S 35 8 W 2416.24 S 35 34 W 2~+65.66 ~'46 S 36 13 W 2515.31 ,' 3,1 S 37 3 W 2564.78 8500.00 78~5.07 71311.07 129 16 S 38 Z1 W 2613.93 8600.00 7972.45 7898.45 28 51 $ 39 14 W 266Z.43 8700.00 U060.10 7986.10 28 4Z S 39 57 W 2710.50 8800.U0 8148.01 8074.01 28 10' S 40 45 W Z758.07 8900.00 87.36.42 8162.42 27 21 S 41 51 W 2804.65 9000.00 8325.68 8251.68 26 18 9100.00 8415.71 8341.71 Z5 16 9200.00 8506.43 8432.43 24 24 9300.00 8597.8! 8523.81 23 43 9400°00 86~9.66 8615.66 22 41 9bOO.U0 8782.16 8~08.16 2! 56 9600.00 8875.25 8801.25 21 7 9100.00 8968.59 8894.59 20 46 9800.00 906Z.34 8988.34 ZO 28 9900.00 9155.87 9081.87 ZO 51 S 43 12 W 2849.50 S 44 16 W 289Z.71 S 45 24 W 2934.33 S 46 Z1 W 2974.43 S 47 25 W 3013.37 S 4~ 46 W 3050.60 S 49 25 W 3086.28 S 49 25 W 3121.27 S 49 33 W 3155.26 S 50 23 W 3189.64 9980.0U 9230.63 9156.63 ZO 51 S 50 23 W 321'7.33 DEG/IO0 FEET FEET FEET DEG MIN 0.46 O.Z1 0.31 0.51 0.61 0.75 0.48 0.26 0 1.45 1.14 1 I .23 1.15 1.50 I .07 0.35 I .18 I .00 0.00 2070.17 S 1183.77 W 2384.72 ,:5 Z:9 45 W 2110.57 S 1211.96 W 2433.7'9 S 29 51 W 2150.90 S 1240.54 W 2483.01 S 29 58 W 2191.13 S 1269.64 W 253Z.40 S 30 5 W 2230.85 S 1299.13 W 2581.55 S 30 12 W 2.2,59.6') S 1329.11 W Z630.21 S 30 Z1 W 2307.54 S 1359.63 W 2678.31 S 30 30 W 2344.62 S 13'90.32 W 2725.85 S 30 40 W 2381.01 S 14Z1.10 W 2772.85 S 30 49 W 2416.08 S 1451.98 W 2818.81 S 31 0 W 2449.30 S 1482.45 W 2862.99 S 31 11 W 2480.75 S 1512.56 W 2905.50 S 31 22 W Z510.54 S 1542.23 W 2946.40 5 31 33 W 2538.80 S 1571.41 W 2985.77 5 31 45 W 25,55.86 S 1600.25 W 3023.98 S 31 57 W 2591.19 S 1628.55 W 3050.46 S 32 8 W 2615.12 S 1656.]3 W 309b.42 S 32 ZO W 263R.42 S 1683.41 W 3129.72 S 32 32 W ;7651.11 S 1709.83 W 3163.07 S 32 43 W 2683.72 S 1737.03 W 3196.81 'S 32 54 W 2701.88 S 1758.97 W 3223.99 S 33 3 W ANCO ALASKA INC. U.S. 12-33 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 15-MAR-BO PAGE 4 DATE IJF SURVEY: IS-FEB-BO KELLY 3!JSHING ELEV&T/ON: 74.00 FT ENGINEER: REYNOLDS INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SE,~ COURSE MbASUR~,D VERTICAL VERTICAL DEVIATION AZIMUTH DEPIH DEPTH OEP'TH IN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HURIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH PEET OEG/IO0 FEET FEET FEET DEG MIN o.oo o.oo -~.oo N o 0 E 0.00 ~000.o0~0o0.0~~Z~. N ss ~ E ~.~ zooo.uozooo.o~~oz~.o s ~ ~ ~ 6.0z ~000.00z9?~.~ z90~.~9: s z~ ~ w ~000.00~8~.~6 ~.96 s z~ ~ w 6ooo.oos~z~.oo~o.oo,"~ ~ s ~ z w ~.~ '-Jgl:lO.O0 9Z30.63 9156.63 20 51 S 50 23 W 321'~'.33 0.00 0.10 0.91 1 0.51 0.50 Z .21 0.69 0.46 1.14 0.00 N, 0,00 E 0.00 N 0 0 E 4.19 S 0.19 W 4.19 S 2 39 W 5.59 S 2.57 W 6.16 S' 24 41 W 159.61 S 70.85 W 174,63 S 23 56 W 521.54 S 249.40 W 578.11 S 25 33 W 854.81 S 451.19 W 956.58 S Z7 49 W 1197,79 S 677,02 W 1375.89 S 29 28 W j 1648.52 S 928.77 W 1892.14 S 29 23 W 2070.17 S 11~3.77 W 23B4.72 S 29 45 W 2449.30 S 1482.45 W 2862.99 S 31 11 W 0.00 2701.88 S 1758.97 W 3223.99 S 33 3 W ARIJO ALASKA INC. O.S. 12-3~ PRUDHUE BAY NORTH ,SLOPE, ALASKA COMPUTATION DATE: 15-MAR-B9 PAGE 5 DATE DP SURVEY: 18-FE8-89 KELLY BUSHING ELEVATION: 74.00 PT ENGINEER: REYNOLDS INTERPOLATED VALUES FOR EVEN 100 FEET OF SUO-SEA DEPTH TRUE SUB-SEA COURSE MEASURbD VERTICAL VERTICAL !vIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN O.OU 0.00 13.95 74.00 173.95 174.00 273.96 274.00 373.g6 374.00 473.96 474.00 573.96 574.00 673.96 674.00 713.96 77..00 873.96 874.00 -74.00 0.00 100.00,iii ZO0.O0 300.00 4oo.oo ~i~ '!6 500.00 '~ 0 18 600.00 O, 18 700.00 0 13 800.00 0 8 N 0 0 E S 44 40 W S 29 4 W S 15 10 W S 4 40 E S 7 53 E S 3 39 E $ 3 15 E S 28 2 E S 59 21 E 973.96 974.00 900.00 1013.'J6 1014.00 1000.00 11'/3.96 1174.00 llO0.O0 1Z73.96 1274.00 1200.00 1573.97 1314.00 1300.00 1473.97 147q. O0 1400.00 1573.9-/ 1574.00 1500.00 1673.V7 1674.00 1600.00 1'1'73.91 1774.00 1700.00 1873.97 1874.00 1800.00 0 5 0 7 0 6 0 24 0 18 0 13 0 11 0 ~ 0 3 0 11 N 68 43 E N 9 6 W N 85 4 W S 72 35 W S 62 53 W S 66 45 W S 48 25 W S 37 57 W N 72 49 E S 52 40 N 1973,.97 1974.00 1900.00 0 15 Z073.97 ZOt4.00 2000.00 0 31 2.1'13.98 2174.00 2100.00 0 19 2274.04 ZZ74.00 2200.00 3 37 237~.41 2374.00 2300.00 6 1Z Z~75.37 24-1'4. O0 2400.00 9 10 Z5'i6.96 2574.00 2500.00 11 28 2679.69 2614.00 2600.00 14 34- 2183. 1'3 2774.00 2'100.00 17 28 2889.43 281'4.00 2800.00 ZO 4 S 4 11 E S 31 51 E S 79 32 E S 11 40 W S 14 31 W S 26 7 W S 25 29 W S 26 17 W S 24 36 W S ~3 19 W , Z996.56 2974.00 2900.00 21 48 310~.63 3074.00 3000.00 22 33 5213.09 3174.00 3100.00 23 1 ~3Z1.96 3274.00 3200.00 23 35 3431.32 3374.00 3300.00 24 7 3541.06 3474.00 3400.00 24 28 3651.IZ ~574.U0 3500.00 24 51 3761.Z0 3674.00 3600.00 24 25 3870.95 ~774.00 3700.00 24 15 3~80.38 38'r4.00 3800.00 23 45 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET 0.00 0.00 0.00 N 0.00 0.11 0.61 0.08 S 0.08 0.90 0.23 0.72 S 0.54 1.56 0.06 1.36 S 0.79 2.06 0.04 1.92 S 0.87 2.40 0.11 2.39 S 0.81 2.77 0.07 2.89 S 0.75 3.21 0.17 3.46 S 0.74 3.50 0.10 3.91 S 0.62 3.59 0.15 4.17 S 0.42 3.51 0.08 4.21 S 0.25 W 5.36 0.28 4.08 S 0.15 W 3.33 0.30 3.94 S 0.29 W 3.72 0.15 4.10 S 0.73 W 4.32 0.14 4.37 S 1.37 W 4.71 0.07 4.54 S 1.73 W 5.04 0.10 4.72 S 2.11 W 5.35 0,12 4.94 S 2.32 W 5.~6 0.23 5.06 S 2.35 W 5.53 0.34 5.07 S 2.45 W 5.95 0.50 5.49 S 2.60 W 5.87 0.45 5.81 S 2.03 W 5.44 0.96 5.83 S 1.29 W 7.85 2.46 8.73 S 1.42 W 15.91 3.92 16.67 S 4.27 W 29.49 1.51 29.11 S 10.31 W 47.04 3.43 45.16 S 18.15 W 70.10 2.64 66.2~ S 28.46 W 98.Z0 3.0Z 92.09 S 131.53 1.58 123.42 S S 24 38 W 169.03 1.39 S 23 50 W 208.98 0.53 S 24 3~ W 250.00 0.51 S 35 ZO W 292.11 0.73 S 25 4~ W 335.55 0.46 S 26 14 W 379.95 0.39 S 17 13 W 425.23 0.26 S 27 45 W 470.54 0.52 S 2-) 4 W 515.31 0.25 S 28 50 W 559.30 0=60 FEET DEG MIN 0.00' N 0 0 E 0.11 S 46 20 W O. 90 S 36 34 W 1.57 S 30 4 W Z.11 5 24 15 W 2.52 S 18 50 W 2.99 S 14 33 W \ 3.54 S 1Z 2 W / 3.96 S 9 0 W 4.19 S 5 43 W 4.21 S 3 8 W 4.08 S Z 5 W 3.95 S 4 13 W 4.17 S 10 2 W 4.58 S 17 Z1 W ~.8~ S 21 32 W 5.17 S 24 4 W 5.46 S 25 11 W 5.59 S 2~ 53 W 5.63 S 25 49 W 6.07 S 25 20 W 6.15 S 19 18 W 5.97 S 1Z Z9 W 8.85 S 9 14 W 17.20 S 14 21 W 30.88 S 19 29 W 48.67 S Z1 53 W 72.09 S 23 14 W 40.81 W 100.72 S 23 54 W 54.55 W 134.94 S 23 50 W 158.45 S 70.31 W 173.35 S 23 55 W 195.86 S 87.00 W 214.31 S 23 57 W 234.15 S 104.27 W 256.31 S 24 0 W 273.17 S 122.39 W 299.33 S 24 8 W 313.08 S 141.55 W 343.59 S 24 19 W 353.71 S 151.36 W 388.77 S 24 31 W 394.78 S 182.03 W 434.73 S 2~, 45 W 435.60 S 203.26 W 480.69 S 2~ 0 W 475.55 S 2Z4.41 W 525.85 S 25 15 W 514.64 S 2~5.59 W 570.24 S 25 30 W AgCU ALASKA D.5. 1Z-33 PRUDHOE BAY NURTH SLUPE, INC. ALASKA CDMPUTATION M~ASUR~D DEPTH 4089.67 4198.78 4J07.78 4416.43 4524.81 4741.27 4849.57 5066.13 5174oZB 5282.41 5590.61 5499.29 5608.94 5719.59 5U50.89 6057.25 617Z.93 6Z90.33 6527.20 6644.53 6161.33 6877.28 6992.U0 7107.69 7ZZZ.4U 7337.42 7&5Z°48 T567.b6 1682o75 7797.65 7912.44 U027.26 8142.21 8Z57.33 U4U7.3Z TRU_~ VERTICAL DEPTH 39'74 · O0 4074.00 ~+1 74 .(JO 4274.00 4374.00 4474.00 6~574o00 4674.00 47 '14. O0 4874.00 ~97~.00 5074.00 5114.00 5274.00 5374.00 5474.00 b57~.00 5674.00 5774.00 5874.00 507a.00 6174.00 6274.00 6374.00 6474.00 6574.00 66?4.00 6774.00 6874.00 6974.00 7074.00 7174.00 12 74. O0 1374.00 7474.00 7574.00 7674.00 1'7 74.0 0 7~7q.00 DRTE: 15-MAR-89 INT~RPOLATEO VALUES FOR FVEN 100 SUB-SE A COUR S E V E RT LC AL VERTICAL D:E¥IATIgN AZTMUTH SECTION DEPTH Bi ~.:MIN DEG MTN FEET 3900.00 S 29 21 W 602.99 4000.00 S 30 1 W 646.30 4100.00 S 30 42 W 689.40 4200.00 ~'~il; S 31 16 W 731.66 4300.00 ,:22 S 31 39 w 773.'29 4400.00 22 ~ S 31 45 W 814.59 4500.00 . 22 33~,, S 32 8 W 855 77 4600.00 ,~?122~ ~!~ S 32 38 W 897.24 4700.00 S 32 15 W 938.78 4~00.00 22 24 S 32 41 W 980.06 4900.00 22 213 S 33 34 W 102t.15 5000.00 22 24 S 34 24 W 1062.25 5100.00 22 40 S 34 38 W 1103.55 5Z00.00 23 33 S 34 6 W 1146.07 5300.00 24 49 S 32 39 W 1190.96 5400.00 Z5 41 S 32 41 W 1238.18 5500°00 26 31 S 33 15 W 1286.95 5600.00 27 48 S 32 45 W 1338.03 5700.00 29 30 S ~9 52 W 1392.52 5800.00 30 49 S Z9 31 W 1450.22 5900.00 32 24 S ~9 1Z ~ 1511.21 6000.00 32 27 S 28 51 W 157~.70 6100.00 31 51 S 29 7 W 1636.96 6200.00 31 19 S 28 54 W 1697.78 6300.00 30 43 $ 28 59 W 1757.57 6400.00 30 12 S 28 56 W 1815.72 6500.00 29 50 S 29 6 W 1873.02 6600.00 29 21 S 29 21 W 1929.10 6700.00 29 29 S 29 24 W 1985.00 6800.00 29 35 S 29 45 W 2041.23 6900.00 29 40 S 30 22 . 2097.74 7000.00 29 46 S 31 It W Z154.38 7100.00 29 38 S 32 6 W 2211.27 7200.00 29 26 S 33 11 W 2267.77 7300.00 29 26 S 33 56 W 2324.04 7400.00 29 29 S 34 45 W 2380.~1 7500.00 29 36 S 35 IT W 2437.07 7600.00 29 47 S ~5 55 W 2494.10 7700.00 29 35 S 35 44 W 2551.21 7~00.00 29 1'1 S 38 10 W 2607.64 FEET OF DOGLEG SEVERITY OEG/IO0 0.36 0.32 0 0.38 0.12 0.17 0.24 0.12 0.36 0.36 0.29 0.30 0.60 1.43 1.07 0.48 0.97 I .87 1.38 1.19 1.26 0.41 0.49 0.35 0.95 0.33 0.51 0.40 0.25 0.23 0.43 0.52 0.46 0.35 0.33 0.40 0.27 O.Z7 0.64 0 °81 KELLY DATE OF SURVEY: BUSHING ELEVATION: ENGINEER: SUB-SEA DE:PTH RECTANGULAR COORO NORTH/SOUTH EAST/ FEET FEET PAGE 6 1B-FEB-B9 7~.00 FT REYNOLDS 910.55 S 487.3 944.66 S 510.3 978.69 S 533.7 1013.'73 S 557.9 1051.36 S 582.5 1091.26 S 608.0 1132.21 S 634.7 1175.04 S 662.7 1221.90 S 691.0 1272.44 S 719.8 1326.03 S 749.95 138Z.07 S 781.04 1436.96 S 811.58 1490.63 S 841.35 1543.43 $ 870.59 1594.80 S 898.98 1645.38 S 927.02 1694.75 S 954.63 1743.85 S 982.29 1793.15 S 1010.25 1842.42 S 1038.73 W 2115.06 5 29 24 W 1891.35 S 1067.87 W 2171.99 S 29 26 W 1939.98 S 1097.82 W 2ZZ9.07 S 29 30 W 1987.66 S 1128.40 W 2285.62 S 29 35 W Z034.61 S 1159.58 W 2341.85 S 29 60 W Z081.20 S 1191.40 W 2398.09 S 29 47 W 2127.59 S 1223.97 W 2454.53 S Z9 54 W Z173.98 S 1257.17 W 2511.31 S 30 2 W 2220.01 S 1290.97 W 2568.08 S 30 10 W 2Z64.83 S 1325.26 W Z624.08 5 30 ZO W 553.16 S 267.03 591.08 S 288.63 628.49 S 310.57 664.91 S 332.43 700.54 S ~54.28 735.83 S 376.05 770.92 S 337.90 806.02 S 420.20 841.15 S 442.58 876.09 S 464.78 61w.Z4 5 25 46 W 657.79 $ 26 I W 701.04 5 2.6 17 W 743.38 S 26 33 W 785.03 S 26 49 W 826.36 S 27 4 W 867.55 $ 27 17 W 908.97 S 27 32 W 950.47 S Z7 45 W 991.75 S 27 56 W 1 W 103Z.75 S Z8 9 W 2 W 1073.69 S 28 22 W 7 W 1114.79 S 28 36 W 1 W 1157.1Z S 28 49 W 4 W 1201.96 S 28 59 W 4 W 1249.23 5 29 7 W 1 W 1297.99 S 29 16 W 3 W 1349.05 5 29 Z5 W 4 W 1403.77 S 29 29 W 0 W 1461.93 5 29 29 W W 1523.42 S 29 Z9 W W 1587.49 S Z9 28 W W 1650.31 S 29 27 W W 1711.68 S 29 26 W W 1772.03 S 29 25 W W 1830.72 S 29 24 W W 1888.55 S 29 23 W W 1945.12 S 29 Z3 W W 2001.48 5 29 23 W W 2058.15 S 29 23 W IN~TES HORIZ. DEPARTURE WEST DIST. AZIMUTH FEET DEG MIN ARCO ALASKA INC. D.S. 12-33 PRUUHOE BAY NORTH 5LOPE· AL.ASKA COMPUTATION D~TE: 15-MAR-B9 PAGE 7 DATE OF SURVEY: 18-FEB-~9 KELLY BUSHING ELEVATION: 7`$.00 FT ENGINEER: REYNOLDS INTERPOLATED VALUE5 FOR EVEN 100 FEET OF SUS-SEA DEPTH TRUE SUB-SEA MEASURED VtRTICAL VERTICAL DEPTH DEP'TH DEPTH 1 'COURSE TION AZTMUTH DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. ~ZIMUTH FEET DEG/IOO FEET FEET FEET DEG B6Ulo'T7 'r974.00 7900.00 S 39 15 W 2663.28 8715.85 8074.00 8000.00 S 40 1 W Z718.10 88Z9.~6 8174.00 8100.90 '~ S ~*11 7 W 2771.90 894Z.Z1 BZ'I~.O0 8200.00 S 42 24 W 2823.79 9063.19 ~314.00 8300.00 2 ,6 S 43 49 W ZBTZ.98 9164.3Z 8474.00 8400.00 2~ ,45 S 45 5 W Z919.64 9Z73.99 8574.00 8500.00 ~Z3 47. S 46 12 W 296~.11 9583.0Z B6/~.OO 8500.00 Z2 58 S 47 lZ W 3006.91 9491.19 8774.00 8700.00 22 0 S 48 39 W 3047.36 9598.66 8874.00 8800.00 21 7 S 49 24 W 3085.31 0.47 0.53 0.78 1 I .07 0.84 0.96 2.04 I. 04 0.37 2308.20 S 1350.17 W Z679.15 S 30 30 W 2350.45 S 1395.ZZ ,W 2733.36 S 30 ,$1 W 2391,47 S 1430,21 W 2786.51 S 30 52 W 2430.35 S 1464,87 W Z837.68 S 3! 4 W 2466.45 S 1498.72 W 28~6.10 S 31 17 W 2500.08 S 1531.67 W 2931.96 S 31 29 W 25.31.55 S 1553.8'3 W Z975.63 S 31 42 W 2561.40 S 1595.42 W 3017.63 S 31 55 W 2589.00 S 1626.06 W 3057.29 S 32 7 W 2614.80 S 1655.77 W 3094.96 S 32 20 W 9105.19 8974.00 8900.00 20 42 ~81Zo46 9074.00 9000°00 20 35 9980.00 9Z30.63 9156o63 20 51 S 49 26 W 3123.29 S 49 44 W 3159.52 S 50 Z~ W 3217.33 1.49 1 0.00 2639.77 S 1684,99 W 3131.70 S 32 33 W 26,53.95 S 1713.15 W 3167.Z6 S 3Z 44~ W 2701.88 S 1758.97 ~ 3223.99 S 33 3 W ARCO ALASKA D.S. 12-33 PRUDHOE BAY NOR'TH SLOPE INC. ALASKA MARKER SAt; SHUBLI& Z ONE '~ TUP SADLEROCHIT H.O.T. [J.W.C. GCT LAST READING PBTU TD COMPUTATION DATE: 15-MAR-89 INTERPOLA'TEg VALUES FOR CHOSEN HURIZONS SURFACE LOCATION = 169' ~SL & TVD FROM KB 8909.78 8932.18 900~.18 9004.18 9068.89 9105.38 9151.20 9185.71 9230.63 i~E~SURE9 OE~TH B E L 0 W Z ~:79637.00 9738. O0 9738 O0 ~9807:00 9933.00 9980.00 SUB-SEA 8835.78 9858.18 8930.18 8930.18 8994.89 9031.38 9077.20 9112.71 9156.63 KELLY OATE OF SURVEY: BUSHING ELEVATION: ENGINEER: PAGE 8 IS-FEB-89 7~.00 FT REYNOLDS 692' FEL, SEC18, TION~ R15E RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2623.76 S 1666.25 W 2629.35 S 167'2'79 W 2547.10 S 1693.53 W 2647.10 S 1693.53 W 2662.71 S 1711.70 W 2671.58 S 1722.25 W 2682.58 S 1735.65 W 2691.21 S 1746.08 W 2701.88 S 1758.97 W ARCO ALASKA U.S. 12-33 PRUDHOE BAY NURTH SLOPE, iNCo ALASKA MARKER S A G SHUULIK ZONE 4 TOP SADLEROCHIT H .O.T. U.W.C. GC1 LAST READING P~3TD TD COMPUTATION DATE: ~~:0~~ STRAT IGRAPHIC SURFACE ~*MEASUREO OEP'TH i~:BELOW KB 9637.00 9738.00 ~;9807.00 9846.00 9895.00 9933.00 9980.00 1S-MAR-89 SUMMARY LOCATION fVO FROM KB 8909.78 8932.18 9004.18 9004.18 906~.89 9105.38 9151.20 9186.71 9Z30.63 KELLY DATE DF SURVEY: BUSHING ELEVATION: ENGINEER: PAGE 9 18-FE~-89 74.00 PT REYNOLDS 169' FSL & 69Z' FEL, SEC18, 110N, R15E RECTANGULAR COORDINATES SU,~-SEA NORTH/SOUTH EAST/WEST 8835.7~ 2623.76 S i666.2.5 W 8858.1~ 2629.35 S 1672.79 W 8930.18 2647.10 S 1693.53 W B994.89 2662.71 S 17II.TO W 90~1.38 2671.58 S 1722.25 W 9077.20 2682.58 S 17~5.65 W 9112.71 2691.21 S 1746.08 W 9156.63 2701.88 S 1758.97 W t-INAL WELL LOCATION TO: IRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9980.00 9230.63 9156.63 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET BEG MIN 3223.99 S 33 3 SCHLUMBERGER O I RE CT I ONAL SURV E Y COMPANY ARCO ALASKA INC. 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T'T'?T'"~"'r'T'T" -.~.~..44-;+--~+-H-..~4-4-~+~--4--4--~--¢.-4.++-4- ~?..-~--~-~-q-~-.?.-~-~-+-f--:--i---~"-? ~'"~"'~"~'"!r:: ! ~ i ~ : ! ~ ~ ~ ~ : ~ ~ L4-~4-~4~--~-~-: ~ ~ ~ +..~-,-~-+-?~4 ..... ,~..-,.-?-~.--?..?-.*."? F--*"'?*'"? '-,-?r"T"'rT":-T"T'"~-*-r"r"¥ ~ ~ I I { [ } [ ~.{ ~ ~ { [ { ~-~-~-~-~ : ~ ~ i-'-~ {= i~'-~-"~?~"~-:"~-'r-~"~-"T'W~'"F"~"'F~'~T~ ,..~ { ] ,~ , ,~ ~ i t .1 { t i . i , i ~. i ~ i I l.d~, --~- } i' ,; ~ ,.~ { -< ,, ~ ~i { i ~. .... ~4-4-*.-.:; , ~.. ~... -~-~?--, --~.-T-~-~ , .~'~, i I i { { I{ [ [ { i i i i { i_i ~ L~..~...&4..4-L4-~ ~ 4~4-~4 ~:.~ -+-4-.-+-+---.4-.4-.+.4...-++++ ....... -2000 - 10120 0 0 1000 2000 :BO00 4000 S000 6OOO 21'7, PROJECTION ON VERTICAL PLANE 217. - 3?. ~ZALED IN vER?IC{:IL DEP'[I-16 HORIZ SCALE = 1/1000 IN/FT ARCO At_A~KA, INC. I:".O. BOX i00360 ANCHORAGE, ALASKA 995i 0 DATE: 8-~°-89 REFERENCE- ARCO CASED HOLE FINAI_~ i -4 5-26-89 i -1 7 7-3-89 "2-4 6-24-89 2- t 6 7-3-89 3-9 5-i ~-89 4-5 6- i t -89 4-t 9 5.-3t -89 7-i6 5-i-89 t t -t 3 5--24-89 t t -i 6 5-24-89 't t.-28 7-24-89 i i-28 '7-24-89 t i-28 7--24-89 t 2-2~ 6-4-89 t 2-25 6-i 5-89 ~-~.- 6-i -89 i2-St 6-2--.89 i 2-33 6-3-89 t4-2 7-3-89 i 4-2'7 6-29-89 i '7-9 6-i 6-89 PERF REC;ORD F'ERF RECORD F'ERF' RECORD F'ERF RECORD COL. LAR/F'ERF PERF RECOI;,'D F'ERF RECORD COLLAR/PERF PERF RECOF,'D P EF,'F RECORD CBT CE'/ GR F'ERF RECORD PERF RECORD F'ERF RECORD PERF RECORD PERF RECORD PERF RECORD PERF RECORD PERF RECORD RUN i ,..,.'~" I'JL~-" RUN i, RUN i ,..,.~'~'" i-iL-'--': I;,'UJ'~ i , RUN t , 5" HL£' RUN t , 5" HLZ RUN. IRON i, 5" HL~' RUN RUN i , 5" HL~ RUN i , 5" ~3CH RUN t , 5" ~CH RUN i, ~;'" 3'CH RUN ~, ~" HL~' RUN i, ~:" HL~' RUN}: i-6, 5" HL~ RUNZ'. t-6, 5" HL3' RUN~' i-3, 5 ~' HL~ RUN t, 5 ~ HLS RUN;~ t RUN i,' 5''~ .......: ..... HE2'" PLEASE SIGN AND-RE'¥URKk THE ATTACHED COPY AS RECEIPT OF' DATA. RECEIVED BY HAVE A NICE DAY! ... ~ALLY HOFFECKER AT0-t529 ..... ?:' --;.-/'~;: - D I ~IR I BU'F I ON CHEVRON .'::'~:; EXTENSION EXF'LORATION EXXON MARATHON MOBIL O&¢ f4 J OIL & B.O,iP,B. luspe.ction J:eport ~725 ~eserve Trip Tsr, h Fit Gauge · ,iml ' ~?~,..$ t~ck Annular Prevente: Pipe Rom~ ....... ._ ~lind R~mm... Choke Line Valves H.C,X. Valve £i1! Line Valves Check Yalve Drill: Contractor Location, Censral.~~Vell General Housekeepin8 Visual Audio , ~,~~ Full Chorea Pressure Pressure After Closure Pump inet. clos. pres. ~est Resulcm: Fatlures~ -- Repair or ~eplaceue~t of failed equipment to be made vithin Cou~ission office notified. acne:ks: 200 psi& min.~J~_sec. Full Cbmrie Pressure Attained: Controls: Hmlter ........ , ._ _ Kelly and ~1o,9~ Saf ety._Valve~ Upper Eel~y._ / Test Pressure ~ ............... ~oeer Kelly ~ Tes~ Pressure. __. Ball Type ~' Test Pressure , Inside BO~ .... ..~emt Presmure__..~D... .... ___ Choke Hanifol~~e~t Pzemsure Re, Valves lr~uicn].]~' ~,,~'r, rc.' c;~',~r* ] -- Test Time ~ ..-- !::" days and Inspector/ , Pist~!bution erie. - ~O&GCC cc - Operator cc - Supervisor Inspector = .. ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator ARCO Alaska, Inco 3. AdCr.e~.s Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 169' FSL, 692' FEL, Sec.18, TION, R15E, UN At top of productive interval 2478' FNL, 2386' FEL, Sec.19, TION, R15E, UM At effective depth 2522' FNL, 2438' FEL, Sec.19, TION, R15E, UM At total depth 2533' FNL, 2451' FEL, Sec.19, TION, R15E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 8. Well number 12-33 9. Permit number/approval number 89-10/9-156 10. APl number 50--029-21909 11. Field/Pool Prudhoe Bay Oil Pool 12. Present welt condition summary Total depth: measured true vertical Effective depth: measured true vertical feet 9980 'HD feet 9231 ' TVD 9933 'MD feet 9187 'TVD feet Plugs (measured) Junk (measured) None None Casing Length Size Structural Conductor 80 ' 20" Surface 3539 ' 1 3-3/8" Intermediate 9611 ' 9-5/8" Production 635' 7" Liner Perforation depth: measured None Cemented Measured depth True vertical depth 2150# Poleset 1lO'MD 2000 sx CS Ill & 3573'MD 600 sx Class G - Top job w/396 sx CS I 500 sx Class G 9643'MD 300 sx Class G 9344'-9979'MD 110'TVD 3503 ' TVD 8915 ' TVD 8639'-9231 'TVD true vertical None Tubing (size, grade, and measured depth) 5-1/2", L-80, tbg w/tail ~ 9714' ~".~.,. ~ C..~--I ~' ' ~D"~ PasCal~erSra[IbdBS-~'~Y(t~kPre~n?0r~J~iu~rel~lrdoe~nth;)2B' pkr @ 11242', & Camco 'Bal-0' SSSV ~ 2189' ~\~ ~]] '"'" 13. St~lation or cement squeeze summary ,. ,, ¢,, ~ ? ~. Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15. Attachments ,/' Gyro 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations '" w ~ Oil ~ Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"'~- ~. (~~~----~~- Title Regional Dri 11 ing Engr. Form 10-404 Rev 06/15/88"*(/ ; Compl eti on Wel 1 Hi story (DAM) SW04/027 Tubing Pressure Perforate ~ Other ~ Complete 6. Datum elevation (DF or KB) RKB 74 ' feet 7. Unit or Property name Prudhoe Bay Unit Date 3/z '~/~~ SUBMIT IN DUPLICATE 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing Repair well __ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a welt is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ~O A~,A~KA INC. Field ~ ~[JL;HO~ ~AI Auth. or W,O. noA$2530 Operator CountyI par'~rR~u~LOPE Lease or ur~mL: 28330 ITit e COMPLETE API: 50-029-21909 Spudded or Date and depth as of 8:00 a.m. 02115189 TD: 9980 PB: 9933 SUPV:TJ 03/16/89 ( TD: 9980 PB: 9933 SUPV:RWO J Date 03/14/89 JHour 2000 HRS Complete recorAr~c~ day reported RIM W/6" GR/JB ¸2) 7"~ 9979' MW: 9.0 NaCl State DS 12-33 Wetlno. ARCO W I 21.0000 Prior status if a W,O. MIRU AUDI 4. ACCEPT RIG @ 2000 ERS 03/14/89. ND TREE, NU BOPS. TST BOPE AND CHOKE MANIFOLD TO 5000 PSI, ANNULAR TO 2500 PSI. TST 9-5/8" CSG TO 3000 PSI F/15 MIN. RU WESTERN ATLAS. RIH W/8.5" GR/JB TO TOL @ 9350. POOH, RECVD SEVERAL LARGE PIECES RUBBER. RERUN 8.5" GR/JB TO TOL, POOH. MU 6" GR/JB AND RIH. DAILY:S153,490 CUM:$2,003,482 ETD:S2,003,482 EFC:$2,247,000 SET BPV AND ND BOPS 7"@ 9979' MW: 9.0 NaC1 RIH W/6" GR/JB TO 9920'. POOH. MU BROWN 7" '2-B' PERM PKR AND TAILPIPE AND RIH. SET PKR @ 9685' ELM. POOH, RD ATLAS. MU BAKER 9-5/8" 'SB3-A' PERM PKR AND 4-1/2" TAIL ON 5-1/2" MOD 8RD IPC CL B TBG @ 9714', & RIH. MU MCEVOY GEN 4 TBG HNGR & LAND HNGR IN TBGHD. FREEZE PROTECT TOP 2200' OF WELL .W/DIESEL. DROP BALL AND SET PKR @ 9265'. CAMCO 'BAL-O' SSSV @ 2179'. PU TO 215,000 LBS W/1500 PSI TBG PRESS TO SHEAR 'SEAL ASSY. RELARD HNGR & RILDS. ~ST TBG TO 3500 PSI F/30 MIN. PRESS ANN TO 3000 PSI, LEAKING. BOLDS AND PU HNGR. REPLACE HNGR SEALS AND RELAND. TST ANN TO 3000 PSI F/30 MIN. LD LANDING JOINT, SET BPV, ND BOPS. DAILY:S160,914 CUM:$2,164,396 ETD:S2,164,396 EFC:$2,247,000 T..,o..,.t ..... / , / , Signature/ /Pr / /.... / I"at. /' I .-- I'r,,,e For for~prjara6on and distribu~Lon, ~/ ~ & ' - Drilling Supt. INumber all daily well history forms consecutively as they are prepared for each well. iPage no. AR3B-459-1-D ARCO Oil and Gas Company .~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allow:~ble has been assigned or wrdl is Ph. Jqged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable !ength of time On w(~rkovers when an offi(:~41 Iest is not required upon completion, report comp et on and representat ve es da a in blocks provided The "Final Report" form may be used for reporting operation if space is available. District ARCO ALASKA INC. Field PRUDHOE BAY Icounty or ~O~TH SLOPE Lease or UADL: 28330 Title COMPLETE IAccom~ting cost center code State AK DS 12-33 lwell '~o. Auth. or W.O. ne%S2530 API: 50-029-21909 Operator J~°,CO Spudded or Date and depth as of 8:00 a.m. 03/17/89 ( TD: 9980 PB: 9933 SUPV:RWO AR.Co. W2.1 · 0000 Date 03/14/89 Complete reco~:[,,T~rIea4h day reported I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well if a W.O. IHour 2000 HRS Prior status :3) RIG RELEASED 7"@ 9979' MW: 9.0 NaCl ND BOP'S, NU MCEVOY GEN 4 5-1/2" TREE. TEST HNGR SEALS AND CONTROL LINES TO 5000 PSI. PULL TST PLUG AND INSTALL BPV. INJECT 530 BBLS SEAWATER DOWN 9-5/8" ANNULUS. FREEZE PROTECT ANNULUS W/200 BBLS 50/50 CRUDE. RELEASE RIG @ 1330 ERS 03/16/89. DAILY:S20,609 CUM:$2,185,005 ETD:S2,185,005 EFC:$2,247,000 Old TD New TD I PB Depth Released rig Date [ Kind of rig Classifications (oil, gas, etc.) Producing method Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choate size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected / Signajure I . ) ! I ~'_ ., / IDate ) / ix.,/~:~/~~~.-//rT/ ~/.~.~/~ Drilling Supt. sFe°; ,~;cr~e%ruerPe~ral~l,,.i~)nnu:ln, dsedic~tir~nbU~i0o, n' /~..~/v ~-~,.~/- 7- ~1 Drilling, Pages 86 and 87. ~ AR3B-459-3-C INumber all daily well history forms consecutively i Page no. as they are prepared for each well. I Division of AtlantlcRIchfleldCompany ARCO ALASKA, F'. O· BOX ANCHORAGE, ALA£KA DATE: 2--28-89 REFERENCE.' ARCO MAGNETIC I'APE~' W/LISTING t~ 33 2-tt-89 OH: BHC/DIFL/CZD/CZD-CNLo RUN 2 JOB~3719 RECEIVED BY HAYE A NICE DAY! $~ALLY HOFFECKER ATO- t 529 TRAN£ APF'ROVED .'~ PLEASE SIGN AND RETURN THE AI'TACHED COPY~A$ .RECEI OF DATA. ', DISTRIBUTION ATLAS CENTRAL FILES (CH) CHEVRON D&M TAMMA~ BROWN (OH) EXXON MARATHON MOBIL . PHILLIF'£ F'B WELL FILES ,S'AF'C STATE OF ALASKA TEXACO C, A 'T' E · 2.... 2 2 .... iii: 9 R E F' iii: i::.' [il N !:1:: E ' A R Ii:: 0 Pi A 6 N E T 1t1C T A P iii:,? W /t... :i1 ,S T 1t: N 6. P L. !iil A,'S ii. ,.S 'J: {1~-i"-! A N D R Iii: '~" U R N "[' !'-t Iii: A '¥' T A C i--i [il D C: (1} P T' A ,{.:; R Iii: C Iii: 1[ i." "[' C! I:: D A 'i"A., R E C iii: ]1 ¥ E D B Y ..................................................................................... · ' ' :'"~::' DAY! H~'::'~ V iii. A N I ........ ~i-:,~ A i... L. "~" i-'i ill)F:' !::' E C K Ii.:. R A T 0 .... i i:.}: 2 9 'i" F.: A N S" .'l,': 8 9 ,:}) '~ A t::' i::' !:;.'. 0 ",/i.:.'1D .... I..~ ...... ~V D 111 :S' T R I B U T ]10 N C: I'i N T IR A L. F' 1i1L. El S.' ( C: H ) C I.'i [il ¥ IR 0 N D ~:!.... H 'T'AHMA,?:,' BROWN ( C)i-.t ) E X X 0 N H A i::..' A T !..I 0 N H 0 B 111 t... C Z i)/C: N i...--'-G A i'"i H A ( F' C! F;:. (]) F' :l: L..i::.3' ARCO ALAJ:."KA, INC:~ F'~O, BOX i0(')'360 AN(":FiO!;'.AC;.E, ALAS'I< A DATE · 2-23-8? REFERENCE.' ARCO CASED HOLE FINALS S-,~O 2-S-89 COLI._AR/F'EF;:F i -i 5 2-i 7-89 COLLAR/PERF' t2'-~'=,., ~.'-~-i ~ :q --.q. c~ ~,, CBT 2-SS '2.- ~; 8-89 CET 7-4 2-i 7-89 COLLAR/F'ERF 8-9 2'--i 2-89 F'EF..'F' RECORD 8-2.5 2-! 7- 8'-7' CBT :::2-2'.:'5. ,~:- i 7-89 CET 8 - 22; 2 - i '? - 89 G i:;.'. - C C L PLEASE ,~IGN AND RETLIRN THE ATT~CHED COPY A,': RUN 1, ...'-:" RUM t, <.,-~ RUN i, 5" RUN t : 2"&.'5" RUN ~, ~'._.." RUN i, 5" RUM. i , ~.~"" F.'.UNt , 5" RUN i , ~'_," IF't- OF DATA, RECF_']: VED BY___ HAVE A NiCE DAY! SALI__Y HOFFEC:KER ~,TC - t ~<o, TRAN$ ~:'.,:.::. ~~ APF'ROYED DIS]'RIBUTION '"' F.'~NTC'AI FILES -,- CHEVRON D & M ~ EXTENSION EXF'LOR"t~TION · ,,-'"' EXXON HARATHON -.,- MOBIL F'H I L.I_ I F'S' F'B WELL F'Ii._E¢'',:. t:;,: & D SAF ~ STATE OF AI_A3'KA TEXACO STATE OF ALASKA AL,-,,.,KA OIL AND GAS CONSERVATION COM MIb,.,.'ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon I Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 169' FSL, 692' FEL, Sec.18, TION, R15E, UM At top of productive interval 2400' FNL, 2610' FEL, Sec.19, TION, R15E, UM (approx.) At effective depth 2500' FNL, 2506' FEL, Sec.19, TION, R15E, UM (approx.) At total depth 2513' FNL, 2520' FEL, Sec.19, TION, R15E, UM (approx.) 6. Datum elevation (DF or KB) RKB 74 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-33 9. Permit number 89-10 10. APl number 50-- 029-21909 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9980 'MD feet 9218'TVD feet Plugs (measured) None Effective depth: measured true vertical 9933 'MD feet 9175 ' MD feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3539 ' 9611 ' 635 ' measured None true vertical None Size 20" 1 3-3/8" 9-5/8" 7" Cemented Measured depth True vertical depth 2150 Cf Poleset 1lO'MD 110'TVD 2000 sx CS II! & 3573'MD 3502'TVD 600 sx Class G - Top job w/396 sx CS II 500 sx Class G 9643'MD 8910'TVD 300 sx Class G 9344-9979 'MD 8665'-9217'TVD RECEIVED Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Well Hi story Description summary of proposal FEB 2 ¢' :f.,~. ~, ' ' '.Alaska.0il & Gas Cons. ,Corrmiisslo %", chorage Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation Ha rch 1989 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 15. Status of well classification as: Gas__ Suspended__ ~:' ~ ~~t_ ¢//?,p. ~2o~t~'~.,N~'~Title Regional Drilling Engr. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance ~ Mechanical Integrity Test_ Subsequent form required 10- ~Z~ ~ App?'oved Copy Returned ,,~ 0R~GINAL SIGNED BY _..~_ ~ ~ _ ~ Approved by order ofthe Commissioner LONNIE C. SMITH -- Com----missioner JApproval No. Date ~ -~'~ -' ~:~,~' feet Form 10-403 Rev 06/15/88 055/5A4 SUBMIT IN TRIPLICATE ARCO Oil and ~as Company Well History- Initial Report - Daily instructions: Prepare and submit the "Initial Report" On the first Wedr~esday after a well is spudded or workover operations are started. Daily work 'prior to spudding should be summarized on the form giving inclusive dates only. County. parish or borough ]State,a~ District A~CO A~ASK~ INC. I NORTH SLOPE J I 28330 DS 12-33 Iwell n°' Field PRUDHOE BAY Lease or ~)% Auth. or W.O. ~2530 ITM DRILL API: 50-029-21909 Operator ,]~:~CO IARCO W.I. I 21.0000 Spudded°rW~l~un IOate 01/27/89 IHOur1800 HRS IPri°rstatusifaw'O' Date and depth as of 8:00 a.m. 01/27/89 ( TD: 110' ( SUPV: JLH 01/28/89 ( TD: 763'( SUPV:JLH 01/29/89 ( TD: 2068'( SUPV:JLH 01/30/89 ( 4 TD: 3218' ( 13 SUPV:JLH 01/31/89 ( 5 TD: 3590'( 3 SUPV:JLH 02/01/89 ( 6 TD: 3590'( SUPV:JLH RECEIVED Comp,et .... 1~6~1~ h ~.eported FEB 2 Naska 0i! & Gas Cons. C0mmi= ion "~, gnch0rage ' For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. L) NU DIVERTER 20"@ 110' MW: 0.0 VIS: L10) FIN MOVING RIG. ACCEPT RIG 0400 HRS 1/27/89. NU DIVERTER AND FLOWLINE. DAILY:S40,600 CUM:$40,600 ETD:S40,600 EFC:$2,247,000 I) DRILLING 20"@ 110' MW: 8.8 VIS:236 553) FIN NU DIVERTER AND FUNCTION TEST. LEVEL SUB STRUCTURE. PU 17-1/2" BHA& RIH. MIX SPUD MUD, HAMPERED BY COLD WEATHER. SPUD WELL @ 1800 HRS 1/27/89. DRILL TO 763'. DAILY:S60,356 CUM:$100,956 ETD:S100,956 EFC:$2,247,000 ) DRILLING 20"@ 110' MW: 9.1 VIS:213 105) DRILL TO 780'. ATTEMPT MWD SURVEY, TOOL FAILED, DROP SINGLE SHOT. POOH FOR BIT & MWD. RIH, SLIP & CUT, FIN RIH. DRILL TO 1242'. DROP SURVEY & POOH FOR BIT. RIH. DRILL TO 1868'. SERVICE RIG. DRILL TO 2068'. DAILY:S60,751 CUM:$161,707 ETD:S161,707 EFC:$2,247,000 ) SURVEYING 20"@ 110' MW: 9.5 VIS:120 50) DRILL TO 2194'. DROP SURVEY & POOH. CHANGE BHA& RIH. DRILL TO 3051'. DROP SURVEY & POOH. CHANGE BHA& RIH. DRILL TO 3218' (MWD FAILED). DAILY:S54,285 CUM:$215,992 ETD:S215,992 EFC:$2,247,000 ) CEMENTING 13-3/8" CSG 13-3/8"@ 3573' MW: 9.9 VIS: 69 72) ATTEMPT MWD SURVEY, TOOL FAILURE #2. DRILL TO 3346'. WIRELINE SURVEY. DRILL TO 3590'. CBU & DROP SURVEY. POOH TO HWDP, TIGHT HOLE 3000'-3060'. RIH, NO TIGHT SPOTS. CBU. POOH & LD BHA. RU CSG TOOLS & RUN 91JTS 13-3/8", 72#, L-80, BTC CSG TO 3573'. CIRC CSG VOL & RECIP PIPE. RU BJ & PUMP 100 BBLS FW SPACER. PUMPING 2000 SX LEAD CMT @ RPT ~IME. DAILY:S227,831 CUM:$443,823 ETD:$443,823 EFC:$2,247,000 TESTING KELLY 13-3/8"@ 3573' MW: 8.3 VIS: 27 0) FIN MIXING & PUMPING 2000 SX CS III @ 12.2 PPG + 600 SX CL 'G' @ 15.8 PPG. BUMPED PLUG W/ 2000 PSI, FLOATS DID NOT HOLD. HELD PRESSURE DURING TOP JOB. PUMPED 396 SX CS II TOP JOB, CMT TO SURF. PU DIVERTER, SET SLIPS, MADE ROUGH CUT. tVaNDE FINAL CUT. WELD ON CSG HEAD, TEST TO 1500 PSI. NU BOPS. TEST BOPS, TOP RAMS LEAKED. CHANGED RAM PACKING & RETEST, OK. INSTALL WEAR RING. PRESSURE TSTG KELLY. DAILY:S198,892 CUM:$642,715 ETD:S642,715 EFC:$2,247,000 AR3B-459-1-D Number all dally well history forms consecutively , no. las they are prepared f ..... h we . IPage I ARCO Oil 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 tesfs 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 "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 Field ARCO ALASKA INC. C°unty °r~5~H SLOPE Lease or %n~ 12--33 PRUDHOE BAY IWell .no. Date and depth as of 8:00 a.m, Complet ...... d f~31~l;~.~aY~il~e drilling ..... k .... in prog .... 02/02/89 ( 7) POOH FOR BIT & BHA 13-3/8"@ 3573' MW: 9.2 VIS: 29 TD: 5349'( 759) SERVICE RIG. PU BHA & RIH TO FLOAT COLLAR. TEST CSG 2500 SUPV:J"LH PSI. DRILL FC & CMT TO FLOAT SHOE. RETEST CSG TO 2500 PSI. DRILL FLOAT SHOE & 10', PERFORM LOT TO 13.9 PPG EMW. DRILL TO 5349'. DAILY:S48,365 CUM:$691,080 ETD:S691,080 EFC:$2,247,000 02/03/89 ( 8) POPOH FOR BIT 13-3/8"@ 3573' MW: 9.3 VIS: 30 TD: 6313'( 964) POOH. PU NEW BHA. RIH, SLIP & CUT, FIN RIH. WASHED LAST SUPV:JP/ZR 60'. DRILL TO 6313' DROP SURVEY & PUMP SLUG. DAILY:S47,942 CUM:$739,022 ETD:S739,022 EFC:$2,247,000 02/04/89 ( 9) SHORT TRIP 13-3/8"@ 3573' MW: 9.4 VIS: 32 TD: 7083'( 770) POOH. PU NEW BEA, TEST ANADRILL MWD, TOOL FAILED, PU NEW SUPV:JP/ZR MWD TOOL. RIH, WASH & REAM LAST 85'. DRILL TO 7083' SURVEY. SHORT TRIP TO 13-3/8" SHOE. DAILY:S60,142 CUM:$799,164 ETD:S799,164 EFC:$2,247,000 02/05/89 ( O) DRILLING 13-3/8"@ 3573' MW: 9.5 VIS: 34 TD: 7261'( 178) C&C. SURVEY & PUMP SLUG. POOH. RU WESTERN ATLAS. RUN SUPV:JP/ZR DIL/GR/CAL i~ND FMT/GR FROM 7083' TO 13-3/8". RD WESTERN ATLAS. CHANGE BHA, PU NEW MWD. RIH. DRILL TO 7261' DAILY:S98,717 CUM:$897,881 ETD:S897,881 EFC:$2,247,000 02/06/89 ( 1) RIM 13-3/8"@ 3573' MW: 9.7 VIS: 38 TD: 8043'( 782) DRILL TO 8045'. SURVEY & PUMP SLUG. POOH 7811', HOLE SUPV: MR TIGHT, PUMP OUT OF HOLE TO 7435' FIN POOH. CHANGE BITS & SERVICE WEAR BUSHING. .TEST MWD. RIH, LD (1) JT HWDP, SLIP & CUT. FIN RIH. DAILY:S56,049 CUM:$953,930 ETD:S953,930 EFC:$2,247,000 02/07/89 ( 2) DRILLING 13-3/8"@ 3573' MW:10.0 VIS: 44 TD: 8620'( 577) FIN RIM, WASHED & REAMED LAST 50'. DRILLED TO 8561'. MWD SUPV: ZR SURVEY. POOH FOR BIT. RIH W/ BIT # 10. WORKED TIGHT SPOT @ 7961'. FIN RIM. DRILL TO 8620'. DAILY:S54,582 CUM:$1,008,512 ETD:S1,008,512 EFC:$2,247,000 02/08/89 ( 3) DRILLING 13-3/8"@ 3573' MW: 9.9 VIS: 41 TD: 9315'( 695) DRILL TO 8689'. MWD SURVEY. POOH FOR BIT. RIH, WASHED SUPV: ZR LAST 48'. DRILL TO 9315'. DAILY:S53,439 CUM:$1,061,951 ETD:S1,061,951 EFC:$2,247,000 02/09/89 ( 4) SHORT TRIP 13-3/8"@ 3573' MW:10.4 VIS: 43 TD: 9656'( 341) DRILLED TO 9646'. C&C. SHORT TRIP, HOLE TIGHT @ 9346', SUPV:JLH WASHED & REAM TO 9550', 20' OF FILL ON BOTTOM. RAISE MUD WT TO 10.2 PPG. SHORT TRIP, 20' OF FILL ON BOTTOM. RAISE MUD WT TO 10.4 PPG. DRILL TO 9656'. CBU. SHORT TRIP. ' I DAIL~Y:$57,414 CUM:$1,119,365 ETD:SI, ii9,365 EFC:$2,247,000 s,g.,uril.). I / . // ,Date Title I I ~ ~rm ~reparation~ff'~o~.-ff~"fff~ut~ // / "'-"-- ' -- see Procedures Manual Section 10, / / Drilling, Pages 86 and 87 ,. ,Anchofa~~ AR3B-459-2-B INumber all daily well history forms as they are prepared for each well, Consecutively Page no. ARCO Oil 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 "Final" form. 1) Submit "Interim" sheets when lilled qut 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. Date and depth as of 8:00 a.m. District A~CO ALASKA INC. County OrNORTHParish SLOPE IStat,%,K Field ILease or Unit PRUDHOE BAY I DS 12-33 Comple, ...... dl~l~C[~aY2,,~e drilling ..... k .... in prog .... 02/10/89 ( TD: 9656'( SUPV:JH 02/11/89 ( TD: 9980'( SUPV:JH 02/12/89 ( TD: 9980'( SUPV:JH 02/13/89 ( TD: 9980 PB: SUPV:JH li) 0) 1 ;) 924) 1t) 0) lt) )) R/D CSG TOOLS 9-5/8"@ 9643' MW:10.4 VIS: 38 FIN 40 STD SHORT TRIP. CBU. POOH. L/D 12-1/4" BHA. CHANGE TOP RAMS TO 9-5/8", TSTD RAM DOORS TO 3000 PSI. PULL WEAR BUSHING. RU CSG TOOLS. RUN 225 JTS 9-5/8", 47#, L-80, BTC & BTC MOD TO 9643'. C&C WHILE BATCH MIXING CMT. PUMPED 50 BBL MCS-A SPACER @ 8.3 PPG. PUMPED 500 SX OF B. J. TITAN'S GAS BLOCK CMT @ 15.8 PPG. BUMPED PLUG W/ 3000 PSI, HELD FOR 10 MIN. R/D CSG TOOLS. DAILY:S308,000 CUM:$1,427,365 ETD:S1,427,365 EFC:$2,247,000 POOH FOR LOGS 9-5/8"@ 9643' MW: 8.9 VIS: 36 R/D CSG TOOLS. CHANGE RAMS TO 5" & TEST BOPS. INSTALL WEAR BUSHING. PU 8-1/2" BHA. RIH, SLIP & CUT, FIN RIH. TAG CMT @ 9551'. TEST CSG TO 3000 PSI F/ 30 MIN. DRILL FLOAT EQUIP TO FLOAT SHOE. RETEST CSG F/ 10 MIN. DRILL SHOE & 10' NEW HOLE, C&C, PERFORM LOT TO 10.7 PPG EMW. DRILL TO 9980' CBU, SHORT TRIP, CBU. PUMP SLUG, DROP SURVEY, POOH FOR LOGS. DAILY:S107,908 CUM:$1,535,273 ETD:S1,535,273 EFC:$2,247,000 RNG 7" LINER 7"@ 9979' MW: 9.0 VIS: 38 FIN POOH. RU WESTERN ATLAS. RUN DIL/BHCS/GR/SP F/ 9980'-9639'. RUN CNL/GR/ Z-DEN/CAL F/ 9980'-9639'. RD WESTERN ATLAS. RIH, C&C, DROP SS, POOH. RU 7" CSG TOOLS. RUN 15 JTS 7", 29#, L-80, BTC CSG & BOT LINER HANGER W/SHOE @ 9979'. CIRC LINER CAPACITY. RIH W/ LINER ON DRILL PIPE. DAILY:S108,590 CUM:$1,643,863 ETD:S1,643,863 EFC:$2,247,000 DRILLING CMT @ 9550' 7"@ 9979' MW: 9.0 WBM FIN RIH W/ LINER. C&C WHILE BATCH MIXING. PUMP 50 BBLS VISCOSIFIED MCS-A SPACER @ 8.3 PPG. PUMP 300 SX CLASS G, BJ GAS BLOCK CMT @ 15.8 PPG. RECIP LINER DURING JOB. BUMP PLUG & SET LINER HGR W/ 3500 PSI. RELEASE F/ LINER & POOH. RD CSG TOOLS. RIH W/ 8-1/2" BIT & SCRAPER, TAG CMT @ 9058'. DRILL HARD CMT F/ 9058'-9344' (TOL). CIRC HOLE CLEAN. POOH. RIH W/ 6" BIT & SCRAPER. DRILL SOFT CMT F/ 9343'-9550'. DAILY:S95,632 CUM:$1,739,495 ETD:S1,739,495 EFC:$2,247,000 02/14/89 ( NU DRY HOLE TREE 7"8 9979' MW: 9.0 NaCl TD: 9980 DRILL SOFT CMT TO LDG COLLAR. TEST CSG TO 3000 PSI. DRILL PB: 9933 LDG COLLAR & CMT TO FLOAT COLLAR. TEST CSG TO 3000 PSI. SUPV:JH CBU & INJECTED MUD. REVERSED IN 300 BBL FRESH WTR, 50 BBL HI-VIS PILL & 9.0 PPG NACL. CIRC UNTIL CLEAN NACL RTNS. TEST LINER TO 3000 PSI FOR 30 MIN. POOH & LD DRILL PIPE & BHA. FREEZE PROTECT W/ 29 BBLS DIESEL. ND BOPS. NU DRY HOLE TREE. FREEZE PROTECT 9-5/8" X 13-3/8" ANNULUS W/ 100 BBLS CRUDE. DAILY:~96,197 CUM:$1,835,692 ETD:S1 835,692 EFC:$2,247,000 The above is correct ~ / Signa~re I ~ ') ~' / For f~m~reparati~ and d~ibution see Procedures Manual Section 10, / / ¢ ' Drilling, Pages 86 and 87 / / IWell no. AR3B-459-2-B Number all daily well history forms conseculively /Page no as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been 'assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repod completion and representative test data in blocks provided. The "Final Report" form may be used for reporhng the entiro operation if space is avadable. Accounting cost center code District County or Parish State ARCO ALASKA INC. AK Lease NORTH SLOPE well Field or Unit no. ?RUDHOE BAY ADL: 28330 DS 12-33 Auth. or W.O. no. T t e AS2530 DRILL API: 50-029-21909 Operator A.R.Co. W.I. rTotal number of wells (active or inactive) on this~ Icost center prior to plugging and ARCO 21,0000 labandonment of this well Spudded or W.O. begun Date IHour Prior status if a W.O. / SPUD 01/27/89 ~ 1800 }{RS Date and depth I Complete record for each day reported as of 8:00 a,m. NABORS 28E 02/15/89 ( 2~ TD: 9980 ?B: 9933 SUPV:JH RIG RELEASED 7"@ 9979' MW: 9.0 NaCl FIN NU TBG SPOOL, INSTALLED 7" DUMMY TBG HGR W/ BPV, NU 7" DRY }{OLE TREE. TEST WELLHEAD ASSEMBLY TO 5000 PSI. PUMPED OUT CELLAR. SECURE WELL. RELEASE RIG @ 0930 HRS 2/14/89. DAILY:S14,300 CUM:$1,849,992 ETD:S1,849,992 EFC:$2,247,000 Old TD New TD Released rig Date PB Depth K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected For form preparation and distribution, see Procedures Manual, Section 10, /,/ ' -/ Drilling, Pages 86 and 87. Number all daily well history forms consecutively I Page no. ~ ~as they are prepared for each well. I 1 AR3B-459-3-C Olvlaion of AtlanticRIchfieldCompany 1:;.: E i::' Iii: i:;.: E i'".! C: ii: i::' L. !ii: A E: E ,? :i: (;;. N A N i) i:;.', iii:'i" U F..' N ]" :'i Iii: A"f' "f' A F'; i"i iii: :0 C: () t:" Y .."::'.,,?? t:;.: Iii: C ii!: :t; ?:' 7 (:) F' t;' A 'f' A ,. A 'f i... A J' A 1' !... r.':i ,: ,'::', 'f' i... i'::~ ,% I'-":'i f i... A ,'!i.' i"i -'". '..; t'2t , L,, t"! ,.;. ':'f f' i... ,'::'~ ;:.'i.~ I";: ti;: C: E ]: ",." F:' ¥) 'r:,' ',' i"i A ¥ ii!: ~'.":', i'".i ]; C: t!i: i) A Y ! E: A t... i... Y t"i ()F:' F:' Ii!: C 14 I.-] I:;.'. A'i"O ..... i527 t) :i: :!i.' '¥' I:;: ]: ii-,' LJ T ]: 0 N · ii-'I::' i"i :I: t... i... :i: i::' 1::' B W Iii: i... i... i::' :Ii I... liil i~ F;..' ,-':..:. :Ii: ,?:; A F' C :~,':.;!;"i" A 'f' iii: (] 1::' A L A E.' i( A :,'l: T iii: X A C ARCO Alaska, Inc. January 30, 1989 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Conductor As-Built Location Plat - DS 12 Pad (Wells 24, 30-33) Dear Mr. Chatteron- Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, ~.. I D. Martin Engineering Aide DM:czm Enclosure If you have GRU13/010 ~ V/C/N/FY MAP I "= ,~1000' t' · I ~ , i NOTES: +/u I. COORDINATES ARE ALASKA STATE zz, +" PLANE ZONE 4 ~1,,~ I , .jj~S i ~e ELEVATIONS ARE ARCO DATUM ~. f j~ 3. WELLS ARE WITHIN SEC. 17 ~ 18, +~ z~ - ' T~ I0 N., R. 15E. U.M. ~~ , /8~ /~ . J · WELL AS-BUILT THIS SURVEY I ' REFERENCE FIELD BOOK: I LPB 88-30 Pgs. 46-49 Well AZ.P Y AS.~ X LAT LONG. SECT/ON LINE DATA 24 5,9~0, 4~. 44 696, 935. OI 70° 1~'50.817" 1~°24' ql. 58~" 109' FSL 688' m~L SEC /8 ~0 5, 930, 730.5~ 697, ~05. 5~ 70° ~'53. 674" /48° 24' ~/. 835" 400' FSL 6' 31 5,930,541.79 696,9~1. OI XO° 1~'~1.994" 1~°~4' 41.846" 229' FSL 696"FEL SEC 18 3~ 5,931,J63.66 Egx, xIE.J~ XO° 1~'59.8X0" 148°~4' 18.0~0' IOJO' FSL 1~5' F~L SEC 33 5,930,482.~ 696,9~?.~ 70° I~'EI. 405" 148°~4' 41.XI5" 169'FSL 69~'FEL SEC ' ~~¢~;'5' I her,y certify that lam proper my registered ~ ~ ~ · ' .... ' ~ t and licensed fo practice land surveying in the We II Ce//er 8ox E/tv. ~ ~' ' ..~ ~Sfote of Alaska end th~ this plot represents on ~4. 4t. 0 ~RCO Datum / ~ ' ~.- .,~ ~ .~ '. ~ ~l-Built survey made by me or under my 30 40. 9' " ~ ".< ~ '~ "-~ ~ ' /.- .~ ..... ~ ........ ; ' '~oervision and that ~11 dimensions and other ~ 41.J' ,, /. . ............ . ~ ~ ~ ~.~ ~RTH SL~E DM~ICT - ~ ~. AS-BUILT DRILL SITE W ELLS 2.4, 50, ~1, 52, K. D.C. ~.4.~ AS-BUILT gk ~.~. ~ ~ i~'l DA~ ~ISlSS ~ E~ NSOPT 0000 ~ CEA- 1751- 003 January 23, 1989 Telecopy No. (907) 276-7542 T P Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc P O Box 100360 Anchorage, A~K 99510-0360 Re: Prudhoe Bay Unit DS 12-33 ARCO Alaska, Inc Permit # 89-10 Surf Loc 169'FSL, 692'FWL, Sec 18, T10N, R15E, UM Btmhole Loc 2475'FNL, 2666'FEL, Sec 19, T10N, R15E, UM Dear Mr Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The pe~tt to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pe~itting dete~inations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing 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 witness testing before drilling below the shoe of the conductor pipe. /~~tr~y~our s, Chairman : Alaska Oil and Gas Conservation Co~lssion BY O~ER OF THE COPSMISSION jo Enclosure Depar~ent of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA ,..,- AND GAS CONSERVATION CO,,IMISSION PERMIT TO DRILL 2O AAC 25.005 i la. Type of work Drill [] Redrill FqI lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone LJ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc RKB 74' PAD 41 'Glfeet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay 0il Pool P.O. Box 100360, Anchorage, AK 99510-0360 ADL 28330 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 169'FSL, 692'FWL,Sec. 18,T10N,R15E,UM Pr',,rlhn~ Ray Iln~. Statewide At top of productive interval 8. Well nu .tuber Number 2400'FNL, 2610'FEL,Sec. 19,T10N,R15E,UM DS 12-33 #8088-26-27 At total depth 9. Approximate spud date Amount 2475'FNL, 2666'FEL,Sec. 19,T10N,R15E,UM 01/25/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 1 2 - 1 5 89 ' 9990 ' MD 169' @ Surfac~et ~ 3234'MD/3199'TV[Ieet 2560 9217'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2200~et Maximum hole angle 2°7 Maximum surface 2870 psig At total depth (TVD) 3750 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5.~ H-4( Weld 80 7,0 7,0 11 ~)' 110 2f)~f)~ 17-1/2" 13-3/8" 68# K-5.: BTC 20 30 30 5 )' 50 2000 sx CS II I & 72# L-8( BTC 3521 50 50 357 ' 3500 600 sx CS II 12-1//4" 9-5/1~" 47#' L-8( BTC/Mo:I 9625 30 30 965~' 8919 500 sx Class G 8-1/2" 7" 29# L-8( BTC 635 9355 8652 999 ' 9217 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. (Contingency Liner Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate R/C[!VED Production Liner J ~, ;'~J ,j: ~' Perforation depth: measured true vertical ~l~JlJS~ 0il & Gas Cons, 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ Di~Ce~l]lll~..~Itch [] Drilling program ~ Drilling fluid program []'Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge~ Signed"~.~. ~~.,.~,.4~/,.......--''~ Title Reoional Drilling Fngl n~.~r' Date Commission Use Only L/,r..,~b_~ (GSW) PDi3/055 / Permit Number -APl number J Approval date See cover letter ¢~-/O 50- O~_~-.2. / ~O ~J 0.~/23/89/ for other requirements Conditions of approval Samples required [] Yes ,~ No Mud log required L-J Yes ,,~ No Hydrogen sulfide measures [] Yes ~No Directional survey required ~"Yes [] No Required working pressure_for B~;;ZR,E EZ]2M; [] 3M; ~ 5M; [] 10M; [] 15M Other: ~,,~~(/~ by order of Approved by Commissioner the commission Date Form 10-401 Re~5 Submit ir)/:riplicate PBU DS 12-33 OPERATIONS SUMMARY (INJECTOR) 1. MIRU drilling rig. 2. Spud well and drill 17-1/2" hole to 2200'and kick off. Build angle at 2.5°/100' to 27° 01' at S 36° 44' W. Drill 17-1/2" hole to 3500' TVD, 3571' MD. 3. Set 13-3/8" casing and cement same. Test casing to 2500 psi for 30 minutes. NU BOPs and test. , Pick up 12-1/4" bit and BHA. Drill 10' of new hole and perform leakoff test. Maintain angle and direction to 8919' TVD, 9655' MD (top of the Sag River Sand). Note if hole conditions allow, the 9-5/8" casing will be extended to TD. 5. Set 9-5/8" casing and cement same. Test casing to 3000 psi for 30 minutes. 6. Drill 10' of new 8-1/2" hole and perform leakoff test to 12.5 ppg EMW. Drill 8-1/2" hole to TD at 9217' TVD, 9990' MD (150' MD below the OWC). 7. Run wireline logs as programmed. 8. Set 7" liner and cement same. 9. Clean out liner and test casing to 3000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. 10. Release rig. Run cement evaluation logs and gyro after rig release. 11. MIRU completion rig. Run 5-1/2" tubing and packer assembly. Nipple up 5-1/2" tree and test to 3000 psi. Notify the AOGCC 24 hours in advance to final pressure testing of casing, tubing, packer and tree. 12. Rig up wireline and perforate. NOTE: If hole conditions allow, the 9-5/8" casing point will be extended to TD and the 7" liner will not be run. JAN 1 7 t98g ~a~l~ llil & Gas Cons. commission PBU DS 12-33 OPERATIONS SUMMARY CONT. NOTE: ao Excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interuption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. Well within 200' of the proposed well are: DS 12-15 DS 12-23 DS 12-16 89' @ 3199' TVD / 3234'MD 114' @ 2271' TVD / 2273' MD 196' @ 2874' TVD / 2884' MD C, The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi / ft). e. Based upon previous logs on DS 12, no potential productive zones are anticipated above 4000' TVD. f. No potential hazardous levels of H2S are anticipated in this well. D812-33 0 1000 2CI00 3000 4000 5000 60~ 7000 0 0' CASING T'~' -- 110 ,. 1000 - : looo I, i I ARC,:) ALA,SKA, ;;NC. 2[,00 r .... I ........ ~CALI= I IN 2.5 ~KoP TVD =2a~t0 SILL: 169' FSL, 892' FWL, ! i SEC: 12,5 THL: 2400'!FNL, 2610' FILL, 17.5 3000 .e,E~. EOC Tva ~ 32~+2 MO- 3281 DEP ~250 i 13-3/8' (:ASlNG Tva-- 3500 MU-3671 DEP-36:) ~rlO0 i ..... i, ,~OOO [,.l ~ 5000 ' - 8 8e ~'I~48 MIN W ' ~.: *VERAGE ANGLE ~ 6000 ~ ~__.. ~7 ~nm -,w .... j. ,, 6000 8000 ~-5 i'vo - 7884, MI) = 8605 D~_.~ Z~___ 8000 ~ L~U TVD-852~ MD-~212 DEP-2946 SAG RIVER T: ~ '~? MD = 9655 DEP -- 114/ ~ADLEROCHIT T'~D '9009 MD -9756 DEP = 3193 TARGET T~ D ' eOa4 MD , 97a4 DEP '; 206 4/W CONTACT T~ 'D "908~ M~ ' 9840 DEP ' 3232 TD/7' CSG .'VD-9217 ;~ -9990 DEP' 3299 i OqO0 ~ .... l OOOO ~ I 0 ~ 000 2000 3000 4000 5000 6000 7000 VERTICFIL SECTION .J £ - N COOROINRTES o -5000 -4000 -3000 -2000 - i 000 0 i 000 2000 z CD -5000 -4000 -3000 -2000 - ! 000 0 ] 000 2000 [ - N COORDINRT[S E - N OOOROINBT£S -5000 -4000 -3000 -2000 - ! OOO 0 ! 000 2000 0~ 12-2 ' ~~ ~U~ ' ' ' 603 91 , DS12- _ ~ , , III II I I I ' Anchor~ ~e i i I i i i I i i ~ i i i i i i .i i i i i I i i i i i ~ i i i i i i i i i i i i i ~ i i i ! i i i i i i i i i I I ~ ~ i i ~ -5000 -~000 -3000 -2000 -]000 0 ]000 2000 (..,0 W r-~ CD Z c~ I E - N COORDINRZES o L] [-~ ZO OS 1~-1 CD .... E - ~4 OOOROINf~TES~ -400 -300 -200 - O0 0 .100 200 300 68 Z I OS 12-1~ o I I i i i ! i I t I I I I · · i , , ~o9~ , ~300 ~ff', ES 12-23 ' ~ 286 ~b~/~ ' 0 , , 2~96 100 , , , ] 19~ ~ 3/077 , ~~ /~5~ "' ,, , ,---- &[ , , -400 -300 -200 - 100 0 100 200 300 £ - ~ COOROINBT£S DS 12-33 MUD PROGRAM DEPTH DENSITY (TVD) (PPG) PV YP INT. 10 min (CP) (#/100sqft) GEL GEL FL OIL SOLIDS TYPE (cc/30min) % % Surf 8.8 Funnel 40 to to 100 to 13-3/8" 9.2 to 60 Csg Pt. 250 30+ 50+ 25 0 8 Gel - Benex Spud Mud 13-3/8" 8.8 Minimum 2 2 5 25 0 3.5 Low Solids to to Possible to to to to to Non-Dispersed K-10 9.6 4 4 10 10 6.5 K-10 9.6 10 6 4 8 8 2 4 Low Solids to to to to to to to to to Non-Dispersed 9-5/8" PT 10.2 20 10 8 12 6 5 8 9-5/8" 8.8 5 2 2 5 8 2 4 Low Solids to to to to to to to to to Non-Dispersed TD 9.2 10 4 4 10 6 5 8 The above properties are to act as a basic guidline, actual fluid properties are to be adjusted to the hole conditions encountered. o 2. 3. 4. 5. 6. 7. EQUIPMENT - DRILLING FLUID SYSTEM Degasser Shakers Pit level indicator (with both visual and audio warning devices) Drilling flow sensor (with readout convenient to the driller's console) Trip tank Agitators Mud cleaner and centrifuges MUD SYSTEM NABORS 28E II MUD CLEANER MUD CLEANER II I I SAND TRAP 4 BBLS TRIP TANK PIT I 171 BBLS 130 BBLS I I I II PIT 2 PIT 3 81 BBLS 137 BBLS I II I PIT 5 117 BBLS PIT 4 179 BBLS PILL PIT 20 BBLS II II PIT 6 135 BBLS III CAVlEM SB-7 MUD CLEANERS (2 @ 750 GPM EACH) DESANDER 3 X 12" DIAMETER CONES ~J~H ~. ~ ~i DRILCO DEGASSER BRANDT CENTRIFUGE '~a~ D~ E Gas Con~ Co~o~ MUD PUMPS: 2 CONTINENTAL EMSCO FB-1600 ~.,~ ~chorage DACRO GAS BUSTER JG 8/6/87 NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. SCHEMATIC FILL-UP LINE I RISER I FLOWLINE 20" 2O00 PSI DIVERTER 10" BALL VALVE 10" BALL VALVE I I CONDUCTOR NOTE' ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 RESERVE PIT 10" VENT LINE WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. JG 8/6/87 13-5/8''r O0 PSI BOP STACK IAGRAM ACCUMULATOR CAPACITY TEST I I REVENTER J DRILLING i~ SPOOL DRLG SPOOL ~ CSG SPOOL ~ 1~-~/8" STARTING HEAD ALL BOP EQUIPMENT 5000 PSI RATED 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. R U N I N LOC K DOW N SC R EWS. $. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO $000 PSI AND HOLD FOR A MINIMUM OF $ MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST $ MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST $ MINUTES. BLEED PRESSURE TO ZERO. 9. 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 $ MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. 12. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST $ MINUTES. 15. 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. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. GSW 11/07/88 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ( 1 ) F e e .~/~C /~/F~ 1. (~ thru 8)"- ' ¢¢. F4<. l-,e-e (8) (3) Admin ~ /.//F/g~. 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Cas ~ ~zW~//H. 1-/8 - 8¢ (14 thru 22) (5) BOPE ~~.~¢~. (23 thru 28) Company /~fc~ Lease & Well No. YES NO 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 wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait Does operator have a bond in force .................................. ~F~ Is a conservation order needed .. .......... ......................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~/~ Does the well have a unique name and number ......................... ~Q 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string~provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic 'and list of equipment adequate~4~ Are necessary diagrams and descriptions of W~m~,~.~ BOPE attached. Does BOPE have sufficient pressure rating - Test to ~-Od~9 psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. REMARKS (29 thru 31) rev: 01/10/89 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. ,~ Additional Remarks: INITIAL GEO. CLASS STATUS AREA UNIT ON/OFF ! NO. I SHORE POOL J ~z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ..5 1~9-- 33 -//o4, PROGRAM: LISCAN REVISION: 5.1 PART NUMBER: W5790-PE32 Start. of execution: Fri 17 FEB 89 2:22p **** REEL HEADER **** LIS 89/04/02 ATLAS 01 I CROFI LH -ED, 'LIS CUSTOMER LIBRARY TAPE' **** TApE HEADER **** LIS 89/04/02 'DIFL, 4-ARM CALIPER MAIN & REPEAT.' FILE # 1 MAIN .001 1024 CN WN FN COUN STAT **** FILE HEADER **** : ARCO ALASKA, INC. : D.S. 12-33 : PRUOHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYP=# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 1 4 CURVES : NAME CODE SAMPLE// UNIT BYTES ! 3 4 5 6 7 8 9 10 11 12 13 14 ' TTEN SPD RFOC RILM RILD C13 C24 RB DEV CAL CHT 68 ~ 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 I ~API LB 4 F/MM 4 OHMM 4 OHMM 4 OHMM 4 IN 4 IN 4 DEG 4 DEG 4 IN 4 LB 4 DATA DEPTH SPD C24 RECORD 7094.000 29.99701 9.987284 7044.000 39.45732 11 · 21 0'37 6994.000 '40.07539 11.63734 6944.000 40.12259 12.71278 (TYPE# O) CILD RFOC RB 226.7103 4.792166 -1.844113 300.5396 4.260542 -1'.844113 276.2253 4.364677 -1.841252 414.5579 4.321323 -1.838395 966 BYTES * RILM DEV -3.415659 4.108430 368.3376 27.44466 3.438965 368.3376 -4.141390 3.897508 368,3345 -63.09183 2.715806 368,3318 GR RILD CAL 70.54956 4.410915 9.210625 73.86023 3.327349 10.65387 69.38846 3.620233 11.48842 53.65366 2.412209 12.52428 TTEN C13 CHT 1878.612 8.433969 -11498.86 2757.417 10.09736 -11498.86 2778.745 11.33950 -11498.86 2684.942 12.33579 -11498.86 6894.000 40.12259 11.71344 285.5757 4.452579 -1.838395 3.034703 3. 607968 368,3318 67.80464 3.501698 11.58362 2661.542 11.45378 -11498.86 6844.000 40.03169 11.31738 319.7200 4.817997 -1.829817 -18.46368 3.378779 368.3232 58.21855 3.127737 11 .03284 2726.558 10.74829 -11 498.86 6794.000 40.29269 11.76812 6744.000 40.63341 11.53366 6694.000 320.0671 4.011647 -1.829817 254.9394 4.610240 -1.838395 243.9141 21 .55782 3.211199 368.3232 9.062088 4.007215 368.3318 -1.797256 59.88629 3.124345 11.73804 85.00104 3.922501 11 .53802 83.67081 /. 2633.226 11.70797 -11498.86 2614.969 11.54237 -11498.86 2601.627 11 ?cAn~ 6644.000 40.19609 11.41917 6594.000 40.26970 11.49437 6544.000 39.9959g 11.67714 6494.000 41.66931 11.38041 6444.000 41.22581 11.60794 6394.000 41.00180 11.89204 6344.000 40.99591 11.54445 6294.000 40.99591 11.99051 6244.000 41.02571 12.13177 6194.000 40.99591 11.86662 6144.000 41.55391 12.27345 6094.000 40.99591 12.29098 6044.000 40.99591 317.2825 3.886299 -1.832365 301 .2227 4.012520 -1.830175 328.5891 4.070503 -1 .838395 237.7114 4.898629 -1.838395 227.7296 4.876879 -1.829817 307.4612 4.141461 -1.838395 716.9075 6.419368 -1.814695 977.9670 5.706385 -1 .640511 604.2490 6.196354 -1.471748 305.6646 5..349357 -1.303871 410.7236 6.055733 -1.126751 863.2883 7.021113 -0.9529552 466.1377 6.717334 -11.39510 3.163196 368.3259 -6.4720~8 3.407708 368.3237 -12.24152 3.229108 368.3318 -11.99607 4.263291 368.3318 -8.625734 4.291886 368.3232 -24.18622 3.426035 368.3318 -92.12671 I .652831 368.3289 -11 0.,91 02 I .230435 368.3318 -62.80780 2.117904 368.3318 -16.44202 3.579856 368.3318 -61.96814 2.731044 368.3232 -105.0476 I .432671 368.3232 -83.86679 2.502939 ~L ~ ~ 0 73.15741 3.151766 11.58713 72.53178 3.319803 11.64626 65.92918 3.043315 11.77118 77.82005 4.206782 11.52853 90.98181 4.391172 11.64964 78.50145 3.252443 11.90148 40.01607 1.394880 11.33792 32.55060 1.022530 11.83459 50.00725 1.654947 12.00549 63.46393 3.271561 12.56570 48.80811 2.434728 12.61679 3~ . 98592 1.158361 12.34917 49.80852 2.145288 2579.530 11.75508 -11498.86 2550.876 11.79815 -11498.86 2586.350 11.86521 -11498.86 2499.394 11.67665 -11498.86 2549.378 11. 691 35 -11498.86 2565.855 11.91092 -11498.86 2458.917 11.13139 -11498.86 2533.126 11.67866 -11498.86 2433.613 11.8?920 -11498.86 2436.984 13.26478 -11498.86 2406.479 12.96012 -11498.86 2377.865 12.40735 -11498.86 2347.541 12.27097 5994.000 41.99582 12.55780 5944.000 41.96602 12.67554 5894.000 41.69292 12.50360 5844.000 41.89902 12.52821 5794.000 41.40211 12.83276 5744.000 42.24559 13.41484 5694.000 41. 43781 13.36359 5644.000 41.99582 12.52957 5594.000 41.92232 13.45255 5544.000 41.99582 12.90305 5494.000 41.86922 12.50403 5444'.000 42.23972 13.02237 5394.000 51.03062 12.59311 697.2725 5.021573 -0.6305131 894.7009 6.289757 -0.4617959 563.6707 5.803807 -0.3053115 276.6479 4.710624 -0.1568416 402.2673 4.932729 0.4733700E-02 328.0066 4.140058 0.1567120 304.3071 3. 997148 0.3077671 232.3031 4.792258 0.4541282 362.1843 3.568004 0.5969803 312'.6157 4.159451 0.7288131 816.0564 5.116343 0.8764384 505.0774 3.683281 1.01~240 272.3503 4.267830 1.124353 -76.91316 1 .797912 368.3318 -115.6298 I .319352 368.3232 -77.15904, 1.894322 368.3232 -41.66551 3.760241 368.3318 -49.42584 2.724319 368.3318 -31.14592 3.286001 368.3232 -35.41656 3.307988 368.3232 -39.88147 4.1 43790 368.~3232 -18.$5161 2.841565 368.3232 -27.54558 3.125475 368.3345 -111.0457 1.489176 368.3232 -55.13164 2.160911 368.3281 -31.59880 3.589947 368.3315 43.84134 I .434159 12.49445 25.63806 1.117692 12.58601 45.47508 1.774086 12.50161 62.35451 3.614702 12.99638 53.36583 2.485909 12.89658 70.33452 3.048719 13.84530 68.64018 3 ~286154 13.51691 57.79327 4.304721 13.07462 65.50885 2.761025 13.72864 71 .48824 3 .-1 9881 5 13.19124 33.10356 1 .225406 12.62996 49.71057 1.979895 13.16555 83.13040 3.671741 13.15737 2344.631 12.43110 -1149~.86 2330.603 12.49648 -11498.86 2351 .062 12.49961 -11498.86 2359.762 13.46453 '~11498.86 2346.506 12.96039 -11498.86 2350.250 14.275?6 -11498.86 2329.209 13.67023 -11498.86 2330.604 13.61965 -11498.86 2312.861 14.00472 -11498.86 2323.088 13.47943 -11498.86 226?.039 12.75589 -11498.86 2261 .519 13.30873 -11498.86 2236.172 13.72163 -1 I 498.86 51.60262 4. 760565 1 .9731 27 1 3. 00547 1 .232623 368. 3318 S S':'S 6'07 1.670232 13.12966 2258.706 13.25385 -11498.86 294.000 540.2705 -111.3688 31.99770 2217.194 50. 99492 6. 3361 25 2. 074211 I . 850924 1 3. 03497 I 2.'90797 1 . 33431 6 368. 3232 1 2.971 47 -11498.86 -57.40543 3.952491 368.3318 5244.000 51.96503 12.68415 292.7056 7.354652' 1.435332 -91.50703 3.330542 368.3318 5194.000 51.07433 12.55642 353.8345 6.617942 I .535299 -40.78778 8.497936 368.3306 5144.000 51.73383 14.84219 111 .9536 10. 36487 I .631506 -64.39644 3.014964 368.3289 5094.000 50.95122 12.46660 397.2693 5.627979 I .723335 -51.49658 4.175398 368.3235 5044.000 50.99492 12.74675 265.0173 6.497627 1.822318 -75.92744 3.704521 368.3318 4994.000 51.56531 12.51567 335.9307 6.646566 1.906945 -126.4513 2.014101 368.3232 4944.000 52.26762 12.39927 586.2869 6.224208 1.989995 -114.7429 I .887439 368.3318 4894.000 52.00073 12.52987 64'9.9861 5.205158 2.074804 -117.2843 2.228833 368.3318 4844.000' 52.59441 12.41055 554.8613 6.753970 2.161242 -51 .93893 14.94158 368.3318 4794.000 52.92123 16.04984 65.58467 13.03727 2.241719 -122.9044 3.226521 368.3318 4744.000 52.86221 12.46548 54.44331 3.416403 13'00906 50.99953 2.826180 13.00054 31.21869 8.932268 14.69872 48.25830 2.517184 12.46365 49.40805 3.773338 12.95846 45.63536 2.976805 12.52362 21.77498 1.705649 12.45178 23.30444 1.538494 12.58716 22.98303 1.802252 12.44160 30.48692 15.24747 15.24849 20.63531 2.417057 12.48694 413.7263 9.347218 2.314302 2213.380 13.33396 -11498.86 2195.918 13.44466 -11498.86 2130.267 14.55525 -11498.86 2147.611 12.46069 -11498.86 2161 .062 13.17016 -11498.86 2067.694 12.53157 -11498.86 2111.651 12.50430 -11498.86 2070.152 12.64444 -11498.86 2081.097 12.47265 -11498.86 2010.060 14.44714 -11498.86 2038.730 12.50840 -11498.86 13.17688 4644.000 52.79462 12.39049 4'69'1::930' : "4'2410t3 2.398776 368.3318 444.4976 7.877130 2.478301 -115.3001 2.991595 368.3308 4 ¢5340 67 13.14834 31 .31027 2.249731 12.59827 13.11979 -11498.86 1989.370 12.80603 -11498.86 4594.000 52.20671 12.49504 589.8020 6.686608 2.557438 -115.4979 2.107574 368.3232 26.10884 1.695484 12.57166 1940.059 12.64827 -11498.86 4544.000 52.40092 12.52669 563.2439 7.932501 2.628410 -129.5135 2.338853 368.3318 22.23930 I .775430 12.51222 1937.536 12.49776 -11498.86 4494.000 52.00073 12.73821 223.5084 6.726567 2.693491 -54.94336 4.586963 368.3318 57.09293 4.474104 13.10612 1923.373 13.47402 -11498.86 4444.000 52.87962 12.55140 185.5561 6.361992 2.761933 -44.46622 5 · 1 90475 368.3235 64.86343 5.389206 13.23023 1926.703 13.90906 -11498.86 4394.000 53.02452 13.31469 4344.000 52.86812 12.60221 220.8851 5.137401 2.834608 209.7709 7.995753 2.895482 -49.03778 4.493813 368.3232 -65.27386 4.881227 368.3232 65.58942 4.527240 13.56202 - . 52.21944 4.767106 12.75917 1907.720 13.80935 -11498.86 : 1895.842,, 12.91613 -11498.86 4294.000 52.99472 12.62840 191.2039 6.142443 2.959803 -44.65570 5.342432 368.3289 58.37378 5.,230018 12.94061 1920.466 13.25272 -11498.86 4244.000 53.27431 12.55758 4194.000 53.00063 12.54028 159.7541 5.620645 3.02071 4 I 44. 4811 7.145810 3.080652 -31.64215 5.725943 368.3232 -33.86781 6.476939 368.3318 69.92181 6.259620 13.-42879 62.43745 6.921320 13.53481 1866.965 14.30001 -11498.86 1814.739 14.52934 -11498.86 4144.000 53.81831 12.68881 187-6924 9.279011 3.135985 -77.49286 6.151486 368.3232 44.36023 5.327866 12.68467 1773.575 12.68052 -11498.86 4094.000 54.00272 12.71127 226.5231 9.277548 3.190664 -85.51311 5.429882 368.3298 38.11589 4.414560 12.61529 1789.605 12.51930 -11498.86 -11498.86 3994.000 223.2746 -29.12788 83.21359 1750.196 53.86211 5.329923 4.288797 4.478790 14.75541 12.08858 3.300674 368.3232 13.42200 -11498.86 3944. 000 132.11 28 -36. 59445 68. 58580 1 751 . 303 53. 0741 i 7. 97321 5 7. 207895 7. 569287 1 4. 2861 3 I 2.69981 3.351 047 368.331 8 I 3.49297 -11498.86 3894. 000 1 35. 4246 -52 . 57440 57.44437 1740. 345 53.44470 9.051 207 7. 6081 57 7. 3841 85 1 3. 29332 1 2. 78471 3. 403317 368. 331 8 1 3 . 03902 -11 498.86 3844.000 119.6955 -47.46260 5?.12617 1727.004 54.51221 8.398737 7.678502 8.354532 14.11038 12.54405 3.445841 368.3318 13.32722 -11498.86 3794.000 148.5899 -65.64755 61.04245 1697.893 54.44461 8.638239 7.020331 6.729933 13.24379 12.52286 3.496126 368.3232 12.88332 -11498.86 3744. 000 1 52. 1737 54.19470 7.845417 12.62548 3.541431 -60.50732 6.838928 368.3235 62.61612 6.571439 13.09399 1665.294 13.56251 -11498.86 3694. 000 1 22. 6584 -59.01 268 57.1 5?52 I 692. 393 54. 23041 8. 796329 7. 694047 8 . 1 52719 14.61907 1 2. 53339 3. 576186 368. 3345 I 3. 57623 -11 498.86 3644.000 150.~931 -33.49814 74.80402 1623.148 55.40880 7.015558 6.137422 6.636003 14.72860 12.07863 3.625325 368.3232 13.40362 -11498.86 3594. 000 1 88.0555 -44. 45538 64.65892 1 721 . 481 54. 53860 5.538297 4.906594 5.31 7579 13.1 5261 I 2.711 84 3.678273 368. 3232 1 2.93223 -11 498.86 3544.000 53.99460 12.62665 -14.15468 0.9839517 3.693942 -46.64838 10000.00 368.3232 41.19005 10000.00 12.49224 1683.432 12.35783 -11498.86 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** : 450 : 7094.00 ENDING TAPE DEPTH 3502.00 FILE # 2 REPT .002 **** FILE HEADER **** lO24 . FORMAT ONE DEP TAPE DE 14 RECORD (TYPE# 64) TH PER FRAME PTH UNIT : FT CURVES : NAHE CODE SAMPLE# ! CILD 68 1 2 SP 68 1 3 GR 68 1 4 TTEN 68 1 5 SPD 68 1 6 RFOC 68 1 7 RILM 68 1 8 RILD 68 1 9 C13 68 1 0 C24 68 1 I RB 68 1 2 OEV 68 1 3 CAL 68 1 4 CHT 68 I UNIT BY MMHO 4 MY 4 AP1 4 LB 4 F/MM 4 OHMM 4 OHMM 4 OHMM 4 IN 4 IN 4 DEG 4 DEG 4 IN 4 LB 4 TES DATA DEPTH SPD C24 RECORD (TYPE# CILD RFOC RB O) 966 BYTES * _ -- SP RILM DEV GR RILD CAL TTEN C13 CHT 7094.000 23.99762 10.29253 226.7103 4.944654 -1.829817 -1. 219879 4.A14485 368.3232 79.95618 4.410915 9.648148 1854.215 9.003763 -11498.86 7044.000 27.99719 11.35686 303.8779 4.289222 -1.829817 -14.60127 3.406787 368.3232 75.16483 3.290795 10.87913 2750.766 10.40141 -11498.86 6994.000 28.99710 11.84746 277.4775 4.654045 -1.838395 -31.04430 3.865610 368.3318 68.29593 3.603895 11.83386 2757.993 11.82026 -11498.86 6944.000 41.49281 13.11194 421 .8748 4.430422 -1 .829817 -91.73138 2.659807 368.3232 52.91460 2.370372 12.95045 2709.080 12.78897 -11498.86 68e4.000 41..58960 11.95485 267.2891 4.456403 -1.835534 -16.36981 3.599442 368.3289 69.14711 3.480815 11.98867 2636.342 12.02248 -11498.86 6844,000 317.0291 /. ~ o~'~/, o -15.32183 "~ /, I r~7-~ ~ 62.40538 2622.738 I I I A1 ~7 TOTAL DATA RECORDS : STARTING TAPE DEPTH : **** FILE TRAILER **** 38 7094.00 ENDING TAPE DEPTH : 6798.00 **** TAPE TRAILER **** LIS 89/04/02 3711 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 498 **** REEL TRAILER **** LIS 89/04/02 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL R'E~L : 499 TOTAL RECORDS IN THIS PHYSICAL REEL: 499 End of execution: Fri 17 FEB 89 2:25p Elapsed ex~ecution time = 2 minutes, 16.0 seconds. SYSTEM RETURN CODE = 0 !. 4 R!LM i ] 5 RILD 6 RFOC ! ? SPD i 8 TTEN ! 9 CAL 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 FT 68 I LBS 68 1 INCH PROGRAM: LISCAN REVISION: 5.1 Start of execut±on: Fri 24 FEB 89 10:28m **** REEL HEADER **** LIS 88/11/02 ATLAS 01 'LIS CUSTOMER FORMAT TAPE' **** TAPE HEADER **** LIS 88/11/02 PART NUMBER: W 5790-P E32,,.~ NICROFILHED ,, '%,3 3719 01 'DIFL, BHC, CZD/CN/POR., CZD RAW DATA, DOWN & UP-CALIPER CLOSED' FILE # 1 MAIN .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : PRUDHOE BAY : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) -ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 16 CURVES : NAME CODE SAMPLE# UNIT BYTES 172.6888 435.8750 -232.3869 328.8125 61.71738 3940. 206 326.8750 0.1128000 475.7500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 63 10001.00 ENDING TAPE DEPTH = 9561.00 FILE # 2 **** FILE HEADER **** REPEAT.O02 1024 FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 16 CURVES : NAME CODE SAMPLE# UNIT BYTES I CILD 68 I MMHO 4 2 CHT 68 I LB 4 3 GR 68 I API ~:: 4 4 RILM 68 I OHMM 4 5 RILD 68 1 OHMM 4 6 RFOC 68 I OHMM 4 7 SPD 68 I FT 4 8 TTEN 68 I LBS 4 9 CAL 68 1 INCH 4 10 TEMP 68 I DEGF 4 11 SP 68 I MV 4 12 AC 68 I US/F 4 13 T2R2 68 I US 4 14 T2R1 68 1 US 4 15 TlR2 68 I US 4 16 TlR1 68 1 US 4 * DATA RECORD DEPTH RILO TEMP TlR2 10002.000 3.742437 176.3824 941.6250 9952.000 2.801207 (TYPE# O) CILD RFOC' SP TlR1 267.2056 4.332408 -85.87947 918.6875 356.9890 10.18997 958 BYTES * CHT SPO AC -11498.86 16.99831 44.18311 -11498.86 19.99799 GR TTEN T2R2 23.51654 2647.135 402.5625 26.27165 3913.725 RILM CAL T2R1 4.390697 -1.000000 556.3750 3.353658 -1.000000 9902. 000 412 . 6104 -11498.86 2.423594 10. 78381 I 9. 99799 I 76.9420 -98. 13342 80. 27261 575. 0625 41 2.31 25 852.000 451.9321 -11498.86 2.212722 8.593370 12.58660 178.0889 -t00.8626 86.52679 607.5625 441.8125 802.000 256.1328 -1149~.86 3.904224 14.97708 17.99821 178.6912 -99.89270 88.79790 622.5000 450.0625 752. 000 70. 73753 -11498.86 I 4.1 3677 23. 5161 3 16.99831 I 79. 0693 -94. 79269 94. 03883 650.1875 466.0000 9702.000 10.20991 97.94403 155.1760 178.8119 -28.59564 467.56Z5 352.5625 -11498.86 14.,99850 59.4~575. 9652.000 95.49966 10.47124 10.77491 175.4933 -44.35562 596.0000 421.5625 -11498.86 12.99870 87.60089 9602.000 314.0969 3.183731 0.4207515 171 . 2502 -239.8281 432.3750 326.5000 -11498.86 12.99870 63.76082 TOTAL DATA RECORDS : 65 STARTING TAPE DEPTH = 10002.00 **** FILE TRAILER ***.* ENDING TAPE FILE # 3 **** FILE MEADER **** MAIN .003 1024 24.03568 3928.562 406.7500 29.25264 3901.177 431.37510 22.44878 3924.520 44'2.5625 40.81635 3995.269 458.3750 233.2414 3930.1 01 338.5625 60.29395 3897.094 417.8125 59.51929 3928.007 369.2500 DEPTH = 2.694423 -0.2005000 571.0000 2.427699 -1.054501 605.8125 4.487932 -1.289000 621.3125 12.80936 -1.462501 645.2500 72.81310 -0.9735001 458.6250 10.03275 0.3292000 597.5625 10000.00 -0.1167000 474.0000 9554.00 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 1¸8 CURVES : NAME CODE 1 CAL 68 2 CN 68 SAMPLE# UNIT 1 INCH I PCT. BYTES 4 4 I 5 SSD 6 SSN 7 LSN 8 ZCOR 9 ZDEN 10 SPD 11 TTEN 12 HRD1 13 HRD2 14 SFT2 15 SHR 16 CHT 17 PE 18 PORZ DATA RECORD DEPTH SSD SPD SHR 10008.000 9472.055 20.99789 0.4498961 9958.000 8745.531 25.41180 0.7257980 9908.000 9233.125 20.07149 0.6718292 9858.000 9281.613 20.02779 0.6191308 9808.000 9132.059 19.99799 0.0298469 9758.000 8834.223 19.99799 0.5930799 9708.000 8123.984 20.02779 0.4334340 9658.000 8604.000 19.99799 0.5841018 68 68 68 68 68 68 68 68 68 68 68 68 68 68 I :~CTS- : 4~ I CTS 4 I CTS 4 I GMCC 4 I GMCC 4 I FT 4 I LBS 4 I CTS 4 1 CTS 4 I CTS 4 I DIM 4 1 LB 4 I BARN 4 I PCT 4 (TYPE# O) 9 CAL SSN TTEN CHT 8.110716 317.9683 2830.261 -11498.86 8.346430 278.4675 4034.875 -11,498.86 8.374350 245.2007 4075.494 -11498.86 8.368916 '235.7879 4051.042 -11498.86 8.581284 237.9051 3985.618 -11498.86 8.504240 227.1531 3988.996 -11498.86 8.594177 362.4189 4083.565 -11498.86 12.35357 195.9423 4021.641 -11498.86 94 BYTES CN LSN HRD1 PE 15.00000 116.9883 1203.880 '3.000000 17.94385 111.1444 1266.590 2.815699 23.54335 88.38431 1556.400 3.576504 21.49292 84.23941 1549.057 2.346389 22.00404 85.29210 1484.271 2.352778 23.66721 75.85820 1406.475 3.274696 11.67072 219.2530 769.5720 5.021253 26.61581 63.45021 1272.576 2.899550 CNC ZCOR HRD2 PORZ 19.00000 0.0000000 1584.842 9.090889 21.94385 0.1192750E-01 1638.053 9.714245 27.54335 0.5063070E-01 1861.505 16.45961 25.49292 0.1529802E-01 1981 .031 21.45132 26.00404 0.3442087E-02 1863.908 24.68439 27.66721 0.1305144E-01 1809.416 8.675200 15.67072 0.3311164E-01 1063.879 1.665174 30,61581 O. 1701747E-01 1 579. 060 14.40898 GR ZDEN SFT2 56.09416 2.500000 856.9146 58.70879 2.489715 1149.290 25.51431 2.378416 1323.557 34.94580 2.296053 1340.291 27.08081 2.242707 1271.092 33.95117 2.506859 1168.546 98.24272 2.622524 615.2209 55.36980 2.412251 1094.067 1 9. 99799 3976.803 411. 9590 662. 9336 0.1699831 -11498.86 25.71504 34.25316 2.084823 181 .9818 TOTAL DATA RECORDS : 66 STARTING TAPE DEPTH = 10008.00 FILE TRAILER **** ENDING TAPE DEPTH : 9584.00 FILE # 4 **** FILE HEADER **** REPT 1.004 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 18 CURVES : NAME CODE SAMPLE# UNIT I CAL 68 I INCH 2 CN 68 1 PCT. 3 CNC 68 I PCT. 4 GR 68 1 API 5 SSD 68 I CTS 6 SSN 68 I CTS 7 LSN 68 I CTS .8 ZCOR 68 I GMCC 9 ZDEN 68 I GMCC 10 SPD 68 1 ~T .11 TTEN 68 1 LBS 12 HRD1 68 1 CTS 13 HRD2 68 I CTS 14 SFT2 68 I CTS 15 SHR 68 I DIM 16 CHT 68 I LB 17 PE 68 1 BARN 18 PORZ 68 I PCT BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 . DATA RECORD (TYPE# O) 994 BYTES * DEPTH CAL CN SSD SSN LSN SPD TTEN HRD1 SHR CHT PE 10009.000 7.992857 9106.090 325.9673 16.99831 2683.732 0.4399561 -11498.86 , 15.00000 119.9880 1154.885 3.000000 CNC ZCOR HRD2 PORZ 19.00000 0.0000000 1587.841 9.090889 GR ZDEN SFT2 62.10423 2.500000 961 .9041 I 9,'99799 0.7300812 9909.000 9207.492 20.23380 0.6287510 9859.000 9279.246 19.99799 0.6684021 9809.000 9134.738 19.99799 0.6515630 9759.000 8936.738 19.99799 0.6217569 9709.000 7801.313 19.99799 0.4384370 9659.000 8702.355 19.99799 0.6251919 9609.000 2839.794 20.06940 0.1605251 -11498.86 8.346430 248.8799 4021.323 -11498.86 8.228148 247.7688 4003.577 -11498.86 8.346430 243.3348 4087.086 -11498.86 8.288445 222.5714 3972.022 -11498.86 8.424038 380.0051. 4004.354 -11498.86 12.20536 197.8629 3931.982 -11498.86 8.434351 134.1030 3945.180 -11498.86 135:2, 095 2.179051 25.56604 81.93091 1526.287 3.114723 22.86044 89.98140 1481.718 3.173161 21.99333 83.10571 1295.606 2.064891 23.40674 74.67131 1569.979 2.752505 7.186971 226.0645 779.8059 4.952218 26.58093 60.39481 1287.264 2.889564 59.15578 27.30330 341.0254 21.02301 16~8-693 13.98757 29.56604 0.3137047E-01 1851.487 21.49478 26.86044 0.3174681E-01 1821.825 22.24640 25.99333 -0.1088031E-01 1551.699 25.00258 27.40674 0.2737632E-01 1856.200 5.136202 11.18697 0.1809412E-01 1015.067 1.131520 30.58093 0.5077828E-02 1585.058 14.94715 63.15578 -0.7025695 517.7097 33.20399 1175.997 34.56888 2.295336 1312.548 26.06261 2.282934 1315.454 23.28673 2.237457 1093.747 69.80470 2.565252 1334.902 82.67926 2.631330 597.2756 59.33321 2.403372 1085.598 59.50980 2.102134 183.8523 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 68 10009.00 ENDING TAPE DEPTH = 9569.00 FILE # 5 REPT 2.005 1024 * FORMAT RECORD ONE DEPTH PER TAPE DEPTH 18 CURVES : NAME **** FILE HEADER **** (TYPE# 64) FRAME UNIT : FT CODE SAMPLE# UNIT BYTES / 4 GR 5 SSD 6 SSN 7 LSN 8 ZCOR 9 ZDEN 10 SPD 11 TTEN 12 HRD1 13 HRD2 14 SFT2 15 SHR 16 CHT 17 PE 18 PORZ 68 I API 4 68 1 CTS 4 68 1 CTS 4 68 I CTS 4 68 I GMCC 4 68 I GMCC 4 68 I FT 4. 68 I LBS 4 68 I CTS 4 68 I CTS 4 68 1 CTS 4 68 I DIM 4 68 '. I LB 4 68 I BARN 4 68 I PCT 4 * DATA RECORD (TYPE# O) 994 BYTES * DEPTH CAL CN CNC GR SSD SSN 'LSN ZCOR ZDEN SPD TTEN HRD1 HRD2 SFT2 SHR CHT PE PORZ 10009.000 9022.102 17.99821 0.4399561 9959.000 8239.215 20.68860 0.6740341 9909.000 8813.363 20.07149 0.5259531 9859.000 9455.316 19.99799 0.6929370 9809.000 9047,871 20.12459 0.6551862 9759.000 9202.852 19.99799 0.5840470 9709.000 7879.707 19.99799 0.4680769 9659.000 8636.496 8.228573 315.9685 2732.527 -11498.86 8.464287 276.9841 3890.852 -11498.86 8.426760 244,0172 4241.887 -11498,86 8.464287 245.2877 4021 .695 -11498.86 8.700003 249.6756 4250,383 -11498.86 8.611643 228,4856 4025.172 -11498.86 8.558500 377.5649 4040.820 -11498.86 12.23486 200.1764 15.00000 118.9881 1182.882 3.000000 19,84775 108.9672 1086.345 2.045002 25.70525 88.73032 1169.448 2.574648 25.84723 87.11150 1523.101 3.761909- 21.71503 88.02190 1525.648 2. 334t 04 24.45425 77.01831 1455.337 2.566957 6.712683 235.6656 758.3416 4.785213 25.67870 65.35020 19.00000 0,0000000 1531.847 9.090889 23.84775 0.2400132E-01 1368.230 12.73820 29.70525 -0.1585163E-01 1476.321 22.90790 29.84723 0.4303919E-01 1857.856 20.21899 25.71503 -0.1131457E-01 1886,599 24.28217 28.45425 0.3926803E-01 1816.456 6.577116 10.71268 0.3676970E-01 993.6013 0.7977921 29.67870 O. 451 21 57E-01 62.10423 2.50OO0O 851.9153 60.86493 2.439819 942.7656 32.01605 2.272019 922. 801 8 26.70567 2.316386 1321.778 22.85271 2.249344 1313.596 73.38741 2.541477 1220.065 69.36813 2.636836 612.9072 61.48018 2.457821 9609.000 2875.712 19.g9799 0.1899809 8.464287 125.9874 3940.206 -11498.86 61.81635 23.99762 391.9609 '31 °07021 65.81635 -0.7307620 665.9336 34.79115 64.96983 2.075946 165.9834 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 63 10009.00 ENDING TAPE DEPTH : 9601.00 FILE # 6 DOWN .006 **** FILE HEADER **** 1024 FORMAT RECORD (TYPE# ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 18 CURVES : NAME CODE I CAL 68 2 CN 68 3 CNC 68 4 GR 68 5 SSD 68 6 SSN 68 7 LSN 68 8 ZCOR 68 9 ZDEN 6~ 0 SPD 68 I TTEN 68 2 HRD1 68 3 HRD2 68 4 SFT2 68 5 SHR 68 6 CHT 68 7 PE 68 8 PORZ 68 SAM 64) PLE# UNIT BY 1 INCH I PCT. 4 I PCT. 4 I API 4 I CTS 4 I CTS 4 I CTS 4 1 GMCC 4 1 GMCC 4 1 ~T 4 I LBS 4 I CTS 4 1 CTS 4 I CTS 4 1 DIM 4 I LB 4 1 BARN 4 I PCT 4 TES , DATA RECORD DEPTH SSD 5PD SHR 9558.000 2973.703 23.99762 (TYPE# CAL SSN TTEN CHT I .510714 133.9866 2646.847 O) 994 BYTES * CN LSN HRD1 PE 15.00000 27.99719 400.9597 CNC ZCOR HRD2 PORZ 19.00000 0.0000000 681.9319 GR ZDEN SFT2 57.42970 2.500000 188.9811 2667.394 126.2542 23.02750 2094.079 0.1759639 -11498.86 24.82339 321.3738 17.91701 -0.6859043 547.7407 30.05115 9658.000 1.510714 25.54414 29.54414 7507.219 256.9768 128.5053 0.3115194E-01 22.99770 2111.292 769.8774 1031.386 0.4572849 -11498.86 3.135869 13.06777 9708.000 1.562276 7901.109 361.7612 22.99770 2162.823 0.4599951 -11498.86 9758.000 1.547508 8922.270 237.9601~ 22.99770 2136.544 0.6065708 -11498.86 9808.000 1.549936 8646.766 247.5,401 22.99770 2169.384 0.5602832 -11498.86 9858.000 1.510714 9457.910 243.9655 22.99770 2211.101 0.6575770 -11498.86 9908.000 1.549512 9245.711 222.9300 22.99770 2234.232 0.5528941 -11498.86 8.835850 203.5157 733.0667 5.093732 24,23825 83,99733 1403.105 2.299838 22.53825 84.96640 1279.675 2.064254 22.51440 86.44952 1633,890 3.277438 24.33603 71 .28070 1 467 2.972585 18.73175 109.3902 875.6992 2.223598 9958.000 1.565705 7911.496 269.1379 22.99770 1869.947 0.6042260 -11498.86 12.83585 -0.1345341E-02 983.1245 I .754184 28.23825 0. 731955 36E-01 1814.703 2.713464 26.53825 0.9951193E-02 1582.667 23.70944 26.51440 0.4387750E-01 2042.469 19.64581 28.33603 0.1797208E-01 ~1 8'9 ? · ?90 21.58459 22.73175 0.2858012E-01 1100.105 12.58926 84.95966 2.154156 164.8830 77.47636 2.434381 62?.3269 95.71017 2.621056 601.0745 133.3633 2.605227 1241.281 46.22025 2.258794 1043.120 44.19731 2.325844 1409.748 47.27243 2.293854 1194.523 94.56418 2.442277 748.7314 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** : 67 = 9558.00 ENDING TAPE DEPTH = 9989.00 FILE # 7 DOWN .007 **** FILE HEADER **** 1024 FORMAT RECORD (TYPE# ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 64) I CAL ~68 -1 2 CN 68 1 3 eNO 68 1 4 GR 68 1 5 SSD 68 1 6 SSN 68 1 7 LSN 68 8 ZCOR 68 1 q ZDEN 68 10 SPD 68 1 11 TTEN 68 1 12 HRD1 68 1 13 HRD2 68 1 14 SFT2 68 1 15 SHR 68 1 16 CHT 68 1 17 PE 68 '1 18 PORZ 68 I DATA RECORD DEPTH SSD SPD SHR 10009.000 9054.098 17.99821 0.459953'9 9959.000 8604.762 20.96809 0.7132362 9909.000 9080.418 20.39830 0.6426691 9859.000 9414.563 20.87129 0.6812180 9809.000 8993,492 20.87129 0.6147540 9759.000 9056.520 20.39830 0.5787088 9709.000 7794.891 20.99789 0.4471660 (TYPE# CAL SSN TTEN CHT 1.510714 308.9690 2695.930 -11498.86 1.628571 280.2671 3981.247 -11498.86 1.628571 250.9078 3886.659 -11498.86 1.576572 247.5691 3904.705 -11498.86 1.628571 255.1607 3937.668 -11498.86 1.576148 234.8590 3910.361 -11498.86 I .579872 374,4451 3938.508 -11498.86 O) I :N CH 4 PC.T. 4 PCT. 4 API 4 CTS 4 CTS 4 CTS 4 GMCC 4 GMCC 4 FT 4 LBS 4 CTS 4 CTS 4 CTS 4 DIM 4 LB 4 BARN 4 PCT 4 994 BYTES * CN LSN HRD1 PE 1 5 · 00000 119.9880 1204.879 3 ' '00 17.86339 115.1091 1246.887 2.657330 24.43199 87.37462 1370.009 2.546700 23.97760 90.53032 1478.463 3.613499 22.29375 86.31061 1310.592 2.032241 23.23846 74.93282 1542.130 2.674801 7.631 64-5 243.6312 738.3354 5.154871 CNC ZCOR HRD2 PORZ 19.00000 0.0000000 1407.860 9 ~09088 9-- 21.86339 0.8439407E-02 1518.332 12.92697 28.43199 0.1675933E-01 1691.941 20.12634 27.97760 0.3637162E-01 1799.698 21.70529 26.29375 -0.4688311E-02 1613.300 24.55827 27.23846 0.1018697E-01 1903.190 9.892666 11.63165 0.3926740E-01 1000.542 -0.1740311 GR ZDEN SFT2 74.12437 2.500000 881.9116 69.81052 2.436705 1088.688 26.17418 2.317915 1134.899 25.48991 2.291862 1310.169 25.23933 21244788. 1086.392 85.50697 2.486771 1312.006 69.15630 2.652871 593.4238 0.6157870 9609.000 2896.710 20.99789 0.2199780' -11498.86 1.628571 123.9876 3891.411 -11498.86 2.821653 63.67909 22.99770 460.9541 19.54169 ~'23; 344 .0991 8 67.67909 -0.7402910 660.9341 36.94708 1054.230 62.39030 2.040373 209.9790 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** **** TAPE LIS 88/11/02 3719 01 TRAILER **** 65 10009.00 ENDING TAPE DEPTH : 9593.00 TOTAL RECORDS IN THIS LOGICAL TAPE : 482 **** REEL TRAILER **** LIS 88/11/02 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 483 TOTAL RECORDS IN THIS PHYSICAL REEL: 483 End of execution': Fri 24 FEB 89 10:30a Elapsed execution time SYSTEM RETURN CODE : 0 : 2 minutes, 10.0 seconds.
