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Home My WebLink About192-145 - STATE OF ALASKA ) ALA~ lOlL AND GAS CONSERVATION COMI\¡..~iSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 52 KB 8. Property Designation: ADL-028297 11. Present Well Condition Summary: Total Depth measured 16465 true vertical 9446.83 Effective Depth measured 16273 true vertical 9339.86 Casing Conductor Surface Production Liner Length 80 4661 14584 1999 Size 20" 91.5# H-40 13-3/8" 68# L-80 9-5/8" 47# N-80 7" 26# N-80 Perforation depth: Measured depth: 16007 - 16027 True Vertical depth: 9196.64 - 9207.04 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Plug Perforations [2] Perforate New Pool D Perforate D 4. Current Well Class: Development [;?]' StratigraphicL feet feet feet feet MD 40 - 120 39 - 4700 38 - 14622 14466 - 16465 16147 - 16171 9270.78 - 9283.79 4-1/2" 12.6# "V'E ~~'):'\ . _rJt¡(rI AUG 3 () 2005 Stimulate DiJI.\ ",PtÞ. '!¡!.' r,,·.G:l.... "' i.~dß~,,1. ,"") ,;1', '.,. ,:"'¡'.\: Waiver D Time Exten'slorì'D'''') Re-enter Suspended Well D 5. Permit to Drill Number: 192-1450 6. API Number: 50-029-22322-00-00 9. Well Name and Number: t '. .AJmm~$sron Exploratory Service WB-03 10. Field/Pool(s): PRUDHOE BAY Field/ N PRUDHOE BAY OIL Pool Plugs (measured) Junk (measured) None 16273 SCio\g~NED S E P 0 1 2005 TVD 40 - 120 39 - 3993.76 38 - 8594.95 8528.22 - 9446.83 Collapse 470 2270 4760 5410 Burst 1490 4930 6870 7240 16176 - 16190 9286.51 - 9294.15 L-80 37 - 15847 4-1/2" Cameo TRDP-4A SSV 4-1/2" TIW HBBP Packer 4-1/2" Baker SABL-3 Packer 2205 14376 15832 RBDMS BFL AUG 3 1 2005 Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure 15. Well Class after oroposed work: Exploratory r Development P 16. Well Status after proposed work: Oil P Gas r WAG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name. Sharma, ine ves..tal _ / _." Signat~~_~ Form 10-404 Revised 04/2004 Tubing pressure SHUT-IN Service r GINJ r WINJ r WDSPLr Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Date 8/26/2005 Phone 564-4424 uKIG1NAL Submit Original Only ) ) WB-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 6/4/2005 Continued from 6/3/05 WSR... POH w/ PDS temp/pressure gauges.. Good data.... Set Baker IBP (elements) @15,820'. Circulate gas out above IBP while POOH. Freeze protect to 5500' with diesel. Test IBP to 500 psi WHP, good test. RDMO. Leave well shut in. Notify DSO of well status. Note: 3 3/8" IBP set at 15820' center of element. (1 element). /Top of FN at 15814'./ FN = 1.75" JDC./ OAL of IBP = 11.58' 5500# pull release. 1800# push down equalize 6/8/2005 T/I/O O/Vac/O CMIT Tx IA to 2000 psi (PASSED) [Secure Well] Fill & pressure up IA x T to 2000 psi w/ 31 bbls of crude. Passed on 1st attempt. Lost 60/70 1 st 15 mins, lost 30/20 2nd 15 mins for a total of 90/90 in 30 mins, Pass Bled IA x T RDMO Final WHP's 0/0/0 7/18/2005 CTU #5, PullIBP/Sand Lock Treat; Well Shut In Upon Arrival. MIRU. RIH to pullIBP. Tagged and latched IBP at 15825' ctmd. Released and POOH. IBP stuck at 2094' ctmd, possibly in paraffin or hydrates. Call out LRS to pump hot diesel. Cont' on WSR 7/19/05 .., 7/19/2005 CTU #5, PullIBP/Sand Lock Treat; Cont' from WSR 7/18/05... Stuck with IBP at 2095' ctmd (suspect hydrates). Wait on LRS and diesel. Pumped hot diesel down coil and IA. Had leak from flange on the bottom of ASRC's flowcross to x-over spool. Bled off WHP to tiger tank. Closed SSSV. Retightened flange & pressure tested to 1600 psi - good. Pumped 180 deg F 2% KCI down IA. CT broke free then stuck again w/ IBP @ 2025'. Continue pumping hot KCL down IA. CT broke free but pulling 10 -12 k# over. At surface. FP the IA w/ diesel to 3000' & FP the tbg to 3000' w/ 50/50 MeOH. IBP recovered but missing 2- 6" rubber elements and the 1" stiffening ring. RD OS BOP's. Begin RD ASRC's flowcross to replace API ring. Cont' on WSR 7/20/05 ... 7/19/2005 T/I/O=1000/180/140 Assist CTU. Pumped down the tubing; 53 bbls of diesel @160*. Pumped down IA; 135 bbls of diesel @ 190*,296 bbls of 2% KCL, 165 bbls of diesel. FWP's=1000/400/160 7/20/2005 CTU #5, FCO/Sand Lock Treat; Cont' from WSR 7/19/05... Load well w/ 10 bbl spear 50/50 MeOH - 260 bbls of 2% KCI - 45 bbls of 50/50 MeOH. RIH for FCO. CT @ flag depth. Reset depth to 15810.4' = corrected nozzle depth @ flag. RIH for dry tag. Sat down at 15996'. PUH. RBIH and jet through possible bridge. Continue RIH jetting with no returns. Line up to take returns to tanks, drop WHP. Establish partial returns and clean out to hard bottom at 16233'. Pump several FloPro sweeps. POOH. Top well with 50/50 methanol. Cont' on WSR 7/21/05 '" ) ) I ACTIVITYDA TE I SUMMARY cont'd 7/21/2005 CTU #5, Sand Block Treat; Cont' from WSR 7/20/05... At sutface after FCO. FP well with 50/50 MEOH. Injectivity = 2.0 bpm @ 850 psig WHP. MU and RIH with 2.5" BON assy (no checks). Tag and confirm TO at 16235' . Mix and pump 16 bbls of 7ppg 16/20 Carbolite slurry (3500# bulk). Lay-in sand at 1 for 1 from 16230'. Pull to safe and wait for sand to settle. RIH to tag sand top. Tag sand top @ 16068', PUH. RIH & wash sand down from 15500' to 16020'. Dry tag sand top at 16045'. Pumped 50/50 MeOH down CT backside @ 5.0 bpm. Dry tag at 16046'. PUH. Confirm tag @ 16045', POOH. RIH with 2.5" JSN assy. Perform treatment on perf interval 16007' to 16027' as per program; pumped 20 bbls - 7% HCL acid, 50 bbl KCL spacer, 23.5 bbls Sand Lock V, 50 bbl KCL overflush. Max. treatment pressure = 1140 psig WHP @ 1.2 bpm. Wait for resin to set. Cont' on WSR 7/22/05 ... 7/22/2005 CTU #5, Sand Lock Treat; Cont' from WSR 7/21/05... Wait on resin treatment to set-up. RIH to clean out sand plug. Found top of sand at 16050'. Cleaned out to 16197' CTM using FloPro sweeps. Obstruction was encountered at this depth in earlier runs, suspect old cement node or ledge. Chased last FloPro sweep out of liner @ 50% until in 4.5" tbg & chase out @ 60%. Swap to diesel @ 5770' while POOH to lighten hydrostatic & FP well to 4150'. RDMO. Well handed over to ASRC for flowback thru test sep. DSO notified of well condition. Note: Electronic depth counter was found to be considerably off depth at surface, hence the actual TO of 16235' was probably reached. ***Job Complete*** BBLS 382 603 175 890 2139 20 143 16 13 23.5 4404.5 FLUIDS PUMPED 50/50 Methanol Diesel 1 % KCL 2% KCL 20/0 XS KCL 7% HCL FloPro 7ppg 16/20 carbolite slurry (3500# bulk) Gel Sand Lock V TOTAL bp -) ) .,. ..\-'.'11. -......~ ~....- ~~- ~~~ '-."\ F..... ·'1'·"1'" ". Terrie Hubble Technical Assistant GPB Drilling & Wells BP Exploration (Alaska) Inc, 900 East Benson Boulevard P,O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 25, 2005 Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Well Name Changes RECEIVED APR 2 7 2005 Alaska Oil & Gas Cons. Commission Anchorage Direct: (907) 564-4628 hubbletl@bp,com Mr. Steve McMains: The operator respectfully requests that the following wells within the Prudhoe Bay Unit be re-named as follows: Current Name New Name Permit # API # L6-25 N K-25 197-068 50-029-22760-00 L6026 NK-26 194-005 50-029-22440-00 N K-34 L5-34 1 98-085 50-029-22883-00 NPBST03 WB-03 192-145 50-029-22322-00 We recently have learned that while we have been using these corrected names for some time, an official request to the AOGCC to make these changes was never generated. These new well names identify more correctly the surface location from which the wells were drilled. Thank you very much for your assistance in this matter. Sincerely, -£ thWL Terrie Hubble Distribution Well Files PDC Marian Sloan Performance Unit Partners Conoco Phillips - Sandra Lemke Exxon - Phillip Thibodeaux ~C'L~\ïi\.iE-·¡~, nOl:' ~~ S-i 2.005 \:~l .,M,r\!lr~_ L~ .. ,j \ t.. \..} STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 52 feet 3. Address Exploratow___ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5205' FNL, 3487' FEL, Sec. 25, T12N, R14E, UM (asp's 687707, 5982964) NP-03 At top of productive interval 9. Permit number / approval number 2453' FNL, 1505' FEL, Sec. 22, T12N, R14E, UM (asp's 678929, 5990788) 192-145/(397-211 12/2/1997) At effective depth 10. APl number 50-029-22322 At total depth 11. Field / Pool 2060' FNL, 1769' FEL, Sec. 22, T12N, R14E, UM (asp's 678654, 5991171) North Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 16465 feet Plugs (measured) Tagged PBTD (1/31/2000) @ 16222' MD. true vertical 9447 feet Effective depth: measured 16222 feet Junk(measured)ORIGINAL true vertical 9312 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 121' 20" 11 yards AS 121' 121' Surface 4648' 13-3/8" 3579 cuft E, 464 cuft Class G, & 4700' 3994' 235 Sx C Intermediate 14570' 9-5/8" 518 cubic It Class G 14622' 8595' Liner 1989' 7" 731 cubic It Class G 16465' 9447' Perforation depth: measured 16007'- 16027'; 16147'- 16171'; 16176'- 16191'. AUG 22 2000 true vertical 9197' - 9207'; 9271' - 9284'; 9287' - 9294'. Tubing (size, grade, and measured depth) 4-~/2", 12.6#, L-80 PCT @ 15647' MD. ' Packers & SSSV (type & measured depth) TIW HBBP, 9-5/8" X 4-1/2" PACKER @ 14376' MD; BAKER SABL-3, 7" X 4-1/2" PACKER @ 15837' MD. 4-1/2" CAMCO TRDP-4A SSSV, ID=3.812" @ 2205' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 382 1185 4186 - 716 Subsequent to operation 773 18727 1133 2134 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __X Gas __ Suspended _ Service 17. I hereby certify that the~for~gcng, is tru_e and correct to the best of my knowledge. "-'"' /¢/f-~f' ~,c ~.~.~.~,/ -/ North Prudhoe Bay 3 Detail Remedial Work Chronoloqy Date Operation 10/21/1997 POOL 6 ACCEPTED ON PAD TO DRILL WB-05 11/14/1997 RECORD SBHP, PRESS. 3695 PSI AT 9245' SS DATUM 11/18/1997 APPLICATION FOR SUNDRY APPROVAL SUBMITTED BY AAI 11/26/1997 POOL 6 REACHED TD OF WB5 11/27/1997 POOL 6 APPROVED TO SIDETRACK WB-05 12/03/1997 AOGCC APPROVED SUNDRY APPLICATION (APPROVAL 397-21) 12/10/1997 PRE IBP PULL DRIFT AND TAG, TAG @ 16,165' CSLM; TIGHT AT 14275' 12/14/1997 LOAD WELL IN PREP TO PULL IBP 12/15/1997 FISHED IBP, LEFT ELEMENT IN HOLE; FCO FROM 16150 TO 16250 12/15/1997 12% HCL ACID STIMULATION (PRE-SQUEEZE): INJECTIVITY IMPROVED AFTER ACID. 12/16/1997 DRIFT/TAG (POST FCO); TAGGED AT 16,266' ATTEMPT TO RECOVER IBP ELEMENT 12/17/1997 DRIFT/TAG (POST FCO)@16,274' (20' FILL) 12/19/1997 NPB3 REMEDIAL WORK SHUT DOWN, UNSAFE SIMULTANEOUS OPERATIONS, WILL RESUME FOLLOWING RELEASE OF RIG & CAMP 12/21/1997 POOL 6 AT TD ON WB-05A 01/16/1998 POOL 6 RIG RELEASED, WILL BE LEFT ON PAD PENDING ICE ROAD CLEARANCE FOR ALPINE 02/11/1998 POOL 6 CAMP OFF PAD; ACCESS RESTRICTIONS LIFTED 02/14/1998 DUMMY OFF GL; L/T; TAG TD; IN PROGRESS (PRE SQZ) 02/15/1998 D/T @16,268, 54' RH; TEST I/A 2000; GOOD TEST (CEMENT SQZ) 03/03/1998 WSO CEMENT SQZ; 4 bbp, 3500 psi; CO TO 16263', TBG FRZ PROTECTED TO 2500' 03/06/1998 PT SQZ TO 1500~, FAILED,TAG'D TD @16,278 (16' FILL) 03/20/1998 CET (ATTEMPTED, COULD NOT GET PAST 10100') 03/21/1998 CET/SBHP; SOME SMALL CHANNELS BUT WATER ISOLATED AND IVISHAK ISOLATED FROM SAG. SBHP 4209 AT 9220'SS(press. Survey invalid) 03/22/].998 SAND PLUG (PRE-FRAC); LAY IN 7100#, REVERSE OUT TO 16065' IT @ 1.8BPM & 1900 PSI, FP WELL. 03/23/1998 PERF (PRE FRAC 16007-16027', TAG AT 16071', IN PROGRESS) 03/30/1998 PUMP IN TEMP. SURVEY IN PROGRESS 03/31/1998 PITS, VERY LOW INJECTIVITY; SQZ'D PERFS @ 15,948' MAY BE TAKING FLUID 04/01/1998 PRE-PITS SBHP @ 3913 PSI @ 9245'SS DATUM. 04/02/1998 TAGGED W/ 3.5" CENT @ 16,076', RAN FRAC SLEEVE (PRE-FRAC) 04/11/1998 SAG FRAC: 118K% CARBO BEHIND PIPE, 46K~ IN CSG, 72 BBLS FLUSH AWAY 04/12/1998 CTU FREEZE PROTECT TUBINGWITH 60/40 TO 2500' 04/13/1998 FCO TO 16,100' PART PIPE IN LUB AT 12063' MD, CT TOP EST'D @ 4000'; FRZ P TO 2200' W/ 60/40; RDMO (POST-FRAC) 04/14/1998 PULLED FRAC SLV; TAG C/T FISH W/ LIB 84170 04/15/1998 CIRC IN FILTERED WTR, VIDEO CT FISH@ 4155' VLM 04/15/1998 SWAP WELL OVER TO FILTERED WATER; PRE VIDEO 04/15/1998 VIDEO LOG TOP OF FISH; 50 BBLS FRESH WATER, FRZ PR TO 2200' 04/18/1998 MILL/DRESS CT TOP, PLANT OS, FISH CT (POST FRAC/FCO) IN PROG 04/19/1998 MILL TOP OF CT, SET OS, FISH COIL; WHP @ 2400# (IN PROGRESS) 04/19/1998 RAN LIB'S, RUN OVERSHOT (ASSIST CTU) - IN PROGRESS 04/20/1998 LATCH CT FISH @ 4,200' CTM, PULL TO 4,080' (FISH CT IN PROGRESS) 04/20/1998 RAN OVERSHOT ON CT FISH (ASSIST CTU) 04/21/1998 FISH, 12,060' OF COIL, OOH, FP WELL 04/22/1998 D&T TO 12,623 SLM ,GEL SAMPLE ,RUN GLV (POST FCO/FISH) (IN PROGRESS) 04/23/1998 COMPLETE OGLV INSTALLATION, 51/64" IN STN3 (POST 04/24/1998 ATTEMPT TO FLOW WELL WITH SAND IN LINER, NO GO Page 1 North Prudhoe Bay 3 Detail Remedial Work Chronology Date Ooeration 04/30/1998 POST FRAC FCO (IN PROGRESS) 05/01/1998 FCO #2 F/ 14,500 (TOP PERF 16007') TO 16,100' CTM (POST-FRAC); WELL ON VACUUM. MADE ONE ATTEMPT WITH CRUDE, SOME PROPPANT STILL IN WELL. 05/01/1998 FREEZE PROTECT WELL 05/02/1998 INITIAL TEST: 2141 FTP, 800 BOPD, 217 BWPD, 9.9 MMSCPD GAS (WATER MTR NOT CALIBRATED) 05/02/1998 WELL TEST: 1509 FTP, 1833 STBOPD, 944 BWPD, 27 MMSCFPD (WATER METER NOT CALIBRATED) 05/02/1998 L1 MANIFOLD PIPING FAILED DOWNSTREAM OF NPB-03 CHOKE; 120 GALLON SPILL; 425 LBS. HALON DUMPED. WELL SHUT-IN PENDING INVESTIGATION. 06/03/1998 DRIFT AND TAG @ 15950' CSLM; SITP 2500 PSI, SBHP 3690 06/10/1998 RIG UP PTS FOR FRAC FLOWBACK 06/11/1998 FRAC FLOWBACK IN PROGRESS - RATES AT 300 TO 2100 BOPD, 10 TO 15 MMSCFPD GAS AT 2100 TO 2500 PSI WHP 06/12/1998 FLOWBACK HAVING PROBLEMS DUE TO HYDRATES AND TOO BIG A WELL FOR PTS AND OPEN TOP TANKS. 06/13/1998 FRAC FLOWBACK REINITIATED, RATES AT 300 TO 2900 BOPD, GOR AT 12M; HAVEING PROBLEMS OPERATIONALLY 06/14/1998 DRIFT-TAG @ 15,930' SLM - HARD BOTTOM 06/15/1998 FRAC FLOWBACK ATTEMPTED AGAIN: RATES 1800 TO 6000 BPD, GORS HIGHLY VARIABLE 6m TO 22m 06/16/1998 FRAC FLOWBACK SHUTDOWN, COULD NOT SAFELY OPERATE FLOWBACK AND DUMP TO TANKS. RE-EVALUATE OPTIONS. 08/26/1998 DRIFT TO SET SAND SCREEN, ASPHALTENES @ 14,250' 08/27/1998 PUMPED DIES/XYL, RAN GAUGE RING 08/28/1998 ATTEMPT TO RUN SAND SCREEN. BRUSH ASPHALTENES, FLOW WELL 08/30/1998 DRIFT FOR SAND SCREEN W/3.805" CENT TO 15,432' 09/04/1998 FCO (PRE-SCREEN) IN PROGRESS; SITP 2400 PSI; RIH TO 3800', NOTICED PIPE DAMAGE, POOH. 09/07/1998 PULLED DGLV STN 5 (PRE LOAD & KILL F/ FCO) 09/09/1998 JET TUBING FOR SAND SCREEN INSTALLATION 09/11/1998 DRIFTED TO 15,455' SLM (392' SHORT OF TT) W/20' x 3.78" (PRE SCREEN) 09/12/1998 DRIFT TO 15820' WITH DUMMY; MAKE UP SCREEN ASSEMBLY RIH, TAGGED UP AT 15438' WORKED TO 15478' POOH; HUNG @ 10663', LEFT SCREEN IN HOLE. 09/13/1998 FISH SCREEN: NO LUCK WHILE CIRCULATING, DROPPED CUTTER BAR IN WELL. 09/14/1998 FISH SCREEN: CIRC. CRUDE DN IA THRU STN 5 OPEN POCKET; NO LUCK WITH SCREEN, RETR'D SPANGS. 09/14/1998 RAN CHECK-SET TOOL: TAGGED @ 10673', X-LOCK IS CLOSED 09/15/1998 CONFIRMATION CHECK SET: TAG FISH @ 10674', CHK INDICATES LOCK IS CLOSED 09/18/1998 FISH SCREEN WITH BRAIDED LINE - NO LUCK 09/22/1998 ATTEMPT TO FISH SCREEN 09/28/1998 FISH SCREEN WITH CTU: SITP @ 0 PSI; LATCH FISH AT 10681'; PULL 30k, 7 LICKS NO MOVEMENT; PUMP MUD ACID AT 0.5 BPM (SUSP. CARBOLITE); NO LUCK. 09/29/1998 RIG UP BETA SLUGGER; TROUBLE SHOOT TOOL, LATCH FISH; BETA SLUGGER LOCKED UP, CAN'T RELEASE FROM FISH. KILLED WELL BY CIRCULATING'1000 BBLS KILL FLUID, PREP TO CUT COIL.CUT COIL, SET SLIPS AND CUT, RD CTU RU SLICKLINE. 09/30/1998 DRIFT THRU CTU FISH TO 10 669'/OPEN CHECKS ON CTU FISH ~ %~ % ~[i~i~~,~ .... ~ ~ Page 2 Date North Prudhoe Bay 3 Detail Remedial Work Chronolo_~v 0~_ eration 10/01/1998 RU CTU INJECTOR, DROP BALL TO ATTEMPT TO DISCONNECT; INJECTIVITY 0.4 BPM @ 3000 PSI BUT FALLING. DROP SECOND BALL; DISCONNECTED FROM BETA SLUGGER, RETREIVE COIL. 10/10/1998 POOL 7 ACCEPTED AND ON PAD TO DRILL WB-05B 10/14/1998 FISHING BETA-SLUGGER & SCREEN ASSY WITH CTU: LATCHED AT 10,662', JAR; RU DAILEY JARS, HIT 4 40k LICKS, FISH MOVING UP HOLE DRAGGING AT EACH COLLAR, HUNG UP @ STN 3, 8274' AND SSSV; BETA SLUGGER AND SCREEN FISHING NECK RETRIEVED. 10/20/1998 TAG FISH @ 2178' SLM W/ LIB 10/21/1998 TAGGED TOP OF X-LOCK,DRIFTED THRU SCREEN 10/29/1998 MILL XN LOCK; DRIFT TO 2300' CTM; SITP 0 PSI. 10/31/1998 ATTEMPT TO FISH SCREEN ASSEMBLY, FOUND @ 5890', PUSHED TO 7192' 11/01/1998 RAN LIB TO FISH, PICTURE OF PKG MANDREL 11/13/1998 ATTEMPT TO FISH SCREEN; SITP = 0 11/14/1998 HOT 11/14/1998 MILL AND RETRIEVE FISH:MILL EXPANDER MANDREL, CHASE FISH TO 15830 (XN) AND LATCH. SITP = 0, 11/15/1998 FISH CT TOOLS FROM TREE (FISH AND MILL RECOVERED) 11/16/1998 FULL BORE DRIFT TO TAG TO 15330': 3.73" SWAGE SAT DN IN ALL GLMS AND OTHER DEPTHS 11/22/1998 DRIFT WITH 3.8" SWAGE TO 15816' SLM, TOOLS SCARRED UP 11/24/1998 BRUSH / FLUSH SSSV NIPPLE, TBG TO 15860' WITH 3.5" BAILER; COULD NOT GET 3.8" SWAGE PASE 12760'. OBSTRUCTION IN TBG, PERFS PLUGGED LIMITED INJECTIVITY. 11/25/1998 ATTEMPT TO CLEAN TBG FOR SCREEN: BRUSHED TO 15815', GAUGE SD IN XN; RET'D RUBBER; DRIFT WITH 3.7" JUNK BASKET OUT TAIL, NOTHING RET'D. 11/29/1998 CT JUNK BASKET TO 15831' (xn), BASKET FULL OF METAL SHAVINGS; 2ND RUN WITH REVERSE JUNK BASKET PACKED OFF WITH METAL JUNK TOO/ RUN SCREEN AND SET IN XN. 12/01/1998 SET SLIP STOP AT 15817 ON TOP OF SCREEN; PLACE DGLV IN STA 5 12/01/1998 NPB3 TO REMAIN SHUT-IN UNTIL RIG IS OFF PAD. SIMULTANEOUS OPERATIONS CONSIDERED UNSAFE. 12/03/1998 POOL 7 RELEASED FROM WB-05B, MOVE TO WB-06 12/03/1998 POOL 7 ACCEPTED TO DRILL WB-06 AT 1930 HRS. 01/30/1999 POOL 7 RELEASED FROM WB-06 AT 1700 HRS. 02/04/1999 POOL 7 OFF PAD, STAGED AT WDSA 02/05/1999 PROD LINE DEPRESSURED TO ALLOW FOR WELL TIE-INS, NORCON STAGING EQUIPMENT FOR WB5B, WB6 TIE-IN WORK 02/14/1999 NORCON FINISHED WITH FLOWLINES, PT'D AND READY TO GO. 02/20/1999 ATTEMPT TO FLOW NPB#3 USING RAW LIFT FROM WB-04, MAINTAINING 1000 PSI FTP ON NPB3, WB4 AT 2000 PSI. 02/27/1999 PIPELINE ROAD CROSSING IN PROGRESS, CONGESTED PAD 07/15/1999 ATTEMPT TO PULL SLIP STOP & SCREEN. ATTEMPT TO PULL SLIP STOP /RIH W/4 1/2" GR TO 15746'SLM UNABLE TO PASS, OJ SPANG LICK'S OF 1700# + TO GET OUT OF GR SHEARED ,HARD ASPHALTINES ON TOOL RIH W/3.50" CENT,SAMPLE BAILER TO 15753'SLM ,NO SAMPLE /RAN 3.20" CENT, 2.79" LIB NO PICTURE OF SLIP STOP , SMALL THUMB NAIL OF ASPHALTINES / FRAC SAND ON LIB 07/16/1999 FCO-N2: PULL SCREEN. FISHED OUT SLIP STOP (DID NOT HAVE MUCH FILL ON TOP OF FISH - MAYBE 2-3'), LATCHED AND ATTEMPTED TO PULL SCREEN. 50 JAR LICKS AND NO MOVEMENT. ADDED ACCELERATOR AND FIVE WEIGHT BARS TO FISHING ASS'Y AND RELATCHED SCREEN...CONT. ON NEXT WSR. ~.~~%~=~,~~ ~% Page 3 Date North Prudhoe Bay 3 Detail Remedial Work Chronology 07/17/1999 FCO-N2: FISH SCREEN. HIT 55 JAR LICKS ON SCREEN W/WT BARS AND ACCELERATOR. NO MOVEMENT OF FISH. JET WASHED INSIDE OF SCREEN WITH DIESEL-XYLENE AND ALLOWED DIESEL-XYLENE TO SOAK ACROSS SCREEN. RE-RAN FULL FISHING BHA. LATCHED AND JARRED UP ON FISH W/37-42K LICKS. APPEARED TO PULL FREE AFTER 31ST LICK. POOH W/SCREEN (CONTINUED ON NEXT WSR). 07/18/1999 FCO-N2: FISHED SCREEN / N2-FCO TO 16,050' CTM. FISHED SAND SCREEN, FCO SAND FROM 15,898' CTM TO 16,050' CTM. WASHED GLM'S. LEFT S/I FOR EITHER A SURFACE OR DOWN HOLE SAND SCREEN. 11/21/1999 INITIATE SAG RIVER FLOW TEST THRU SURFACE SAND SCREENS Date Test Length WHP STBOPD 11/26 04:14 2163 1383 11/25 04:31 2164 1364 11/25 00:40 2168 1665 11/25 02:35 21 89 1379 11/24 03:34 21 72 1552 11/21 08:27 2057 1471 11/21 12:88 2848 2887 BWPD WC BFPD Fm. Gas 121 8% 1504 22,941 129 9% 1493 22,912 105 6% 1770 22,944 154 10% 1533 22,279 231 13% 1783 22,531 538 27% 2009 25,528 456 18% 2543 21,837 FGOR 16,590 16,799 13,783 16,152 14,521 17,358 10,465 11/26/1999 COLLECTED SEPARATOR GAS AND LIQUID SAMPLES FOR RECOMBINATION PVT ANALYSES. WELL SHUT-IN DUE TO HIGH GOR AND HIGH COST OF MANNING SOLIDS EQUIPMENT. 12/15/1999 SL DRIFT TO 15960' WITH 3.25" GR; SBHP PRESS. 3642 PSI AT 9245' SS DATUM (BHT 212). 12/25/1999 ATTEMPTED PRE-PERF FILL CLEANOUT. UNIT FAILED DURING PRESSURE TEST. RD 12/26/1999 PRE-PERF FCO USING NITRIFIED KCL TO 16,266' CTM. FREEZE PROTECT AND SI. 12/27/1999 SL TAG AT 16,219 'MD WITH 3.55" DG. NO SAMPLE. 12/28/1999 RU ELINE FOR ADD PERF. RIH TO 12500', COULD NOT DROP BELOW. RD. 01/31/2000 RU SL, BRUSH AND FLUSH TBG WITH DIESEL-XYLENE. TAG TD WITH 3.5" DG AT 16,222 'MD 02/01/2000 RU ELINE, PERFORATE 16176'-16190' (9235'-9242' SS) @ 6SPF WITH 3-3/8" Gl/NS. RD. 02/02/2000 RU ELINE. PERFORATE 16161'-16171' (9226'-9232' SS) @ 6SPF WITH 3-3/8" GUNS. RD. 02/03/2000 RU ELINE. PERFORATE 16147'-16161' (9219'-9226' SS) @ 6SPF WITH 3-3/8" GUNS. RD. 02/04/2000 BEGIN FLOWTEST. Page 4 North Prudhoe Bay No. 3 Subject: North Prudhoe Bay No. 3 Date: Wed Apr 22 09:30:43 1998 From: jack hartz~admin.state.ak.us To: dave_johnston~admin.state.ak.us, cammy_oechsli~admin, state.ak.us, robert christenson~admin.state.ak.us CC: blair_wondzell~admin.state.ak.us, bob_crandall~admin.state.ak.us John Groth, ARCO, made a courtesy call 4/15 and 4/20 to say that NPB %3 recompletion ran into some snags while doing CTU work after the frac job. Seems they lost 12000' of Coil in the well while pulling out of the hole. The top was at 4000' and they were fishing. The had been using West Beach 4 to lift NPB 3 during the recompletion and clean out. They have since SI WB 4 (4/20) and are.still fishing for the coil w/o any success to date. Jack 6/16/98 10:53 AM I-K'.?J'I: HI~L:U HLH~KH FI:IX NO, : 9072634894 11-2~1-~)? Ob:l~k' I~,U]. G P MA Facsimile Tr~osmi.~-,sion (907) 263-4894 verify (90?) 263-4948 (Ashley) To: Blair Wondzell From: Mike Morgan 'Z~ ~-/4' ~J Fax: 276-7542 Pages: 1 Phone: 279-1433 ext. 226 Date: 11/25/97 Re: Permit 92-145 Sundry Application CC: J.A. Leone, S, Holland (Exxon) Urgent [] For Review [] Plesse Comment [] Please Reply [] Please Recycle · Comments: Attached is the expanded outline of the planned operations for NPB-03 detailing the temporary use o! West Beach #4 to supply raw gas lift during the remedial operations and subsequent clean-up periods, We are in the process of mobilizing equipment necessary for this work in preparation for some Lisburne wellwork; thus, we plan to do the preliminary stimulation and squeeze work while we've got this equipment up and running early next week. I appreciate your timely review of this application. ! also understand your concern regarding the Oct, 1, 1997 Decision disallowing the exception to the GOR waiver; however, I believe ARCO and Exxon have demonstrated a commitment to progress West Beach development with the drilling of the West Beach 5 well, and it is not our intent to circumvent the GOR waiver ruling. The temporary use of West Beach produced gas is fundamental to our plans to re-establish NPB#3 production. ! will call you tomorrow to discuss any questions you might have regarding the proposal and submitted information, RECEIVED NOV 2G 199,7 Alaska 011 & Ga; C..s. Anchorage North Prudhoe Bay 3 Summary of Planned Remedial Well Operations Remedial~Objectives: 1. R~-establi~h low watereut Sag River and !vishak production from North Prudhoe Bay State No. 3 (NPB~3). ~..Capture remainin~ reserves estimated between 300 and 800~STBO. 3. Evaluate standalone Sag River production potential in terrace fault block area. NPB#3 Current Status: · Shut-in since 8/11/96 · 7/96 Production Profile showed majority of fluid l~akin~ around inflatable bridge plug and little to no production from the Sag ~iver formation * Static botton%hole pressure estimated at 3750 psi ~ 16150'MD/9220'SS; BHT @ 2087F- - Last ta~: 7/13/96 @ 16,165' MD (ELM) Planned NPB#3 Remedial Work Scope: All work will b~ conducted in accordance with the requirements of AAC 20 25.280 and consistent with ARCO Alaska, Inc. Prudhoe Bay Unit standard wellwork practices. Please refer to attached wellbore schematic and log ~ection. (1) rccor~ static-~rcssurc survcy; completed 11/13/97: SB~P 3813 (2) pull inflatable bridge plug at 16,169' MD; (3) flow Wes= Beach g4 (wB$4) £oz ~/- 48 hours prior to NPD~3 cleanout an~ s~imula~ion to warm U~ lines and raw lift stream prior ltO inltla~ing raw lift (hydrates and paraffin are a3rimary concern), (4) clean out fill ~o 16,250'MD and aci~ wash (HC1/Xylene) perforation~ from 15,9~8' MD to 16,214'-MD. (5) perform post-stim./pre-squeeze production test(s) utilizing WB~4 for gas lift; Elow period will Be determined by. results. M~nimum day:maximum I0 days; if operations allow, shut-in WB~4. (6) Shut-in WB#~ & NPB#3; (7) cement sc/u~eze exi=tlng NPB~3 perforations; (8) tag top of cement and dump sand to cover Ivishak squeeze per~orations; (9) per{orate Sag River interval from 16,020'MD to 16,040' MD; (10)Hydraulically frac. Sag R~ver formation; (Il)clean out proppant to 16,100' MD, tag, run ga~ lif~ valve~ and Sag River;..{ +/- 48 hours prior to initiating NPB~3 ~rodufti0n, the WB#4 well will be turned on to warm up the raw lifK s~ream and production line.) (12)perform 7 day pressure build-up test, shut-in WB4; West Beach $4 for +/- 48 hours prior to initiating NPB#3 (13) flow production; (14)flow NPB#3 to cleanup +/- 60 days, or if temt result= are le~s than expected, proceed to s~ep lb. (15)clean out ~and p]ug to uncover Ivishak interval; interval from 16,170'MD to 16,!90'MD; flow (16) perforate Shublik/Ivishak West ~each $4 for +/- 48 hours prior to 60 day.NPB~3 production test. ~1~ (17)record co-mingled production log. RRCO RLI:ISKR FR:~ NO, ,' 9872634894 11-24-97 10:01P p.01 GREATER POINT MclNTYRE AREA FACSIMILS TRANSMISSION Fax Number (90"/) 263-J094 veri~ (~/) ~6,~-4~ (Ashley) RECEI,VED NOV 25 199i' Alaska 011 & Gas Cons. Commission Anchorage NUMBER OP PAGi~5: C 4. _ ] ,, ~£/o£ _. Jl ilLLi " _ I · .... --- Choke T~ L~ NP-3 Dirty Gas Lift WB-4 ~II""~-0 LLP Hook up ~7 To Shut in WB-4 2" Line 2" Choke 2" Valves NP-3 Wing Choke 2" Valves To L1 ~7 Revised 1 t/22,~95 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 17, 1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: North Prudhoe Bay No. 3 Sundry Application Permit 92-145 Dear Mr. Johnston: ARCO Alaska, Inc., as operator of the North Prudhoe Bay Oil Pool, submits the attached Application for Sundry Approval (Form 10-403), detailing our plans to re-establish production from the North Prudhoe Bay State No. 3 well (NPBS No. 3). All work will be conducted in accordance with the requirements of AAC 20 25.280. Additionally, as operator of the West Beach Oil Pool, we are requesting a temporary waiver of the gas-oil rati° limit set by 20 AAC 25.240. West Beach 4 formation gas will be used to supply lift gas during and subsequent to the remedial operations on NPBS No. 3 for sixty days. If remedial operations are successful on NPBS No. 3, it is our expectation that gas lift will not be required permanently. Should you have any questions regarding the request please contaiT.~ ~_ ~k~~at 263- 4332 or myself at 265-6846. Sincerely, J. W. Groth Enclosure Cc.' , M. P. Evans, Exxon Company, U. S. A. S. W. Holland, Exxon Company, U. S. A. J. A. Leone, ARCO Alaska Inc. " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~. Type of Request: Abandon __ Suspended __ Operation Shutdown Alter casing __ Repair wellX__ Plugging __ Chan~le approved pro~lram __ Pull tubin~ __ Variance __ 2. Name of Operator 15. Type of Well: ARCO Alaska, Inc. | Development ! Exploratory 3. Address ! Stratigraphic P.O. Box 100360, Anchorage, AK 99510 ! Service 4. Location of well at surface 71' NSL, 179' EWL, Sec. 25, T12N, R14E, UM At top of production interval 2830' NSL, 1505' WEL, Sec. 22, T12N, R14E, UM At effective depth 3170' NSL, 1737' WEL, Sec. 22, T12N, R14E, UM At total depth 3224' NSL, 1776' WEL, Sec. 22, T12N, R14E, UM __ Re-enter suspended well __ Time extension __ Stimulate X__ Perforate x__ Other _ Datum elevation (DF or KB) 52.5 RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number NP-03 (aka, 09-03 or North PRB St. #3) 9. Permit number 92-145 10. APl number 500292232200 11. Field/Pool North Prudhoe BaY 12. Present well condition summary Total Depth: measured: 16465 feet true vertical: 9447 feet Effective Depth: measured: 16385 feet true vertical: 9402 feet Casing Length Size Cemented Conductor 80' 20" 11 yds ArcticSet 4660' 13-3/8 3579 cu ft "E"/464 cu ft Surface Class "G"/235 sx "C" Intermediate 14584' 9-5/8'' 518 cu ft Class "G" Plugs (measured) None. Junk (measured) None.0 RIGINAL Measured depth True vertical depth 121' 121' 4700' 3994' 14422' 8595' Production Liner Perforation depth: 1999' 7" measured 15948' through 16294' (pis refer to attached schematic) true vertical 9167' through 9352' (pis refer to attached schematic) Tubing (size, grade, and measured depth) 4-1/2'', L80 @ 15848' MD Packers and SSSV (type and measured depth) 7x4-1/?'' @ 15832', 9-5/~"x4-1/~,"@ 14376', SSSV 4-1/2`` @ 2205' 13. Attachments Description summary of proposal __x Detailed operation program __ Please refer to attached summary 14. Estimated date for commencing operation November 25'~ 1997 1 16. If proposal was verbally approved Name of approver D~ate approved Service 17. I hereby certify thaL.the/foreeoJ~3 is true and correct to the best of my knowledge· S~ne M~chael R Mo'r n Z~,?-.~ ~ Sr En ~ d ga ,/ ~ ,',.~tle g neet ,/ .... ' /~" FOR COMMISSION USE ONLY Conditions of approval: No~tffy Commis~'i0n so representative may witness Plug integrity __ '?' BOP tes,.t~/ ,,"" Location clearance __ Mechanical Integrity Test __ Subsequent for required 10- ,.~,,~}~l'~a~ ~§nect By Approved bv order of the Commission ~'~,,,;H ~AI .lnhn~fnn Cemmissieqer Form 10-403 Rev 06/15/88 .,~o~ .... Returned 731 cu ft Class "G" 14465' 9447' RECEIVED NOV 20 199 ' Naska 0il & Gas Cons. Commission Anchorage BOP sketch _ 15. Status of well classification as: Oil X Gas Suspended Date November 17, 1997 I Appr°val~o.~'~_~ / · . SUBMIT IN TRIPLICATE North Prudhoe Bay 3 Summary of Planned Remedial Well Operations Remedial Objectives: 1. Re-establish low watercut Sag River and Ivishak production from North Prudhoe Bay State No. 3 (NPB~3). 2. Capture remaining reserves estimated between 300 and 800MSTBO. 3. Evaluate standalone Sag River production potential in terrace fault block area. NPB~3 Current Status: · Shut-in since 8/11/96 · 7/96 Production Profile showed majority of fluid leaking around inflatable bridge plug and little to no production from the Sag River formation · Static bottomhole pressure estimated at 3750 psi @ 16150'MD/9220'SS; BHT @ 208°F. · Last tag: 7/13/96 @ 16,165' MD (ELM) Planned NPB~3 Remedial Work Scope: Ail work will be conducted in accordance with the requirements of AAC 20 25.280 and consistent with ARCO Alaska, Inc. Prudhoe Bay Unit standard wellwork practices. Please refer to attached wellbore schematic and log section. (1) record static pressure survey; (2) pull inflatable bridge plug at 16,169' MD; (3) clean out fill to 16,250'MD and acid wash (HC1/Xylene) perforations from 15,948' MD to 16,214' MD. ~~-- (4) perform post-stim./pre-squeeze production test(s) utilizing West Beach 4 for gas lift; (5) cement squeeze existing perforations, (6) tag top of cement and dump sand to cover Ivishak squeeze perforations; (7) perforate Sag River interval from 16,020'MD to 16,040' MD; (8) hydraulically frac. Sag River formation; (9) clean out proppant to 16,100' MD, tag, run gas lift valves and test Sag River; (10)perform pressure build-up test; (Il)clean out sand plug to uncover Ivishak interval; (12)perforate Shublik/Ivishak interval from 16,170'MD to 16,190'MD; (13)record co-mingled production log. RECEIVED ov 2 0 199 ' Alaska 011 & Gas Cons. Commission Anchorage 11/17/97 NORTH PRUDHOE BAY / STATE # ' ' / Well Status: Producer Surface Location: Sec 25, T1ZI. 4E, UM Top of Formation: RKB To Tubing Hanger:. 25.0 Feet RKB To Sea Level: 52.5 Feet Top of Sag River:. 15893' MD/9088' SS Top of Shublik: 16039' MD/9161' SS Top of SadlerochiC 16177' MD/9235' SS Reference Log: CNL/GR/CCL ATLAS 2/7/93 Annulus Fluids: 2100' DIESEL, 9.8 BRINE BELOW Spud Date: 1/Z/93 Completion Date: Z/16/93 MINIMUM ID: 3.725" · 15843' MD JEWELRY 1. 2205 MD - 4-1/Z" CAMCO TRDP-4A SSSV, 3.812"1D 2. 14314 MD - PARKER SWS NIPPLE, 3.813' ID 3. 14376 MD - TIW HBBP 9-5/8' x 4-1/Z' PACKER 4. 15781 MD- OTIS X NIPPLE, 3.813" ID 5. 15837 MD - BAKER SABL-3 7' x 4-1/2' PACKER 6. 15843 MD - PARKER SWN NIPPLE, 3.725' ID 7. 15847 MD - TUBING TAIL WITH WIREUNE ENTRY GUIDE 7a. 16169 MD - IBP SET 11/11/95 GAS LIFT MANDREL INFO , MD SS MANDREL TYPE VALVE/LATCH 5927 4502 1-1/2" MERLA TGPD DUMMY/TG 7226 5095 1-1/2" MERLA TGPD DUMMY 8326 5605 1-1/2" MERLA TGPD FLOW VALVE/RK 10695 6696 1-1/Z" MERLATGPD DUMMY" 12073, 7377 1-1/2" MERLA TGPD DUMMY 14285 8398 1-1/Z" MERLA TGPD EQ DM¥/RKP PORT TRO .51/64" 22 10 16 CASING AND TUBING SIZE WT GRADE TOP BOTTbM DESCRIPTION 9. 13-3/8" 68# L-80 0 4700 CASING 10. 9-5/8" 47# NT80S 0 14622 CASING 11. 7" 26# NT80SS 14466 16465 LINER 4-1/Z" 12.6# L-80 (IpC) 0 15847 TUBING PERFORATION DATA INTERVAL ZONE FT SPF SIZE 13. 15948-15968 SAG RIVER 20 6. 3-3/8 15994-16014 SAG RIVER ZO 6 3-3/8 16014-16034 SAG RIVER 20 6 3-3/8 16150-16170 SHUBLIK 20 6 3-3/8 16180-16214 SADDLEROCHIT 34 6 3-3/8 PHASE DATE 60 11/02/94 60 10/09/94 60 09/19/94 60 11/02/94 60 04/18/93 15'9u,~ , 14. 13t¢~ 15. 17 ~'o- SQUEEZED PERFORATIONS: INTERVAL ZONE ~ SPF SEE PHASE f&,t~ 16. 15820-158ZZ Z 4 3-3/8 17. 1fi05~16052 2 4 3-3/8 15 NO SUCCESSFULL PRES~RE ~ OF ~E SQUE~E PERFS PRODU~ION LOG CONFIRMED ~AT S~E~E PERFS ARE LEAKING (1/23/g4) 2O 18 18. 16292-16294 SADDLEROCHff Z 4 3-3/8 19. 16204 ELMD - TOP OF FILL 1/23/94 20. 16273 MD - 7" EZSV CEMENT RETAINER Z1. 16385 MD-PBTD 22. 16465 MD-TD DATE ANGLE THROUGH SADLEROCHIT: -56' MAXIMUM ANGLE: 65° @ 14000' AND 14900' MD Anchorage Issue Date: 01-09-96 (4) 21 11 RECEIVED NOV Alaska 011 & 13al C0ns. C0mmiuion Exhibit 1.A CONFIDENTIAL North Prudhoe Bay State #3 Well Log API- 500292232200 GR ,. z Resistivity zooo, , --IS'/O0 90O0 - im ............. -~ ..... · "': .........................................~ - · . -isaoo!.~ · ti;.:. '~1~ -~ ,,i"2/93 SQZ PERFS .: ~ ''' ! .:Y: :i ' '' ...................... ,,. ............. .... ..................... ~ 11/94 Add Perle '".-~- .... i' ~,~. ' ' ~ ....i ............. .... --II01~ ~ ' : '"' -" ' "~;:: , ,, 10/94 Add Perle. ..~, ~-~_ - i~ 9/94 Add Perfe. ""i .... : :...._L:..i~"; 16,040' l~O ...... -- '~""-['1 II ..... IT I' '11" ~i":'"': ..... .......................... ~]1~,,~... ~ ....... "'tl{l~ m .. 2/93 SQZ PERFS ..... i;'i i' :....................~~----"~"'-'-'~'-..~?,,, ~-- .........~ · ~ I 11/95 ~e-'Pl'-'~g~~ ''~"~'';ILI/~'''' ' ' ..... ...... -.-~,,,.-.- , -:...-i..-:.~ ..... .-.: ....... ,~. ~ o .~1~ 4/93 Original Perfe. , iI ;__m,~__ - -- ; '; , , : ...,,: ...... '--~ . _.'~_.~ ......... ! ~ v~ '.... ..-.~--.-.: ...,,~'.,.:- .c ........... '" · · '"""'--" '"'""----~:'.'~ -' " ', ..... '""~ ......... 7 -' ° !; .' ~ ~' .. : ........ ~ ....... ..... ~ ........... ~~-- __2/93 Cmt. Reteiner__. .~ ,-1~3~II ~ -2/93 SQZ PERFS :'"+ ~&t ~¢ ............... ~,~.~ .............. ~,.~. - .' · . .... ~- ................. ~ ......................... . . ........ , ....................................... '-il~a ~, . ' ' "~ · i . ............... ~,~ ..... ~,.T.' ": ........... ,, .- ; ....... ,.:..,~:, .... : ...... : ..- · , .............................. -,.~? .... . n~ ....... '~'--'; ....... ~ ........... - : ~. ...... ~ .......... -- .... ,, -- ~- -.~ ~ ..................... ..;.~. ~.. .............. -. . : . ............. ;... :-~ .......... :,:..--. ..... ........ ~ ............ : ............. I ...... ;.. ..... ; .... ~.. . , ..... ~ . .,~ . · .... GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10090 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 3/26/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy RF Sepia Disk Well Job # Log Description Date BL N PRUDHOE BAY ST #3 IBP SE'I-I'ING RECORD 9 51 1 1 1 I 1 LISBURNE L4-32 TUBING PATCH RECORD 9 51 1 2 2 I I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Aiaska Oil & (:;as Co s, ,Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing __ Stimulate __ Plugging __ Perforate Repair well__ Alter casing __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 71' NSL, 179' EWL, Sec. 25, T12N, R14E, UM At top of production interval 2830' NSL, 1505' WEL, Sec. 22, T12N, R14E, UM At effective depth 3170'NSL, 1737'WEL, Sec. 22, T12N, R14E, UM 0RI6INAL At total depth 3224' NSL, 1776' WEL, Sec. 22, T12N, R14E, UM !6. Datum elevation (DF or KB) 52.5 RKB 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number 9. Permit number/approval number 92-145 / 94-298 10. APl number 500292232200 11. Field/Pool North Prudhoe Bay 12. Present well condition summary Total Depth: measured: true vertical: 16465 feet 9447 feet Plugs (measured) None. Effective Depth: measured: 16385 feet true vertical: 9402 feet Casing Length Size Cemented Conductor 80' 20" 11 yds ArcticSet 4660' 13-3/8 3579 cu ft "E"/464 cu ft Surface Class "G"/235 sx "C" Intermediate 14584' 9-5/8" 518 cu ft Class "G" Liner 1 999' 7" 731 CU ft Class "G" Junk (measured) None. Measured depth 121' 4700' 14422' 14465' True vertical depth 121' 3994' 8595' 9447' Perforation depth: measured 16180-16214', 15994-16034', 15948-15968', 16150-16170' true vertical 9289-9307', 9190-9211', 9167-9177', 9273-9284' Tubing (size, grade, and measured depth) 4-1/2'', L80 @ 15848' MD Packers and SSSV (type and measured depth) 7X4-1/2'' @ 15832', 9-5/8"X4-1/2"@ 14376', SSSV 4-1/2`` @ 2205' FEB 0 1 i j96 13. Stimulation or cement squeeze summary Intervals treated (measured) Alaska 0il & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 14. 15. Prior to well operation Subsequent to operation Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X__ Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 4460 18300 2500 16. Status of well classification as: Oil × Gas __ Suspended Tubing Pressure 680 1500 7. I hereby certify that the. fgregaing is true and correct to the best of my knowledge. ~igned M. Herr "'~?~SOt~'/,.~ Title Engineer Service Date January 22, 1996 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE EL Well Work Log Date Description DS-Well 1 1/02/94 PERFORATE 40' NPBS-3 FTP/ITP PSI IA PSI OA PSI I SITP I Min ID SSSV nipple I I 300 psi 400 psi 1,200 psiI 3.725 @ 15843 TRDP SSSV Information Tubular or Casing Problems PBTD 16213' ELM CIE #1 SWS C/E#2 DIE CIE #3 CIE #4 CIE #5 $2OO48 Diesel (Recov.) Diesel (non Recov) AFE # CC# I Class Activity I 2 D 0006 NAN PDS1 DH Time Log Entry 07:30 MIRU SWS 08:00 PT & RIH W/3-3/8" 41B ULTRAJET, 6 SPF, 90 DEGREE PHASING, CCL 10:00 SD AT 15443. COME ON LINE WITH CRUDE AT 3 BPM. STILL SD AT 15443. 10:10 INCREASE TO 5 BPM. CONTINUE RIH. SD PUMP. TIE INTO TUBING TAIL. RELOG ON DEPTH. PULLED SOME WEIGHT COMING INTO 1-1'. LOG UP PASS AT 80 FPM TO SEE COLLARS. WELL ON LINE. 10:53 LOG UP FROM PBTD AT 16213'. ON DEPTH. SHOOT INTERVAL #1. SI WELL. LOG UP 3 COLLARS. POOH. 11:00 OOH. ALL SHOTS FIRED. 13:10 PT & RIH W/3-3/8" 41B ULDTRAJET, 4 SPF, 90 DEGREE PHASING, CCL 14:10 SDAT15443. COMEON LINE WITH CRUDE AT S BPM. THROUGH TAIL. 79 BBLS TOTAL CRUDE AWAY 14:20 TIE IN TO FLAG. 14:50 BRING WELL ON LINE. LOG UP. ON DEPTH. SHOOT INTERVAL. 14'58 SI WELL. LOG UP. POOH. 16'00 OOH. ALLSHOTS FIRED. RDMO. A~__~ mt & Gas Cons, Comm~ssion Top (ft) Bottom ~ Grams/EHD~rTP Phasing Ofien! O/B/II Zone Ad/Repeff 15948 15968 6 22 GR, .55~ 13.8 60 F~ANDOM U SAG ADPERF 1 6150 1 61 70 8 22 GR~ .55, 13.8 80 F1ANDOM U SHUBLIK ADPERF BOPD: F/ITP: MD: Tot. Gas~ GOB_. BWPD: WC (%): Press: GL Gas: Choke o: Temp: Signed Page No. of Jennifer Julian 1 1 Anchorage, AK 99518-1199 '~ ~ ~'~ \I~)/{~ ~/~ Well / Jobs Log Description Date NO. 9990 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/17/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy RF Sepia Disk N. PRUDHOE BAY STATE #3 ! ~--~t~,'5 STATIC BHP SURVEY 951 223 I 1 N. PRUDHOE BAY STATE #4/ STATIC BHP SURVEY 951 22 4 I 1 L1-15 ~-~ I ~'7-.- .STATIC BOTTOMHOLE PRESS SUl 951226 I 1 L2-16 ~'~- ~7 STATIC PRESS SURVEY 951231 I 1 iL4-30 I 0 [ STATIC PRESSURE SURVEY 951 230 I 1 L5-09 ~ ~) 'IZ~ STATIC BoTrOMHOLE PRES 951 22 5 I I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska Inc. Greater Point McIntyre Engineering Date: November 23, 1994 Subject: Transmittal Number 749 From: ARCO Alaska, Inc. To: Bob crandall AC)GCC 3001 Porcupine Drive .~.~~ Anchorage, AK 99501 The following Greater Point McIntyre Area data are enclosed, tt~formation and your cooperation in maintaining confidentiality is appreciated: is confidential · :,:~:: Well . Name Data Description Run # · :.., ~Leak Detection Log. 1 /\c~ c~. 0'/?~3PIN/TEMP/P~SS / G~DIO · , L3-01 Tub~g Puncher ( I n/~6,, Tubing 1 Puncher) Record >n Record (3 3/d' HSD - 4lB HI ement Bond Log (CB~/SGTL/CALY) Diskette: CDR in LDWG format . NP-03 ~erforation Record (3 3/, HSD ~~F) ~,~ '~~ Perfora~g Record (3 3/8"-20'- 6sp0 ~" ~ 1 ~~erforating Record (3 3 A" HSD - 4lB ~H) 1 '~CDN ~ LDWG format (w/list~g) (~ B~L~ Depth Corrected) Diskette: 5 Pass Cased Hole ~~ (w/list~g) 1 Date Run 9/25/94 9125/94 10/8/94 10/8/94 6116/94 ~q 9//9194 10/9/94 1112194 6113/94 6/14/94 119194 Company Schlumberger · Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Transmittal Number: 749 Page: 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspended __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well m Plugging __ Time extension__ Stimulate __ Change approved program __ Pull tubin? __ Variance __ PerforateX Other__ 2. Name of Operator J5. Type of Well: .~. Datum elevation (DF or KB) ARCO Alaska, Inc. | Development × 52.5 RKB ~ J Exploratory 3. Address ! Stratigraphic 7. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 . / Service __ Prudhoe Bay Unit 4. Location of well at surface 71' NSL, 179' EWL, Sec. 25, T12N, R14E, UM At top of production interval 2830' NSL, 1505' WEL, Sec. 22, T12N, R14E, UIV0 R I G I N A L At effective depth 3170' NSL, 1737' WEL, Sec. 22, T12N, R14E, UM At total depth 3224' NSL, 1776' WEL, Sec. 22, T12N, R14E, UM feet 8. Well number 9. Permit number 92-145 10. APl number 500292232200 11. Field/Pool North Prudhoe Bay 12. Present well condition summary Total Depth: measured: true vertical: 16465 feet 9447 feet Plugs (measured) None. Effective Depth: measured: 16385 feet true vertical: 9402 feet Casing Length Size Cemented Conductor 80' 20" 11 yds ArcticSet 4660' 13-3/8 3579 cuft "E"/464 cuft Surface Class "G"/235 sx "C" Intermediate 14584' 9-5/8'' 518 CUft Class "G" Junk (measured) None. Measured depth 121' 4700' 14422' True vertical depth 121' 3994' 8595' Liner 1999' 7" 731 CUft Class "G" 14465' 9447' Perforation depth: measured 16180-16214', 15994-16034' true vertical 9289-9307', 9190-9211' Tubing (size, grade, and measured depth) 4-1/2'', L80 @ 15848' MD Packers and SSSV (type and measured depth) 7X4-1/~.'' @ 15832', 9-%"X4-1/~"@ 14376', SSSV 4-1/~," @ 2205' 13. Attachments Description summary of proposal __X RECEIVED 0CT 2 5 1994 Alaska Oil & Gas Cons. Commission Anch0ra.ie Detailed operation program __ BOP sketch -- Please refer to the attached 14. Estimated date for commencing operation October 28, 1994 16. If proposal was verbally approved Name of al)prover Date approved Service 17. I hereby certify that the foregoing is true/~nd correct to the best of my knowledge. Michael S. Harr ,/Z~...ZQ_5/(~t~ Title Engineer s igned FOR COMMISSION USE ONLY 15. Status of well classification as: Oil X Gas .... Suspended Date October 19, 1994 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP test Location clearance __ Mechanical Integrity Test__ Original li~{j.~j~q~J~ for required 10-_.~{~>___t~ A.o_oroved bv order of the CommissioDnaVid W. Johnston Approved Copy Form 10-403 Rev 06/15/88 Returned , ,...~ ---?¥ Commissioner JApproval No.. ~ SUBMIT IN TRIPLICATE GREATER POINT MCINTYRE AREA PERFORATING PROCEDURE Well: APl #: Date: NPBS#3 Prop. Code: NANPDS1DH AFC#: 2D0006 50-029- 22322 Endorsed By: ...M.!..c..h...a...e..L.S..:....H...a...r.r' ...................................................... 9/13/94 Office Ph: 263-4749 Home Ph. 522-2122 Well Status and Objectives: Expected NOB ....... .2...2...0...0..,bopd Proc. Dist. Wireline (4) Field Engineer DS Supervisor LPC Supt. ENG Supervisor DS Engineer WF (W2-2) Add 0* feet ................... to the tie-in log to be on depth with the reference log. Reference Log Tie in Log Log: CNL/GR SBL Date: 2/7/93 2/15/93 Company: ....... ..A..t.!..a...s. ........... ..A..t.!..a..s.. ...... Depths (from-to) Depths (from-to) Feet SPF Orient. Phased Zone 15,948' 15,968' 15,948' - 15,968' 20 ...... .6.. ............................... ..6...0..©. ..... .S...a...g.....R..[.v...e.r .... '~'~i':l"~J; ........ :1"~':i'~'6'" ........ :!"~'~'~'6" .... -'"'~"~'i:i'~'; ....... ~;~J ....6 60© Shublik - . - . - . Orient'n Note Min. Accept. Hole Size/Penetration: Achieve Drawdown By (check method): · N2 Lift · Hardline Lift Gas · Gas Lift · Flow Well __ · Backflow Through Drain or Hardline Tie in to Jewelry @ Minimum ID: Tail Depth: Casing Size: Est Res. Press. @ Last Tag: 16,204 15,847 MD--Description: .......................... 3.725 in Jewelry Type: ........................ 15,847 ft MD ........................ 7 in Gas Jetting Expected? None @ ' Comments: Perforate well under balanced. Flow well to tank on location. ~..U~.s.~.e.~..G.~..R./...c....c.~.L..~!~.°.~.r~t.i~.e.:!~.n.~.c.~.~[!.a...r~.s.~..w.~.e.~r...e.~.n.~.°..t.~.e.~.s.~!!.y.. ................... .!..n...d...e...n.!!.f.!..e.`.d....d...u..r.!..n...g..~!~..s.L.p...e.E.~..r..a..!!..n...g....a..t.!..e....m...p..t.... ............................ *NOTE: Need to confirm tie-in with CNL/GR Parker SWN @ 15,843 'MD .... .1...6...,.1....9...8. .... MD is ....... ..3..8...0...0.. psi ft MD on 1/23/94 H2S Level: 0 ppm Well: Date: Service Co. General Comments: Perforation Summary Eng Review Summary Dist Wireline Supervisor: ........................................................................................... Field Engineer Carrier ........................ "Charge ....................................................................................... ENG Supervisor PBTD Entry Hole Diameter DS Engineer ........................................... WF (W2-2) Shot balanced Depths over/under Referenced to __ Feet SPF Orient. Phasing ...o...:..?....,. ................................ - ................................................ .............. ............. ...O..../...B../....U. ................................ - .................................................................. O/B/U - O/B/U - "~'~"~'70 ................................ - .................................................... .~i¢ t'-5----~ ............. "6'F~'7'0 ................................ - ............................................................ _ "7;;:;;;'; ............................................................................................ ~i~.~--& ~-~"'%,"- ................... - Zone Aperf/Reperf GPMA 3/25/94 v2.1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing __ Stimulate __ Plugging __ Perforate Repair well __ Alter casing __ X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510 4. Location of well at surface 71' NSL, 179' EWL, Sec. 25, T12N, R14E, UM At top of production interval 2830' NSL, 1505' WEL, Sec. 22, T12N, R 14E, UM At effective depth 3170' NSL, 1737' WEL, Sec. 22, T12N, R14E, UM At total depth 3224' NSL, 1776' WEL, Sec. 22, T12N, R14E, UM 5. Type of Well: Development Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) 52.5 RKB feet 7. Unit or Property name P~ud ho_e, Bay Unit 8. Well number "" 9. Permit number/approval number 92-145 /94-251 10. APl number 500292232200 11. Field/Pool North Prudhoe Bay 12. Present well condition summary Total Depth: measured: true vertical: 16465 feet 9447 feet Plugs (measured) None. Effective Depth: Casing Conductor Surface Intermediate measured: true vertical: Length Size 80' 20" 4660' 13-3/8 14584' 9-'~/8'' 16385 feet Junk (measured) None. 9402 feet Cemented Measured depth 11 yds ArcticSet 121' 3579 cuft "E"/464 cu ft 4700' Class "G"/235 sx "C" 518 cu fl Class "G" 14422' True vertical depth 121' 3994' 8595' Liner 1 999' 7" 731 cuft Class "G" 14465' 9447' Perforation depth: measured 16180-16214', 15994-16034' (Received verbal approval from B. Wondzell) true vertical 9289-9307', 9190-9211' Tubing (size, grade, and measured depth) 4-1/~_'', LB0 @ 15848' MD Packers and SSSV (type and measured depth) 7x4-~/-.¢.'' @ 15832', 9-s/8"x4-V2"@ 14376', SSSV 4-Vz 13~ Stimulation or cement squeeze summary Intervals treated (measured) RECEIVED ~l~ l. lil& Gas Cons. Commissio. n Please refer to the attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure The well was unable to flow before and after the perforations were added. A coiled tubing unit tried to kickoff the well with Nitrogen but was unsuccessful 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ..:~_ Oil _.~_ Gas ___ Suspended ___Service 17. hereby certify for~ing/i$ true and correct to the best of my knowledge. I that the Signed M,S. Harr ,~¢:;'~/7/~_"¥'~,,,.,.~ Title Engineer Date Form 10-404 Rev 06/15/88 October 18, 1994 SUBMIT IN DUPLICATE · F GREATER POI?'-',MCINTYRE AREA PERFORATIN¢~'~ROCEDURE Well: NPBS~3 APl #: 50-029- 22322 Date: 9/13/94 Prop. Code: NANPDSIDH AFC, t: 2D0006 Endorsed By: Michael S. Herr Office Ph: 263-4749 Home Ph. 522-2122 Well Status and Objectives: nxpe=~,o8 2200 bopd Well is unable to flow becuase of high water cut. Perforate with 3 3/8 inch guns, loaded ...W..ith .22 gram charges.at 6.SPF and 60. (leg phasing, ..... wiml~,. (4) I=k4d Engineer DS Supewi~or LPC Supt. ~S Engineer wF (w2o2) Gas Jetting Expected? None O ' cmamem.: Perforate well under balanced. Flow well to Mnk on Io~tion. ~NOTE::: Need to '~i~ ti~ii~'~h :CNL/GR .................... .... :_: ............ :: .......... Min. Accept. Hole Size/Penetration: Achieve Drawdown By (check method): · N2 Bit · Hardline Lift Gee -- · Gas Mit · Flow Well X_ · Back/Iow Through Drain or Hardlino ................ ............ , ................. Tie in to Jewelry O 15,847 MD-Description: Tubing_'[:ai_! .................. : ............................ : ......................... Minimum ID: 3.725 in Jewelry Type: Parker SWN $ 15,843 'MD Tail Depth: 15,847 ItMD Casing Size: 7 in Est Res. Press. $ ..... _1_6_,_!98 MD is 3800 psi Last Tag: 16,204 tt MD on ....1/23/94 H2S Level: ......... : ........ ._.0 ppm Well: /3/~-<~_~ Perforation Summary Eng Rwlew d, ~o ~ Summaw Di.t Date: /o-' ?- ¢~ ~ Wiroline ~upm~l,or: _/1/), /~/~ ~./ ...................... Field Engineer PBTD Entzy Hole Diamet~er -- _0_:___~_ D~ Engineer General Comments ~ / ¢ WF 2 2 ~ I ' --" : ................................ 7 .............. ~ "':~"--", .... .. . ~ ' , - __ ~.__ ? ......... ~ ........ , .......................................... over~ Referenced lo ~ ~' '~ ~J,~ Feet SPF Orient. Phasing O/B/U - - o,.,u . ................. o :--::::: :::::: ~ ...... ::::1 :-:::z::zz_z: OISlU - O/B/U . Zone Apoff/Roporf GREATER POINT;~_ jINTYRE AREA PERFORATING F JCEDURE Proc. Dist. ~O.~ ~. -~ Wireline (4) Well: .....N...p..B...s..~..3.... Prop. Code: ..,N..,A.....W...B...,D..,..S~.....D....H' ..... AF{_~ ,~~ ............. Field Engineer APl #: S0-029- 22322 Endorsed By: Michael S. Harr DS Supervisor Date: .... '§;/;i'~'§~ .................................. Office Ph: 263-4'~'~'§' ............ '~'~'"lS'J~:"'~'~:'~'~'~ ................... LPC Supt. ENG Supervisor Well Status and Objectives: Expected NOB 2200 bopd DS Engineer ........... ..................................................................................................................................... Reference Log Tie in Log Log: CNL/GR PERF Date: 2/7/93 4/14/93 Company: ....... ..A..!.l..a...s. ............ ..S....W...S.. ...... Depths (from-to) Depths (from-to) 16,014' 16,034' 16,014' - 16,034' · , Add 0* feet 'to'the tie-in log to be on depth with the reference log. Feet SPF Orient. Phased Zone ................................................... ,.2.,.0.. ......... ..6. ............................... ,.6.,.o.,°' ..... s...a...g...R..!.v...e..r Orient'n Note ©© Min. Accept. Hole Size/Penetration: Achieve Drawdown By (check method): · N2 Lift · Hardline Lift Gas · Gas Lift · Flow Well m ® Backflow Through Drain or Hardline Tie in to Jewelry @ Minimum ID: Tail Depth: Casing Size: Est Res. Press. @ Last Tag: 16,204 Gas Jetting Expected? None @ ' Comments: ~~..w..~!!!~~.p.~.e.~.d..~~...r~.a.!~.e.~~..W"e.~!!~~!-n.~~..b...a.!..a.~.n..c...e.~.d' ................. condition. 'NOTE: Neod to confirm tie-in w~lh CNL/GR ..... .1...5.;....8~....7.. ...... MD-Description: Tubing Tail 3.725 in Jewelry Type: ii~i~?i~i:~iii:iiiiiiiiiiiiiiiiiiiiii~i ...... ii!i~i;~ii;'j~ ............................ 15,847 ft MD 7 16,198 MD is ...... ..3.,.8.,.0..0.. psi ft MD on .... .1.,/..,2..3.../,.9.,.4.... H2S Level: .................... .0.. ppm Well: ~,.~.-..,.O.,..~...... Perforation Summary Eng Review ~_~"'. ~.~, 0 ~K-~ Summary Dist Date: ..~.T./..~.:..?:.~../. Wirelin. e Supervisor: ..~..,Ov/~ ~~,~';'~' ............................. Field Engineer Service Co. ...~..,C?...~. ......... Carrier ~"~/t~ "Charg;; ...... ~'~-*'""~'~'~"~' ............................................. ENGSupervisor PBTD /~ ~....~.. Entry Hole Diameter . iDS Engineer General Comments: ~,~, .~.'.';'~'~ ..... ~, /~.. c,,/ ~'/..~ ...~..."~'.~."'~[ WF (W2-2) .... ~ ........ r~ ......................... u ................. ~.. ................ ; ........... ~1'"' ..... ~ .................... .......................... ~ .................... ~. ............................................................ ~.~. ...................... z ..... .~.~..~..~. .............................. .....~ .......................................... - ~"/.3 'z ~'4¢,,- ~'~¢/~;.'. Co~../ ..~ ~ Ir,,;~ u,~,f/ o..~ ~' ~ ~./~ / ..... .'. ............. : ..... ~...,....: ...................... : ........................... , ................ :.. ........... ~ ....... ,.~ ..... , ..................................... ~ ............................................ %...;..; ...... .,. ............ '~;i'i;',;i;;',:i;;~i ................ 6~i'i:i~ ........... : ....................... ' ........................................................................................................................................................... over_~/under Referenced to /r~p/~ Feet SPF Orient. Phasing Zone Apprf/Reped o u /~.~ o/5/ - !~,, ~?V .20' ° ..... .............................................. : .................................. 0 O/B/U . ' ............................................ O ........ r" ............................................. 'i5'i"i~'7'0' ................................ : ............................................... ~ .......................................................................................................... ................................ : ........................................... R EC'EIVED .................... o '8';~7'0' ................................ : ............................................................................................... Aiaska Oil & Gas Cons. Commission Anch0r~ ¢ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspended __ Operation Shutdown Alter casing __ Repair well _ Plugging __ Chan~le approved program _ Pull tubin~l _ Variance _ 2. Name of Operator 15. Type Of Well: ARCO Alaska, Inc. | Development x__ / Exploratory __ 3. Address ! Stratigraphic __ P.O. Box 100360, Anchorage, AK 99510 ! Service__ 4. Location of well at surface 71' NSL, 179~ EWL, Sec. 25, T12N, R14E, UM At top of production interval 2830' NSL, 1505' WEL, Sec. 22, T12N, R14E, UM At effective depth 3170' NSL, 1737' WEL, Sec. 22, T12N, R14E, UM At total depth 3224' NSL, 1776' WEL, Sec. 22, T12N, R14E, UM 12. Present well condition summary Total Depth: measured: true vertical' Effective Depth: __ Re-enter suspended well Time extension _ Stimulate Perforate X__ Other __ 5. Datum elevation (DF or KB) 52.5 RKB 7. Unit or Property name Prudhoe Bay Unit Casing Conductor Surface Intermediate 8. Well number 09-03 9. Permit number 92-145 10. APl number 500292232200 11. Field/Pool North Prudhoe Bay 16465 feet Plugs (measured) None. 9447 feet measured: true vertical: Length Size 80' 20" 4660' 13-3/8 14584' 9.5/8'' 16385 feet Junk (measured) None. 9402 feet Cemented 11 yds ArcticSet 3579 cu ft "E"/464 cuft Class "G"/235 sx "C" 518 cu fi Class "G" feet Measured depth 121' 4700' 14422' i GINAL True vertical depth 121' 3994' 8595' Liner 1999' 7" Perforation depth: measured 16180-16214' true vertical 9289-9307' Tubing (size, grade, and measured depth) 4-1/2'', LSO @ 15848' MD Packers and SSSV (type and measured depth) 7x4-1¥' @ 15832', 9-%"x4-1/?"@ 14376', SSSV 4-1/~, 13. Attachments Description summary of proposal .___X Please refer to the attached 731 cuft Class "G" 14465' 9447' "@ 2205' RECEIVED SEP 1 4 1994 Oil & Gas Cons. Commission Anchorage Detailed operation program _ BOP sketch 14. Estimated date for commencing operation September 17, 1994 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Michael S. Harr '--/~ Title Engineer FOR COMMISSION USE ONLY COnditions of approval: NOtify Commission so representative may witness ' Plug integrity __ BOP test ___ Location clearance __ Mechanical Integrity Test _ Subsequent for required 10-._~o'7 Approved by order of the Commission Form 10-403 Rev 06/15/88 5. Status of well classification as: Suspended Date September 13, 1994 IApproval .No. .~r~ginal Signed By 're;iH IA!. Johnston ~;grpmissioner Approved Oopy Returned ¢._ re D~,te SUBMIT IN TRIPLIC~ GREATER POINT MCINTYRE AREA PERFORATING PROCEDURE Well: APl #: Date: NPBS#3 Prop. Code: NANPDS1DH AFC#: 2D0006 50-029- 22322 Endorsed By: ..M..!..c...h..a...e..!...S.:....H...a...r.r. ...................................................... 9/13/94 Office Ph: 263-4749 Home Ph. 522-2122 Well Status and Objectives: Expected NOB 2200 bopd Well is unable to flow becuase of high water cut. Perforate with 3 3/8 inch guns, loaded Proc. Dist. Wireline (4) Field Engineer DS Supervisor LPC Supt. ENG Supervisor DS Engineer WE (W2-2) Reference Log Tie in Log Log: CNL/GR SBL Date: 2/7/93 2/15/93 Company: ....... ..A...t!..a...s. ............. ..A..t.!..a..s.. ...... Depths (from-to) Depths (from-to) Feet 16,014' - 16,034' 16,014'- 16,034' 20 Add 0* feet to the tie-in Icg to be on depth with the reference Icg. SPF Orient. Phased Zone ...... ~ ............................... .6...0...©. ..... S...a...g.....R.?...e.r Orient'n Note ©© Min. Accept. Hole Size/Penetration: Achieve Drawdown By (check method): · N2 Lift · Hardline Lift Gas · Gas Lift · Flow Well · Backflow Through Drain or Hardline Tie in to Jewelry @ Minimum ID: Tail Depth: Casing Size: Est Res. Press. @ Last Tag: 16,204 15,847 MD--Description: .......................... 3.725 in Jewelry Type: 15,847 ft MD ........................ 7 in ........................ .... .1....6..,.1....9...8. .... MD is ....... ..3...8...0...0.. psi ft MD on 1/23/94 H2S Level: Gas Jetting Expected? None @ ' Comments: ....W..!.[!.,.p...e...ri .o..r...a.!..e.....w...e.!.!.!..n....b..a.!a...n...c...e...d' ................. condition. *NOTE: Need to confirm tie-in with CNL/GR ................................................................................................... Parker SWN @ 15,843 'MD .................... ..0.. ppm II Well: Perforation Summary Eng Review IlSummary Diet Date: iiiiiiiiiiiiiiiiiiiiiiiiiiWireline Supervisor: ................................................ iiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiillF,e,d~' Engineer Service Co. Carrier "Charge F IV I: D Supervisor .......................... PBTD ............. Entry Hoi;'i~i;;~;~;;" ............... liDS Engineer General Comments: ....................................................................................................... ................... llWF (w2-2) .............................................................................................................................................. Alaska..Oit.&.Gas. Coas..Commissio~ .......................................... ....................................................................................................................................................................... ~..c..h..0.r.~. ................................................................... Shot balanced Depths ove~under Referencedto__ Feet SPF Orient. Phasing O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - Zone Aperf/Reperf GPMA 3/25/94 v2.1 ARCO Alaska, Inc. Post Office Box lu0360 Anchorage A~aska 99510-0360 Telephone 907 276 1215 July 1,1994 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: N~~ay State Tract Operation Pressure Report /,.~'~3h~idential) ' -~ Dear Mr. Johnston: Included is a second quarter 10-412 Reservoir Pressure Report for the North Prudhoe Bay State Tract Operation (Confidential). If you have any questions concerning the information reported, please contact me at 265-6274. Sincerely, Karl G. Privoznik Senior Operations Engineer Greater Point Mclntyre Engineering KGP/jm Attachment ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT Name of Operator I Address ARCO Alaska, Inc.I P.O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool I Datum Reference I Oil Gravity I Gas Gravity Undetermined North Prudhoe Bay State Tract Operation 9245' ss (mid perf.) 35.1 0.7 ~ .-. Final Pressure Test Data Production and Test Data APl ~.~ Date Shut-in Shut-in Tool Final PRODUCTION RATES Liquid Wt. of Wt. of Casing Pressure Well Name and No. Number ~ (~: Tested Time Tubing Depth B.H. Observed (Bbls. per Day) (Mcfd) Gradienl Liquid Gas Pressure at 50- 029- O ~ (Hrs.) Pressure MD Temp Pressure Oil Gas Water Column Column Datum PRESSURE SURVEYS NPBS#3 22322 O 5/12/94 51 2100 16198 206 3803 2122 7501 1209 .40 - 3803. R .CEtVE£ dt L I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '. ¢~ //''~-'"-*/4,~,.,~ Title Senior Operations Engineer Date *7///'~'d/~ Form 10-412, Rev 7-1-80 ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 4, 1994 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: North Prudhoe Bay State Tract Operation Pressure Report (Confidential) SR ENG SR ENG ENG ASST' ENG ASST SR GEOL GEOL ASST GEOL ASST STAT Dear Mr. Johnston: Included is a first quarter 10-412 Reservoir Pressure Report for the North Prudhoe Bay State Tract Operation (Confidential). If you have any questions concerning the information reported, please contact me at 265-6274. Sincerely, Karl g Privozni Senior Operations Engineer Lisburne/Point McIntyre Engineering KP/jm Attachment RECEIVED APR -7 1994 ~/as?,a 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT ~lame of Operator ~ Address ~,RCO Alaska, Inc. I P.O. Box 100360, Anchorage, AK 99510-0360 ! Jndetermined North Prudhoe Bay State Tract Operation 9245' SS (mid perf.) 137.2 0.7 ~ ,-, Final Pressure Test Data Production and Test Data APl ~,~ Date Shut-in Shut-in Tool Final PRODUCTION RATES Liquid Wt. of Wt. of Casing Pressure Nell Name and No. Number --- o) Tested Time Tubing' Depth B.H. Observed (Bbls. per Day) (Mcfd) Gradienl Liquid Gas Pressure at 50- 029- ~ ~ (Hrs.) Pressure MD Temp Pressure Oil Gas Water Column Column Datum =RESSURE SURVEYS NPBS#3 22322 O 1/23/94 18 2350 16150 204 3800 2617 561 10400 .43 - - 0 3811 R E VED ~,nch0 age . I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '/~~. ,~_~~,j Title Senior Operations Engineer Form 10-412. Rev 7-1-80 Date North Prudhoe Bay State #3 Review March 29,1994 · Well Status · Production status Diagnostic data analysis · Material balance · Future plans Field Rules timing RECEIVED NORTH PRUDHOE BAY STATE #3 HISTORICAL SUMMARY Production Start-up October 13, 1993 Initial Rate: 9115 BOPD, 818 GOR, 0% WC (690 psi WHP, 34.9° APl) Reservoir Pressure (psia) @ 9245'ss (Mid-perfs) - April 1993 (Initial)~ 3922 0 MSTB - October 25, 1993,. 3872 to3922 85 MSTB - January 23, 1994,: 3825 479 MSTB Immediate GOR Increase, GOR Waiver: November 5, 1993 P.I. Test Indicated GOR Insensitive to Rate Shut-in Cycles, Ineffective in Controlling GOR Channel Detection Borax Pump-In Log (12/9/93) - Gas Source Inconclusive - Sadlerochit in Communication with Shublik Significant Watercut Show On 1/2/94, (7%) Production Profile Log (1/23/94) - Majority Gas From Top-Sadlerochit Perfs - Sag River/Shublik Squeeze Perfs Leaking Gas - Packer Appears Sound Last Rate: 18!9 BOPD, 4072 GOR, 28% WC (620 psi WHP) Cumulative Production as of 3/15/94:600 MSTB. APl Gravity 34.9 to 37.5° RECEIVED MAR 2 9 199~, Oil & Gas C0.s. Commission ~nch0rage NORTH PRUDHOE BAY STATE//3 WELL MECHANICS High Angle / High Step Out - Angle across pay: ~57.0° (66° maX.) - Drilling PBTD: 16,273'MD - Last Tag: 16,209'MD (64' of fill, lower 5' of perfs, covered) Perforations - Production: 16180-214'MD (34'MD Sadlerochit) Middle Squeeze: 16050-52 (Top Shublik.) ' Upper Squeeze: 15820.22 (Kingak- behind straddle) Tubulars - 4-1/2" tubing / 7" Production Liner PRODUCTION LOGGING Borax Pump-i.n / TDT-P Channel Detection Log (12/9/93) - Dislacement. 445 bbls crude/Il0 bbls Borax/285 bbls Crude Repeat TDT Logging Passe. s ' No Rathole (~5' of perforations covered) Conclusions - Sadlerochit in Communication w/Lower Shublik - Potential leak of Middle Squeeze Perforation (Sag/Shublik) - Gas Indicated Across Sag River Spinner / Temp./Gradio Log (.1/23/94) - Static Pass after ~16 hr shut-in - Dynamic Pass at 40 FPM Logging Up - Hole Conditions Prohibited Consistent Downhole Logs - No'Rathole (~5' .o.f. perforations covered) - Producing Conditions: 4305 BOPD, 572 BWPD, 2565 GOR Conclusions - Water Production from Base of Sadlerochit Perforations Significant. Gas Production from Top of Sadle.r. Perforations ' Confirm M~ddle Squeeze Perforations Leak, S~gnificant Gas - Straddle Pack Appears Mechanically Sound RECEIVED MAR 2 9 199,~ .0il .& Gas Cons. Commission ..... ' ~mchorage. NPBS#3 Well Test Data 20000 18000 16000 14000 12000 10000 8000 6000 4000 2O0O Startup Oct. 13 Z 30-Sep 20-Oct 9-Nov 29-Nov 19-Dec 8-Jan Date o I 28-Jan Oil Rate Water Rate Cum Oil 17-Feb 9-Mar 29-Mar Gas Rate 5000 4000 m 3000 '"" O E 2000 0 1000 KGP 3/9/q4 at 1~2o. 2~' MQ. w NUle~ NORTH PRUDHOE BAY STATE #3 BORAX PUMP-IN / TDT-P CHANNEL DETECTION LOG 12/9/93 SIGMA CURVES C~E Crude PueN)qn Pm. Dude BiNhm P~ml)-m ~ -.. _~... ~ ...... It 16110-~14'M0, AIN~- S4' M ~ovmd imam. ,_ , ,-- ~ wi TOT iT'... '~ by Kmpk = PRODUCJNG PJu~S 4305 BOPO. 57'2 BWPO. 2MS GO~ LOGGING SPEED 40 FPM UP SPINNER / TEMP. / GRADIO LOG 1/23/94 WELL ~flJT~N i .,,,,, ~ .... ~,,i ' i '- : ...... ...... f.. i ..... ',., ,- ........ 0.4 tO I 1 I~". ll200'IdD (kJe to M. letup. 4Mli M 4..q' MmmMe FeW North Prudhoe Bay Reservoir MATERIAL BALANCE Pressure Data' NPBS#3 Reservoir Pressure 4/26/93: Pressure measured 1/23/94: Pressure drop: 3922 psia 3825 psia 97 psi Cumulative production: (10/13/93- 1/23/94) Oil Gas Water 479 1.3 10 MSTB oil BSCF gas MSTB water Range of Hydrocarbon Volumes: Oil-in-Place Block 1 11-24 MMSTB Blocks 1-3 20-47 MMSTB Free Gas 18-32 BSCF 24-54 BSCF Material Balance Results: Conclusion: Pressure support external to Block 1 1) Cannot match measured pressure drop with just Block 1 volumes a) Assume Block 1 only, mid-range oil and gas volumes; AP = 170 psi 2) 3) Assuming Blocks 1-3 are in communication, can match measured pressure drop with gas cap = 50 BSCF Assuming Block 1 volumes only, can match measured pressure response if Block 1 is in communication with an aquifer = 7,000 Acres in area (20 times the area of Block 1) DEVELOPMENT PLAN · Continue producing NPBS#3 · Production data and pressure monitoring will allow refinement of oil-in-place estimates · Additional drilling dependent on estimated reservoir size and economic conditions · Ultimate development plan (drilling, gas or water injection) uncertain due to wide range of oil-in-place values and economic conditions ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 300'1 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-'1433 TELECOPY: (907) 276-7542 March 2, 1994 Andrew D. Simon Manager, Lisburne/Point McIntyre ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska, 99510-0360 Subj: North Prudhoe Bay State No. 3 Long Term Production Test Dear Mr. Simon: We have received your request t° extend long term testing at North Prudhoe Bay St. No. 3 dated February 11, 1993. According to your request, additional testing and diagnostic efforts are necessary to better understand the development potential of the pool tapped by North Prudhoe Bay St. No. 3. Review of the available information indicates that further testing is justified and that GOR limitation may still be waived according to the provisions of 20 AAC 25.240 (c)(3) during the test period. While the Commission supports your request to extend testing operations through September 30, 1994, we would appreciate a meeting to discuss your findings to date. We are particularly interested to know more about how you plan to manage the GOR and the general plans you have to clarify reservoir issues regarding development. Contact me or Russ Douglass to arrange a meeting. Sincerely, ( Chairman INSTRUCTIONS Use a separate sheet for each pool Show all data requested for each well separately, and determine the gas-oil ratio according to the following procedure: (1) (2) (3) (4) (5) (6) (7) (8) General: All well data and gas-oil ratio tests submitted to the Commission on this form shall be made by a person qualified by training or experience to make such tests. Methods of gas measurement used shall be in accordance with APl Standards. Gas Volumes: The volume of gas used in computing the gas-oil ratio and reported as being produced during the test (except tests on gas lift wells) shall be the total volume of gas produced from the well in the test period. This total volume of gas shall include all gas withdrawn from the casing as well as that produced through the tubing. Flowing Wells: The oil flow shall be stabilized during the 24-hour period immediately preceding the test. Adjustments in the rate of flow should be made during the first 12 hours of the stabilization period and no adjust- ment shall be made during the last 12 hours or during the time in which the well is being tested. Gas Lift: In submitting gas-oil ratio tests for gas lift wells, the total input and total output gas volumes shall be recorded separately. These volumes shall be properly identified and determined by continuous measurement during the test. The volume of gas used in determining the operating gas-oil ratio here- under shall be the volume remaining after the total input gas has been deducted from the total output volume: this net volume is to be reported on this form. Pumping Wells: In computing the operat'ing gas-oil ratio, the total volume of gas a'nd the total barrels of oil produced during the test period must be used regardless of the pumping time' in the test period. Method of Operation: ~- Under "Method of Operation" use the following code: 1-Flowing, 2-Gas Lift, 3-Rod Pump, 4- Hy- draulic Pump, 5-Submersible, 8-Standing or shut-in, 9-Other. ~ Pressures: Show the stabilized working pressure on the tubing, casing, and separator, while the well is being tested. Gas Production: The Gas Production listed 'shall be the total volume of gas produced during the test, expressed in thousands of cubic feet (MCF) at a standard pressure of 14.65 pounds per square inch, absolute, and a standard temperature of 60 degrees Fahrenheit; volume corrections to be made in accordance with Chapter 14.3 of the APl Manual of Measurement Standards (adopted A.G.A. Report No. 3). Form 10~,09 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION r~,, ,,~~.i,L... lct,--,..3 WEIl STATUS REPORT AND GAS-OIL RATIO TESTS ARCO Alaska, Inc. NORTH PRUDHOE BAY STATE ~3 TRACT OPERATION Name of Operator: __, Field and Pool: , Unit or Lease Name: P.O. BOX 100360, ANCHORAGE, ALASKA 99510 711193 to 12/31/93 (24 Hour Rates) Address: Reporting Period: ~ SEPARATOR LENGTH PROOt~TION DURING IIr.~i GAS-OIL RATIO WELL ~U_¥~E AND NO. APINUMBER DATEOFTEST METHOO CI~KE._Cj[~'__ ~ ~ SEPARATOR TEMPff: OFTEST WATER_R~__$ GRAVITYOtL* OIL_RRLS. GRAVITY GAS* GASMscF CU. FT. PERBI~-. NPBS ~3 50-029-22322-00 Dec-93 1 92 950 549 127 5.0 39 37.5 4905 0.72 16637 3392 , .... __ -- All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservalion Commission. hereby certify that the foregoing is true and co,reel to the best of rn~ knowledge. ' Last gravity measured, not neces~ly from I~ed test ~:~ Form 10-409 Rev 7-1-80 INSTRUCTION,SON REVERSE SIDE Submit in duplicate ARCO Alaska, Inc. Post Office Box ,0'0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4275 Andrew D. Simon Manager Lisburne/Point Mclntyre February 11, 1994 Mr. D. W. Johnston Chairman, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: North Prudhoe Bay State No. 3, Long Term Production Test RECEIVED FEB 1 4 1994 A~aska 0il & Gas Cons. Commission Anchorage Dear Mr. Johnston: ARCO Alaska, Inc., as Operator of the North Prudhoe Bay State #3 (NPBS-3) Tract Operation requests an extension of the production test period of NPBS-3 (APl #50-029-22322) under the plan of development described in my letter dated May 17, 1993 and as approved in your correspondence dated May 17, 1993. The requested extension is for the period of March 13, 1994 through September 30, 1994. As discussed in more detail below, production during this extension period would facilitate further evaluation of the development potential of the accumulation penetrated by NPBS-3. Granting the requested extension would also allow production activities to continue for the full period currently approved by the Director of the Division of Oil and Gas of the Alaska Department of Natural Resources for the execution of tract operations. (See Decision and Findings of the Director of the Division of Oil and Gas on the Application to Produce North Prudhoe Bay State No. 3 as a Tract Operation, Well Certification of North Prudhoe Bay No. 3, and Approval of the Plan of Development for the North Prudhoe Bay Reservoir, dated December 30, 1993, '1] 10. A copy of the decision is attached.) Initial production from NPBS-3 commenced on October 13, 1993 and is commingled with other production streams in the Greater Pt. Mclntyre Area. To date, this well has produced in excess of 500 MSTB of 35-37.5° APl gravity crude. The producing Gas/Oil Ratio (GOR) has risen from an initial tested value of 818 to 3,830. Attached is a copy of the PVT analysis from the crude produced from this well (report labeled as "Wheatall No. 1") which indicates a Solution GOR of 982 SCF/STB. Recent well tests also indicate an increase in the producing watercut ( to 16%). The primary objective of the production testing of NPBS-3 is to help determine the reservoir size, oil and gas in place, and thus provide further data to support future development and depletion plans. To this end, a significant number of diagnostic operations have been performed in the well's short productive history. Two forms of production logging have been used to determine the well's mechanical integrity and the source of high GOR production. Results of these efforts indicate that the packer appears to be sound and that the high GOR production originates from the top Sadlerochit as well as the previously squeezed Sag River perforations. The reservoir pressure continues to be monitored and is currently at 3,825 psi at datum. This compares to an original pressure of 3,922 psi taken in April 1993. Diagnostic testing will continue as well performance dictates. Material balance calculations honoring the measured pressure drop of just under 100 psi and the historical production data indicate pressure support external to the producing fault block. Neglecting potential aquifer contributions, the calculated pressure decrease corresponding to the measured reservoir voidage for the mapped OOIP would be almost twice the actually measured 100 psi. Conversely, to match the measured pressure drop requires increasing the mapped OOIP by a factor of two. This scenario requires more hydrocarbon pore volume than is mapped in the producing fault block, indicating some form of external pressure support. Since only one data point has been collected to date, there is not a unique solution to the material balance. It is not ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Mr. Johnston February 11, 1994 Page 2 currently possible to determine if the support is from a gas cap, larger than mapped OOIP, an aquifer, or some combination of the three. Substantial uncertainty remains as to the development potential of this accumulation. Continued production performance from NPBS-3 will clarify some of this uncertainty and lead to additional development if warranted. At this time, we see no adverse conservation issues resulting from continued production. Therefore, an extension of the production testing period is requested. Sincerely, A. D. Simon JLH~m CC: R. L. Steinmetz T. J. Obeney J. E. Eason Exxon BPX DNR RECEIVED 8 1 4 1994 Gas Cons. Commission Anchorage PRUDHOE BAY UNn' APPLICATION TO PRODUCE NORTH PRUDHOE BAY STATE NO. 3 AS A TRACT OPERATION, WI~.I. CERTIFICATION Ol~ NORTH PRUD~E BAY STATE NO. 3; AND APPROVAL Ol~ THE PLAN ON DEVELOP~ NOR THE NORTH PRUDHOE BAY {t~l~tVOl~ DECISION AND FINDINGS OF THE DntE~lt O1~ TI, lB DIVISION OF OIL AND OAS DECEMBER 30, RECEIVED FEB 1 4 1994 A!~ska Oit & Gas Cons. Commission Anchorage On August 18, 1993, I issued the Decision and Findings of the Director of the Division of Oil and Gas (Expansion Decision) on the Application for the Third Expansion of the Prudhoe Bay Unit (PBU) and Formation of the Pt. Mclntyre Participating Am".a (Application). I denied the Application. The Expansion Decision start, however, that the denial would be reconsidered if the Applicants~ amended their Application to mitigate the negative effects on the state's interest which were described in the Expansion Decision. On October 13, 1993, the Applicants submitt~ an Amended Application for Proposed Pt. Mclntyre Participating Area and Prudhoe Bay Unit Expansion (Amended Application). In the Amended Application, the Applicants incotl~'ated a May 17, 1993 application from ARCO and Exxon requesting, among other things, to produce the North Pmdhoe Bay State (NPBS) No. 3 well as a tract operation within the PBU (Production Application). Prior to October 13, 1993, the Division of Oil and Gas had not issued a decision regarding the application to produce the NPBS No. 3 well as a tract operation. On October 13, 1993, I issued an Order granting the Application as amended by the Amended Application. Further, the ~ granted the Production Application. The ~ granting the Amended Application and the Production Application stated that a decision explaining the basis for these orders would be issued by the end of 1993. The following findings set forth my basis for granting the Production Application. The NPBS No. 3 Well was drilled, compleled, and tested from January through April 1993. At the time the well was drilled (January - February 1993), its bottomhole location within Tract 8 was within the PBU. On April 14, 1993, however, I issued a decision denying a request for a further deferral of conn-action ("the Contraction Decision") of all or portions of Tracts 5, 6, 7, and 8 ( "the Contracted A~") from the PBU. As of April 1, 1993, these tracts were contracted out of the PBU. The Contraction Decision was appealed to the Commissioner of the Department of Natural Resources (DNR) on April 30, 1993. The appeal stayed the Contrncdon Decision. At the time of the Order, October 13, 1993, the Commissioner of the DNR had not issued his Decision and Findings regarding the Contraction Decision appeal. The Production Application issues were entanlFled in the Contraction Decision, and it impractical to rule separately on the ~on Appli_c_ ation. In order to allow early production and evaluation of the formations that encompass the North ~oe Bay reservoir under Tract 8 (ADL 25297), the provisions of paragraph d. of the October 13, 1993 Amended Application were developed as ~ prnctical means to resolve the Production Application. RECEIVED Gas Cons. Commission Anchorage ~The Applicants are ARCO Alaska, Inc. (ARCO), BP Exploration (Alaska) Inc. (BPX), and Exxon Cotp<ntion (Exxon). Based on the foregoing, I .hereby make findings and impose conditiom u foUows: (1) A review of the application, including the attached well test information, as weU as the. available geological, geophysical and engineering data which were submitted demonstrate that a paying quantities certificafien is appropria~ for the North Prudhoe Bay State No. 3 well in acc~ce with 11 AAC 83.361. The North Prudhoe Bay State No. 3 well, the producing intervals of which are located on ADL 28297, is hereby ~ed capable of producing in paying quantities effective as of the date of this decision. (2) That portion of oil and gas lease ADL 28297 containing the producing interval of N-PBS No. 3 weU contracted out of the Pmdhoe Bay Unit effective April 1, 1993. Acc~gly, the terms and conditions of paragraph d. of the Amended Application arc incorporated into this Decision as they regard the N'PBS Acreage. (3) Approval to operate NPBS No. 3 as a Tract Operation within the PBU is granted for the period October 13, 1993 through September 30, 1994. During the period of the approved tract operation, all production will be allocated to lease, ADL 28297. (4) Based upon the department's review of the well test-based production allocation methodology submitted to the state in Attachment 2 to the "North Pmdhoe Bay Reservoir Request for Tract Operation", that methodology is determined to be acceptable for royalty allocation purposes and for allocating the commingled gas and hydrocarbon liquids production among the North Pmdhoe Bay Reservoir, the West Beach Participating Area, Pt. McIntym Participating Area, and the Lisbume Partidpating Area as those streams are processed through the Lisburne Production Center ([.PO. The LPC Operalm,, ARCO, shall provide the Division with the monthly Production allocation reports and well test data for the wells producing through the LPC by the 20th day of the following month. The Division reserves the right to request any information it deems pertinent to the review of those relmm. The aHocalion relX~ shall include a monthly oil, gas,. and water allocation factor to be applied uniformly to the commingled production, a summary of monthly allocation by well, a summary of the aHocalmt volumes of oil, hydmcarlxm liquids, gas, and wamr by participating area, oil gravity for ench part~'pating ama and the oil gravity of the combined streamS, and specific well test data for all tests which have been conducted. allocations to inmre compliance with the methodology prescribed in this decision. Such review may include but is not limited to, i_n_specfion of facilities, equipment, F~.~ '~ 4 ~99~, well test data, and separator backpressure adjustments. (6) In order to account for the gas produced from each reservoir, the gas volume disposition and gas reserves debited from or credited to each reservoir or pool utilizing the shared Lisburne production facih'ties, the N'PBS Tract Operator and the LPC Operator shall submit a monthly gas disposition and reserves debit report using the form indicated in Attachment 1, or such form as may be acceptable to the division. The gas disposition report shah be submitted with the monthly production allocation repons. The state is not a party to the current Greater Point Mclntyre Area Gas Management Agreement. Should the North Prudhoe Bay State Tract Operation area ultimately be eliminated from the PBU Area, a gas management agreement will have to be approved by the state if the produced gas is not sold or returned to the North Prudhoe Bay reservoir. (7) Any deductions from the state's royalty share of oil ptxxinced from the approved North Prudhoe Bay Tract Operation Area (T12N - R14E, Sec. 22, U.M.) is governed by the 1980 Prudhoe Bay Settlement Agreement. Whether or not the state bears any deduction from the state's royalty share of the repm',ed "NGLs" and dry gas, and if so, what those costs may be, is a matter of dispute as part of the Severed Issues in the ANS Royalty Litigation. Those field cost allowances, if any, are subject to the final resolution of the litigation. (8) With respect to the preduction allocated from the North Prudhoe Bay Tract Operation and the state's taking of any royalty-in-kind from the North Prudhoe Bay Reservoir, it continues to be the state's position that it has only nominated the taking of royalty oil in kind and has never nominated gas, for in-kind ~idng. (9) Diligent exploration and delineation of the North Prudhoe Bay Reservoir is to be conducted by the Tract Operator under the plans of development and operation approved by the state. (I0) The plan of development and operations for the North Prudhoe Bay Tract Operation meets the requirements of 11 ,sAC 83.158. The plan is approved for a period October 13, 1993 through September 30, 1994. This plan is for operations conducl~i in (T12N - R14E, Sec. 22, U. M.). If the NPB$ Acreage is ultimn__te!y eliminated from the PBU Area, a new and separate unitization action An updam to the plan of development shall be submitted on September 1, 1994. The update should describe the status of projects undertaken and the work completed, as well as any changes to the plan. RECEIVED FEB I 4 1994 Oil & Gas Cor~s. Commission Anchorage For these reasons and subject to the conditions, interpretations, and limitations noted, the Decision and Finding regarding the Production Application is approved ¢ffccfive October 13, Under 11 AAC 02.010-.080, Exxon has thirty calend~rs after the date of delivery of the decision to appeal thc decision to the commissioner. (ARCO and BPX have a/reed not to appeal the Amended Decision.) To be timely filed, the appeal must bo received by the Department of Natural Resources, at 5th Floor, 400 Willoughby Avenue, Juneau, Alaska, 99801-1724, within the thirty calendar days. Any use of this Decision regarding the ~on Application is subject to the limitations set forth in the Applicants' Amended Application, dated October 13, 1993. Vision o~ Oil and Gas cc: Harry A. Noah, Commissioner Alaska Deparm~ent of Nann'al Resources Da~ Attachments: I) Delegation of Authority 2) Example Gas Reserves and Debit Repo~ PBU.NPBS#3 FEB ~1-4 1~4. .Anchorage 'DELEGA ..)NS OF AUTHORITY FOR THE DIVISIL,,,~ OF OIL,nJ'qB G~S Regul .atory Purpose or Authority Authority Action ~ Oeleoated to 11 AAC 82.40O 11 AAC 82.405 11 AAC 82.410 11 AAC 82.445 11 AAC 82.450 11 AAC 82.455 11 AAC 82.460 11 AAC82.465 11 AAC 82.470 11 AAC 82.475 11 AAC 82.600 11 AAC 82.605 11 AAC 82.610 11 AAC 82.620 11 AAC 82.625 11 AAC 82.635 11 AAC 82.640 11 AAC 82.645 Parcels Offered for Competitive Lease Method of Bidding Minimum Bid Incomplete Bids Rejection of Bids Tie Bids Additional Information Award Leases Issue Leases Bid Deposit Return Required Bonds Approve/Deny Assignments of Oil and Gas Leases Segregate Leases Transfer of a Lease, Permit or Interest as a Result of Deattt , Elf. Date of Assignments Surrenders Survey Requirement Conforming Protracted Description to Official Surveys ATTACH}tENT 1 Commissioner No Delegation Commissioner No Delegation Commissioner No Delegation Commissioner No Delegation Commissioner No Delegation COmmissioner No Delegation Commissioner No Delegation Commissioner Director, Div. of Oil & Gas (DOG) Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director. DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Commissioner Director, DOG No Delegation Commissioner No Delegation RECEIVED FEB ! 4 1994 Oit & Gas Cons, Commission Anchorage Delegations of Authority Page 2 Regulatory Purpose or Action Authority Authority Delec~ated to 11 AAC 82.650 11 AAC 82.660 11 AAC 82.665 11 AAC 82.700 11 AAC 82.705 11 AAC 82.710 11 AAC 82.800 11 AAC 82.805 11 AAC 83.153 11 AAC 83.158 11 AAC 83.303 11 AAC 83.306 11 AAC 83.'311 11 AAC 83.316 11 AAC 83.326 11 AAC 83.328 11 AAC 83.331 11 AAC 83.336 Control of Lease Boundaries Excess Area; Partial Termination Rental and Royalty Relief Taking Royalty in Kind Bidding Method Notice of Sale Production Records Test Results Well Confidentiality ApprovelDeny Lease Plan of Operations Unit Agreement ,Approval Accept Application for Unit Agreement Approval Publish Public Notice of Unit Agreement Application Approve/Deny Unit Agreement Require or Accelot Nonstanclarcl Unit Agreement Language Mandate Unitization (Involuntary Unitization~ Approve/Deny Change. in Grant Extension of Unit Term; Grant Suspension of Operations (Force Majeure); Terminate Unit Commissioner No Delegation Commissioner No Delegation Commissioner No Delegation Commissioner No Delegation Commissioner No Delegation Commissioner Commissioner No Delegation D[rector, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner Director, DOG Commissioner No Delegation Commissioner Director, DOG Unit Operator Commissioner No Delegation Delegations of Authority Page 3 I=,eguiatory Purpose of Authority Authority Deleq_ atecl 11 AAC 83.341 11 AAC 83.343 11 AAC 83.346 11 AAC 83.351 11 AAC 83.356 11 AAC 83.361 11 AAC 83.371 11 AAC 83.373 11 AAC 83.374 11 AAC 83.383 11 AAC 83.385 11 AAC 83.393 Approve/Deny Plan of Exploration Approve/Deny Plan of Development Approve/Deny Plan of Operations Approve/Deny. Participating Area Expanci/Contract Unit Area Certify Wells as CapaDie of Production in Paying Quantities Approve/Deny Allocation of Cost and Production Formulas Sever Leases Declare Unit in Default Notation of Approval on Joinder Modification of Unit Agreement Approval of Federal or Private Party Unit Agreements Commissioner Commissioner Commissioner Commissioner Commissioner Commissioner Commissioner Commissioner Commissioner Commissioner Commissioner Commissioner Director, DOG Director, DOG Director, DOG Director, DOG Director, DOG Director, DOG Director, DOG Director, DOG No Delegation Director, DOG Director, DOG No Delegation i hereby delegate ttte au~ority vested in me through AS '38.05.180 to the Director of the Division of Oil an(:[ Gas as noted above, This delegation of authority is effective until revoked by me. .Harry' ,A. Noa,rX'. Commissioner'"'~ ,~,,-Alast~. Dep/a~tment of Natural Resources / .RECeIVeD FEB 1 4 1994 Gas Cons. Commission Anchorage I. inbume WiI Befall AAI ,TOTAL RECEIVED FEB ! 4 1994 Aiaska. Oil & Gas Cons. Commission Anchorage NO~ Emmm ~ mm mmmmmmm m M mm ~mm mmmm m m~ u~ mm mmmm gram in m,,y mom ARCO Alaska, inc. ~ Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 January 31, 1994 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Point McIntyre Oil Field Pressure Report West Beach Oil Pool Pressure Report North Prudhoe Bay State Tract Operation Pressure Report (Confidential) Dear Mr. Johnston: As required by Conservation Order No. 317, Point McIntyre Oil Field Rules, and Conservation Order No. 311, Prudhoe Bay field Rules (West Beach Oil Pool) we are hereby submitting Form 10-412, Reservoir Pressure Report for the fourth quarter of 1993. Included is a fourth quarter 10-412 Reservoir Pressure Report for the North Prudhoe Bay State Tract Operation (Confidential). A 10-412 report has not been submitted for the Lisburne Oil Pool since no pressures were obtained during the fourth quarter. If you have any questions concerning the information reported, please contact me at 265-6274. Sincerely, Karl G. Privoznik Senior Operations Engineer Lisburne/Point McIntyre Engineering jm Attachments ?::EB - 5 ~994 Oil & 6as Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT Name of Operator I Address ARCO Alaska, Inc.I P.O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool [ Datum Reference I O,I Gravity I Gas Gravitv Undetermined North Prudhoe Bay State Tract Operation 9245' ss (mid peal.) 36 0.7 ~ ..-. Final Pressure Test Data Production and Test Data APl ~-.~ Date Shut-in Shut-in Tool Final PRODUCTION RATES Liquid Wt. of Wt. of Casing Pressure Well Name and No. Number ~ ~ Tested Time Tubing Depth B.H. Observed (Bbls. per Day) (Mcfd) Gradien~ Liquid Gas Pressure at 50-029-2 O ~ ......... (Hrs.) Pressure MD Temp Pressure Oil Gas Water Column Column Datum PRESSURE SURVEYS NPBS4¢3 2322 O 10/25/93 48 - 14,348 183 3648 8349 35 15,412 .255' - - 3857'~.~ to 3907 'Due to well conditions Gauge was set @ , 14,348' MD (820' TVD above datum) Gradient measured above 14,348' M D Pressure range based on uncertainty of fluid gradient below gauge depth. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Senior Operations Engineer Date I' Form 10-412. Rev 7-1-80 AOGCC Individual Well Geological Materials Inventory Page' 1 Date: 01/25/94 PERMIT 92-145 92-145 92-145 92-145 92-145 92-145 92-145 DATA -- CDN MWD SURVEY SURVEY SURVEY BHC/MAC/CSC CDN CNL/GR T DATA_PLUS 16463-15775, LDWG / 297-16465 FINAL / L~ 100-16465, GCT ~ MWD-LDWG.TIF ~//L 15700-16274 ,L 15800-16400~ LWD 15270-16331 CH RUN DATE_RECVD 1 04/02/93 04/02/93 04/02/93 04/26/93 1 04/02/93 1 04/02/93 1 04/02/93 92-145 DGR/EWR/FXE 5345-9458 MWD-TVD 6-10 04/02/93 92-145 DGR/EWR/FXE 5345-9458 MWD-TVD 6-10 04/26/93 92-145 DGR/EWR/FXE 7664-16465 MWD-MD 6-10 04/02/93 92-145 92-145 92-145 92-145 DGR/EWR/FXE EPM GCT MAC/AC/FWF 7664-16465 MWD-MD 10200-16400, 40-15750 MD 15700-16274 6-10 04/26/93 1 04/02/93 I 04/02/93 1 04/02/93 92-145 MAC/GR 15700-16274 1 04/02/93 92-145 MUD 10200-16486, MD 1 04/02/93 92-145 MUD 6520-9458, TVD 1 04/02/93 92-t~5 92-145 92-145 92-145 PET PFC/GR PFC/GR SBT/GR/CCL AL 6500-9500 15270-16365 JL 15930-16150 14000-16254 04/02/93 1 04/02/93 1 04/02/93 1 04/02/93 92-145 92-145 SBT/GR/CCL SURVEY 15682-16380 0.00-16465 SPERRY SUN MWD 04/02/93 04/02/93 92-145 92-145 92-145 407 DAILY WELL OP REPORT U~R COMP DATE: 04/26/93 ~R 01/02/93-02/17/93 ~/ FINAL WELL REPORT 05/06/93 05/06/93 03/19/93 AOGCC Individual Well Geological Materials Inventory Page: Date: 2 01/25/94 PERMIT DATA T DATA_PLUS -- -- RUN DATE_RECVD 92-145 SURVEY 0.00-16465 GCT SSTVD 04/02/93 92-145 DRY DITCH 92-i45 5575 92-145 5576 10200-16465 SS#867 14480-16260 MAC WF *MEMO ~ 14593-16331 OH-MAC/GR 03/19/93 04/02/93 04/02/93 Are dry ditch samples required?~no And ...... receive -no Was the well cored? yes ~no~ Analysis & description receiv~~ yes no .Are well tests required? yes Received? Sl no Well is in compliance Snitial Comments .~ ~/~-~oJ~~-, ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 5, 1993 J. L. Harris Arco Alaska, Inc. P.O. Box 10360 Anchorage, Alaska, 99510-0360 Subj' North Pmdh°e Bay State No. 3 Long Term Production Test Dear Mr. Harris, We have received your request to continue long term testing of North Prudhoe Bay St. No. 3. A review of thc original application and appropriate regulations revealed the following: 20 AAC 25.240 (a) requires in part, ..."for each new pool, the operator shall determine within 3 months 'after discovery, the original solution gas-oil ratio by a well test conducted in a manner approved by the commission." 20 AAC 25.240 (c)(3) allows the commisSion discretion to waive the gas-oil ratio limitation ..."if acquisition of pool performance data is necessary to determine an optimum reservoir managen~ent program." 3. ARCO Alaska's original well test proposal for NPB St. No. 3 was approved by the Con]mission via letter from D.W. Johnston to A.D. Simon dated July 6, 1993. Thc Commission expects ARCO to determine original gas-oil ratio during the current test operations. Bottom hole and/or surface PVT sampling and well testing are acceptable means of establishing initial gas-oil ratio and should be accomplished within 3 months from thc start of the test period. Commission approval of your test program was granted allowing ARCO Alaska to define and evaluate the producibility of the Sadlcrochit formation at NPB St. No. 3. The testing and collcction of reservoir data are necessary to determine optimum reservoir management. Accordingly, the Commission approves exception to thc gas-oil ratio linfits of 20 AAC 25.240 during the 5 month test period. If you have any questions, feel free to contact thc Commission at 279-1433. Chairman . ARCO Alaska, Inc. (!~' I Post Office E~.. :00360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 October 25, 1993 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Subject: North Prudhoe Bay State No. 3, Long Term Production Test Dear Mr. Johnston: SR ENG ENG ASST I SR GEOL I GEOL ASSTI GEOL ASST1 STAT TECHI STAT TECH ~-- :FILE I _ ARCO Alaska, Inc., as Operator of the North Prudhoe Bay State #3 (NPBS-3) Tract Operation, is requesting permission to cOntinue production of NPBS-3 (APl #50-029-22322) in light of recent well test data indicating an increase in the well's Gas-Oil Ratio (GOR). Initial production of the well commenced on October 13, 1993. The well was tested the following day and showed an oil rate of 9,115 STB and a GOR of 818. Subsequent testing on October 20 and 23 indicated the GOR had increased to 1,707 and 1,846 respectively. The original GOR was not knOWn at the time of submission when filing the Request for Tract Operation (May 17, 1993). The preliminary well test data submitted was obtained by flowing to tanks while venting the gas. The AOGCC approved a five month Plan of Development and Operation on ,J,,uly 6, 1993. HOwever, the Alaska Admini~r~.ti~ Co'-de-~0'~AC'~5.240' sets ~its--for ~'well s ~-'~0--~uci~ (GOR). As additional well/reservoir performance data is obtained from NPBS-3 over the next five months, the standard GOR limits specified by 20 AAC 25.240 may be exceeded. Paragraph (c), Section (3) of 20 AAC 25.240 allows for such administrative actions. As explained in the NPBS-3 plan of Development and Operations, the overriding objective for the near-term production of NPBS-3 is to help determine the reservoir size, oil and gas in place, and thus to provide further data to support future development and depletion plans. Attempts to determine the mechanism for the change in well/reservoir performance are underway. A pressure buildup survey is currently being obtained. Retesting of the well is planned to verify pedormance trends. There continues to be the need to maintain sustained NPBS-3 production in order to fully meet the original testing objectives. Future gas production and reservoir pressure behavior in relation to the cumulative recovery will be vital in determining ultimate development and depletion plans. Approval of this request for administrative action will significantly impact the quality of the NPBS-3 reservoir development plans. If there are any questions or comments, please feel free to contact me at 265-6538. Engineering Supervisor Lisburne/Point Mclntyre Engineering KGP:tg:jb cc: W.J. Pish, Exxon Co., U.S.A., Houston RECEIVED OCT 2 7 199 AJaska .Oil .& Gas Cons. Commission ~Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company ARCO Alaska, Inc. Lisburne/Point McIntyre Engineering Date: August 31, 1993 Subject: Transmittal #NPBS-014, North Prudhoe Bay State #3 Tape return From' ARCO Alaska Inc. To: Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please find enclosed the MAC Waveforms (Monopole/Dipole) tape for North Prudhoe Bay State #3 well. This tape was returned by you because of a problem with the tape's contents. We returned it to the Western Atlas Wireline Services who found corrupted data when they checked it. They rewrote the original data to tape and returned it. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Please sign Laura S. Lahrson, ATO-40~?¢ ARCO Alaska, Inc 4,~*~O,,~ ~. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #NPBS-014 ALASKA OIL AND GAS CONSERVATION COMMISSION July 6, 1993 Andrew D. Simon Manager Lisburne/Point McIntyre ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7,542 Re: North Prudhoe Bay State No. 3 well testing Dear Mr. Simon: In correspondence dated May 17, 1993 you requested Alaska Oil and Gas Conservation Commission (AOGCC) approval to conduct a long-term production test of the North Prudhoe Bay State No. 3 exploratory well (NPBS-3). Data from the proposed testing will further define the areal extent of the Sadlerochit interval, evaluate its long-term producibility and possibly justify a delineation well. Produced fluids from the NPBS-3 will be commingled on the surface in the Lisburne Production Center (LPC) prior to custody transfer. It is ARCO's proposal to utilize Lisburne facilities to conduct a minimum of two well tests per month in order to properly allocate produced fluids to the NPBS-3. It is understood that facility sharing agreements with the West Beach and Lisburne owners are in place. The Commission hereby approves production testing of the North Prudhoe Bay State No. 3 exploratory well as proposed for a period not to exceed five months from the beginning of first production. Additional test time may be approved upon proper application to the AOCJCC. Chairman ~ printed on recycled paper STATE ~F ALA~ A~aska Oil Gas Conse~ation Commission Anchorage, Alaska 9951}14192 CONFIDENTIAL DATA RELEASE The AOGCC will release confidential well data to aulhorized DNRIDOG employees. All data is to be inventoried prior to release and a copy of the inventory given to the DNRIDOG employee. ,,, 01} Permltto Drill {40i}:~pages 02} Completion Report{4O7}' ~'pages 03} Daily Drilling History: .2~ges 04} Directional Surveys: I ~ pages 4-~ 05} Drill Stem Tests: ,,~pages 06} Core Anaysis Report: ,,~pages 07'} Core Description: ~::~pages 08} Digital Data: ~ reels 09} Formation Picks~ ~ q pages 10} Bluellnes' logs {list below} OTHER -LOG ~PE I INTERVAL ........ RuN ~ SCALE . . ..... ,,, TODAY'S DATE' The under-signed ~/t/,,~,~'~ employee hereby accepts receipt of the above listed confidential materials. Print and sig.~ame below. Name: Authorized ,,f~ersonnel~w to verify transference of these confidential materials. 'Facsim"ile COver Sheet To: company; Phone: Fax: From: Company; Phone= Fax: LARRY GRANT Alaska D.N.R. Oil & Gas Conservation Comm. 907-279-1433 907-276.7542 Alaska D.N.R. - Division of ,.,,, ,, ~o~, (907)762-2140 (907)562-3852 Date: 06t10/93 Pages including this cover page: I Larry, I request Ihe following well data be prepared for me to pickup as soon as possible. Thanks for your help. , BP Cascade #1 (93-00Ol)-all well logs, well history, completion report, horizon picl(s, directional surveys, core descriptions & analyses, & produ~ion leas. BP Cascade #lA (93-0041)--all well logs, well history, completion report, horizon picks, directional surveys, core descriptions & analyses. & production lests. · Conoco N.W, Milne Pt. #1 (91-0145).-all well logs, well history, completion report, horizon picks, directional surveys, Oore descriptions & analyses, & produ~ion tests. · Conoco Badami #2 (91-0144)--all well logs, well history, completion report, hodzon picks, directional surveys, ~ore descriptions & analyses, & production tests. · ARCO N. Prudhoe Bay State #3 (92-0145)--ali well logs, well history, completion report, hodzon picks, directional surveys, core descriptions & analyses, & pmduclion tests. · ARCO Tulaga #1 (95-0010)--ali welt logs, well history, completion report, horizon picks, directional surveys, core descriptions & analyses, & production tests. ,, ARCO Jones Island #1 (92-0140)-all well logs, well history, completion report, horizon picks, directional surveys, core descriptions & analyses, & production tests. · Exxon Thetis Island #I (93-0021)-~all well logs, well history, completion report, hodzon picks, directional surveys, core descriptions & analyses, & produ~ion tests. · ARCO Kuukpik #3 (92-0138)--all horizon picks and production tests, · ARCO Colville River #1 (92-0153)--all core descriptions & analyses, [0'cl. ;~98~:;~9ciL06 '0~I ;~V~ S~9 (Iffy 'II0 AI(]/~i~ J.~; ci0:lB Memorandum State of Alaska Oil and Gas Conservation Commission To: Russell A. Douglass June 2, 1993 Fm: Robert P. Crandall///ff~ NPBS3-1.doc Jack D. Hartz ~>~ North Prudhoe Bay State No. 3 Production Allocation During Tract Operations Subj: We have reviewed the application of ARCO Alaska, Inc. for Tract Operations at North Prudhoe Bay State No. 3 dated May 17, 1993. The Tract Operation is requested to allow evaluation of the producing formations discovered during exploration operations in January and February, 1993. The responsibilities of the Commission in this matter, as defined in Section 31.05.030, include: (d)(6) - gauging or other measuring to determine the quality and quantity of oil and gas; (d)(8) - measuring and monitoring of oil and gas pool pressures; and (d)(9) - filing and approval of a plan of development and operation for a field or pool in order to prevent waste, insure a greater ultimate recovery of oil and gas, and protect correlative rights of persons owning interests in the tracts of land affected. A brief discussion of concerns raised in the ARCO application relating to each of these responsibilities follows. 31.05.030 (d)(6). Relevant issues related to the measurement of hydrocarbons from the North Prudhoe Bay No. 3 well are summarized below. . Surface commingling of North Prudhoe Bay State No. 3 production streams with those from West Beach and Lisbume pools will afford an opportunity for efficient evaluation of formation producibility and viability of the prospect for additional development. . 20 AAC 25.230 governs production measurement before severance from a property or unit. Paragraph (g) allows variance from production measurement requirements based on the Commission's discretion. Short term reservoir testing is an accepted, prudent practice to evaluate potential development of a prospect, and could be considered a justifiable reason for variance from 20 AAC 25.230 during the test period. North Prudhoe Bay state No. 3 June 2, 1993 Page 2 3. Surface commingling may be allowed in accordance with 20 AAC 25.215 and 25.245 provided applicable well(s) are tested at least monthly. . Production allocation methods adopted in Conservation Order 311 for the West Beach Pool are appropriate for the period of evaluation, as long as the length of well tests is a function of a well's producing characteristics, and is not determined by availability of test facilities. 5. Statewide regulations will apply to production operations except for variance from 20 AAC 25.230. 31.05.030(d)(8) invests the Commission with oversight relating to the measuring and monitoring of oil and gas pool pressures. The operators state that "[a]n important aspect of the evaluation process will be implementation of a reservoir surveillance program." 31.05.030(d)(9). The subject property (ADL-28297) has been contracted out of the Prudhoe Bay Unit through a decision of the director of the Division of Oil and Gas, Department of Natural Resources (DNR). The working interest owners of this tract currently are appealing this decision to the Commissioner of DNR. The ADL-28297 owners indicate integration of interests allowing sharing of production facilities between the North Prudhoe Bay State No. 3 well and Lisburne PA facilities is accomplished under Article 53 of the Lisburne Operating Agreement (LOA). If their appeal is unsuccessful, the terms of the LOA will have no bearing on ADL-28297, and a new agreement will be required to satisfy the requirements of 25.517(b)(2) and (c) prior to commingling of North Prudhoe Bay State No. 3 and West Beach production. Recommendation: The request for commingling production from North Prudhoe Bay State No. 3 with that of West Beach and Lisburne Pools should be approved, contingent upon resolution of the Prudhoe Bay Unit owners' appeal to retain ADL-28297 in the Prudhoe Bay Unit. ~"-~0therwise, provisions of 20 AAC ~_5~:..~7(b)(2) and (c) will apply, which require evidence ?f integration of interests before commingling may occur.~Allocation procedures and reporting requirements should follow those of Conservation Order 311 until such time as the test and evaluation are completed, or for one year. Provisions for renewal of the variance should be included in the approval. ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4275 Andrew D. Simon Manager Lisburne/Point Mclntyre May 17, 1993 James E. Eason, Director Division of Oil & Gas Department of Natural Resources P. O. Box 107034 Anchorage, Alaska 99510-7034 David W. Johnston Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 SR ENG ENG ASST ..... .~ :3 ASST :GEOL GEOL ASST '-'GEOL ASST STAT-TECH STAT TECH FILE Subject: 1) Application for Certification of North Prudhoe Bay State No. 3 (ADL-28297) as capable of producing in paying quantities. 2) Request for Tract Operation of North Prudhoe Bay State No. 3. 3) Plan of Development and Operations for North Prudhoe Bay Reservoir. Dear Mr. Eason and Mr. Johnston: Pursuant to the provisions of 11 AAC 83.361 and Article 4 of the Prudhoe Bay Unit Agreement (PBUA), ARCO Alaska, Inc. (ARCO), for itself and on behalf of Exxon Corporation (Exxon) hereby petitions the Department of Natural Resources (DNR) to certify North Prudhoe Bay State No. 3 (NPBS#3) as capable of producing in paying quantities, to approve a request to operate NPBS#3 as a Tract Operation within the Prudhoe Bay Unit, and to approve the Plan of Development and Operations for the North Prudhoe Bay Reservoir. In addition, the Alaska Oil and Gas Conservation Commission is requested to approve the production allocation method proposed in the Request for Tract Operation of North Prudhoe Bay State No. 3. ARCO and Exxon are the only Working Interest Owners in the North Prudhoe Bay well.'l' The North Prudhoe Bay reservoir encompasses three potential oil bearing formations, the Sadlerochit, the Shublik, and the Sag River. The Sadlerochit is the only formation currently perforated in NPBS#3 and the attached calculations (Exhibit l-D) show that this formation alone qualifies the well as capable of producing in paying quantities. It is expected that five months of Tract Operation will allow the collection of additional reservoir information necessary to justify drilling a second well and may allow testing of the Shublik and Sag River formations. Based on the results of testing and the second well it is the Owner's intent to form a North Prudhoe Bay Participating Area within the Prudhoe Bay Unit and issue a new Plan of Development and Operations. Based on the attached development timeline (Exhibit 2-A) this Participating Area application can be submitted as early as fourth quarter of 1993. The following attachments and exhibits are provided to assist in the determination: Attachment 1 Request for Certification as capable of producing in paying quantities Exhibit 1-A Annotated North Prudhoe Bay State No. 3 Log Exhibit 1-B WelITest Chronology Exhibit 1-C Well Test Summary Exhibit 1-D Cost data showing NPBS#3 capable of producing in paying quantities Exhibit 1-E Top Sadlerochit Depth Structure ~' ARCO and Exxon recognize that the DNR has taken the position that ADL-28297, the lease on which the North Prudhoe Bay State No. 3 well is located, contracted from the Prudhoe Bay Unit effective April 1, 1993. As you know, ARCO and Exxon have appealed that issue, and continue to seek a mutually satisfactory resolution of the issue. Consistent with our position, in the hope for an expeditious resolution of the contraction issue, and because of the absence of a practicable alternative, we seek to conduct this test as a Tract Operation under the Unit RECEIV£D ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company MAY 1 9 199 Alaska Oil & Gas Cons. Comt~ssio~'~ Anchora.qe Messrs. Eason and ,Inston Page 2 May 17, 1993 Exhibit 1-F Exhibit 1-G Exhibit 1-H Top Sag River Depth Structure Sadlerochit Hydrocarbon Isopach Gross Hydrocarbon Isopach (Sag River, Shublik, and Sadlerochit) Attachment 2 Request for Tract Operation Exhibit 2-A North Prudhoe Bay Reservoir Development Timeline Attachment 3 Plan of Development and Operations Exhibit 3-A Location Map of West Beach Drill Site and Pipelines Enclosed are an original and five copies of the non-confidential portions of this application, two copies of the confidential portions of this application, and ten copies of the Plan of Development and Operations. ARCO and Exxon request that geological, geophysical, and engineering data, including well and bore hole data, interpretations of the data, and cost data and financial information submitted in support of this application be kept confidential under AS 38.05.035(a)(9)(C), 11 AAC 82.810, and AS 31.05.035. After you have read the attached proposal, I suggest a meeting between the Owners and appropriate State groups to discuss the project. If you have any questions or require additional information, please contact Don Chancey at 265-6330 or me at 263-4275. ARCO and Exxon appreciate your earliest consideration of our request for certification and approval. Sincerely, A. D. Simon Manager PGV/jb Enclosures and Attachments ECE VED Gas Cons. Commissio~ Anchorage ,o Attachment 1 North Prudhoe Bay State No. 3 Request for Certification as Capable of Producing in Paying Quantities In accordance with 11 AAC 83.361, ARCO Alaska, Inc., as operator and joint leaseholder with Exxon Corporation of ADL-28297, submits this request for certification of North Prudhoe Bay State No. 3 (NPBS#3) as capable of producing in paying quantities to the Director, Division of Oil and Gas, Department of Natural Resources, State of Alaska. Well History_ North Prudhoe Bay State No. 3 was spudded January 2, 1993. Drilling continued throughout January and into February. Well TD of 16,465MD reached February 1, 1993 with the initial well logs received February 4, 1993. Well perforating and testing began on April 14, 1993. Well and Reservoir Data To assist in the Division's determination, the following are attached: Exhibit 1-A Exhibit 1-B Exhibit 1-C Exhibit 1-D Exhibit 1-E Exhibit 1-F Exhibit 1-G Exhibit 1-H Annotated North Prudhoe Bay State No. 3 Well Log Well Test Chronology Well Test Summary Cost data showing NPBS#3 capable of producing in paying quantities Top Sadlerochit Depth Structure Top Sag River Depth Structure Sadlerochit Hydrocarbon Isopach Gross Hydrocarbon Isopach (Sag River, Shublik, and Sadlerochit) R 'CE V D MAY 1 9 199;] .Alaska Oil & Bas r.;ons. 0ommissio,~ Anchorag8 Exhibit 1-A North Prudhoe Bay State #3 Well Log API- 500292232200 GR z Resistivity · 2000~ I I , .--15'700 9000 ! ' I ...................................................................................................... ~"_ 15750 ' ................................................................................. '~' -"-'"" --15800 .......... ~ ............................... ~ ........................ P..~' : ........... , ~: ........ ..... j ........ ~ ............................................... ~ ssuo v ~ .......... [ ........................................... ~ ......... ,. ....... ~- 15,803' ~ ..... ~ .........r .................. t ' .... ......~-'-'-~. -' ........ ~'~"~ ,,oo .... ~'"~":':'?~. ...... :" :':::~ ..... : ...... ~'":'::: ....... ~"-~";":""( ..... -~o~.~ ~, ::::::::::::::::::::::::::::::::: :::::: ::::: ::::::::::::::: :::::::: ...... i ............................. ~~ ................................ __ : .:. ~.-.~' , ~.' _.. ~..~. :... :.:.;.:. ' :~" 6,040' MO ........................~ ]'~ ........ ._ ;-_ , ~ ~~, ,-- ~t~oo 9200 ....... '- ....... ~ '" : , - . ~_ ' _~ 16,180' MD u ~O~ ~OR ISOPACH~8~ ..... ~ ...... ~ ' ,' ' ', ' ~16300 g300 ........... .~'~" ~ ~ ~ _ ............. . .......... ~- · ., ~.. ~ ~ .... ~ ................. ~ ....................... ~ ........ ~ ........... ~ .......... _ .... .... "~' ....... ~"~ ......... ' ..................... - ~: ...:.....~ M . .~ .... ~ ........ , ....... ~ ........................... . ........... ~ ...................... ........................... ' ........................................... ; ........ ~ ........... , ......... ~ .............. .......... 1 .................................... ~ ~: ":: ,, "~nc'hora~e::: Testing Chronology Exhibit 1-B North Prudhoe Bay State No. 3 Testing Chronology April April April · April April April 14, 1993 Rigged up surface testing equipment 15, 1993 RU Schlumberger E-line Pulled BPV RIH w/gun #1 Fired gun #1 to perforate 16,194'-16,214' Shut well in and POOH w/gun #1 All shots fired. SI WHP 500 psi Stranded wireline while RIH with gun #2 16, 1993 Repairing stranded wire 17, 1993 RIH w/gun #2, could not get past 10,761'. RD Schlumberger to repair surface equipment 18, 1993 RU SWS RIH w/gun #2 Fired gun #2 to perforate 16,180' to 16,194' Shut well in and POOH w/gun #2 Ail shots fired. SIWHP 500 psi 19, 1993 SIWHP 585 psi Began high rate cleanupthrough a 49/64 choke 607 Bbls fluid produced over 4 hour flow period Final stabilized conditions 43/64 choke, 35°API @ 61°F, 0.7% BSW Emptied White Elephant tank Began conditioning well for bottom-hole sampling Well choked back to 10/64 to obtain minimum sustainable drawdown of 87 psi. Flow period will last for 24 hours Page I A~aska Oij & Gas Cons. Cornmissior~ Anchorage Testing Chronology April 20, 1993 Finished 24 flow period conditioning well at 640 BOPD rate. Shut well in for bottom hole s~mpling Monitored pressure buildup with production logging tool (PLT) April 21, 1993 Finished monitoring PBU with PLT Began collecting bottom hole samples, one sample recovered and transferred April 22, 1993 · Collected two additional bottom hole samples, completed bottomhole sampling · Programmed Panex gauges and ran in NP-3 on Baker downhole shutin tool April 23, 1993 · Opened choke to 40/64 and Flowed well for 8.5 hours · Recovered 825 Bbls of 35°API gravity crude with 0.4% BSW. · Average rate 2335 BOPD · Downhole shut-in device kicked-in on time and shut well in for pressure buildup April 24, 1993 · Well remained shut in for PBU April 25, 1993 · Well remained shut in for PBU April 26, 1993 · PBU completed, memory gauges pulled and data recovered · Shut SSSV, installed BPV · Summary of new well data: Pres = 3922 psi @ 9245 ss Tres = 207°F @ 9245 ss Oil = 35°API (crude @ 61°F) Page 2 1 9 !99; Oil & Gas Cons. 8ornrnissio;~ Anchoraga Exhibit 1-C North Prudhoe Bay State No. 3 Well Test Summary Test Interval Data Interval Parameters: Log Calculations: Interval Top-Bottom Top-Bottom Perf 0 effective Sw Perfs ('MD) Rerfs ('SS) MD/SS (%) (%) "Sadlerochit 16,180'-16214' 9235'-9255' 34/20 19.7 37 Production Test Data Flow Contributing Length Avg. Rate Avg. WHP PI Cum Oil Cum H20 Description Test # Interval (hr) (bopd) (psi) (bbl/psi) (bbl) (bbl) 1 Sadlerochit 4 -- -- -- 607 60 High Rate Cleanup (43/64 choke) 2 Sadlerochit 24 -- -- -- 648 0 Conditioning Flowrate (10/64 choke) 3 Sadlerochit 8.5 2335 1020 8.5 825 0 Drawdown Test (40/64 choke) * Tests were flowed to tank only, no GOR data was collected * Rates for these tests were converted from tank straps Pressure Test Data Pressure Interval Test Length Pressure Before or After Comments # Open Type (hrs) (psi) Conditioning 1 Sadlerochit Static -- 3915 Before Static prior to Conditioning 2 Sadlerochit Static -- 3915 Before Static prior to Conditioning 3 Sadlerochit Static -- 3915 Before iStatic prior to Conditioning 4 Sadlerochit Static -- 3923 After :Run in hole with sampler 5 Sadlerochit Static -- 3932 After Bottom hole sample run 6 Sadlerochit Static -- 3928 After : Bottom hole sample.run 7 Sadlerochit Static -- 3921 After Bottom hole sample run 8 Sadlerochit Static -- 3920 After Bottom hole sample run 9 Sadlerochit Static -- 3930 After Bottom hole sample run 10 Sadlerochit Static ~ 3925 After Bottom hole sample run 11 Sadlerochit Static ~ 3936 After Bottom hole sample run 12 Sadlerochit PBU 53.5 3922 After 53.5 hour PBU * All pressures corrected to M PP (16,197' MD, 9245' TVD SS) Exhibit 1-D North Prudhoe Bay State No. 3 Paying Quantities Calculation Assumptions: 1) The Sadlerochit interval is produced at the rate at which it was tested (2300 BOPD) 2) Cost of processing fluids through existing facilities, and overhead and operating costs are $3.72/Bbl 3) Well head price based on Lisburne's March 1993 well head price 4) Field cost allowance 5) Calculations represent one (1) year Calculation: Gross Annual Production 839,500 Gross Revenue $12,097,195 Royalty ($1,430,298) Production Costs ($3,122,940) Before Tax Cash Flow Unitary State Tax (9.4%) Federal Tax Base Federal Tax (34%) After Tax Cash Flow $7,543,957 ($709,132) $6,834,825 ($2,323,840) Bbl Oil / Year S/Year S/Year S/Year S/Year S/Year S/Year $4,510,984 S/Year Rate 2300 BOPD Op_Cost $3.72 $/Bbl Price $14.41 $/Bbl Allowance $0.78 $/Bbl (2300 Bbl/day * 365 days) (Gross Production * Price) (12.5% * Gross Production * (Price - Allowance)) (Gross Production * Op_Cost) (Gross Revenue - Royalty - Production Costs) (Before Tax Cash Flow * 9.4%) (Before Tax Cash Flow - Unitary State Tax) (Federal Tax Base * 34%) (Federal Tax Base - Federal Tax) Since after tax cash flow is positive, well produces in paying quantities 9 !99, & 6as Cons. 00mmissi0~ Anchorage Exhibit 1-E ADL 28297 Pt. Mc , L. aAbel St. Pr'udhoE: 31 North Prudhoe Field Top Sadlerochit Depth Structure 1 Mile I I Contour Interval = 50' N. Prudhoe 1 N. P~tidho,.~ ;! ADL 28297 Exhibit 1-F Mc N. Prudhoe 3 ,q l),_:l St.3 North Prudhoe Field Top Sag River Depth Structure 1 Mile I I iiii- Contour Interval = 50' Prudhoe Pl udhoe Z. Exhibit 1-G Exhibit 1-H ~"'"'~ , ...... . ..... -\~-~ , ,, ~ ~ --. ,~___~/( ~ ~- f ,,.__ North Prudho,e Field ADL 28297 .., "t' ~f~"--'~~,~ ./" J~ Gross Hydrocarbon Isopach Request for Tract Operation Attachment 2 North Prudhoe Bay Reservoir~taska 0ii & Gas Cons. Request for Tract Operation Anch0rag~ In accordance with Article 4 of the Prudhoe Bay Unit Agreement and Article 8 of the Prudhoe Bay Operating Agreement, this Request for Tract Operation for the North Prudhoe Bay Reservoir has been prepared for submission to the Director, Division of Oil and Gas, Department of Natural Resources, State of Alaska. This document has also been prepared for submission to the Chairman, Alaska Oil and Gas Conservation Commission (AOGCC). Included in this document is a request to commingle test production from North Prudhoe Bay State No. 3 (NPBS#3) with production from other reservoirs at the Lisburne Production Center (LPC). Production allocation method complies with 20AAC 25.215 and was previously approved by the AOGCC, the Alaska Department of Natural Resources, and the Alaska Department of Revenue for commingled production at the Lisburne Production Center. The North Prudhoe Bay State No. 3 well drilled in January and February 1993 has contacted hydrocarbon reserves in the Sadlerochit formation. The areal extent of this formation is uncertain as is the potential for two additional hydrocarbon bearing formations directly above the Sadlerochit; the Shublik and the Sag River. To evaluate the North Prudhoe Bay Reservoir the Owners request approval to produce NPBS#3 as a Tract Operation. Initial short-term production tests of NPBS#3 indicate a highly productive sand in the Sadlerochit formation. An extended test period is required to define the areal extent of the reservoir and to evaluate long-term produciblity. It will also afford the opportunity to test the Shublik and the Sag River formations to determine their productivity and if they are oil bearing. It is anticipated that after five months of production, enough data will have been collected to justify drilling an additional well. This well will serve to delineate the reservoir and may provide more information on the Shublik and Sag River formations. Depending on the results of this additional well, the Owners intend to apply to form a North Prudhoe Bay Participating Area within the Prudhoe Bay Unit. As shown on the attached timeline (Exhibit 2-A) this Participating Area application could be filed as early as the fourth quarter of 1993. NPBS#3 was drilled from the West Beach Drill Site. The West Beach and Lisburne Owners have agreed to share the pipelines and facilities necessary to produce North Prudhoe Bay oil (as agreed in Article 53 of the Lisburne Provisions). The West Beach Owners have already installed a 6 inch diameter production line Page I Request for Tract Operation from the West Beach Drill Site to Lisburne Drill Site L1 (DS-L1). Existing well testing facilities at DS-L1 will be used to test NPBS#3. Lisburne production pipelines will then transport North Prudhoe Bay production from DS-L1 to the LPC. No modifications to the LPC are planned to process North Prudhoe Bay production. The LPC will be operated to maximize total hydrocarbon fluid production. The only new construction required to bring NPBS#3 on production is a short piping connection from the well to the production line on the West Beach Drill Site. NPBS#3 could begin producing oil within days of approval of this document. Production Allocation Current development plans for NPBS#3 call for fluids to be produced into the Lisburne Production Center (LPC) via the West Beach pipeline which currently connects West Beach State No. 4 to Lisburne Drill Site L1. This connection will facilitate periodic well testing utilizing the test separator at DS-L1. Since custody transfer metering of NPBS#3 fluids will not be possible prior to severance from the property (per 20 AAC 25.230), ARCO Alaska, Inc. requests AOGCC approval to surface commingle NPBS#3 production with other fluids produced into the LPC and to utilize well test based production allocations for metering of NPBS#3 fluids. Since West Beach State No. 4 and NPBS#3 would flow though the same production pipeline, it is understood that in order to obtain accurate well tests of both of these wells, periodic shut-ins will be required to production test the individual wells. Consistent with the AOGCC approved West Beach field rules, NBP#3 will be tested a minimum of twice per producing month. The results of these well tests will be used to allocate NPBS#3 production in a manner consistent with the methodology recently discussed with various State agencies pertaining to commingled production at the LPC and subsequently approved by the AOGCC, the Alaska Department of Natural Resources, and the Alaska Department of Revenue. Page 2 Aiask~ OiJ & Gas Cons, Anchorage Exhibit 2-A ' North Prudhoe Bay Development Timeline Complete & Test NPB#3 Apply for Tract Operation Begin NPB#3 Tract Operation Drill Delineation Well Complete & Test New Well File for NPB Participating Area Apr-93 Ma¥-93 Jun-93 Jul-93 Aug-93 Sep-93 Oct-93 Nov-93 Dec-93 Jan-94 iii~iii~?~il i' Approved PA I I Plan of Development and operations Attachment 3 Plan of Development and Operations for the North Prudhoe Bay Reservoir In accordance with 11 AAC 83.343 and Exhibit E-2 of the Prudhoe Bay Unit Agreement, this Unit Plan of Development and Operations has been prepared for submission to the Director, Division of Oil and Gas, Department of Natural Resources, State of Alaska. This plan proposes production of the North Prudhoe Bay Reservoir as a Tract Operation within the Prudhoe Bay Unit. Project Description The North Prudhoe Bay Reservoir lies in that part of the Prudhoe Bay Unit which is north of and adjacent to the Prudhoe Bay Fault. The North Prudhoe Bay State No. 3 (NPBS#3) exploratory well, drilled from the West Beach Drill Site, has contacted hydrocarbon reserves in the Sadlerochit formation. The Owners propose to produce NPBS#3 as a Tract Operation to gather information on the size and producing characteristics of the North Prudhoe Bay Reservoir, to justify drilling a second exploratory well to delineate this reservoir, and to evaluate two potentially hydrocarbon bearing formations above the Sadlerochit formation; the Shublik and the Sag River formations. It is anticipated that after five months of production, enough data will have been collected to justify drilling an additional well. This well will serve to delineate North Prudhoe Bay and may provide additional information on the Shublik and Sag River formations. Depending on the results of this additional well, the Owners will then apply to form a North Prudhoe Bay Participating Area within the Prudhoe Bay Unit and a second Plan of Development and Operations will be filed providing for the design, implementation, and operation of the North Prudhoe Bay Reservoir. The areal extent and number of producing formations in the North Prudhoe Bay Reservoir is uncertain. Approval for Tract Operations is requested to evaluate the areal extent of the Sadlerochit formation (the only formation currently perforated in NPBS#3). Tract operation of NPBS#3 may also offer the opportunity to test the Sag River and Shublik formations and to determine if they are oil bearing. Test production from NPBS#3 will be transported through a permanent pipeline (shared with West Beach) to Lisburne Drill Site L1 (DS-L1) and hence to the LPC for processing. Geologic expectations of the reservoir will be tested with a long term drawdown test and any reservoir pressure decline will be measured. Depending on the reservoir size, development will follow one of three plans: 1) primary depletion without produced gas injection, 2) primary depletion with produced gas injection or 3) waterflood. North Prudhoe Bay production will be commingled with production from other participating areas and processed at the Lisburne Production Center RECEIVED Page I f~AY I 9 l~9J ~AJaska Oil & Gas Cons. Anch0rag~ Plan of Development and Operations This Plan of Development and Operations is designed to maximize economic development of the North Prudhoe Bay Reservoir while minimizing the impact of development and the duplication of facilities by sharing existing facilities. This plan will undergo continued evaluation and modification depending on observed performance. An important aspect of the evaluation process will be the implementation of a reservoir surveillance program. Wells Geophysical mapping in this area has, in part, defined several highly faulted features. Four North Prudhoe Bay wells have been drilled in the area to help evaluate these structural complexities. North Prudhoe Bay State No. 1, drilled in 1970, encountered hydrocarbons in sufficient quantities to encourage further investigation. This well has since been plugged and abandoned. Able State No. 1, drilled in 1976, was wet and has been plugged and abandoned. North Prudhoe Bay State No. 2, drilled in 1982, was also wet and has been plugged and abandoned. NPBS#3 was drilled in February 1993 based on new seismic interpretations and has been submitted for certification as capable of producing in paying quantities. Depending on the reservoir size as estimated from NPBS#8 production test results, additional field development will be evaluated. The number of wells required for field development is estimated at between one and six depending on reservoir size. Drill Sites The Tract Operation (testing phase) of the North Prudhoe Bay development will share the existing West Beach Drill Site. This location (shown in Exhibit 3-A) will not require gravel additions at this time. On-site facilities will be constructed if they are economically feasible, otherwise the existing testing facilities at DS-L1 will be used. Article 53 of the Lisburne Provisions provides for the sharing of Lisburne drill site facilities. Pipelines NPBS#3 production will share a six inch production pipeline connecting the West Beach Drill Site with DS-L1 (shown in Exhibit 3-A). Future development may include a high pressure gas pipeline and a water injection pipeline between the West Beach Drill Site and DS-L1. These pipelines will be made of carbon steel with external coatings to prevent corrosion. From DS-L1 to the LPC North Prudhoe Bay fluids will share Lisburne pipelines as provided by Article 53 of the Lisburne Provisions. Lisburne Production Center No modifications to the LPC are planned to process North Prudhoe Bay hydrocarb production. The LPC will be operated to maximize total Page 2 Plan of Development and Operations production including unrefined liquid hydrocarbons and gas liquids through the facility. If a North Prudhoe Bay waterflood is economic, produced water from the LPC or source water from the Prudhoe Bay Unit Initial Participating Area (IPA) will be used. All facilities will be shared in accordance with Article 53 of the Lisburne Provisions. Support Facilities North Prudhoe Bay development will share North Slope infrastructure with the West Beach Participating Area, Lisburne Participating Area, and the IPA. These shared facilities may include the West Beach Drill Site, some pipelines and vertical support members (VSMs), the co-user camp core facilities, certain roads and bridges, crawlers, operations vehicles, module movement and placement equipment, medical facilities, oily waste disposal facilities, fire fighting and spill response equipment, living quarters, and telecommunication equipment. Production Allocation The production of oil and gas, including those hydrocarbon liquids reported as NGLs by the producers, will be allocated to North Prudhoe Bay according to conditions approved by the Alaska Oil and Gas Conservation Commission, Alaska Department of Natural Resources, and the Commissioner of the Alaska Department of Revenue. Each producing well will be tested at least twice per month. Initially, NPBS#3 will be tested in the DS-L1 test separator. If development warrants, test facilities will be installed at the West Beach Drill Site. Gas Production and Sales Gas sales are dependent upon market demands and the availability of a transportation system. Prior to initiation of gas sales, the North Prudhoe Bay produced gas will be used or consumed for North Prudhoe Bay Operations, or injected into another Greater Point McIntyre Area reservoir as agreed to in the Gas Management Agreement. Fuel will be provided to the LPC as per the LPC Facility Sharing Provisions. Enhanced Recovery Enhanced oil recovery processes such as miscible gas injection may be considered in the future depending upon economic circumstances. The source of the miscible injectant may be from processed North Prudhoe Bay gas or by purchase from an outside source. RE ' VEb Page 3 DS-L5 r-1 LEGEND W. Beach Pipeline W. Beach Drillsite EXISTING FACILITY EXISTING PIPELINES EXISTING ROADS LISBURNE PRODUCTION CENTER SOURCE WATER INJECTION PLANT DS-L3 DS-L4 ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 May 5, 1993 Mr. David W. Johnston Chairman State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: North Prudhoe Bay State # 3 Exploration Well Well Completion Report Dear Mr. Johnston: ARCO Alaska, Inc., as operator of the North Prudhoe Bay State # 3 exploration well, submits the revised "Well Completion Report" (Form 407). This report has been revised to include production perforations and well test results. The Commission is requested to keep the enclosed information confidential, due to the exploratory nature of the well. If you have any questions regarding this matter, contact me at 263-4601 or George Phillips at 263-4280. Sincerely, Operations Engineer Attachments CC: L. S. Lahrson ATO-409 G. K. Phillips ATO496 Well Files ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION O~ WELL COMPLETION OR RECOMPLETION REPORT AND L 1 Status of Well Classification of Service We~'~)~.~,,,.~" ~ OIL [] GAS ~ SUSPENDED E~ ABANDONED [--] SERVICE [-'-'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 92-145 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22322 4 Location of well at surface 9 Unit or Lease Name 71' NSL, 1791' EWL, SEC 25, T12N, R14E, UM ¢ .,,,~; ... ~ ~ ] ~(;?>~.,~ir"i'~NL ~ WILDCAT ! i ..... .: ' ::. i V'~'~'%';.;~-~.'.'~ . 10 Well Number At Top Producing Interval ' - ~'//~'~_~ !m 2830' NSL ,1505' WEL, SEC 22, T12N, R14E, UM !"' ! :;"~ ;¢ ......... ~--~ .. North Prudhoe Bay State #3 At Total Depth ~, ~,..~.. ~ 11 Field and Pool 3224' NSL, 1776' WEL, SEC 22, T12N, R14E, UM ................ '~ UNDEFINED 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KBE = 52' ADL 28297 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 01/2/93. 2/1/1993. 4/26/93.I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 16465'MD,9447' TVD 16280' MD, 9291' TVD YES r~ NO [~I 2205' feet MD 1700' TVD APPROX 22 Type Electric or Other Logs Run GR/SBT/CNL 23 CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5 # H-40 I 41' 121' 30" 11 YDS ARCTICSET 13 3/8" 68# L-80/K-55 40' 4700' 16" 3579 CU FT E/464 CU FT G/235 SX C 9 5/8" 47# NTS0-SS 38' 14622' 12 1/4" 518 CU FT CLASS G 7" 29# NTS0-S 14466' 16465' 8 1/2" 731 CU FT CLASS G I 24 Perforations open to Pro0uction (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Cement Squeezed Peds- 3 3/8" guns 4 spf 4 1/2" 15848' 7" X 4 1/2" @ 15632' ~5620' -15822' MD 9104'-9105'TVD 95/8"X41/2" @ 14376' 16050' - 16052' MD 9220' - 9221' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 16292' - 16294' MD 9351' - 9352' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7" Cement Retainer @ 16273' MD/9340' TVD 15771' - 16052' 140 cu ft Class G-Squeezed to 1600 psi Perfs Open to Production - 3 3/8" guns 4 spf 16180' - 16214' MD 9289' - 9307' TVD 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Not On Production 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 RATE ,,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NO CORE TAKEN Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~.~. 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. Ugna 8960' 5941' Not tested. West Sak 10218' 6522' Not tested. -IRZ 13958' 8310' Not tested. iKingak 13976' 8318' Not tested. Sag River 15893' 9141' Not tested. Shublik 16043' 9216' Not tested. Sadlerochit 16182' 9290' Flow tested Sadlerochit 16180-16214 for 8.5 hrs on 40/64 choke w/ FTP of 1020 psi. Recovered 825 bbls of 35° APl gravity crude and 0 bbls of water for an average rate of 2,335 bopd. Gas rate was not measured. Static BHP = 3922 psi @ 9245' ss. See attached well work log. 31. LIST OF A-I-rACHMENTS DRILLING COMPLETION REPORT AND REPORT OF WELL TEST OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _ Title OPERATIONS ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP EXPLORATION ARCO Alaska, Inc. From: Terry Jordan Prudhoe Bay Drilling Subject: N. Prudhoe Bay State #3 Well Summary Thu, Mar 25, 1993 Date Depth Mud Wt. 1 -2-93 1 -3-93 543' 8.8 1-4-93 1780' 9.2 1-5-93 3351' 9.4 1-6-93 4700' 9.5 1-7-93 4700' 9.7 1 -8-93 4700' 9.7 1 -9-93 5989' 9.3 1 -1 0-93 7659' 9.5 1-1 1-93 9300' 9.4 1-12-93 10600' 9.6 1-13-93 11406' 9.8 1-14-93 11790' 9.9 1-15-93 12620' 10.0 1-16-93 12840' 10.0 1-17-93 13790' 10.0 1-18-93 14197' 10.0 1-19-93 14235' 10.1 1-20-93 15089' 10.1 1-21-93 15626' 10.1 1-22-93 15626' 10.1 1-23-93 15626' 10.1 1-24-93 15626' 10.1 1-25-93 15626' 10.1 1-26-93 15626' 10.1 1-27-93 15626' 10.5 1-28-93 15626' 10.5 1-29-93 15913' 10.5 1 -30-93 16150' 10.5 1-31-93 16382' 10.5 Operation SPUD WELL 1-2-93 22:30 hrs. Drill 16" hole. Shod trip. Drill. Drill building angle. Trip. Drill. Shod trip. Drill. Drill-building angle. Trip. Drill. Drill building angle. Short trip. Run 13-3/8" 68# L-80/K-55 BTC casing to bottom and cement with 1650 sxs of Permafrost E and 400 sxs of Class G cement. Top job with 250 sxs Permafrost C cement. Set slips. Weld on casing head. NU and test BOPE. PU 12-1/4" drilling assembly. Test 13-3/8" casing to 2500 psi. Formation integrity test to 12.5 ppg. Drill. Shod trip. Drill. POOH. Drill. Short trip. Drill. Shod trip. Drill. Drill. TIH. Drill. Drill. Trip. Drill. Drill. Drill. Drill. Trip. Drill. Drill. Drill. Shod trip. Trip. Drill. Drill. Short trip. Drill. Test BOPE. Drill Short trip. Short trip. POOH. Run 9-5/8" 47# NT-80S NSCC casing. 9-5/8" casing stuck @ 14,622'. Spot pill, Unable to free pipe, Cement with 450 sxs of Class G blend. Install wellhead; Test BOPE. RIH with 8-1/2" drilling assembly. Test 9-5/8" casing to 3500 psi. Drill out casing shoe. Test Shoe to 10.5 ppg EMW. Ream to bottom. Ream to bottom. Shod trip. Trip. Drill. Drill. Short trip. Drill. ~PBS #3 Well summary Page #2 2-1 -93 16465' 2-2-93 16465' 2-3-93 16465' 2-4-93 16465' 2-5-93 16465' 10.5 10.5 10.5 10.5 10.5 2-6-93 16465' 10.5 2-7-93 16465' 10.1 2-8-93 16465' 10.1 2-9-93 16465' 10.1 2-10-93 16465' 10.1 2-11-93 16465'. 10.1. 2-12-93 16465' 9.8 2-1 3-93 16465' 9.8 2-14-93 16465' 9.8 2-15-93 16465' 9.8 2-1 6-93 16465' 9.8 2 17-93 16465' 9.8 Drill. Short trip. Drill. '"'4r~~f' Short trip. POOH. Attempt to run wireline logs - could not deeper than 14650'. Test BOPE. RIH and log with Anadril CDN MWD. Finish logging. POOH. Run 7" 29# NT-80S NSCC liner. Run 7" liner to bottom. Circulate. Lose returns. Cement with 140 sxs Class G lead blend and 235 sxs Class tail blend. Release liner. POOH. RU wireline. Could not get GR/CNL/CBL to TD. RIH with 6" bit. Drill to landing collar @ 16383'. Test 9-5/8" and 7" liner to 3500 psi. Cut mud weight. POOH. RU wireline. Could not get GR/CNL/CBL down. RU Atlas wireline. Log GR/SBT/CNL. Perforate 16292'-16294' and 15820'-15822'. Set 7" cement retainer @ 16,380'. Test below to 1100 psi - no pump in. Perforate 16050'- 16O52'. Set cement retainer @ 15865'. Establish circulation. Cement with 25 bbls of Class G blend. POOH. Test BOPE. Drill out cement. Test to 2000 psi. Drill upper cement retainer and cement. POOH. TIH. Circulate to brine. Circulate and filter brine. POOH. LD DP. Run VSP log. Run Dipole Sonic log. Run cement bond log. Run 4-1/2" 12.6# L-80 TDS tubing string w/ 7" and 9-5/8" packers. Set packers. NU tree. Freeze protect. Released rig 2-17-93 1800 hrs. Sperry Sun GR/RES MWD Anadril GR/CDN MWD Atlas GR/CNL Atlas Dipole Sonic Atlas SBT (cement bond) Atlas VSP CORES: none. BP EXPLORA.TION ARCO Alaska, inc. ~~ ., From: Terry Jordan Prudhoe Bay Drilling Subject: N. Prudhoe Bay State #3 Well Summary Mon, Feb 22, 1993 Date Depth Mud Wt. I -2-93 1 -3-93 543' 8.8 1 -4-93 1780' 9.2 1 -5-93 3351' 9.4 1 -6-93 4700' 9.5 I -7-93 4700' 9.7 1 -8-93 4700' 9.7 1 -9-93 5989' 9.3 1-10-93 1-1 1-93 1-12-93 1 -13-93 1-14-93 1-15-93 1-16-93 1-17-93 1-18-93 1-19-93 I -20-93 1 -21 -93 1 -22-93 1 -23-93 1 -24-93 1 -25-93 1 -26-93 1 -27-93 .za.e3 1 -29-93 1 -30-93 1 -31 -93 7659' 9.5 9300' 9.4 · 10600' 9.6 11406' 9.8 11790' '9.9 12620' 10.0 12840' 10.0 13790' 10.0 14197' 10.0 14235' 10.1 15089' 10.1 15626' 10.1 15626' 10.1 15626' 10.1 15626' 10.1 15626' 10.1 15626' 1'0.1 15626' 10.5 15626' 10,5 15913' 10.5 16150' 10.5 16382' 10,5 SPUD WELL 1-2-93 22:30 hrs. Drill 16" hole. Short trip. Drill. Drill building angle. Trip. Drill. Short trip. Drill. Drill building, angle. Trip. Drill. Drill building angle, Short trip. Run 13-3/8" 68# L-80/K-55 BTC casing to bottom and cement with 1650 sxs of Permafrost E and 400 'sxs of Class G cement. Top job with 250 sxs Permafrost C cement. Set slips. Weld on casing head. NU and test BOPE. PU 12-1/4" drilling, assembly. Test 13-3/8" casing to 2500 psi. Formation Integrity test to 12.5 ppg. Drill. Drill. Short trip. Drill, POOH. TIH. D¢ill. Short trip. Drill. Drill. Short trip. Drill. Drill. Trip. Drill. Drill. Short trip. Drill. Drill. Trip. Drill. Drill. Drill. Short trip. Drill. Trip. Test BOPE. Drill Drill. Drill. Short trip. Short trip. POOH. ' Run 9.5/8" 47# NT-80$ N$CC casing. 9-5/8" easing stuck ~) 14,622'. Spot pill. Unable to free pipe. Cement with 450 sxs of Class G blend. Install wellhead. Test BOPE. RIH with 8-1/2" drilling assembly. Test 9-5/8" casing to 3500 psi. Drill out casing shoe. Test shoe to 10.5 ppg EMW. Ream to bottom. Ream to bottom. Short trip. Trip. Drill. Drill. Short trip. Drill. . '9@ 14:45 BP DRILL?~~ ,,,~B.S 63 Well summary Page #2 2-1-93 16465' 10.5 2-2-93 164'65' 10.5 2-3-93 16465' 10.5 2-4,93 16465' 10.5 2-5-93': 16465' 10.5 2-6-93 16465' 10.5 2-7-93 16465' 10.1 2-8-93 16465' 10.1 2-9-93 16465' 10.1 2-10-93 16465' 10.1 2-1 1-93 16465' 10,1 2-12-93 16465' 9.8 2-13-93 16465' 9.8 2-14-93 16465' 9.8 2-15-93 16465' 9.8 2-16-93 16465' 9.8 2-17-93 16465' 9,8 P.4 Drill. Short trip. Drill. Short trip. POOH. Attempt to run wireline logs - could not deeper than 14650'. Test BOPE. RIH and log with Anadril CDN MWD. Finish logging. POOH. Run 7" 29# NT-80S NSCC liner. Run 7" liner to bottom. Circulate. Lose returns. Cement with 140 sxs Class G lead blend and 235 sxs Class tail blend. Release liner. POOH. RU wireline. Could not get GR/CNL/CBL to TD. RIH with 6" bit. Drill to landing collar @ 16383'. Test 9-5/8" and 7"'liner to 3500 psi. Cut mud weight. POOH. RU wireline. Could not get GR/CNL/CBL down. RU Atlas wireline. Log GR/SBT/CNL. Perforate 16292'-16294' and 15820'-15822'. Set 7" cement retainer @ 16,380'. Test below to 1100 psi- no pump in. Perforate 16050'- 16052'. Set cement retainer @ 15865'. Establish circulation. Cement with 25 bbls of Class G blend. POOH. Test BOPE, Drill out cement. Test to 2000 psi. Drill upper cement retainer and cement. POOH. TIH: '~Circulate to brine. Circulate and .filter brine. POOH. LD DP. Run VSP log. Run Dipole Sonic log. Run cement bond log. Run 4-1/2" 12.6# L-80 TDS tubing string w/ 7" and 9-5/8" packers. Set packers. NU tree. Freeze protect. Released rig 2-17-93 1800 hrs. LOGS: sperry Sun Gl:I/RES MWD Anadrii GR/CDN MWD Atlas GR/CNL Atlas D!pole Sonl~ Atlas SBT ((~ement bond) Atlas VSP CORES: none. North Prudhoe Bay State No. 3 Testing Chronology April 14, 1993 · Rigged up surface testing equipment April 15, 1993 RU Schlumberger E-line Pulled BPV RIH w/gun #1 Fired gun #1 to perforate 16,194'-16,214' Shut well in and POOH w/gun #1 All shots fired. SI WHP 500 psi Stranded wireline while RIH with gun #2 April 16, 1993 · Repairing stranded wire April 17, 1993 RIH w/gun #2, could not get past 10,761'. RD Schlumberger to repair surface equipment April 18, 1993 RU SWS RIH w/gun #2 Fired gun #2 to perforate 16,180' to 16,194' Shut well in and POOH w/gun #2 All shots fired. SIWHP 500 psi April 19, 1993 · SIWHP 585 psi · Began high rate cleanupthrough a 49/64 choke · 607 Bbls fluid produced over 4 hour flow period · Final stabilized conditions 43/64 choke, 35°API @ 61°F, 0.7% BSW · Emptied White Elephant tank · Began conditioning well for bottom-hole sampling · Well choked back to 10/64 to obtain minimum sustainable drawdown of 87 psi. Flow period will last for 24 hours April 20, 1993 · Finished 24 flow period conditioning well at 640 BOPD rate. Shut well in for bottom hole sampling · Monitored pressure buildup with production logging tool (PLT) April 21, 1993 · Finished monitoring PBU with PLT · Began collecting bottom hole samples, one sample recovered and transferred April 22, 1993 Collected two additional bottom hole samples, completed bottomhole sampling Programmed Panex gauges and ran in NP-3 on Baker downhole shutin tool April 23, 1993 Opened choke to 40/64 and Flowed well for 8.5 hours Recovered 825 Bbls of 35°API gravity crude with 0.4% BSW. Average rate 2335 BOPD Downhole shut-in device kicked-in on time and shut well in for pressure buildup April 24, 1993 · Well remained shut in for PBU April 25, 1993 · Well remained shut in for PBU April 26, 1993 · PBU completed, memory gauges pulled and data recovered · Shut SSSV, installed BPV · Summary of new well data: Pres = 3922 psi @ 9245 ss Tres = 207°F @ 9245 ss Oil = 35°API (crude @ 61°F) Western Atlas international A [JttOn/Dre~er Company CORE LABORATORIES Arco Exploration & Production Technology FED '1 ~ 1995 Alaska Oil & Gas Cons. Commission Anchorage RFL 930095 28-May-g3 A product of Core Laboratories a division of Western Atlas International, Inc. The analysis, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgement of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or pror~ableness however of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. Western Atlas International A L~ton/Dres~r Company CORE LABORATORIES May28, 1993 Arco Exploration and Production Technology 2300 West Piano Parkway Rm PRC -El 115 Piano, TX 75075 ATTENTION: Mr. Russ Bone Subject: Reservoir Fluid Study Well: Wheatail No. 1 File: RFL 930095 Dear Mr. Bone, Three samples of subsurface fluid were collected from the subject well by representatives of Arco Exploration and Production Technology. These samples were shipped to our laboratory in Carrollton, Texas for use in a reservoir fluid studY. The results of this study are presented on the following pages. It has been a pleasure to perform this reservoir fluid study for Arco 'Exploration and Production Technology. Should any questions arise or if we may be of further service in any way, please do not hesitate to contact us. Sincerely, Karl W. Kames Supervising Engineer Reservoir Fluid Analysis KWK 16 cc: Addressee 15 bound & I unbound Dallas Advanced Technology Center P.O.Box 115044, Carrollton, Texas 75011-5044, 1875 Monetary Drive, Carrollton, Texas 75006, (214) 466-2673, Telex 163166 CORDAL UT, Fax (214) 323-3930 ,Laboratory Procedures Arco Exploration & Production Technology Reservoir Fluid Study Wheatall No. I Well RFL 930095 On May 12, 1993, three samples of subsurface fluid were received in our Carrollton, Texas laboratory. Bubblepoint determinations of each liquid sample were measured at reservoir temperature as a quality check. A summary of samples received in the laboratory may be found on page two. The composition of the reservoir fluid from two of the sample cylinders was measured through a heptanes plus residual fraction by low temperature fractional distillation. The heptanes plus fraction was further analyzed by gas chromatography through hexatriacontanes plus. The composition and density of the fluid can be found on pages three through eight. A portion of the reservoir fluid was charged to a high pressure, windowed cell heated to the reported reservoir temperature of 206°F. During the constant composition expansion at this temperature, a bubblepoint was observed at 3870 psig. The results of the pressure-volume relations are presented on pages nine and ten. During the differential vaporization at the reservoir temperature, the fluid evolved a total of 982 cubic feet of gas at 14.65 psia and 60°F per barrel of residual oil at 60°F. The resulting relative oil volume factor was 1.536 barrels of saturated fluid per barrel of residual oil at 60°F. The oil density and the properties of the evolved gases were measured at each point during the differential pressure depletion and the data included in the summary of the differential vaporization data on page 11. The viscosity of the reservoir fluid was measured over a wide range of pressures at 206°F in a rolling ball viscosimeter. The viscosity of the fluid was found to vary from a minimum of 0.425 centipoises at the saturation pressure to a maximum of 1.39 centipoises at atmospheric pressure. The results of the viscosity measurements are presented on page 12. A small portion of the reservoir fluid was subjected to a multi-stage separator test to determine gas/oil ratio, stock tank oil gravity and formation volume factor. These data can be found on page 13. The gases evolved were analyzed through undecanes and are reported on pages 14 through 16. The separator test data were used to adjust the differential vaporization data to surface conditions and are summarized on page 17. A large portion of reservoir fluid was charged to a PVT cell at 206°F. FroTM this sample three gas depleted oils were prepared at specified saturation pressures. A separator test was performed on the individual "DV" oils at the same conditions as the multi-stage separator test investigated above. The results of these analyses are presented on page 13. Equations and nomenclature are included in the appendix of the report which extend and define the analytical expressions and data relationships presented in the study. TABLE OF CONTENTS Laboratory Procedures Summary of PVT Data Preliminary Quality Checks Reservoir Fluid Composition Cylinder No. 13106E Cylinder No. 920324C Pressure- Volume Relations Differential Vaporization Viscosity of Reservoir Fluid Separator Flash Analysis Separator Test Gas Compositions Differential Vaporization adjusted to Separator Conditions Equations and Nomenclature .................... 9,10 .................... 11 .................... 14-16 .................... Appendix LIST OF FIGURES R e lative Volume Y-Function Pressure-Volume Relations .................... A-1 .................... A-£ Differential Vaporization Relative Oil Volume Solution Gas~Oil Ratio Oil Density Incremental Gas Gravity Deviation Factor, Z .................... B-I .................... B-2 .................... B-3 .................... B-4 .................... B-5 Viscosity Analysis Viscosity below Saturation Pressure Single-Phase Oil Viscosity C-1 C-2 Differential Vaporization Adjusted to Separator Conditions Solution Gas~Oil Ratio Formation Volume Factor .................... D-1 .................... D-2 Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 SUMMARY OF PVT DATA RePorted Reservoir Conditions Average Reservoir Pressure .................. Average Reservoir TemPerature ............ 3925 ps~g 206 °F Pressure-Volume Relations Saturation Pressure ............................... Avg Single-Phase Compressibility ......... 387O 15.10 psig E-6 v/v/psi ( 3925 to 3870 psig ) Differential Vaporization Data ( at 3870 psi~l and 206 °F ) Solution Gas/Oil Ratio ........................... Relative Oil Volume ............................... Density of Reservoir Fluid ..................... 982 1.536 0.6813 scf / bbl of residual oil at 60 °F bbl / bbl of residual oil at 60 °F gm/cc Reservoir Fluid Viscosity 0.425 cp at 3870 psig and 206 °F Se 3arator Test Results Separator Conditions Formation Total Solution Tank Oil Gravity Volume Factor Gas/Oil Ratio ( °APl at 60 °F ) psi~l °F (A) (B) 545 115 1.484 923 34.8 Differentially Liberated Oils { at 3000, 2000 and 1000 psig, respectively ) 545 115 1.402 694 34.8 545 115 1.293 452 34.9 545 115 1.198 242 34.9 (A) Barrels of saturated oil per barrel of stock tank oil at 60 °F. (B) Total standard cubic feet of gas per barrel of stock tank oil at 60 °F. Page 1 CORE LABORATORIES Arco ExploratiOn & Production Technology Wheatall No. 1 Well RFL 930095 PRELIMINARY QUALITY CHECKS PERFORMED ON SAMPLES RECEIVED IN LABORATORY Sampling Conditions Bubblepoint Conditions Approximate Cylinder Number Sampling Sample Water Date psig °F psig °F Volume Recovered (cc) (cc) 13106E* 3,793 206 500 10 13107E 2,860 206 300 0 920324C** 3,720 206 530 0 * Sample selected for further analysis and PVT study. ** Sample selected for compositional analysis only. CORE LABORATORIES Page 2 A,-~o Exploration & Production Tech.,Ology Wheatall No. 1 Well RFL 930095 Composition of Reservoir Fluid ( by Podbielniak I Toepler and extended gas chromatography ) Component Mol % Wt % MVV Dens (gm/cc) Hydrogen 0.00 Hydrogen Sulfide 0.00 Carbon Dioxide 4.64 2.220 44.010 0.8172 Nitrogen 0.35 0.110 28.013 0.8086 Methane 45.51 7.940 16.043 0.2997 Ethane 4.19 1.370 30.070 0.3558 Propane 3.00 1.440 44.097 0.5065 i-Butane 0.89 0.560 58.123 0.5623 n-Butane 1.54 0.970 58.123 0.5834 i-Pentane 0.61 0.480 72.15 0.6241 n-Pentane 1.59 1.250 72.15 0.6305 Hexanes 2.62 2.390 84.00 0.6850 Heptanes plus 35.06 81.270 213.10 0.8620 ! lOO.OO J lOO.OO J Cylinder No. 13106E Sample Characteristics This is Core Lab sample number 804 Average Molecular Weight ........................ 91.9 Sample Density (at 60 °F) ......................... 0.7183 Note: Heptanes plus MW and Density are measured values. Data corrected for benzene and hexanes minus content identified in residue analysis. Page 3 CORE LABORATORIES ~co Exploration & Production Te~c, bnology Wheatall No. I Well RFL 930095 Component Composition of Heptanes Plus Fraction ( From Chromatographic Technique ) % I % I(grn/cc) ~l Hydrogen Sulfide .00 .00 Carbon Dioxide .00 .00 Nitrogen .00 .00 Methane .00 .00 Ethane .00 .00 Propane .00 .00 iso-Butane .00 .00 n-Butane .00 .CIO iso-Pentane .00 .00 n-Pentane .00 .00 Hexanes .00 .05 Heptanes 8.61 3.88 .722 96.0 4.63 Octanes 13.60 6.78 .745 107.0 7.89 Nonanes 9.26 5.26 .764 121.0 5.93 Decanes 7.81 4.91 .778 134.0 5.44 Undecanes 6.28 4.33 .789 147.0 4.73 Dodecanes 5.37 4.06 .800 161.0 4.38 Tridecanes 5.52 4.53 .811 175.0 4.82 Tetradecanes 4.64 4.14 .822 190.0 4.34 Pentadecanes 4.29 4.15 .832 206.0 4.30 Hexadecanes 3.39 3.53 .839 222.0 3.63 Heptadecanes 3.00 3.34 .847 237.0 3.40 Octadecanes 2.73 3.22 .852 251.0 3.26 Nonadecanes 2.45 3.02 .857 263.0 3.03 Eicosanes 2.08 2.68 .862 275.0 2.68 Heneicosanes 1.78 2.43 .867 291.0 2.41 Docosanes 1.53 2.19 .872 305.0 2.16 Tricosanes 1.37 2.05 .877 318.0 2.02 Tetracosanes 1.22 1.89 .681 331.0 1.85 Pentacosanes 1.14 1.84 .685 345.0 1.79 Hexacosanes .90 1.52 .689 359.0 1.47 Heptacosanes .92 1.62 .893 374.0 1.56 Octacosanes .81 1.47 .896 388.0 1.41 Nonacosanes .69 1.31 .899 402.0 1.26 Triacontanes .70 1.37 .902 416.0 1.31 Hentriacontanes .51 1.02 .906 430.0 0.97 Dotriacontanes .51 1.06 .909 444.0 1.01 Tritriacontanes .40 .87 .912 458.0 0.82 Tetratriacontanes .43 .96 .914 472.0 0.91 Pentatriacontanes .31 .70 .917 486.0 0.68 Hexatriacontanes plus 7.75 19.87 1.073 545.4 15.92 Sample Characteristics This is Core Lab sample number 614 from Cyl. No. 13106E Total Liquid Molecular Weight ................................ 213.1 Total Liquid Density (gm/cc) ................................... 0.8620 Total Liquid APl Gravity .......................................... 32.5 Properties of Heavy Fractions ,, 1% 1% l(gm/cc)l I Heptanes plus 100.00 100.00 0.862 32.5 213.1 Decanes plus 68.53 84.08 0.888 27.6 261.3 Undecanes plus 60.72 79.17 0.896 26.2 277.7 Pentadecanes plus 38.91 62.11 0.925 21.3 339.9 Eicosanes plus 23.05 44.85 0.960 15.7 414.3 Pentacosanes plus 15.07 33.61 0.994 10.7 474.6 Triacontanes plus 10.61 25.85 1.030 5.8 518.5 Pentatriacontanes plus 8.05 20.57 1.066 1.1 543.1 Page 4 CORE LABORATORIES Exploration & Production T'"'lnology Wheatall No. 1 Well RFL 930095 Component Composition of Low Temperature Distillation Residue ( From Chromatographic Technique ) Hydrogen Sulfide .00 .00 Carbon Dioxide .00 .00 Nitrogen .00 .00 Methane .00 .00 Ethane .00 .00 Propane .00 .00 iso-Butane .00 .00 n-Butane .00 .00 iso-Pentane .00 .00 n-Pentane .00 .00 Hexanes .28 .11 ,685 84.0 0.14 Heptanes 8.58 3.87 .722 96.0 4.62 Octanes 13.54 6.83 .745 107.0 7.87 Nonanes 9.23 5.25 .764 121.0 5.92 Decanes 7.80 4.91 .778 134.0 5.44 Undecanes 6.25 4.32 .789 147.0 4.72 Dodecanes 5.37 4.06 ,800 161.0 4.38 Tridecanes 5.50 4.52 .811 175.0 4.80 Tetradecanes 4.62 4.13 .822 190.0 4.32 Pentadecanes 4.28 4.14 .832 206.0 4.29 Hexadecanes 3.37 3.52 .839 222.0 3.62 Heptadecanes 2.99 3.33 .847 237.0 3.39 Octadecanes 2.73 3.22 .852 251.0 3.26 Nonadecanes 2,44 3.01 .857 263.0 3.02 Eicosanes 2.07 2.67 .862 275.0 2.67 Heneicosanes 1.77 2.42 .867 291.0 2.40 Docosanes 1.53 2.19 .872 305.0 2.16 Tricosanes 1.37 2.05 .877 318.0 2.02 Tetracosanes 1.21 1.89 .881 331.0 1.85 Pentacosanes 1.1 3 1.83 .885 345.0 1.78 Hexacosanes .90 1.52 .889 359.0 1.47 Heptacosanes .92 1.62 .893 374.0 1.56 Octacosanes .81 1.47 .896 388.0 1.41 Nonacosanes .69 1.30 .899 402.0 1.25 Triacontanes .70 1.37 .902 416.0 1.31 Hentriacontanes .50 1.02 .906 430.0 0.97 Dotriacontanes .50 1.05 .909 444.0 1.00 Tritriacontanes .40 .87 .912 458.0 0.82 Tetratriacontanes .43 .96 .914 472.0 0.90 Pentatriacontanes .31 .70 .917 486.0 0.65 Hexatriacontanes plus 7.78 19.85 1.071 543.6 15.99 Sample Characteristics This is Core Lab sample number 606 from Cyl. No. 131 05E Total Liquid Molecular Weight ................................ 212.8 Total Liquid Density (gm/cc) ................................... 0.8615 Total Liquid APl Gravity .......................................... 32.6 Measured Molecular Weight .................................... 213.0 Corrected Molecular Weight .................................... 212.8 Benzene Content (wt%) ........................................... 0.04 Properties of Heavy Fractions Plus Fractions Moll % I °/' I (gm/cc) l I Hexanes plus Heptanes plus Decanes plus Undecanes plus Pentadecanes plus Eicosanes plus Pentacosanes plus Triacontanes plus Pentatriacontanes plus 100.00 100.00 99.72 99.89 68.37 83.94 60.57 79.03 38.83 62.00 23.02 44.78 15.07 33.56 10.62 25.82 8.09 20.55 0.862 32.6 212.8 0.862 32.5 213.1 0.888 27.7 261.3 0.896 26.3 277.7 0,925 21.4 339.8 0.960 15.8 414.0 0.993 10.8 474.0 1.029 5.9 517,3 1.065 1.2 541.4 CORE LABORATORIES Page 5 Arco ExplOration & Production Technology Wheatall No. 1 Well RFL 950098 Composition of Reservoir Fluid ( by Podbielniak I Toepler and extended gas chromatography ) Liq Component Mol % Wt % MW Dens (gm/cc) Hydrogen 0.00 Hydrogen Sulfide 0.00 Carbon Dioxide 4.58 2.100 44.010 0.8172 Nitrogen 0.35 O. 1 O0 28.013 0.8086 Methane 43.58 7.270 16.043 0,2997 Ethane 4.15 1.300 30.070 0.3558 Propane 3.01 1.380 44.097 0,5065 i-Butane 0.58 0.350 58.123 0,5623 n-Butane 1.76 1.060 58.123 0,5834 i-Pentane 0.69 0.520 72.15 0.6241 n-Pentane 1.59 1.190 72.15 0,6305 Hexanes 2.96 2.590 84.00 0,6850 Heptanes plus 36.75 82.140 215.00 0,6811 I lOO-OO I lOO.OO I Cylinder No. 920324C Sample Characteristics This is Core Lab sample number 805 Average Molecular Weight ........................ 96.2 Sample Density (at 60 °F) ......................... 0.7265 Note: Heptanes plus MW and Density are measured values. Data corrected for benzene and hexanes minus content identified in residue analysis. Page 6 CORE LABORATORIES /-~'co Exploration & Production T¢~"'~nology Wheatall No. 1 Well RFL 930095 Component Composition of Heptanes Plus Residue ( From Chromatographic Technique ) (gm/cc) Hydrogen Sulfide .00 .00 Carbon Dioxide .00 .00 Nitrogen .00 .00 Methane .00 .00 Ethane .00 .00 Propane .00 .00 iso-Butane .00 .00 n-Butane .00 .00 iso-Pentane .00 .00 n-Pentane .00 .00 Hexanes .00 .00 Heptanes 8.51 3.80 .722 96.0 4.53 Octanes 13.44 6.68 .745 107.0 7.73 Nonanes 9.19 5.17 .764 121.0 5.83 Decanes 7.80 4.86 .778 134.0 5.38 Undecanes 6.30 4.31 .789 147.0 4.70 Dodecanes 5.42 4.06 .800 161.0 4.37 Tridecanes 5.58 4.54 .811 175.0 4.82 Tetradecanes 4.73 4.18 .822 190.0 4.38 Pentadecanes 4.42 4.23 .832 206.0 4.37 Hexadecanes 3.46 3.57 .839 222.0 3.67 Heptadecanes 3.08 3.40 .847 237.0 3.45 Octadecanes 2.82 3.29 .852 251.0 3.32 Nonadecanes 2.53 3.09 .857 263.0 3.11 Eicosanes 2.14 2.74 .862 275.0 2.74 Heneicosanes 1.85 2.51 .867 291.0 2.50 Docosanes 1.61 2.28 .872 305.0 2.25 Tricosanes 1.46 2.16 .877 318.0 2.12 Tetracosanes 1.27 1.96 .881 331.0 1.91 Pentacosanes 1.21 1.94 .885 345.0 1.89 Hexacosanes .96 1.60 .889 359.0 1.55 Heptacosanes .95 1.65 .893 374.0 1.59 Octacosanes .94 1.69 .896 388.0 1.63 Nonacosanes .73 1.37 .899 402.0 1.31 Triacontanes .70 1.36 .902 416.0 1.30 Hentriacontanes .65 1.30 .906 430.0 1.23 Dotriacontanes ,57 1.18 .909 444.0 1.12 Tritriacontanes .46 .97 .912 458.0 0.91 Tetmtriacontanes .50 1.09 .914 472.0 1.02 Pentatriacontanes .35 .80 .917 486.0 0.75 Hexatriacontanes plus 6.37 18.22 1.081 614.7 14.50 Sample Characteristics This is Core Lab sample number 615 from Cyl. No. 920324C Total Liquid Molecular Weight ................................ 215.0 Total Liquid Density (gm/cc) ................................... 0.8611 Total Liquid APl Gravity .......................................... 32,7 Properties of Heavy Fractions 1% 1% Ilgm/cc)l I Heptanes plus 100.00 100.00 0.861 32.7 215.0 Decanes plus 68.86 84.35 0.887 27.9 263.4 Undecanes plus 61.08 79.49 0.894 26.6 279.9 Pentadecanes plus 39.03 62.40 0.922 21.8 343.7 Eicosanesplus 22.72 44.82 0.957 16.3 424.0 Pentacosanes plus 14.39 33.17 0.991 11.2 495.6 Triacontanes plus 9.60 24.92 1.029 5.9 557.9 Pentatriacontanes plus 6.72 19.02 1.073 0.2 608.0 Page 7 CORE LABORATORIES Component ': i-co Exploration & Production T~..nology Wheatall No. 1 Well RFL 930095 CompositiOn of Low Temperature Distillation Residue ( From Chromatographic Technique ) % I % l igm/cc) Hydrogen Sulfide .00 .00 Carbon Dioxide .00 .00 Nitrogen .00 .00 Methane .00 .00 Ethane .00 .00 Propane .00 .00 iso-Butane .00 .00 n-Butane .00 .00 iso-Pentane .00 .00 n-Pentane .00 .00 Hexanes .20 .08 .685 84.0 Heptanes 8.50 3.80 .722 96.0 Octanes 13.44 6.69 .745 107.0 Nonanes 9.18 5.17 .764 121.0 Decanes 7.77 4.85 .778 134.0 Undecanes 6.28 4.30 .789 147.0 Dodecanes 5.40 4.05 .800 161.0 Tridecanes 5.57 4.54 .811 175.0 Tetradecanes 4.72 4.18 .822 190.0 Pentadecanes 4.41 4.23 .832 208.0 Hexadecanes 3.45 3.57 .839 222.0 Heptadecanes 3.07 3.39 .847 237.0 Octadecanes 2.81 3.29 .852 251.0 Nonadecanes 2.52 3.09 .857 263.0 Eicosanes 2.14 2.74 .862 275.0 Heneicosanes 1.85 2.51 .867 291.0 Docosanes 1.60 2.27 .872 305.0 Tricosanes 1.45 2.15 .877 318.0 Tetracosanes 1.27 1.96 .881 331.0 Pentacosanes 1.21 1.94 .885 345.0 Hexacosanes .96 1.60 .889 359.0 Heptacosanes .95 1.65 .893 374.0 Octacosanes .93 1.68 .896 388.0 Nonacosanes .73 1.37 .899 402.0 Triacontanes .70 1,36 .902 416.0 Hentriacontanes .65 1.30 .906 430.0 Dotriacontanes .57 1.17 .909 444.0 Tritriacontanes .45 .97 .912 458.0 Tetratriacontanes .50 1.09 .914 472.0 Pentatriacontanes .35 .80 .917 486.0 Hexatriacontanes plus 6.37 18.21 1.081 614.6 0.10 4.53 7,72 5.83 5.36 4.69 4.36 4.82 4.38 4.37 3.67 3.44 3.32 3'.11 2.74 2.50 2.24 2.11 1.91 1.89 1.55 1.59 1.62 1.31 1.30 1.23 1.11 0.91 1.02 0.75 14.51 Sample Characteristics This is Core Lab sample number 607 from Cyl. No. 920324C Total LiquId Molecular Weight ................................ 214.8 Total Liquid Density (gm/cc) ................................... 0.8609 Total Liquid APl Gravity .......................................... 32.7 Measured Molecular Weight .................................... 215.0 Corrected Molecular Weight .................................... 214.8 Benzene Content (wt %) .......................................... 0.04 Properties of Heavy Fractions Plus Fractions % I % I(~m/cc) l I I Hexanes plus Heptanes plus Decanes plus Undecanes plus Pentadecanes plus Eicosanes plus Pentacosanes plus Triacontanes plus Pentatdacontanes plus 100.00 100.00 0.861 32.7 214.8 99.80 99.92 0.861 32.7 215.0 68.68 84.26 0.887 27.9 263.5 60.91 79.41 0.894 26.6 280.0 38.94 62.34 0.922 21.8 343.8 22.68 44.77 0.957 16.2 424.1 14.37 33.14 0.991 11.1 495.7 9.59 24.90 1.029 5.9 558.0 6.72 19.01 1.073 0.2 607.9 -.., Page 8 CORE LABORATORIES Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 VOLUMETRIC DATA (at 206 °F) Saturation Pressure (Psat) 3870 psig Density at Psat 0.6813 gm/cc AVERAGE SINGLE-PHASE COMPRESSIBILITIES Pressure Range psig Single-Phase Compressibility v/v/psi 5OOO 45OO 4200 4100 4000 3900 to to to to to to 450O 4200 4100 4000 3900 387O 12.88 E -6 14.35 E -6 14.71 E -6 14.80 E -6 14.92 E -6 15.19 E -6 Page 9 CORE LABORATORIES Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 PRESSURE-VOLUME RELATIONS (at 206 °F) Pressure psig Relative Volume (A) Y-Function (B) Density gm/cc 5000 0.9844 4500 0.9908 4200 0.9951 4100 0.9966 4000 0.9981 3900 0.9995 b~3870 1.0000 3850 1.0013 3834 1.0024 3820 1.0034 3802 1.0047 3785 1.0059 3748 1.0085 3615 1.0188 3378 1.0402 3020 1.0819 2632 1.1453 2275 1.2296 1968 1.3339 1700 1.4630 1462 1.6249 1300 1.7742 930 2.3346 740 2.8575 520 3.9581 3.609 3.422 3.220 3.033 2.873 2.734 2.609 2.525 2.332 2.233 2.118 0.6921 0.6876 0.6847 0.6837 0.6826 0.6816 0.6813 (A) Relative Volume: VNsat or volume at indicated pressure per volume at saturation pressure. (B) Where: Y-Function = (Psat - P) (Pabs) * (VNsat- 1) CORE LABORATORIES Page 10 Arco Expiorotion &: Production Technology Wheoto~l No~ 1 We~l t~FL 9~0095 1.005 RELATE VOLUME at 206 ~F ) 1.000 0,995 0.990 0,985 0,980 3750 LEGEND S~tumtion Pressure 4250 ~0 4750 500© 52543 GORE LABOPC~TORIES Arco Ezxplorotion & Production Technology Wheotoil No, 1 We~l RFq_ 930095 4,50 4.00 5.50 $.00 Y-FUNCTION ( dt 206 'F } LEGEND Confidence Umf~ ~turctlon Pre.ute 3,870 p~ig r 8q u~red: 0.998271 0onfiden~ lnterv~I (+/-): 0.0179 Confidence: 98 % Pressure-Volume Rek~tions Figure CORE LABORATORIES Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 Pressure psig Solution Gas/Oil Ratio Rsd (A) DIFFERENTIAL VAPORIZATION (at 206 °F) Relative Oil Volume Sod ia) Relative Total Volume Btd Oil Density gm/cc Deviation Factor Z b~3870 982 1.536 1.536 0.6813 3400 846 1.475 1.593 0.6937 0.881 3000 737 1.428 1.665 0.7041 0.873 2600 635 1.384 1.771 0.7143 0.872 2300 563 1.353 1.884 0.7218 0.876 2000 494 1.324 2.040 0.7293 0.884 1600 407 1.287 2.357 0.7392 0.898 1300 344 1.260 2.741 0.7466 0.912 1000 282 1.235 3.374 0.7540 0.928 600 200 1.199 5.251 0.7641 0.952 200 104 1.156 14.551 0.7753 0.980 0 0 1.074 0.7975 @60 °F =1.000 Gas Formation Volume Factor 0.00484 0.00543 0.00626 0.00711 0.00823 0.01044 0.01302 0.01716 0.02908 0.08566 Incremental Gas Gravity (Air=1.000/ 0.775 0.767 0.760 0.755 0.751 0.749 0.752 0.765 0.810 0.962 1.735 Gravity of Residual Oil = 33.5 °APl at 60 °F Density of Residual Oil = 0.8567 gm/cc at 60 °F (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of residual oil at 60 °F. (B) Barrel of oil at indicated pressure and temperature per Barrel of residual oil at 60 °F. (C) Barrels of oil plus liberated gas at indicated pressure and temperature per Barrel of residual oil at 60 °F. (D) Cubic Feet of gas at indicated pressure and temperature per Cubic Feet at 14.65 psia and 60 °F. Page 11 CORE LABORATORIES Arco Execration & Production Technology Wheatoll No, 1 Welt RFL 950095 RELATIVE OIL VOLUME ( at 206 'F ) t LEGEND o Laboratory Data ......... Confidence Limit9 Analy~Jcol ~xpr~eeion Soturotion Pressure 33870 peig 1,30 1.20 1,10 1.00 0 1000 2000 3000 4.900 Pressure, psig Analytical Expression (below bubblepoint) 1.074E00 + 2.910E-02 (Pi)--0,01 + 5,420E-05 (P0^0.51 + 1.527E-08 Statistical Summary r squared: 0.999990 Confidence Inte~ol (+/-): .0004 Confidence; 99 % Differentio~ Voporizotion FTgure CORE LABORATORIES 1000 Arco Explorotion & Production Technology Wheototl No. I Well RFL 950095 SOLUTION GAS/OIL RATIO ( scf/bbl ct 206 'F ) 800 600 4OO 200 LEGEND o Lebordtory D~t~ ....... Confidence Limlt~ AnoJyficel Expression Saturation Preseure 3,870 psi9 0 1000 2000 5000 4000 Pressure, psig AnoiytJcol Expreseion (below bubblepoint) 4,630E--02 (Pi) + 6,647E00 (P0~-0.5 + 2,802E-05 Stotfsticol Summory r squored: 0,999976 Confidence tntervoI (+/-): 1 Confidence; 99 % Different)ol Vaporization Figure B-2 CORE LABORATORIES Arco Ex¢ordtion & P~oduction Technology Whea~:~H No, 1 We~l RFL 9.30095 O~L DENSITY ( 9m/cc o~ 208 ~F 0,800 ,-- M 0.750 0.700 ....... ~nfidence 3,870 psig 0 ]~O0 2000 $000 40(t0 r ~quore~: 0,99998~ Oonfiden~lnte~i (+/-): 0,0001 C~nfidence: 99 % DlfferentioJ Vaporization ~gure CORE LABORATORIES 1,80 1.40 1.20 1.00 Arco Exploration & Production Technology Wheatall No, 1 Well RFL 950095 GAS GRAVITY ( at 206 'F ) Laborato6¢ Date Confidence Limits Anstytleel Expression Saturdtion Pressure 5,870 pstg 0.80 0 1000 2000 5000 4000 r squared: 0.999976 Confidence tnterYel (+/-): 0.0014 Confidence: 99 % Differentiel Vaporization Figure B-¢ CORE LABORATORIES Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 1.050 Z - FACTO R ( at 206 'F ) 1.000 0.950 0,900 LEGEND Laboratory Data Confidence Umlts Analytical Expression Saturation Pre~sure 5,870 psig 0.85( 1000 2000 3000 4000 Pressure psig Analytical Expression 1 + -6.293E-05 ( Pi ) + -1,565E-05 Pi )--0.5 + 9.734E-I2 ( Pi )^2,85 Stef:isticel Summery r squared: 0.998051 Confidence Interval (+/-): 0.002 Confidence: 99 % Differential Va porizetion Figure B-5 CORE LABORATORIES Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 RESERVOIR FLUID VISCOSITY (at 206 °F) Pressure psig Oil Viscosity cp 6000 0.486 5500 0.472 5000 0.457 450O 0.443 4000 0.429 b~3870 0.425 3400 0.454 3000 0.488 2600 0.526 2300 0.559 2000 0.595 1600 0.648 1300 0.693 1000 0.742 600 0.818 200 0.923 0 1.39 Calculated Gas Viscosity* cp Oil/Gas Viscosity Ratio 0.0237 19.2 0.0216 22.5 0.0198 26.6 0.0185 3O.2 0.0173 34.3 0.0160 40.4 0.0152 45.6 0.0144 51.4 0.0135 60.8 0.0122 75.6 * Gas Viscosity data calculated from correlation of Lee A.L., Gonzalez M.H., and Eakin B.E., "The Viscosity of Natural Gases", Journal of Petroleum Technology, August, 1966, pp. 997-1000. Page 12 CORE LABORATORIES Arco Exploration & Production Technology Wheotall No. 1 Welt RESERVOIR FLUID VISCOSITIES (cp at 206 'F) Analy.&~I 3,870 ps~g 2OOO 30CV3 40OO 1,595 mO + -1.398E-04- ( F~ ) + -2.615E-0t ( Pi )--0, I + 2.107E-09 ( PI V~scosity Analyses Figure CORE: Arco Explorotion & Production Technology Wheotoll No, 1 Well ~FL 9Z~)095 0.50 0.42 0.40 ~00 SINGLE-PHASE VISCOSITY ( cp at 206 °F) L~G~D DoW 3.870 p~lg 4000 4500 5000 5500 6000 6500 4.250E-01 Statietical Summary r ~quored: 0.987534 Confidence Interval (+/--): 0.004 Confidenoe: 99 % V~scosity AnoIyses F~gure C--2 OORE LABORATORIES Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 SEPARATOR FLASH ANALYSIS (Stock Tank -- 0 psig and 60°F Basis) Flash Gas/Oil Gas/Oil Stock Tank Formation Separator Specific Oil Phase Conditions Ratio Ratio Oil Gravity Volume Volume Gravity of Density ( scf/bbl ) ( scf/STbbl ) i at 60 °F Factor Factor Flashed Gas ( gm/cc ) psig I °F (A) (B) (°API~ Bofb (C) (D) (Air=l.000 t 3870 206 0.6813 545 115 632 728 1.151 0.686 * 0.7835 115 186 120 132 1.097 0.966 * 0.7968 5 184 59 63 1.062 1.779 * 0.8002 0 60 0 0 34.8 1.483 1.000 ** 0.8498 Rsfb = 923 Differentially Liberated Oils 3000 206 0.6966 545 115 438 502 1.147 0.700 0.7849 115 186 127 139 1.096 1.003 0.7938 5 184 50 53 1.062 1.710 0.8005 0 60 0 0 34.8 1.402 1.000 ** 0.8502 Rsfb = 694 2000 206 0.7266 545 115 227 258 1.139 0.716 0.7893 115 186 130 141 1.089 1.005 0.7972 5 184 50 53 1.062 1.626 0.7998 0 60 0 0 34.9 1.293 1.000 ** 0.8495 Rs~ = 452 1000 206 0.7552 545 115 47 53 1.124 0.729 0.7972 115 186 134 146 1.092 1.007 0.7914 5 184 41 44 1.062 1.542 0.7999 0 60 0 0 34.9 1.198 1.000 ** 0.8496 Rs~ = 242 * Collected and analyzed in the laboratory by gas chromatography. ** Insufficient quantity for measurement. (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of oil at indicated pressure and temperature. (B) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 60 °F. (C) Barrels of saturated oil at 3870 psig and 206 °F per Barrel of Stock Tank Oil at 60 °F. (D) Barrels of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 60 CORE LABORATORIES Page 13 Arco Exploration & Production Technology Wheatall No. 1 Well RFL 930095 SEPARATOR FLASH ANALYSIS (Stock Tank -- $ psig and 184°F Basis) Flash Gas/Oil Gas/Oil Stock Tank Formation Separator Specific Oil Phase Conditions Ratio Ratio Oil Gravity Volume Volume Gravity of Density ( scf/bbl ) ( scf/STbbl ) at 60 °F Factor Factor Flashed Gas ( gm/cc ) psi~l I °F CA) lB) C°API) Sofb CC) ID) (Air=l.000 ! 3870 206 0.6813 545 115 632 685 1.084 0.686 * 0.7841 115 186 120 124 1.033 0.966 * 0.7969 5 184 59 59 34.8 1.396 1.000 1.779 * 0.8002 Rsfb = 869 Differentially Liberated Oils 3000 206 0.6966 545 115 438 473 1.080 0.700 0.7849 115 186 127 131 1.032 1.003 0.7938 5 184 50 50 34.8 1.320 1.000 1.710 0.8005 Rs~ = 654 2000 206 0.7266 545 115 227 243 1.073 0.716 0.7893 115 186 130 133 1.025 1.005 0.7972 5 184 50 50 34.9 1.217 1.000 1.626 0.7998 Rsfb = 426 1000 206 0.7552 545 115 47 50 1.058 0.729 0.7972 115 186 134 137 1.028 1.007 0.7914 5 184 41 41 34.9 1.128 1.000 1.542 0.7999 Rsfb= 228 * Collected and analyzed in the laboratory by gas chromatography. (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of oil at indicated pressure and temperature. (B) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 5 psig and 184 °F. (C) Barrels of saturated oil at 3870 psig and 206 °F per Barrel of Stock Tank Oil at 5 psig and 184 °F. (D) Barrels of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 5 psig and 184 °F. Page 13A CORE LABORATORIES ,~"'~rco Exploration & Production T~'""~nology Wheatall No. 1 Well RFL 930095 Composition of Primary Stage Separator Test Gas ( From Chronmtographic Technique ) Liq Component Mol % GPM MW Dens (gm/cc) Hydrogen Sulfide 0.00 Carbon Dioxide 6.44 44,010 .8172 Nitrogen 0.94 28.013 ,8086 Methane 84.85 16.043 .2997 Ethane 4.43 1.178 30.070 .3558 Propane 1.90 .521 44.097 .5065 iso-Butane 0.29 .094 58.123 .5623 n-Butane 0.54 .169 58.123 .5834 iso-Pentane 0.14 .051 72.150 .6241 n-Pentane 0.16 .058 72.150 .6305 Hexanes 0.13 .050 84.000 .6850 Heptanes 0.10 .042 96.000 .7220 Octanes 0.06 .027 107.00 .7450 Nonanes 0.02 .010 121.00 .7640 Decanes Trace Undecanes plus Nil Totals ........... I 100.001 2.200 I I Properties of Plus Fractions Liq Component Mol % MW Dens APl (~m/cc) Gravit~ Heptanes plus 0.18 102.4 0.735 44.8 * From: Standing, M.B., "Volumetric and Phase Behavior of Oil Field Hydrocarbon Systems", SPE (Dallas),1977, 8th Edition, Appendix I1. Sampling Conditions 545 psig 186 °F Sample Characteristics This is Core Lab sample number 208 Critical Pressure (psia) ............................. 689.3 Critical Temperature (°R) .......................... 377.5 Average Molecular Weight ........................ 19.87 Calculated Gas Gravity (air = 1.000) ......... 0.686 Gas Gravity Factor, Fg ................................................ 1.2073 Super Compressibility Factor, Fpv at sampling conditions ............................. 1.0215 Gas Z-Factor at sampling conditions *. ......................... 0.958 at 14.65 psia and 60 °F Gross Heating Value (BTU/scf dry gas) ................................... 1035 Page 14 CORE LABORATORIES ?"~rco Exploration & Production T~"~nology Wheatall No. 1 Well RFL 930096 Composition of SecOndary Stage Separator Test Gas ( From Chromatographic Technique ) Liq Component Mol % GPM MW Dens (gm/cc) Hydrogen Sulfide 0.00 Carbon Dioxide 9.97 44.010 .8172 Nitrogen 0.22 28.013 .8086 Methane 60.18 16.043 .2997 Ethane 11.68 3.107 30.070 .3558 Propane 8.68 2.379 44.097 .5065 iso-Butane 1.61 .524 58.123 .5623 n-Butane 3.29 1.032 58.123 .5834 iso-Pentane 0.92 .335 72.150 .6241 n-Pentane 1.14 .411 · 72.1 50 .6305 Hexanes 0.92 .355 84.000 .6850 Heptanes 0.76 .318 96.000 .7220 Octanes 0.46 .208 107.00 .7450 Nonanes 0.12 .060 121.00 .7640 Decanes 0.04 .022 1 34.00 ,7780 Undecanes plus 0.01 .006 154.00 .7950 Totals ........... I lOO.OOl 8.757 I I Properties of Plus Fractions Liq Component Mol % MW Dens APl (gm/cc) Gravity Heptanes plus 1.39 103.3 0.735 44.8 Decanes plus 0.05 138.0 0.780 38.8 Undecanes plus 0.01 154.0 0.795 35.9 Sampling Conditions 115 psig 186 °F Sample Characteristics This is Core Lab sample number 211 Critical Pressure (psia) ............................. 691.2 Critical Temperature (°R) .......................... 460.2 Average Molecular Weight ........................ 27.99 Calculated Gas Gravity (air = 1.000) ......... 0.956 Gas Gravity Factor, Fg ................................................ 1.0173 Super Compressibility Factor, Fpv at sampling conditions ............................. 1.0093 Gas Z-Factor at sampling conditions *. ......................... 0.982 at 14.65 psia and 60 °F Gross Heating Value (BTU/scf dry gas) ................................... 1391 * From: Standing, M.B., "Volumetric and Phase Behavior of Oil Field Hydrocarbon Systems", SPE (Dallas),1977, 8th Edition, Appendix II. Page 15 CORE LABORATORIES ~,~"~,, rco Exploration & Production T~"~nology Wheatall No. 1 Well RFL 930095 Composition of Tertiary Stage Separator Test Gas ( From Chromatographic Technique ) Liq Component Mol % GPM MW Dens (gm/cc) Hydrogen Sulfide 0.00 Carbon Dioxide 5.33 44.010 .8172 Nitrogen 0.10 28.013 .8086 Methane 19.44 16.043 .2997 Ethane 11.54 3.069 30.070 .3558 Propane 17.25 4.727 44.097 .5065 iso-Butane 4.74 1.542 58.123 .5623 n-Butane 11.88 3.725 58.123 .5834 iso-Pentane 5.52 2.009 72.150 .6241 n-Pentane 6.88 2.478 72.150 .6305 Hexanes 7.15 2.760 84.000 .6850 Heptanes 5.99 2.507 96.000 .7220 Octanes 3.46 1.564 107.00 .7450 Nonanes 0.68 .339 121.00 .7640 Decanes plus 0.04 .023 141.00 .7840 Totals ........... I 100.00 I 24.743I I Properties of Plus Fractions Liq Component Mol % MW Dens APl (gm/cc) Gravity Heptanes plus 10.17 101.6 0.733 45.0 Decanes plus 0.04 141.0 0.784 38.3 * From: Standing, M.B., "Volumetric and Phase Behavior of Oil Field Hydrocarbon Systems", SPE (Dallas),1977, 8th Edition, Appendix I1. Sampling Conditions 5 psig 184 °F Sample Characteristics This is Core Lab sample number 212 Cdtical Pressure (psia) ............................. 597.8 Critical Temperature (°R) .......................... 669.2 Average Molecular Weight ........................ 51.51 Calculated Gas Gravity (air = 1.000) ......... 1.779 Gas Gravity Factor, Fg ................................................. 7498 Super Compressibility Factor, Fpv at sampling conditions ............................. 1.0478 Gas Z-Factor at sampling conditions *. ......................... 0.911 at 14.65 psia and 60 °F Gross Heating Value (BTU/scf dry gas) ................................... 2757 Page 16 CORE LABORATORIES b)) ArCo Exploration & Production Technology Wheatall No. 1 Well RFL 930095 DIFFERENTIAL VAPORIZATION ADJUSTED TO SEPARATOR CONDITIONS* Pressure psig 5OOO 45OO 4200 4100 4000 3900 3870 34OO 3000 2600 2300 2000 1600 1300 1000 600 200 0 Solution Gas/Oil Ratio Rs (A) 923 923 923 923 923 923 923 791 686 588 518 451 367 306 247 167 75 Formation Volume Factor Bo (B) 1.461 1.470 1.477 1.479 1.481 1,483 1.484 1.426 1,380 1.337 1.307 1.279 1.243 1.218 1.193 1.159 1.117 1.038 Gas Formation Volume Factor (C) Oil Density gm/cc Oil/Gas Viscosity Ratio 0.00484 0.00543 0.00626 0.00711 0.00823 0.01044 0.01302 0.01716 0.02908 0.08566 0.6921 0.6876 0.6847 0.6837 0.6826 0.6816 0.6813 0.6937 0.7041 0.7143 0.7218 0.7293 0.7392 0.7466 0.7540 0.7641 0.7753 0.7975 19.2 22.5 26.6 30.2 34.3 40.4 45.6 51.4 60.8 75.6 *Separator Conditions First Stage Second Stage Third Stage Stock Tank 545 psig at 115 °F 115 psig at 186 °F · 5 psig at 184 °F 0 psig at 60 °F (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 60 °F. (B) Barrel of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 60 °F. (C) Cubic Feet of gas at indicated pressure and temperature per Cubic Feet at 14,65 psia and 60 °F. _ Page 17 CORE LABORATORIES 1000 Arco Expiorotion & Production Technology Wheata]i No. 1 Well RFL 950095 SOLUTION GAS/OIL RATIO ( scf/STbbt 800 600 400 2OO 0 0 Saturation Pressure 3,870 psig 1000 2000 5000 4OOO LEGEND Differential Vaporization Stock Tank = 0 psig at 60'F Stock Tank = 5 psig at 184'F DV Adjusted to Separator Figure D-1 CORE LABORATORIES Arco Exploration & Production Technology Wheatall No. 1 Well RFL g30095 FORMATION VOLUME FACTOR 1.60 1 1.30 1,20 I,I0 1,00 0 Saturation Pressure 3,870 psig 1000 2000 3000 ¢000 5000 Pressure, psig LEG END Olfferen(iul Vdporiz~tion Stock Tank = 0 peig at 60'F Stock Tank = 5 psig at 184'F DV Adjusted to Seporotor Figure 0-2 CORE LABORATORIES m m~m Pressure peig 5000 4500 4200 4100 4000 3900 3870 3400 3000 2600 2300 2000 1600 1300 1000 600 200 0 Arco Exploration & Production Technology Wheatall No. I Well RFL 930095 DIFFERENTIAL VAPORIZATION ADJUSTED TO SEPARATOR CONDITIONS* Solution Formation Gas/Oil Volume Ratio Factor Rs (A;) , Bo 869 1.374 869 1.383 869 1.389 869 1.391 869 1.393 869 1.395 869 1.396 744 1.341 646 1.298 553 1.258 487 1.230 425 1.203 345 1.170 288 1.146 232 1.122 157 1.090 70 1.051 Gas Formation Volume Factor 0.00484 0.00543 0.00626 0.00711 0.00823 0.01044 0.01302 0.O1716 0.02908 0.08566 Oil Density gm/cc Oil/Gas Viscosity Ratio 0.6921 0.6876 0.6847 0.6837 0.6826 0.6816 0.6813 0.6937 0.7041 0.7143 0.7218 0.7293 0.7392 0.7466 0.7540 0.7641 0.7753 0.7975 19.2 22.5 26.6 30.2 34.3 40.4 45.6 51.4 60.8 75.6 *Separator Conditions First Stage Second Stage Stock Tank 545 psig at 115 °F 115 psig at 186 °F 5 psig at 184 °F (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 5 psig and 184 °F. (B) Barrel of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 5 psig and 184 °F. (C) Cubic Feet of gas at indicated pressure and temperature per Cubic Feet at 14.65 psia and 60 °F. Page17A CORE LABORATORIES Appendix Nomenclature and Equations PRESSURE-VOLUME RELATIONS Nomenclature and Equations Pb RV C~p Bubblepoint Pressure Dimensionless Pressure ( Pi / Pb ) Pressure Difference ( Pi - Pb ) Y-Function (dimensionless compressibility) PV Relative Volume Average Single-Phase Compressibility of Reservoir Fluid For Relative Volume below bubblepoint pressure: RVi = ( (Pb ' Pi)/Pi ) / Yf For Average Single-Phase Compressibility above bubblepoint pressure: Csp = ( RVi - RVi. 1 )/[ RVi( Pi-1 - Pi ) ] DIFFERENTIAL VAPORIZATION Nomenclature and Equations Pb Pb~e Tb~ Tres RV Dens Densb ROV ROVb Bg Bubblepoint Pressure Base Pressure Base Temperature Reservoir Temperature Dimensionless Pressure ( Pi / Pb ) Pressure Difference ( Pi - Pb ) Relative Volume from Pressure-Volume Relations Single-Phase Oil Density Oil Density at Bubblepoint Pressure Relative Oil Volume Relative Oil Volume at Bubblepoint Pressure Gas Formation Volume Factor For Oil Density above bubblepoint pressure: Densi = Densb / RVi For Relative Oil Volume above bubblepoint pressure: ROVi = ROVb * RVi For Gas Formation Volume Factor below bubblepoint pressure: Bg = Pbase * Z i* Tres / (Pi * Tbase) DIFFERENTIAL VAPORIZATION DATA ADJUSTED TO SURFACE CONDITIONS Nomenclature and Equations Bolo Bod Bodb RV Bubblepoint Pressure Oil Formation Volume Factor Formation Volume Factor from field conditions or optimum separator flash test Relative Oil Volume from differential vaporization test Value of Bod at bubblepoint pressure Relative Volume from Pressure-Volume relations For Bo above bubblepoint pressure: Bo = RV * Bofb For Bo below bubblepoint pressure: Bo = (Bod) * (Bom / Bodb) Gas in solution Sum of separator gas and the stock tank gas from field conditions (or optimum) separator flash test Gas in solution from the differential vaporization test RSd at bubblepoint pressure Rs = Rslo - [ (Rsdb - Rsd) * (Bolo / Bodb) ] PRUDHOE BAY DRZLLZNG EXPLORATZON/N,PRUDHOE BAY STATE 500292232200 NORTH SLOPE CONPUTATZON DATE' 2/ 8/93 S;""'%tRY-SUN DRILLZNG SERVZCES PAGE 1 09,1 i I- DATE OF SURVEY: 02/01/93 NWD SURVEY JOB NUNBER: AK-NH-930101 KELLY BUSHZNG ELEV. = 52,00 FT, OPERATOR: ARCO ALASKA ZNC TRUE SUB-SEA COURS COURSE DLS TOTAL HEASD VERTZCAL VERTZCAL ZNCLN DZRECTZON RECTANGULAR COORDZNATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT, 0 .00 -52.00 0 0 N ,00 E .00 .OON .OOE .00 297 296.99 244.99 0 37 N 53.91 E .21 .95N 1.30E -.21 477 477.87 425.87 0 30 N 33.67 E .13 2,19N 2.54E -,16 650 650,03 598.03 1 49 N 24.62 W .94 5.32N 1,82E 2.59 833 833,28 781.28 3 35 N 28.06 W .97 13.03N 2.09W 10.87 1019 1018.62 966.62 6 21 N 22.49 W 1.51 27.70N 8.78W 26.10 1202 1200.37 1148,37 7 4 N 23.58 W .40 47,40N 17.17W 46.14 1379 1376.07 1324.07 7 50 N 41.85 W 1.40 66,41N 29.60W 68.48 1565 1560.04 1508.04 8 22 N 44.93 W .37 85.44N 47.62W 94.68 1660 1653.39 1601.39 8 51 N 43.49 W .56 95.59N 57.48W 108,83 1876 1866.10 1814.10 10 48 N 37.60 W 1.01 123.68N 81.27W 145.58 2120 2104.18 2052.18 16 13 N 47.55 W 2,40 164.98N 120.54W 202.57 2305- 2280.02 2228.02 18 28 N 49.80 W 1.28 201.20N 161.83W 257.28 2490 2453.36 2401.36 22 36 N 43.88 W 2.49 245,81N 208.94W 322.08 2674 2620.66 2568.66 26 21 N 46.90 W 2.15 299.20N 263.26W 398.20 2764 2701.36 2649.36 27 0 N 44.60 W 1.35 327.50N 292.30W 438.72 2952 2866.64 2814.64 29 40 N 46.12 W 1.48 390.09N 355.75W 527.81 3120 3010.43 2958.43 33 20 N 47.10 W 2.20 450.63N 419,85W 615.86 3323 3174.58 3122.58 38 35 N 43.37 W 2,80 534.66N 504.23W 734.91 3506 3315.40 3263,40 40 27 N 48.67 W 2.11 615,18N 587.82W 850.87 3690 3450,51 3398.51 45 5 N 45.98 W 2.71 699.98N 679.61W 975.59 3877 3576.66 3524.66 49 50 N 42.85 W 2.83 798.30N 775.74W 1113.08 4062 3688.35 3636.35 56 3 N 43.75 W 3,37 905.96N 877.26W 1261.06 4244 3784,94 3732,94 59 43 N 44,57 W 2,05 1016.36N 984,50W 1414,96 4428 3875,79 3823.79 61 0 N 46,05 W ,99 1128,65N 1098.03W 1574,58 4522 3920.05 3868.05 62 45 N 46.56 W 1.91 1185.86N 1157.92W 1657.31 4631 3970,21 3918.21 62 45 N 46.91 W .28 1252.62N 1228.84W 1754.58 4898 4092.62 4040.62 62 42 N 44.78 W .71 1418,06N 1399,23W 1991,90 5083 4176.88 4124.88 63 4 N 44.56 W .22 1535,10N 1514.94W 2156.46 5463 4348.50 4296.50 63 10 N 43,16 W .33 1779.26N 1749.56W 2495.07 5741 4474.04 4422.04 63 7 N 43.17 W .02 1960.14N 1919.22W 2743.05 5924 4556,55 4504.55 63 24 N 45,89 W 1.33 2076,88N 2034,06W 2906,79 6110 4640,19 4588,19 63 12 N 46,42 W .28 2192,10N 2154.03~ 3072.97 6292 4722,68 4670,68 62 52 N 46,46 W .18 2303,86N 2271.55W 3234.96 6479 4807,69 4755.69 62 50 N 44.85 W .77 2419.76N 2390,13W 3400.68 PRUDHOE BAY DRILLING EXPLORATZON/N.PRUDHOE BAY STATE ~3 500292232200 NORTH SLOPE COMPUTATION DATE: 2/ 8/93 S~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA DATE OF SURVEY: 02/01/93 MWD SURVEY JOB NUMBER: AK-MN-930101 KELLY BUSHING ELEV. = 52.00 OPERATOR: ARCO ALASKA INC PAGE FT. TRUE SUB-SEA COURS HEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS DIRECTION DEGREES DG/IO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 6661 4891.59 4839.59 6849 4977.41 4925.41 7037 5062.58 5010.58 7221 5145.45 5093.45 7406 5229.31 5177.31 62 21 N 42.56 W 1.15 63 10 N 44,50 W 1,02 63 9 N 45.29 W .37 63 7 N 43.73 W .76 63 1 N 43.82 W .07 2536.75N 2501.95W 3562.51 2657.64N 2616.81W 3729.26 2776.89N 2735.63W 3897.56 2893.56N 2850.32W 4061.15 3012.82N 2964.58W 4226.31 7584 5312.49 5260.49 7781 5405.38 5353.38 7969 5492.87 5440.87 8248 5623.52 5571.52 8439 5711.89 5659.89 61 17 N 42.33 W 1.22 62 27 N 43.63 W .83 61 59 N 42.12 W .75 62 17 N 43.72 W .52 62 20 N 43..75 W .03 3127.86N 3072.17W 4383.82 3255.03N 3190.68W 4557.63 3376.74N 3303.69W 4723.71 3557.72N 3471.99W 4970.83 3679.42N 3588.44W 5139.26 8628 5798.29 5746.29 8815 5882.87 5830.87 9000' 5967.11 591.5.11 9184 6051.77 5999.77 9371 6137,83 6085.83 63 15 N 43.25 W .54 63 0 N 43.18 W .14 62 43 N 44.83 W .81 62 46 N 43.22 W .77 62 8 N 44,28 ~ .61 3801.37N 3704.t6W 5307.38 3923.03N 3818,47W 5474.31 4041,22N 3932,61W 5638,62 4159.40N 4046.84W 5802.98 4278.61N 4160,95W 5968.00 9555 6223.79 6171.79 9742 6311.22 6259.22 9931 6399.22 6347.22 10117 6484.60 6432.60 10305 6572.08 6520.08 62 17 N 45.07 W .39 62 0 N 43.78 W .63 62 31 N 45,94 W 1.05 62 35 N 47.23 W .62 62 3 N 45.56 W .83 4394.65N 4275.69W 6131.16 4512.84N 4391.53W 6296.64 4631.48N 4509.60W 6463.98 4744.47N 4629.03W 6628.17 4859.50N 4749.81W 6794.78 10495 6661.68 6609.68 10683 6751.05 6699,05 10875 6843.79 6791.79 11065 6935.35 6883.35 11256 7028.43 6976,43 61 48 N 46.31 W .37 61 9 N 45.55 W ,50 61 13 N 45.34 W .10 61 12 N 44.08 W ,58 60 30 N 42.96 ~ .63 4976.38N 4870.56~ 6962.70 5090.76N 4988.72W 7127.03 5209.04N 5108.85~ 7295.53 5327.45N 5226.07N 7462.11 5448.48N 5341.01W 7629.03 11433 7116.00 7064.00 11614 7206.29 7154.29 11881 7340.34 7288.34 12084 7441.94 7389,94 12273 7535.32 7483.32 60 12 N 43.17 W .20 59 50 N 43.70 W .33 59 47 N 48.59 W 1.59 60 17 N 46.41 W .96 60 34 N 44,49 N ,89 5560.92N 5446.10W 7782.93 5674.59N 5553.72W 7939.46 5834,12N 5719,76W 8169.50 5953.21N 5849.71W 8345.38 6068,69N 5967.02W 8509.91 12457 7622.76 7571.76 12640 7711.96 7659.96 12831 7804.96 7752.96 13019 7893,64 7841,64 13207 7979.95 7927,95 61 56 N 44.98 W .78 60 24 N 44.59 W .86 61 13 N 46,72 W 1.07 62 28 N 45.98 W .75 62 53 N 44.03 W .95 6183.25N 6080.52W 8671.15 6297.00N 6193.43W 8831.39 6413.39N 6312.53W 8997.81 6527.79N 6432.44W 9163.36 6645.90N 6550.57W 9330.36 :RY-SUN DRT._LL]'NG SERVTCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG EXPLORATZON/N,PRUDHOE 500292232200 NORTH SLOPE COMPUTATZON DATE: 2/ BAY STATE :~3 8/93 DATE OF SURVEY' 02/01/93 MWD SURVEY JOB NUMBER' AK-MM-930101 KELLY BUSHZNG ELEV. : 52.00 FT, OPERATOR' ARCO ALASKA ZNC TRUE SUB-SEA HEASD VERTTCAL VERT]'CAL DEPTH DEPTH DEPTH COURS COURSE ZNCLN DZRECTZON DG MN DEGREES DLS TOTAL RECTANGULAR COORDZNATES VERT, DG/IO0 NORTH/SOUTH EAST/WEST SECT. 13397 8067.36 8015.36 13592 8157.32 8105.32 13677 8196.24 8144.24 13866 8278.32 8226.32 14054 8358.88 8306.88 62 19 N 41.45 W 1.24 62 37 N 42.52 W .51 63 22 N 43.98 W 1.75 65 5 N 44.01 W .91 64 11 N 43.03 W .67 6769.77N 6665.04W 9499.01 6898.11N 6780.54W 9671,58 6953,75N 6832,89W 9747.98 7076.11N 6951.03W 9918.07 7199.37N 7068.09W 10088.06 14242 8440,39 8388,39 14426 8520.60 8468.60 14616 8601.98 8549.98 14897 8721.91 8669.91 15084 8801.78 8749.78 64 9 N 42.31 W .35 64 22 N 41.33 W .49 64 41 N 41.35 W .16 64 56 N 43.84 W .80 64 30 N 41.33 W 1.24 7323.21N 7182.24W 10256.45 7447.24N 7293.22W 10422.80 7575.55N 7406.10W 10593.55 7763.24N 7578.67W 10848.47 7887.73N 7693.09W 11017,53 15274 8883.12 8831.12 64 37 N 42.24 W .44 15463 8962.89 8910.89 65 24 N 42.30 W .41 15544 8996.65 8944.65 65 52 N 40.69 W 1.89 15661 9044.07 8992.07 65 58 N 40.49 W .18 15756 9084,61 9032,61 63 25 N 37.17 W 4.15 8015,22N 7807,02W 11188.42 8141,88N 7922.15W 11359.53 8197.71N 7971.54W 11434,02 8278.31N 8040.59W 11539,99 8345,07N 8094.36W 11625,42 15849 9128.08 9076.08 60 50 N 35.51 W 3.19 15943 9174.92 9122.92 59 24 N 35.04 W 1.59 16034 9222.09 9170.09 58 28 N 34.34 W 1.22 16128 9272,01 9220.01 57 28 N 34.68 W 1.10 16223 9323.82 9271,82 56 32 N 32.17 W 2.42 8411.31N 8143.10W 11706,98 8477.89N 8190.21W 11787.67 8542.28N 8234.78W 11865.02 8608.05N 8280.00W 11943,82 8674.65N 8323.96W 12022.35 16315 9374.67 9322.67 56 19 N 34.35 W 1.99 16407 9425.60 937'3.60 55 58 N 36,16 W 1.69 16465 9457,91 9405.91 55 58 N 36,16 W .00 8738.74N 8365.99W 12097.73 8800.74N 8409.82W 12172.84 8839.37N 8438.05W 12220.27 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON MZNZMUM CURVATURE METHOD. HORZZONTAL DZSPLACEMENT = 12220.27 FEET AT NORTH 43 DEG. 40 MZN, WEST AT MD = 16465 VERTZCAL SECTZON RELATZVE TO WELL HEAD VERTZCAL SECTZON COMPUTED ALONG 316.33 DEG. !:~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHO'E BAY DRILLING EXPLORATION/N.PRUDHOE BAY STATE ¢3 500292232200 NORTH SLOPE COMPUTATION DATE: 2/ 8/93 DATE OF SURVEY: 02/01/93 JOB NUMBER: AK-MM-930101 KELLY BUSHING ELEV. = 52,00 OPERATOR: ARCO ALASKA ZNC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -52,00 ,00 N ,00 E ,00 1000 999,11 947,11 25,74 N 7,96 W ,89 ,89 2000 1987,32 1935,32 143,36 N 98.34 W 12,68 11,79 3000 2907,88 2855,88 406,68 N 373,10 W 92,12 79,44 4000 3652,44 3600,44 868,80 N 841,86 W 347.56 255,44 5000 4138.96 4086.96 1481.92 N 1462.57 W 861.04 513.47 6000 4590.24 4538.24 2123.72 N 2082.39 W 1409.76 548.73 7000 5045.52 4993.52 2753,18 N 2711.68 W 1954.48 544.72 8000 5507.23 5455.23 3396,77 N 3321.80 W 2492,77 538.29 9000 5967.10 5915.10 4041.20 N 3932.60 W 3032.90 540.14 10000' 6430,68 637.8,68 4673,56 N 4553,08 W 3569,32 536.42 11000 6903,75 6851,75 5286,16 N 5186,08 W 4096,25 526,93 12000 7400,09 7348,09 5902,62 N 5796,56 W 4599,91 503,66 13000 7884,68 7832,68 6515,84 N 6420,08 W 5115,32 515,41 14000 8334.98 8282,98 7163,25 N 7034,37 W 5665,02 549,70 15000 8765,23 8713,23 7830,19 N 7642,48 W 6234,77 569,75 16000 9204,03 9152,03 8517,97 N 8218,17 W 6795,97 561,20 16465 9457,91 9405,91 8839,37 N 8438,05 W 7007,09 211,12 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE'DIMENSION MINIMUM CURVATURE METHOD. FT. SF RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHO'E BAY DRILLING EXPLORATION/N.PRUDHOE BAY 500292232200 NORTH SLOPE COMPUTATION DATE: 2/ 8/93 STATE :1'3 DATE OF SURVEY' 02/01/93 JOB NUMBER' AK-MM-930101 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR' ARCO ALASKA ZNC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGULAR COORDINAT NORTH/SOUTH EAST/WE ES MD-TVD VERTICAL ST DIFFERENCE CORRECTION 0 .00 52 52.00 152 152.00 252 252.00 352 352.00 -52 lO0 2OO 3OO .00 .00 .00 .00 .00 .00 N .00 E .00 .00 N .00 E .00 .00 .04 N .06 E .00 .00 .66 N .91 E .01 .01 .30 N 1,78 E ,01 .01 452 452.00 552 552.00 652 652.00 752 752.00 852 852.00 400.00 2.00 N 2.41 500.00 2.74 N 2.90 600.00 5.37 N 1.80 700.00 8.55 N ,29 800,00 14.13 N 2.66 E .02 .01 E .02 .00 E ,07 .04 E .13 .07 W ,33 .20 952' 952.00 1053 1052.00 1153 1152.00 1254 1252.00 1355 1352.00 9OO 1000 1100 1200 1300 .00 21.42 N 6,10 .00 3!.14 N 10.20 .00 41.90 N 14.76 .00 53.28 N 19.73 .00 63.94 N 27.39 .66 .33 1 .22 .56 1 .90 .68 2.67 .77 3.55 .88 1456 1452.00 1557 1552.00 1658 1652.00 1759 1752.00 1861 1852.00 1400 1500 1600 1700 1800 .00 74.20 N 36.57 .00 84.60 N 46.78 .00 95.43 N 57.33 .00 106.74 N 68.06 .00 121.55 N 79.63 4.49 .94 5.55 1 .06 6.68 1 .14 ? .89 1 .21 9.65 1 .76 1963 1952.00 2066 2052.00 2170 2152.00 2275 2252.00 2381 2352.00 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 137.35 N 92.76 155.01 N 109.94 174.37 N 130.81 195.15 N 154.68 217.96 N 180.70 W 11 .74 2.10 W 14.74 3.00 W 18.72 3.98 W 23.63 4.91 W 29.45 5.82 2488 2452.00 2598 2552.00 2709 2652.00 2821 2752.00 2925 2852.00 24O0 2500 2600 2700 2800 .00 .00 ,00 .00 .00 245.42 N 208.56 276.51 N 239.49 309.82 N 274.60 346.11 N 310.82 384.33 N 349.79 W 36.84 7.39 W 46.04 9.2O W 57.14 11.10 W 69.53 12.38 W 83.46 13.93 3051 2952.00 3171 3052.00 3295 3152.00 3423 3252.00 3554 3352,00 2900.00 3000,00 3100.00 3200.00 3300,00 425.12 N 392.58 469.92 N 440.23 521.81 N 491.98 579.23 N 548.59 636.42 N 611,63 W 99.64 16.18 W 119.13 19.50 W 143.13 24.00 W 171.61 28.48 W 202.94 31.33 :RY-SUN DRZLLZNG SERV]:CES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG EXPLORATZON/N.PRUDHOE BAY STATE 500292232200 NORTH SLOPE COMPUTATZON DATE: 2/ 8/93 ~3 DATE OF SURVEY: 02/01/93 JOB NUHBER: AK-MN-930101 KELLY BUSHZNG ELEV. = 52,00 OPERATOR: ARCO ALASKA ZNC FT. ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL NEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES MD-TVD VERTZCAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DZFFERENCE CORRECTZON 3692 3452,00 3400.00 701.05 N 680.70 W 240.62 37.68 3839 3552.00 3500.00 777,34 N 756.09 W 287.29 46.67 3999 3652.00 3600,00 868,37 N 841.46 W 347,26 59.98 4180 3752.00 3700.00 977.09 N 946.01 W 428.28 81.02 4379 3852,00 3800.00 1098.85 N 1067.12 W 527.03 98.75 4591 3952.00 3900.00 1228.46 N 1203.02 W 639.82 112.79 4810 4052.00 4000.00 1362.17 N 1343.77 W 758.22 118.40 5028 4152,00 4100.00 1500,20 N 1480.57 W 876.78 118.56 5249 4252.00 4200,00 1640.47 N 1618,70 W 997.58 120.80 5471 4352.00 4300.00 1784,31 N 1754.30 W 1119.13 121.55 5692' 4452.00 4400.00 1928,43 N 1889.47 W 1240.58 121.45 5914 4552.00 4500,00 2070,55 N 2027,53 W 1362.57 121.99 6137 4652.00 4600.00 2208.22 N 2170.96 W 1485.11 122.54 6357 4752.00 4700.00 2343,29 N 2313.04 W 1605,18 120.07 6576 4852.00 4800.00 2481.08 N 2450.74 W 1724.17 118.98 6792 4952.00 4900.00 2621.78 N 2581.58 W 1840,78 116.62 7014 5052,00 5000.00 2762.19 N 2720.77 W 1962.34 121.56 7235 5152.00 5100.00 2902,91 N 2859.26 W 2083.68 121.33 7456 5252.00 5200.00 3044,99 N 2995.46 W 2204.44 120.77 7666 5352,00 5300.00 3181.22 N 3120.77 W 2314.85 110,41 7882 5452,00 5400.00 3319.75 N 3252.16 W 2430.39 115.54 8095 5552.00 5500.00 3459,19 N 3378,25 W 2543.33 112.94 8310 5652.00 5600.00 3596.91 N 3509.47 W 2658.24 114.92 8525 5752.00 5700.00 3734.76 N 3641.39 W 2773.66 115,41 8747 5852.00 5800,00 3878.85 N 3777.00 W 2895.36 121.71 8967 5952.00 5900.00 4020.44 N 3911.96 W 3015.06 119.70 9185 6052.00 6000.00 4159,73 N 4047.15 W 3133.43 118.37 9401 6152,00 6100.00 4297.81 N 4179,68 W 3249.38 115.95 9616 6252.00 6200.00 4432.60 N 4313.72 W 3364.18 114.80 9829 6352.00 6200.00 4568.23 N 4444.67 W 3477.59 113.41 10046 6452.00 6400.00 4701.79 N 4582.88 W 3594.26 116.67 10262 6552.00 6500.00 4833.00 N 4722.78 W 3710.58 116.31 10475 6652.00 6600,00 4963.90 N 4857.50 W 3823.39 112.81 10685 6752.00 6700.00 5091.97 N 4989,95 W 3933.03 109.64 10892 6852.00 6800.00 5219.55 N 5119.49 W 4040.52 107.50 i1RY-SUN DRZLL:[NG SERV]:CES ANCHORAGE ALASKA PRUDHOE BAY DRZLLZNG EXPLORATZON/N.PRUDHOE BAY 500292232200 NORTH SLOPE COMPUTATZON DATE: 2/ 8/93 STATE ~3 PAGE DATE OF SURVEY: 02/01/93 JOB NUMBER: AK-NH-930101 KELLY BUSHZNG ELEV. = 52.00 OPERATOR: ARCO ALASKA ZNC ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST D]:F HD-TVD VERTZCAL FERENCE CORRECTZON 11100 6952.00 6900.00 5349.20 N 5247.13 W 4148.15 107.63 11304 7052.00 7000.00 5478.98 N 5369.41 W 4252.59 104.44 11506 7152.00 7100.00 5606.78 N 5489,12 W 4354.25 101.65 11705 7252.00 7200.00 5730.61 N 5608,85 W 4453.43 99.18 11904 7352.00 7300,00 5847.37 N 5734.78 W 4552.17 98.74 12104 7452.00 7400.00 5965.37 N 5862,48 W 4652,78 100,61 12307 7552.00 7500.00 6089.80 N 5987.75 W 4755.71 102.94 12517 7652.00 7600,00 6220.73 N 6117.98 W 4865,73 110.02 12721 7752.00 7700.00 6347.22 N 6242,95 W 4969,74 104,01 12929 7852.00 7800.00 6472,39 N 6375.06 W 5077.41 107,67 13146 7952.00 7900.00 6606.65 N 6512.62 W 5194.10 116.69 13364 8052.00 8000.00 6747,81 N 6645.65 W 5312.37 118.26 13580 8152.00 8100.00 6890.53 N 6773,59 W 5428.57 116.20 13804 8252.00 8200,00 7035.33 N 6911,63 W 5552,25 123.69 14039 8352.00 8300.00 7188.98 N 7058.39 W 5687,10 134,84 14268 8452.00 8400.00 7340.94 N 7198.38 W 5816.64 129.55 14499 8552.00 8500.00 7496.42 N 7336,46 W 5947,39 130,74 14733 8652.00 8600,00 7654.95 N 7475.97 W 6081.04 133.66 14968 8752,00 8700.00 7809.66 N 7623,25 W 6216,91 135,87 15201 8852.00 8800.00 7966.67 N 7762,93 W 6349,65 132.74 15436 8952.00 8900.00 8124.28 N 7906,14 W 6484.92 135,27 15680 9052.00 9000.00 8291.74 N 8051.92 W 6628,45 143.53 15898 9152.00 9100.00 8446.09 N 8167.89 W 6746.00 117.55 16091 9252.00 9200,00 8582.22 N 8262,13 W 6839,44 93.44 16274 9352.00 9300,00 8710.58 N 8346,85 W 6922,93 83,49 16454 9452.00 9400.00 8832.30 N 8432.88 W 7002.44 79.51 16465 9457.91 9405,91 8839.37 N 8438.05 W 7007.09 4,65 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT ND (FROM NZNZNUN CURVATURE) POZNTS FT. SUB - S URFA CE DIRECTIONAL SURVEY Company ARCO ALASKA, INC. Well Name NORTH PRUDHOE BAY STATE t3 (71' FSL,1791' FIlL,SEC 25,T12N,R14E) Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 93066 LogQed By: IIARNER Date 20-FEB-93 Computed By: KRLrdELL SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. NORTH PRUDHOE BaY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' 20-FEB-93 ENGINEER' D. WARNER METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION' LINEAR VERTICAL SECTION' hORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 44 DEG 32 MIN WEST COMPUTATION DATE' 21-FEB-93 PAGE I ARCO ALASKA, INC. NORTH PRUDHOE BAY STATE #3 PRL~HOE BAY NORllq SLOPE, A~SKA DATE OF SURVEY- 20-FEB-93 KELLY BUSHING ELEVATION- 52.50 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NDRTH/S0UTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 0.00 100.00 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 O0 200 O0 299 99 399 99 499 99 599 97 699 92 799 78 899 56 -52.50 0 0 N 0 0 E 47.50 0 21 N 46 46 E 147.50 0 41 N 57 4 E 247.49 0 18 N 20 9 W 347.49 0 19 N 4 38 W 447.49 0 41 N 0 48 W 547.47 1 13 N 12 ll W 647.42 2 28 N 23 53 W 747.28 3 25 N 27 17 W 847.06 4 14 N 26 51 W 0 O0 0 O4 -0 11 0 O3 0 48 I 02 2.23 5.11 10.10 16.44 0 oo 0 74 0 36 0 66 0 39 0 32 0 51 1 02 0 99 0 77 0.00 N 0.24 N 0.74 N 1.44 N 1.92 N 2.69 N 4.23 N 7.21 N 11.92 N 17.81 N 0 O0 E 0 18 E 0 91 E 1 43 E 1 26 E 1 28 E 1 12 E 0 05 E 2 29 W 5 33 W 0o0 N 0 0 E 0 1 2 2 2 4 7 12 18 3O N 36 56 E 17 N 5O 58 E O3 N 44 42 E 30 N 33 24 E 98 N 25 21E 37 N 14 52 E 21 N 0 22 E 14 N 10 52 W 59 N 16 40 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 20 O0 1098 O0 1197 O0 1297 O0 1396 O0 1495 O0 1594 O0 1693 O0 1792 946.70 64 1046 14 96 1145 46 21 1244 71 39 1343 89 47 1442 97 52 1542 02 41 1640 91 14 1739 64 5 36 6 25 6 52 7 10 7 38 7 49 8 10 8 51 9 32 O0 1890 56 1838 06 10 49 N 22 59 W N 22 37 W N 24 52 W N 33 0 W N 43 48 W N 44 31W N 44 28 W N 43 6 W N 41 28 W N 43 10 W 24.45 34 17 45 08 56 77 69 54 83 O1 96 80 111 62 127 50 145 21 1 . 28 O. 98 0.57 0.83 1.47 0.63 0.26 0 72 0 69 I 30 25 51 N 35 22 N 45 88 N 56 61 N 66 52 N 76 14 N 85 96 N 96 64 N 108 41 N 121 62 N 8 93 W 12 17 23 31 40 50 60 71 83 27 03 N 19 17 W 93 W 37 64 W 49 41W 61 55 W 73 98 W 86 65 W 99 93 W 114 61W 129 45 W 147 51 N 2O 10 W 16 N 21 2 W 26 N 22 28 W 62 N 25 22 W 46 N 28 17 W 78 N 30 3O W 24 N 32 14 W 93 N 33 27 W 49 N 34 27 W 2000 O0 1988.35 1935 85 13 44 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2085.20 2032 70 15 9 O0 2181.23 2128 73 16 59 O0 2276.53 2224 03 18 16 O0 2371.06 2318 56 19 47 O0 2463.98 2411 48 24 2 O0 2554.50 2502.00 25 44 O0 2644.41 2591.91 26 14 O0 2733.71 2681.21 27 20 O0 2821.76 2769.26 29 21 N 50 22 W N 49 30 W N4g 6W N 48 54 W N 47 25 W N 44 20 W N 45 13 W N 46 44 W N 45 36 W N 46 4O W 166 O1 190 80 218 56 248 76 281 30 318 17 360 65 404 41 449 38 496 76 2 47 2 44 1 97 1 62 1 61 2 38 2 83 2 7O 1 59 1 31 135 56 N 151 169 189 211 237 267 297 328 361 98 93 W 167 82 N 36 7 W 56 N 118 78 N 139 64 N 161 38 N 186 17 N 212 40 N 242 62 N 274 77 N 306 65 N 340 O0 W 192 07 W 219 95 W 249 24 W 281 60 W 318 45 W 360 13 W 404 60 W 449 72 W 496 08 N 37 54 W 47 N 39 19 W 38 N 40 30 W 73 N 41 23 W 51 N 41 52 W 95 N 42 12 W 63 N 42 39 W 54 N 43 0 W 88 N 43 18 W 3000 O0 2908'09 2855.59 31 18 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2992 62 2940 12 33 26 O0 3074 O0 3153 O0 3231 O0 3308 O0 3381 O0 3451 O0 3517 O0 3582 87 3022 96 3101 64 3179 06 3255 02 3328 09 3398 53 3465 50 3530 37 35 57 46 38 51 14 39 26 56 41 10 52 44 3O 59 47 1 03 49 4 oo 5o 0 N 47 25 W N 48 18 W N 47 32 W N 45 0 W N 47 52 W N 49 2O W N 48 39 W N 48 11W N 47 39 W 1059 N 46 47 W 1135 547.17 600.49 657.23 718.38 781 31 845 61 913 79 984 95 56 48 59 94 20 82 74 65 40 5'7 73 .98 396 05 N 377 65 W 547 24 N 43 38 W 431 469 512 555 598 643 690 740 792 91N 417 78 N 459 43 N 503 94 N 548 35 N 597 29 N 649 58 N 702 72 N 757 32 N 813 23 W 600 63 W 657 48 W 718 98 W 781 56 W 845 09 W 913 50 W 985 91W 1059 71W 1135 52 N 44 1W 24 N 44 22 W 38 N 44 30 W 31 N 44 38 W 64 N 44 58 W 86 N 45 15 W 09 N 45 29 W 76 N 45 39 W 74 N 45 46 W COMPUTATION DATE' 21-FEB-93 PAGE 2 ARCO ALASKA, INC. NORTH PRUDHOE BAY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 20-FEB-g3 KELLY BUSHING ELEVATION' 52.50 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3644 61 3592.11 53 33 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3700 O0 3753 O0 3804 O0 3853 O0 3901 O0 3947 O0 3993 O0 4040 O0 4086 93 3648.43 57 26 80 3701.30 58 42 64 3752.14 60 13 34 3800.8,4 61 7 31 3848.81 61 57 54 3895.04 62 25 79 3941.29 62 32 03 3987.53 62 20 35 4033.85 62 42 N 46 19 W 1213 78 N 46 44 W 1296 N 46 55 W 1381 N 47 30 W 1467 N 47 29 W 1554 N 47 21W 1642 N 47 21W 1730 N 47 20 W 1819 N 47 16 W 1907 N 47 2 W 1996 33 14 16 38 O1 57 14 70 23 2 21 2 58 2 70 0 76 0 99 1 14 0 95 0 74 0 31 0 36 846 29 N 870 50 W 1214 08 N 45 48 W 903 961 1019 1078 1138 1198 1258 1318 1378 08 N 930 21N 992 69 N 1055 69 N 1119 10 N 1184 17 N 1249 28 N 1314 38 N 1380 67 N 1445 49 W 1296 33 W 1381 54 W 1467 94 W 1554 51W 1642 73 W 1731 91W 1819 10 W 1908 05 W 1997 67 N 45 51 W 54 N 45 55 W 63 N 45 59 W 94 N 46 5 W 66 N 46 9 W 31 N 46 12 W 96 N 46 16 W 61 N 46 19 W 23 N 46 21 W 5000 O0 4132 17 4079 67 62 54 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4177 O0 4222 O0 4267 O0 4312 O0 4357 O0 4402 O0 4448 O0 4493 O0 4538 43 4124 33 4169 30 4214 25 4259 26 4304 31 4349 15 4395 22 4440 01 4485 93 63 15 83 63 18 8O 63 18 75 63 17 76 63 14 81 63 5 65 62 44 72 63 34 51 63 27 N 46 56 W 2085 03 N 46 35 W 2174 N 46 32 W 2263 N 46 33 W 2352 N 46 33 W 2441 N 46 33 W 2531 N 46 14 W 2620 N 46 4O W 2709 N 47 36 W 2798 N 48 28 W 2887 14 44 7O 98 22 45 28 46 68 0.41 0.46 0.36 0.29 0.18 0.16 0.26 0 60 0 66 0 89 1439 32 N 1510 03 W 2086 10 N 46 22 W 1500 1561 1623 1684 1746 1807 1869 1929 1989 44 N 1574 91N 1639 34 N 1704 80 N 1769 21N 1834 77 N 1898 13 N 1963 89 N 2028 44 N 2095 96 W 2175 80 W 2264 65 W 2353 47 W 2443 30 W 2532 96 W 2621 25 W 2710 65 W 2799 33 W 2889 27 N 46 23 W 62 N 46 24 W 94 N 46 24 W 27 N 46 24 W 57 N 46 25 W 85 N 46 25 W 72 N 46 24 W 98 N 46 26 W 34 N 46 29 W 6000 O0 4582 84 4530 34 63 20 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4627 O0 4673 O0 4718 O0 4764 O0 4810 O0 4856 O0 4902 O0 4948 O0 4994 90 4575 48 4620 73 4666 24 4711 O1 4757 28 4803 80 4850 82 4896 25 4941 40 63 6 98 62 57 23 62 54 74 62 49 51 62 42 78 62 9 30 62 10 32 62 58 75 62 56 N 48 46 W 2976 83 N 48 41W 3065 N 48 20 W 3154 N 48 4 W 3243 N 47 50 W 3332 N 47 39 W 3421 N 47 26 W 3509 N 47 14 W 3598 N 47 38 W 3686 N 47 41W 3775 87 66 65 54 31 84 26 92 88 0 79 0 35 0 43 0 69 0 64 0 41 0.43 O. 50 O. 69 O. 59 2048 46 N 2162 47 W 2978 67 N 46 33 W 2107 2166 2225 2285 2345 2405 2465 2525 2585 33 N 2229 28 N 2296 71N 2362 37 N 2428 18 N 2494 02 N 2560 O1N 2625 04 N 2690 12 N 2756 58 W 3067 26 W 3156 75 W 3245 86 W 3335 64 W 3423 05 W 3512 14 W 3601 56 W 3689 33 W 3778 88 N 46 37 W 83 N 46 40 W 98 N 46 43 W O1 N 46 45 W 90 N 46 46 W 55 N 46 47 W 06 N 46 48 W 84 N 46 49 W 91 N 46 50 W 7000 O0 5039 53 4987 03 63 13 7100 7200 7300 7400 75OO 7600 7700 7800 7900 O0 5084 O0 5130 O0 5176 O0 5221 O0 5267 O0 5315 O0 5362 O0 5408 O0 5454 95 5032 84 5078 21 5123 39 5168 60 52~5 02 5262 58 5310 76 5356 69 5402 45 62 51 34 62 50 71 63 6 89 63 ~4 10 62 2 52 61 17 08 62 14 26 62 37 19 62 18 N 47 58 W 3864 89 N 47 51W 3953 N 47 35 W 4042 N 47 16 W 4131 N 47 0 W 4220 N 46 45 W 4309 N 46 21W 4397 N 46 45 W 4485 N 47 I W 4573 N 46 30 W 4662 83 54 54 67 27 26 18 80 56 0 42 0 44 0 50 0 52 0 5O 0 7O 0 91 1 O2 0 94 0 66 2644 92 N 2822 47 W 3868 06 N 46 52 W 2704 2764 2824 2885 2946 3006 3067 3127 3188 66 N 2888 41N 2954 72 N 3019 46 N 3085 09 N 3149 66 N 3213 37 N 3277 83 N 3342 68 N 3407 55 W 3957 31W 4045 92 W 4135 26 W 4224 97 W 4312 87 W 4401 53 W 4488 42 W 4577 14 W 4666 13 N 46 53 W 98 N 46 54 W 09 N 46 55 W 30 N 46 55 W 98 N 46 55 W 02 N 46 54 W 98 N 46 54 W 68 N 46 54 W 51 N 46 54 W COMPUTATION DATE' 21-FEB-93 PAGE 3 ARCO ALASKA, INC. NORTH PRUDHOE BaY STATE PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 20-FEB-93 KELLY BUSHING ELEVATION' 52.50 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DePth TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 8000 O0 5501 35 5448 85 61 54 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5548 O0 5594 O0 5640 O0 5687 O0 5733 O0 5779 O0 5824 O0 5868 O0 5913 04 5495 17 5541 66 5588 15 5634 44 5680 28 5726 04 5771 64 5816 53 5861 54 62 29 67 62 24 16 62 28 65 62 21 94 62 32 78 63 8 54 63 34 14 63 21 03 63 26 N 46 8 W 4750 96 N 47 55 W 4839 N 47 42 W 4927 N 46 59 W 5016 N 46 47 W 5104 N 46 50 W 5193 N 46 28 W 5282 N 46 36 W 5371 N 47 18 W 5460 N 47 19 W 5550 32 89 32 8O 37 I8 55 96 23 O. 68 1.13 1.07 0 55 0 97 0 92 0 61 0 71 1 06 I 15 3249 78 N 3471 08 W 4754 94 N 46 53 W 3310 3369 3429 3490 3551 3612 3673 3734 3795 30 N 3535 84 N 3601 76 N 3666 66 N 3730 23 N 3795 24 N 3860 94 N 3924 71N 3990 55 N 4056 56 W 4843 33 W 4932 51W 5020 78 W 5109 50 W 5197 12 W 5286 85 W 5376 56 W 5465 01W 5554 37 N 46 53 W 08 N 46 54 W 62 N 46 55 W 15 N 46 54 W 79 N 46 54 W 66 N 46 54 W 08 N 46 53 W 58 N 46 54 W 94 N 46 54 W 9000 O0 5958.94 5906.44 62 41 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 6004.78 5952.28 62 42 O0 6050.57 5998.07 62 43 O0 6096.65 6044.15 62 22 O0 6143.13 6090.63 62 14 O0 6189.68 6137.18 62 24 O0 6236.19 6183.69 62 16 O0 6282.94 6230.44 62 0 O0 6329.73 6277.23 62 16 O0 6376.01 6323.51 62 32 N 48 31 W 5639 14 N 48 19 W 5727 N 48 5 W 5816 N 47 37 W 5905 N 47 29 W 5993 N 48 32 W 6081 N 48 24 W 6170 N 47 59 W 6258 N 47 56 W 6346 N 50 14 W 6435 82 54 14 56 91 22 44 67 O2 i 20 0 88 0 31 0 44 0 37 0 72 0 71 0 42 0 33 I 13 3854 94 N 4122 41 W 5644 01 N 46 55 W 3913 3973 4032 4092 4151 4210 4269 4328 4386 98 N 4188 24 N 4255 79 N 4320 55 N 4386 90 N 4451 57 N 4518 53 N 4584 75 N 4649 72 N 4716 84 W 5732 12 W 5821 91W 5910 25 W 5999 90 W 6087 19 W 6176 06 W 6264 66 W 6352 71W 6441 86 N 46 57 W 74 N 46 58 W 47 N 46 59 W O1 N 46 59 W 51 N 47 0 W O0 N 47 1W 38 N 47 2 W 75 N 47 3 W 32 N 47 5 W 10000 O0 6422.00 6369 50 62 42 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 6467 88 6415 O0 6514 O0 6560 O0 6607 O0 6655 O0 6702 O0 6750 O0 6799 O0 6847 07 6461 75 6508 89 6555 27 6602 96 6650 71 6698 O4 6746 03 6794 38 62 34 57 62 28 25 62 3 39 62 2 77 61 45 46 61 32 21 61 15 54 61 16 53 61 14 N 50 13 W 6523 38 N 49 57 W 6611 N 49 49 W 67OO N 49 32 W 6788 N 49 28 W 6876 N 49 10 W 6963 N 48 46 W 7051 N 48 47 W 7139 N 48 48 W 7226 N 48 35 W 7313 82 13 21 O8 84 47 O9 39 9O 1 11 0 31 0 56 0 95 1 O0 0 55 0 56 0 99 0 96 0 69 4443 53 N 4784 95 W 6529 99 N 47 7 W 4500 53 N 4853 4557 72 N 4920 4614 98 N 4988 4672 27 N 5055 4729 71N 5122 4787.42 N 5188 4845.28 N S254 4903.00 N 5320 4960.91 N 5386 12 W 6618 92 W 6707 31W 6795 36 W 6883 11W 6971 40 W 7059 52 W 7147 35 W 7235 25 W 7322 73 N 47 10 W 33 N 47 12 W 68 N 47 14 W 80 N 47 15 W 81 N 47 17 W 67 N 47 18 W 50 N 47 19 W 02 N 47 20 W 73 N 47 21W 11000 O0 6895 04 6842.54 61 21 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 6943 O0 6991 O0 7040 O0 7090 O0 7140 O0 7190 O0 7240 O0 7291 O0 7341 10 6890.60 61 7 69 6939.19 60 41 78 6988.28 60 21 41 7037 91 60 16 21 7087 71 59 58 20 7137 70 59 54 66 7188 16 59 26 27 7238 77 59 52 90 7289 40 59 19 N 48 19 W 7401 41 N 47 52 W 7488 N 47 30 W 7576 N 47 13 W 7663 N 48 22 W 7749 N 48 13 W 7836 N 49 35 W 7922 N 49 12 W 8008 N 50 38 W 8094 N 50 15 W 8180 94 2O 22 90 43 76 79 66 44 0 6O 0 56 0 62 0 53 0 74 0 85 0 91 0 85 0 65 0 78 5019 09 N 5451 90 W 7410 43 N 47 22 W 5077 5136 5195 5253 5311 5368 5424 5480 5534 65 N 5517 47 N 5581 54 N 5645 83 N 5710 51N S774 27 N 5840 45 N 5905 05 N 5971 96 N 6038 17 W 7498 12 N 47 23 W 82 W 7585 52 N 47 23 W 86 W 7672 64 N 47 23 W 20 W 7759 45 N 47 23 W 95 W 7846 16 N 47 24 W 36 W 7932.73 N 47 25 W 91 W 8019.01 N 47 26 W 84 W 8105.18 N 47 28 W 34 W 8191.30 N 47 29 W COMPLrTATION DATE: 21-FEB-93 PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY- 20-FEB-93 NORTH PRUDHOE BAY STATE #3 KELLY BUSHING ELEVATION' 52.50 ET PRUDHOE BAY NORTH SLOPE, ALASKA ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000 O0 7393 25 7340 75 59 5 12100 12200 12300 12400 12500 12600 12700 12800 12900 O0 7443 O0 7493 O0 7542 O0 7590 O0 7637 O0 7685 O0 7734 O0 7784 O0 7832 46 7390 39 7440 51 7490 42 7537 26 7584 42 7632 94 7682 75 7732 61 7780 96 60 14 89 6O 10 01 60 20 92 62 29 76 61 28 92 60 42 44 59 43 25 60 52 11 61 52 N 49 53 W 8265 85 N 49 45 W 8351 N 49 24 W 8438 N 49 19 W 8525 N 49 42 W 8612 N 49 24 W 87OO N 49 11W 8787 N 48 50 W 8874 N 48 51W 8960 N 48 12 W 9048 95 27 O6 5O 52 85 47 94 53 0 . 74 0.91 O. 92 O. 84 1 .39 1 42 1 O8 0 96 1 18 1 33 5590 04 N 6104 14 W 8277 02 N 47 31W 5645 5702 5758 5815 5873 5930 5987 6044 6102 83 N 6170 10 N 6236 75 N 6302 78 N 6368 10 N 6436 28 N 6502 26 N 6568 40 N 6633 56 N 6699 20 W 8363 09 W 8450 26 W 8537 97 W 8624 2O W 8713 62 W 8800 20 W 8887 41W 8974 20 W 9062 42 N 47 32 W O2 N 47 34 W O7 N 47 35 W 79 N 47 36 W 09 N 47 37 W 70 N 47 38 W 55 N 47 39 W 24 N 47 40 W 03 N 47 40 W 13000 O0 7879 31 7826.81 62 26 13100 13200 13300 13400 13500 13600 13700 13800 13900 O0 7925 O0 7970 O0 8016 O0 8062 O0 8108 O0 8155 O0 8200 O0 8243 O0 8285 28 7872.78 62 46 86 7918.36 63 1 37 7963.87 62 51 38 8009.88 62 24 96 8056.46 62 18 26 8102.76 62 49 45 8147.95 63 29 99 8191.49 64 58 89 8233.39 64 58 N 47 34 W 9136 8O N 46 44 W 9225 N 45 48 W 9314 N 45 10 W 9403 N 44 31W 9492 N 44 32 W 9580 N 46 26 W 9669 N 46 20 W 9758 N 46 6 W 9848 N 45 55 W 9939 52 49 52 3O 79 4O 55 53 3O 1 19 0 88 0 58 0 69 0 72 0 84 1 38 1 32 1 09 1 19 6161 88 N 6764 77 W 9150 45 N 47 40 W 6222 6283 6346 6409 6472 6534 6595 6658 6721 27 N 6829 81N 6894 30 N 6957 20 N 7020 65 N 7081 47 N 7145 95 N 7210 13 N 7275 30 N 7340 88 W 9239 19 W 9328 62 W 9417 28 W 9505 96 W 9594 47 W 9682 11W 9772 2O W 9862 42 W 9952 26 N 47 40 W 24 N 47 39 W 22 N 47 38 W 90 N 47 36 W 23 N 47 34 W 82 N 47 33 W 01 N 47 33 W 01 N 47 32 W 77 N 47 31W 14000 O0 8327 99 8275.49 65 2 14100 14200 14300 14400 14500 14600 14700 14800 14900 O0 8370 O0 8414 O0 8457 O0 8499 O0 8542 O0 8585 O0 8628 O0 8670 O0 8713 77 8318 27 64 12 O1 8361 O1 8404 98 8447 93 8490 68 8533 48 8575 82 8618 30 8660 51 64 35 51 64 35 48 64 37 43 64 27 18 64 53 98 64 53 32 64 48 80 65 5 N 45 0 W 10030 O0 N 44 8 W 10120 N 43 20 W 10210 N 43 29 W 10300 N 43 28 W 10391 N 43 30 W 10481 N 43 24 W 10571 N 43 27 W 10662 N 43 37 W 10752 N 43 37 W 10843 38 54 8O 08 37 76 12 7O 22 1 O2 1 O7 1 13 0 94 0 85 0 42 0 56 0 73 0 56 0 43 6784 89 N 7405 10 W10043 42 N 47 30 W 6849 6914 6980 7045 7111 7176 7242 7308 7373 25 N 7468 51N 7530 05 N 7592 65 N 7654 18 N 7717 79 N 7779 40 N 7841 09 N 7903 65 N 7966 56 W10133 78 W10223 88 W10313 92 W10403 07 W10493 25 W10584 40 W10674 80 W10764 23 W10855 69 N 47 29 W 66 N 47 27 W 72 N 47 24 W 8O N 47 22 W 90 N 47 20 W 10 N 47 18 W 27 N 47 16 W 67 N 47 15 W 02 N 47 13 W 15000 O0 8755.52 8703 02 64 47 15100 15200 15300 15400 15500 15600 15700 15800 15900 O0 8798.33 8745 O0 8841.50 8789 O0 8884.45 8831 O0 8927 49 8874 O0 8968 56 8916 O0 9009 53 8957 O0 9049 59 8997 O0 9094 17 9041 O0 9142 47 9089 83 64 28 O0 64 17 95 64 51 99 64 48 06 64 55 03 66 37 09 65 8 67 62 13 97 60 4 N 43 39 W 10933 85 N 43 38 W 11024 N 43 51W 11114 N 43 38 W 112O4 N 43 48 W 11294 N 43 41W 11386 N 43 55 W 11477 N 42 10 W 11568 N 36 24 W 11657 N 35 16 W 11744 22 41 71 96 12 33 93 94 46 0 38 0 45 0 57 0 59 0 93 2 25 2 58 2 23 3 69 2 32 7439 28 N 8028 76 W10945 49 N 47 11 W 7504 7569 7634 7700 7766 7832 7898 7967 8038 64 N 8091 67 N 8153 91N 8216 11N 8278 09 N 8341 05 N 8404 40 N 8467 90 N 8523 89 N 8575 17 W11035 68 W11125 12 W11215 53 W11306 46 W11397 45 W11488 63 Wl1579 91 Wl1668 12 Wl1754 70 N 47 9 W 75 N 47 8 W 90 N 47 6 W O1 N 47 4 W 02 N 47 3 W 08 N 47 1W 53 N 47 0 W 09 N 46 56 W O0 N 46 51W COMPUTATION DATE' 21-FEB-93 PAGE ARCO ALASKA, INC. NORTH PRUDHOE BAY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 20-FEB-93 KELLY BUSHING ELEVATION' 52.50 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN iO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIWUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 16000 O0 9193 29 9140 79 58 50 16100 O0 9245 82 9193 32 57 47 16200 O0 9299 86 9247 36 56 47 16300 O0 9354 95 9302 45 56 22 16400 O0 9410 58 9358 08 56 0 16465 O0 9446 94 9394 44 55 58 N 34 37 W 11829 37 N 34 35 W 11913 17 N 32 48 W 11995 81 N 33 59 W 12077 66 N 36 1 W 12159 58 N 36 10 W 12212 87 1 36 1 13 2 O9 2 O6 1 71 0 O0 8109 47 N 8624 45 W11838 27 N 46 46 W 8179 53 N 8672 73 W11921 45 N 46 41 W 8249 49 N 8719 46 W12003 46 N 46 35 W 8319 24 N 8765 28 W12084 70 N 46 30 W 8387 35 N 8812 86 W12166 10 N 46 25 W 8430 91 N 8844 57 W12219 11 N 46 22 W COMPUTATION DATE: 21-FEB-93 PAGE 6 ARCO ALASKA, INC. NORTH PRUDHOE BaY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 20-FEB-g3 KELLY BUSHING ELEVATION: 52.50 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR C00RDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000.00 5958 0 O0 O0 999 O0 1988 O0 2908 O0 3644 O0 4132 O0 4582 O0 5O39 O0 5501 -52 50 20 946 35 1935 09 2855 61 3592 17 4079 84 4530 53 4987 35 5448 94 5906 0 0 TO 5 36 85 13 44 59 31 18 11 53 33 67 62 54 34 63 20 03 63 13 85 61 54 44 62 41 N 0 0 E N 22 59 W 24 n 50 22 W 166 N 47 25 W 547 N 46 19 W 1213 N 46 56 W 2085 N 48 46 W 2976 N 47 58 W 3864 N 46 8 W 4750 N 48 31W 5639 0 O0 45 O1 17 78 03 83 89 96 14 O. O0 1.28 2.47 1.59 2.21 0.41 0.79 0.42 O. 68 1.20 0 O0 N 25 135 396 846 1439 2048 2644 3249 3854 0 O0 E 51N 8 56 N 98 05 N 377 29 N 870 32 N 1510 46 N 2162 92 N 2822 78 N 3471 94 N 4122 0 O0 N 0 0 E 93 W 27 93 W 167 65 W 547 50 W 1214 03 W 2086 47 W 2978 47 W 3868 08 W 4754 41W 5644 03 N 19 17 W 82 N 36 7 W 24 N 43 38 W O8 N 45 48 W 10 N 46 22 W 67 N 46 33 W 06 N 46 52 W 94 N 46 53 W 01 N 46 55 W 10000.00 6422 O0 6369.50 62 42 11000 O0 6895 04 6842.54 61 21 12000 O0 7393 25 7340.75 59 5 13000 O0 7879 31 7826.81 62 26 14000 O0 8327 99 8275.49 65 2 15000 O0 8755 52 8703.02 64 47 16000 O0 9193 29 9140.79 58 50 16465 O0 9446 94 9394.44 55 58 N 50 13 W 6523 38 N 48 19 W 7401 41 N 49 53 W 8265 85 N 47 34 W 9136 80 N 45 0 W 10030 O0 N 43 39 W 10933 85 N 34 37 W 11829 37 N 36 10 W 12212 87 1.11 0 6O 0 74 1 19 1 02 0 38 1 36 0 O0 4443 53 N 4784 95 W 6529 99 N 47 7 W 5019 09 N 5451 90 W 7410 43 N 47 22 W 5590 04 N 6104 14 W 8277 02 N 47 31 W 6161 88 N 6764 77 W 9150 45 N 47 40 W 6784 89 N 7405 10 W10043 42 N 47 30 W 7439 28 N 8028 76 W10945 49 N 47 11W 8109 47 N 8624 45 W11838 27 N 46 46 W 8430 91 N 8844 57 W12219 11 N 46 22 W COMPUTATION DATE' 21-FEB-93 PAGE 7 ARCO ALASKA, INC. NORTH PRUDHOE BaY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY- 20-FEB-93 KELLY BUSHING ELEVATION' 52.50 FT ENGINEER- D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 52 50 152 50 252 51 352 51 452 51 552 52 652 54 752 64 852 82 0 O0 52 50 152 50 252 50 352 50 452 50 552 50 652 50 752 50 852 50 -52.50 0.00 100.00 200.00 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 14 N 20 58 E 0 29 N 57 34 E 0 34 N 32 24 E 0 17 N 23 38 W 0 25 N 3 16 E 0 52 N 5 17 W 1 50 N 19 25 W 3 4 N 26 51W 3 50 N 27 21W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O3 -0 O1 -0 0 0 1 3 7 13 16 27 71 56 42 53 27 0 oo 0 54 0 51 0 44 0 62 0 18 0 40 0 74 1 o6 0 81 0 O0 N 0 04 N 0 46 N 1 12 N 1 68 N 2 25 N 3 41 N 5 53 N 9 52 N 14 86 N 0 O0 E 0 O0 E 0 48 E 1 37 E 1 32 E 1 27 E 1 24 E 0 74 E 1 06 W 3 82 W 0 oo N 0 0 E o 0 1 2 2 3 5 9 15 04 N 2 6 E 67 N 46 17 E 77 N 50 40 E 14 N 38 12 E 58 N 29 23 E 63 N 19 57 E 58 N 7 36 E 58 N 6 20 W 34 N 14 25 W 953 11 1053 1154 1254 1355 1456 1557 1658 1759 1861 952 50 58 1052 22 1152 94 1252 73 1352 63 1452 57 1552 61 1652 83 1752 28 1852 900 O0 50 1000 O0 50 1100 O0 50 1200 O0 5O 1300 O0 50 1400 50 1500 50 1600 50 1700 50 1800 4 52 6 4 6 45 7 1 7 24 O0 7 45 O0 7 55 O0 8 35 O0 9 10 O0 10 23 N 25 20 W N 22 4 W N 23 54 W N 28 15 W N 40 31W N 44 35 W N 44 37 W N 43 53 W N 42 9 W N 41 45 W 20 42 29 50 39 99 51 37 63 75 77 13 90 89 105 34 121 O1 138 08 1 O4 1 25 0 76 0 54 1 42 0 89 0 27 0 52 0 67 1 04 21 58 N 30 55 N 40 94 N 51 83 N 62 24 N 71 95 N 81 75 N 92 O8 N 103 57 N 116 35 N 7 18 W 11 15 20 27 36 46 56 67 78 O1W 32 41W 43 57 W 55 65 W 68 85 W 80 50 W 94 61W 108 27 W 123 63 W 140 22 74 N 18 24 W 47 N 19 49 W 75 N 20 37 W 76 N 21 39 W 10 N 23 57 W 84 N 27 7 W 05 N 29 38 W 09 N 31 35 W 50 N 33 0 W 43 N 34 3 W 1963 22 1952 50 1900 O0 12 20 2066 2169 2274 2380 2487 2597 2709 2821 18 2052 99 2152 72 2252 29 2352 48 2452 78 2552 03 2652 19 2752 50 2000 50 2100 50 2200 50 2300 50 2400 50 2500 50 2600 50 2700 O0 14 34 O0 16 37 O0 17 57 O0 19 31 O0 23 31 O0 25 44 O0 26 18 O0 27 40 2935 39 2852 50 2800 O0 30 3 N 49 21 W N 49 57 W N49 5W N49 2W N 47 41 W N 44 25 W N45 8W N 46 40 W N 45 38 W N 46 56 W 157 81 182 17 209 91 240 92 274 67 313 17 359 68 408 41 459 18 514 28 2 11 2 63 2 16 1 61 1 67 2 19 2 82 2 61 1 43 1 39 145 164 184 206 233 266 30O 335 130 26 N 96 N 111 10 N 132 48 N 156 90 N 181 60 N 209 72 N 241 37 N 277 61N 313 92 63 W 159 83 N 35 25 W 40 W 183 51W 210 02 W 241 34 W 275 10 W 313 76 W 359 04 W 408 61W 459 61 N 37 21W 92 N 38 55 W 61 N 40 13 W 12 N 41 14 W 52 N 41 5O W 98 N 42 11W 63 N 42 41W 33 N 43 4 W 373 66 N 353 50 W 514 38 N 43 25 W 3052 27 2952 50 2900 O0 32 17 3172 3298 3427 3560 3702 3853 4013 4197 4398 48 3052 13 3152 05 3252 32 3352 05 3452 59 3552 29 3652 50 3752 27 3852 50 3000 50 3100 50 3200 50 3300 5O 34OO 50 35OO 5O 3600 50 3700 50 3800 N 47 49 W O0 35 5 N 48 19 W 641 O0 38 51 N 44 59 W 717 O0 39 47 N 48 41W 798 O0 43 4'1 N 48 48 W 886 O0 47 6 N 48 10 W 986 O0 49 28 N 47 15 W 1100 O0 54 4 N 46 23 W 1224 O0 58 40 N 46 54 W 1379 O0 61 8 N 47 29 W 1552 574 68 23 21 51 27 44 11 47 O1 86 1 77 2 14 2 82 2 74 2 66 2 58 2 35 2 25 2 70 0 99 414 62 N 398 O0 W 574 73 N 43 50 W 459 511 567 625 691 768 853 959 1077 02 N 447 60 N 502 43 N 561 08 N 628 57 N 703 17 N 787 68 N 878 75 N 990 66 N 1118 76 W 641 65 W 717 82 W 798 36 W 886 61W 986 82 W 1100 24 W 1224 77 W 1379 82 W 1553 24 N 44 17 W 21 N 44 30 W 51 N 44 43 W 32 N 45 9 W 57 N 45 30 W 34 N 45 43 W 77 N 45 49 W 40 N 45 55 W 42 N 46 4 W COMPUTATION DATE' 21-FFR-93 PAGE 8 ARCO ALASKA, INC. NORTH PRUDHOE BaY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 20-FEB-93 KELLY BUSHING ELEVATION' 52.50 FT ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN iO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH PEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4610 7I 3952 50 3900 O0 62 25 4826 5044 5267 5489 5709 5932 6154 6374 6591 77 4052 77 4152 05 4252 43 4352 52 4452 38 4552 06 4652 25 4752 91 4852 50 4000 50 4100 50 4200 50 4300 50 4400 5O 4500 5O 4600 5O 47O0 50 4800 O0 62 7 O0 63 4 O0 63 19 O0 63 11 O0 62 49 O0 63 20 O0 62 47 O0 62 58 O0 62 8 N 47 21W 1740 06 N 47 10 W 1931 N 46 45 W 2124 N 46 35 W 2323 N 46 34 W 2521 N 46 46 W 2717 N 48 39 W 2916 N 48 31W 3113 N 47 52 W 3309 N 47 28 W 3502 36 89 29 79 74 56 89 66 7O 0 91 0 29 0 45 0 34 0 16 0 64 0 89 0 41 0 67 0 42 1204 60 N 1256 71 W 1740 80 N 46 13 W 1334 1466 1603 1739 1874 2008 2139 2269 2400 47 N 1397 60 N 1539 10 N 1683 72 N 1827 94 N 1969 61N 2117 16 N 2265 99 N 2411 18 N 2554 48 W 1932 13 W 2125 28 W 2324 45 W 2523 41W 2719 04 W 2918 70 W 3115 86 W 3312 78 W 3505 30 N 46 19 W 99 N 46 23 W 51 N 46 24 W 13 N 46 25 W 18 N 46 24 W 28 N 46 30 W 99 N 46 39 W 09 N 46 44 W 39 N 46 47 W 6808 10 4952 50 4900 O0 62 58 7028 7247 7467 7678 7895 8109 8325 8541 8763 65 5052 68 5152 63 5252 45 5352 28 5452 68 5552 59 5652 35 5752 85 5852 5O SO00 5O 5100 5O 5200 50 5300 50 5400 50 5500 50 5600 50 5700 50 5800 O0 62 51 O0 63 1 O0 62 22 O0 61 58 O0 62 20 O0 62 32 O0 62 24 O0 62 37 O0 63 36 N 47 37 W 3694 13 N 47 56 W 3890 N 47 25 W 4084 N 46 49 W 4280 N 46 26 W 4466 N 46 32 W 4658 N 47 55 W 4847 N 46 36 W 5038 N 46 41W 5230 N 47 31W 5428 39 96 66 15 38 89 99 03 65 0 68 0 45 0 54 0 62 0 92 0 68 1 13 0 63 0 74 0 98 2529 90 N 2695 89 W 3697 06 N 46 49 W 2662 2793 2926 3054 3185 3316 3445 3576 3712 03 N 2841 12 N 2985 49 N 3129 28 N 3263 80 N 3404 06 N 3541 30 N 3683 36 N 3822 81N 3966 43 W 3893 61W 4088 10 W 4284 70 W 4469 11W 4662 93 W 4851 05 W 5043 23 W 5234 75 W 5433 60 N 46 52 W 45 N 46 54 W 35 N 46 55 W 94 N 46 54 W 33 N 46 54 W 96 N 46 53 W 31 N 46 55 W 48 N 46 54 W 24 N 46 54 W 8985 95 5952 50 5900 O0 62 43 9204 9420 9635 9849 10066 10282 10494 10703 22 6052 10 6152 O0 6252 11 6352 49 6452 31 6552 16 6652 72 6752 50 6000 50 6100 50 6200 50 6300 50 6400 50 6500 50 6600 50 6700 O0 62 44 O0 62 12 O0 62 10 O0 62 27 O0 62 46 O0 62 18 O0 61 44 O0 61 13 10911 36 6852 50 6800 O0 61 18 N 48 33 W 5626 68 N 48 4 W 5820 28 N 47 29 W 6011 32 N 48 14 W 6201 12 N 49 5 W 6390 08 N 50 5 W 6582 17 N 49 36 W 6772 62 N 49 10 W 6958 71 N 48 47 W 7142 34 N 48 35 W 7323 83 1 26 0 31 0 36 0 69 0 62 0 40 0 88 0 58 0 99 0 63 3846 67 N 4113 06 W 5631 53 N 46 55 W 3975 4104 4231 4357 4481 4604 4726 4847 74 N 4257 57 N 4399 17 N 4541 63 N 4682 39 N 4830 83 N 4976 34 N 5118 43 N 5256 91W 5825 36 W 6016 31W 6206 21W 6396 31W 6588 40 W 6780 22 W 6966 97 W 7150 49 N 46.58 W 80 N 46 59 W 96 N 47 1W 25 N 47 3 W 99 N 47 9 W 04 N 47 13 W 67 N 47 17 W 76 N 47 19 W 4967 50 N 5393 72 W 7332 68 N 47 21 W 11119 43 6952 50 6900 O0 61 2 11323 11524 11723 11920 12118 12320 12531 12734 12942 66' 7052 55 7152 27 7252 74 7352 18 7452 30 7552 87 7652 84 7752 32 7852 50 7000 50 7100 50 7200 50 7300 50 7400 50 7500 50 7600 50 7700 50 7800 O0 60 16 O0 59 58 O0 59 23 O0 59 13 O0 60 9 O0 60 38 O0 61 24 O0 59 47 O0 62 6 N 47 49 W 7505 91 N 47 26 W 7683 N 48 40 W 7857 N 49 19 W 8028 N 50 11W 8198 N 49 4O W 8367 N 49 21W 8542 N 49 17 W 8728 N 48 42 W 8904 N 47 55 W 9085 75 64 75 18 67 67 4O 47 81 0 59 0 55 0 86 0 86 0 78 0 91 0 78 I 41 0 92 1 25 5089 07 N 5529 78 W 7515 12 N 47 23 W 5209 5325 5437 5546 5656 5770 5891 6007 6127 47 N 5660 62 N 5790 53 N 5921 37 N 6052 03 N 6182 27 N 6315 34 N 6457 10 N 6590 52 N 6726 97 W 7693 85 W 7867 09 W 8039 04 W 8209 24 W 8379 66 W 8554 43 W 8741 82 W 8917 98 W 9099 19 N 47 23 W 41 N 47 24 W 03 N 47 26 W 11 N 47 30 W 19 N 47 33 W 74 N 47 35 W 07 N 47 37 W 63 N 47 39 W 38 N 47 40 W COMPUTATION DATE- 21-FEB-93 PAGE 9 ARCO ALASKA, INC. DATE OF SURVEY' 20-FEB-93 NORTH PRUDHOE BaY STATE #3 KELLY BUSHINg ELEVATION- 52.50 FT PRUDHOE BaY NORTH SLOPE, ALASKA ENGINEER- D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEg MIN DEG MIN FEET DEg/iO0 FEET FEET FEET DEG MIN 13159 64 7952 50 7900.00 62 54 13378 13593 13820 14057 14289 14522 14756 14992 15225 65 8052 98 8152 19 8252 83 8352 50 8452 19 8552 81 8652 91 8752 41 8852 50 8000.00 62 30 50 8100.00 62 44 50 8200.00 65, 9 50 8300,00 64 34 50 8400.00 64 54 50 8500.00 64 26 50 8600.00 65 0 50 8700.00 64 51 50 8800.00 64 25 15460 89 8952 50 8900.00 66 26 15706 91 9052 50 9000.00 65 3 15920 15 9152 50 9100.00 59 46 16112 60 9252 50 9200.00 57 39 16295 58 9352 50 9300.00 56 23 16465 O0 9446 94 9394.44 55 58 N 46 10 W 9278 55 N 44 42 W 9473 N 46 25 W 9664 N 46 0 W 9866 N 44 34 W 10082 N 43 32 W 10291 N 43 32 W 10501 N 43 34 W 10713 N 43 37 W 10927 N 43 46 W 11137 37 05 84 37 32 39 59 44 31 N 43 36 W 11350 47 N 41 57 W 11575 19 N 35 10 W 11761 70 N 34 38 W 11923 68 N 33 53 W 12074 04 N 36 10 W 12212 87 0 51 0 73 1 37 1 11 0 90 0 99 0 42 0 69 0 37 0 54 1 82 2 6O 1 98 1 11 2 O8 0 O0 6258 81 N 6868 36 W 9292 31 N 47 40 W 6395 6530 6670 6822 6973 7125 7279 7434 7586 72 N 7006 78 N 7141 85 N 7288 07 N 7441 17 N 7586 70 N 7730 76 N 7876 63 N 8024 20 N 8169 99 W 9487 60 W 9677 38 W 9880 99 W10095 35 W10304 85 W10513 83 W10725 33 W10939 53 Wl1148 O0 N 47 37 W 48 N 47 33 W 32 N 47 32 W 73 N 47 29 W 26 N 47 25 W 88 N 47 20 W 64 N 47 15 W 09 N 47 11W 61 N 47 7 W 7740 28 N 8316 86 Wl1361 43 N 47 3 W 7903 05 N 8471 83 W11585 77 N 46 59 W 8053 15 N 8585 21 Wl1771 11 N 46 50 W 8188 33 N 8678 78 Wl1931 89 N 46 40 W 8316 16 N 8763 26 W12081 11 N 46 30 W 8430 91N 8844 57 W12219 11 N 46 22 W COMPUTATION DATE' 21-FEB-93 ARCO ALASKA, INC. NORTH PRUDHOE BaY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA IFFFERPOLATED VAL_UES FOR CHOSEN HORIZONS MARKER LAST READING GCT DRILLERS ID PAGE 10 DATE OF SURVEY: 20-FEB-93 KELLY BUSHING ELEVATION: 52.50 FT ENGINEER: D. WARNER SURFACE LOCATION = 71~ FSL A 1791' FWL, SEC25 T12N R14E MeASUReD DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 15750.25 9071.08 9018.58 7932.51 N 8497.62 W 16465.00 9446.94 9394.44 8430.91 N 8844.57 W COMPUTATION DATE: 21-FEB-93 PAGE 11 ARCO ALASKA, INC, NORTH PRUDHOE BAY STATE #3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 20-FEB-93 KELLY BUSHING ELEVATION: 52.50 FI' ENGINEER: D. WARNER ************ STRATIGRAPHIC SUMMARY ************ MARKER LAST READING GCT DRILLERS TD SURFACE LOCATION = 71' FSL & 1791' FWL, SEC2$ T12N rl4E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 15750.25 9071.08 9018.58 7932.51N 8497.62 W 16465.00 9446.94 9394.44 8430.91N 8844.57 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 16465.00 9446.94 9394.44 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 12219.11 N 46 22 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIE, n PRUDHOE BAY w~t.t. NORTH PRUDHOE BAY STATE #3 COUNTRY USA RUN 1 mvr; LO~a-'.~ 20 - FEB - 93 REFERENCE 93066 WELL' NORTH PRUDHOE BAY STATE #3 (71' FSL, 1791' FWL, SEC 25, T12N, R14E) HORIZONTAL PROJECTION · _ 12000 1OOOO HELL' (7'!' NORTH PRUDHOE BAY STATE FSL, 1791' FWL, SEC 25, T12N, R14E) .~. ~ERTICAL PROJECTION . --~ .')C O ... .... ]~]'!][]]['~]'(]iii!][]!];'~i ...... :]' - '.. . :][](](](]!] ~.~?"~"("~"~ ..... :'"[ ......... ~"~"[]:"i(i'!]~'i[]~ .... i...!]:.i:.ii!] il ......... ' FINAL WELL REPORT ARCO ALASKA INC NORTH PRUDHOE BAY STATE #3 NORTH SLOPE, ALASKA JANUARY 11, 1993 TO FEBRUARY 01, 1993 THE INFORr4ATION, INTERPRETATIONS, RECOI~IENDATIONS, OR OPINIONS CONTAINED HEREIN ARE ADVISORY ONLY AND MAY BE REJECTED. CONSULTANT DOES NOT WARRANT THEIR ACCURACY OR CORRECTNESS. NOTHING CONTAINED HEREIN SHALL BE DEEMED TO BE INCONSISTENT WITH, NOR EXPAND, MODIFY OR ALTER CONSULTANT'S OBLIGATION OF PERFORMzANCE AS PROVIDED FOR IN A WRITTEN AGREEI~ENT BETWEEN THE PARTIES, OR IF NONE, IN CONSULTANT'S MOST RECENT PRICE LIST. EXPLORATION LOGGING OF USA, INC. APPROVED BY: LARRY SHIELDS TABLE OF CONTENTS PAGE INTRODUCTION ............................................ SUMMARY OF DATA ......................................... METHODS OF: ............................................. 3 MUDLOG ............................................ 3 DRILL DATA ACQUISITION ............................ 3 COMMUNICATIONS .................................... 3 SAMPLING PROCEDURES AND INTERVALS ................. 3 FORMATION EVALUATION WEST SAK LITHOLOGY ......................................... 4 DRILL AND GAS DATA ................................ 4 OIL AND GAS SHOWS ................................. 5 HUE SHALES (K10,K5, STt~P ISLAND, HRZ,) LITHOLOGY ......................................... 6 DRILL AND GAS DATA ................................ 6 OIL AND GAS SHOWS ................................. 6 KINGAK LITHOLOGY ......................................... 7 DRILL AND GAS DATA ................................ ? OIL AND GAS SHOWS ................................. ? SAG RIVER, SIRTBLICK, SADLEROCHIT LITHOLOGY ......................................... 8 DRILL AND GAS DATA ................................ 8 OIL AND GAS SHOWS ................................. 8 APPENDIX I · II, III. IV. V. SAMPLE DISTRIBUTION SHOW REPORTS BIT RECORD DRILLING RECORD INTEGRATED FORMATION LOG (MI)). INTEGRATED FORMATION LOG (TVD). DRILLING DATA LOG (MI)). PRESSURE DATA LOG (TVD). INTRODUCTION THE "NORTH PRUDHOE BAY STATE # 3" WELL IS LOCATED ON THE WEST BEACH PAD, APPROXII~TELY 11 MILES NORTH WEST OF PRUDHOE BAY, ALASKA. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 70' FSL & 3490' FEL, IN SECTION 25, TlZN, R14E [~IAT MERIDIAN. PROPOSED BOTTOM HOLE COORDINATES WERE: 3530' FSL & 1523' FEL, IN SECTION 22, T12N, R14E UMIAT MERIDIAN. THE MAIN OBJECTIVE OF THIS WELL WAS TO TEST THE MID - LOWER TRIASSIC IVISHAK FORMATION, THE UPPER I~BER OF THE SADLEROCHIT GROUP, AT A PROJECTED DEPTH OF 9050' SUB SEA TRUE VERTICAL; THROUGH, ELECTRIC LOG ANALYSIS AND THE RECOVERY OF SIDEWALL CORES UPON THE COMPLETION OF DRILLING. PROJECTED TARGET (IVISHAK FORMATION) C~)ORDINATES WERE: 2978' FSL & 980' FEL, IN SECTION 2Z, TlZN, R14E UM. THE PROPOSED TARGET WAS REACHED BY DRILLING A DEVIATED HOLE; THROUGH THE USE OF DIRECTIONAL DRILLING TOOLS AND TECHNIQUES, SUCH THAT THE PROPOSED BOTTOM HOLE LOCATION WOULD BE NORTHWEST AT' AN aZIMUTH OF 31§.§ DEGREES AND WITH A DEPARTURE OF 12Z§4', WITH RESPECT TO S%RFACE LOCATION. THE WELL PROGRA]~I WAS DESIGNED FOR THE KICk-OFF TO START AT ABOUT 500' I~D AND TO GRADUALLY BUILD ANGLE TO §1.55 DEGREES FROM TRUE VERTICAL AT ABOUT 3754' TRUE VERTICAL DEPTH (4~7' lqD) RKB. IT WAS PROPOSED TO HOLD THE ANGLE UNTIL FINAL WELL 7.D. WAS REACHED AT ABOUT 95Z2' TVD (1§435' MI)) RKB. THE WELL PROGRAbi ~S DESIGNED TO SET 9-5/8 INCH CASING, JUST BELOW THE KINGAK FORMATION IN THE LOWER JURASSIC - UPPER TRIASSIC SAG RIVER SANDSTONE, AND DRILL AHEAD TO FINAL WELL T.D. NO CORING WAS PLANNED FOR THIS WELL. THE PROJECTED STRATIGRAPHIC SEQUENCE PENETRATED BY THIS HOLE INCLUDED THE PERMAFROST, K-15, WEST SAK, K-10, STUMP ISLAND, K-5, HRZ, SAG RIVER, SHUBLIK, AND IVISHAK FORMATIONS WITH PROPOSED FINAL WELL T.D. IN THE LOWER TRIASSIC KAVIK FORMATION. -1- SUMMARY OF PERT I NENT DATA WELL NAME: API NUMBER: OPERATOR: PARTNERS: CONTRACTOR: LOCATION: TARGET: NORTH PRUDHOE BAY STATE #3 50-029-22322 ARCO ALASKA INC ARCO ALASKA AND EXXON POOL/ARCTIC ALASKA DRILLING POOL RIG #7 70' FSL, 3490' FEL SEC 25 TlZN, R14E t~IAT MERIDIAN 2978' FSL, 980' FEL SEC ZZ, TlZN, R15E t~IAT MERIDIAN ELEVATION: CASING: DATE SPUDDED: DATE TOTAL DEPTH REACHED: FINAL TOTAL DEPTH: CONVENTIONAL CORES: FORMATION TESTS: HYDROCARBON SHOWS: COMPANY GEOLOGISTS: EXLOG GEOLOGISTS: FINAL WELL STATUS: GROUND LEVEL 10' ABOVE SEA LEVEL RKB 52' ABOVE MEAN SEA LEVEL' 13.375" AT 4700' RKB 9.625" AT 14641' RKB JANUARY 2, 1993 FEBRUARY 01, 1993 16465' MD, 9458' TVD NONE NONE RUN AT THIS TIME SEE SHOW REPORTS - APPENDIX II, JIM GONSIEWSKI, ARCO ALASKA DAVE BOYER, ARCO ALASKA BEVERLY BURNS, ARCO ALASKA TOBY ARCHULETA, ARCO ALASKA DAVE FREEBURG, GARY HAMBURG BILL STEVENS, RALPH WlNKELMAN E-LOGS METHODS GEOLOGIC AND DRILLING DATA WAS COLLECTED AT THE WELLSITE USING EXLOG'S DRILL MONITOR SYSTEM (DMS). THE SYSTEM IS A COMPUTER BASED DATA COLLECTION UNIT, USED IN ACQUISITION, COMPILATION AND OUTPUT OF DATA. ADDITIONAL LITHOLOGIC AND HYDROCARBON EVALUATION WAS PROVIDED BY EXLOG'S ONSITE GEOLOGISTS. METHODS OF ANALYSIS USED FOR EVALUATION ARE PRESENTED IN EXLOG'S MANUAL "MUDLOGGING: PRINCIPLES AND INTERPRETATIONS" (MS-196). THE MUDLOG FORMAT WAS PREVIOUSLY ESTABLISHED ON A FORMER WEST BEACH WELL LOGGED BY EXLOG. DATA DISPLAYED ON THE LOG INCLUDES: LITHOLOGY, RATE OF PENETRATION, TOTAL GAS, CUTTINGS GAS, CHROMATOGRAPH DATA, RESISTIVITY AND GAMMA RAY DATA WAS IMPORTED FROM SPERRY SUN AT THE END OF EACH BIT RUN. TOTAL GAS, RATE OF PENETRATION, CUTTINGS GAS AND GAMMA RAY ARE PLOTTED LINEARLY, WHILE ALL OTHER PARAMETERS ARE PLOTTED LOGARITHMICALLY. LOGS WERE PLOTTED AS Z INCHES PER 100 FEET (1:600), WITH THE EXCEPTION OF THE PRESSURE DATA LOG (Z INCHES PER 500 FEET/l:3000). DRILL DATA DRILLING DATA MONITORED INCLUDED: RATE OF PENETRATION (ROP) USING THE BLOCK HEIGHT SYSTEM, ROTARY SPEED, HOOKLOAD, WEIGHT ON BIT, TORQUE (MINIM[~, MAXIMUM, AND AVERAGE), MUD FLOW IN AND OUT, MUD TEMPERATURE IN AND OUT, STANDPIPE PRESSURE, CASING PRESSURE, PUMP STROKES, AND ALL PITS WERE MONITORED. ALSO FOUR HZS STATIONS WERE MONITORED AT ALL TIMES. THIS DATA WAS PLOTTED ON THE LOGS AS WELL AS BEING DISPLAYED ON REMOTE TERMINALS. COI~UNICATION EXLOG PROVIDED ONSITE LOCATION REMOTE TERMINALS FOR THE DISPLAY OF ALL DRILLING PARAMETERS. AN EXPLOSION PROOF DRILL MONITOR (HADD) WAS PROVIDED FOR THE DRILLER ON THE RIG FLOOR. SAMPLING SAMPLES WERE COLLECTED AS PER THE DIRECTIONS RECEIVED FROM STEVE REUSING IN THE ARCO ALASKA OFFICES. TWO WET AND FIVE DRY SAMPLES WERE COLLECTED. 10200' - 148§O'MD 14850' - 15250' 15250' - TD 30 FOOT SAMPLE INTERVALS ZO FOOT SAMPLE INTERVALS 10 FOOT SAMPLE INTERVALS ALL SAMPLES WERE SHIPPED TO THE BAYVIEW GEOLOGIC FACILITY WAREHOUSE IN ANCHORAGE, IN CARE OF M.V. STANFORD. A COMPLETE LISTING OF SAMPLE SHIPMENTS CAN BE FOUND IN THE APPENDIX. -3- FORMATION EVALUATION COMMENCED LOGGING AT 17:22 HOURS, JANUARY 11, 1993 AT 6523 FEET TVD (10ZO0 FEET MD) IN THE LATE CRETACEOUS. ALL DEPTHS, UNLESS OTHERWISE SPECIFIED, ARE FROM RKB. WHICH WAS 52 FEET ABOVE SEA LEVEL. ALL FORMATION TOPS ARE UNCONFIRMED AND APPROXIMATE, AND ARE SUBJECT TO CHANGE AT A LATER DATE. WEST SAK INTERVAL LITHOLOGY THE WEST SAK 6531' - 8037' TVD (10215 - 13325' MD). THE WEST SAK IN THE NORTH PRUDHOE BAY STATE #3 WELL CONSISTED OF TWO DIFFERENT ZONES. THE FIRST, OR UPPER, ZONE ENCOUNTERED WAS FROM 6531' TO 7350' TVD (lOZ15' - 11900' MD). THIS ZONE CONTAINED A HIGH PERCENTAGE OF SANDSTONE, UNCONSOLIDATED FINE TO COARSE GRAINED SAND AND CONGLOMERATE, WITH ABUNDANT SILT AND CLAY MATRIX. THE SANDSTONE WAS VERY FINE TO FINE GRAINED QUARTZITIC SANDSTONE, WITH CObIMON CALCITE CEMENT. UNCONSOLIDATED COARSE GRAINED QUARTZ SAND AND LiTHIC PEBBLES WERE ALSO VERY ABUNDANT IN THIS ZONE. ABUNDANT SILT AND CLAY WERE ALSO PRESENT PRESI~ABLY AS THE MATRIX FOR THE UNCONSOLIDATED SAND AND CONGLOMERATE. COMMON TO ABUNDANT SILTSTONE, AND MUDSTONES WERE ALSO OBSERVED. TRACES OF PYRITE AND VOLCANIC TUFF WERE PRESENT THROUGHOUT THIS INTERVAL. FROM 3500' TO 8037' TVD (11900' - 13325' biD) THE WEST SAK WAS COMPOSED OF A MEDII~ GRAY TO GRAY BROWN CARBONACEOUS SILTSTONE AND SHALE. COMMON SANDY SILTSTONE AND SANDY SHALES WERE ALSO OBSERVED. WITH OCCASIONAL SAND AND SANDSTONE INTERBEDS. UNCONSOLIDATED LITHIC FRAGMENTS, LOOSE QUARTZ GRAINS AND BROKEN CONGLOMERATE PEBBLES WERE PRESENT THROUGHOUT THE LOWER ZONE OF THE WEST SAK, BUT NOT TO THE DEGREE SEEN IN THE UPPER INTERVAL. TRACE AMOUNTS OF PYRITE AND VOLCANIC TUFF WERE COMMON THROUGHOUT THIS INTERVAL. DRILL RATE AND GAS DATA THE DRILL RATES IN THE WEST SAK RANGED FROM 30 TO 450 FEET PER HOUR. IN THE UPPER ZONE (SAND/CONGLOMERATE), THE RATES RANGED FROM 48 TO 450 FEET PER HOUR WITH AN AVERAGE RATE OF PENETRATION OF APPROXIMATELY 75 FEET PER HOUR. IN THE LOWER ZONE, CHARACTERIZED BY SILTSTONE AND SHALE, THE DRILL RATES RANGED FROM 30 TO 150 FEET PER HOUR WITH AN AVERAGE RATE OF PENETRATION OF APPROXIMATELY 45 FEET PER HOUR IN THE LOWER WEST SAK. LITTLE SLIDING (NON- ROTARY DRILLING) WAS DONE IN THE WEST SAK IN ORDER TO OBTAIN OR KEEP THE PROPER HOLE INCLINATION AND AZIMUTH. AREAS WHERE SLIDING WAS CARRIED OUT EXHIBITED MORE IRREGULAR DRILL RATES, BUT THE AVERAGE DRILL RATES WERE NOT SIGNIFICANTLY DIFFERENT FROM THOSE PREVIOUSLY MENTIONED. DITCH GAS RANGED FROM 5 TO 885 UNITS IN THE WEST SAK, AND AVERAGED 75 UNITS. HIGH VALUES FOR C1 THROUGH C4 WERE RECORDED THROUGHOUT MUCH OF THE SECTION, C1 THROUGH C4 BECAME PRESENT AND REMAINED PRESENT FROM 10850' TO THE BASE OF THIS SECTION. OIL AND GAS SHOWS TRACES OF VERY DULL YELLOW TO GREEN SAMPLE FLUORESCENCE AND A VERY SLOW STREAMING DULL YELLOW CUT FLUORESCENCE WAS PRESENT THROUGHOUT MOST OF THE WEST SAK. THERE WAS OIL STAINING PRESENT FROM 10500' MD TO THE BASE OF THIS SECTION IN VARYING DEGREES, AS THIS BEING A VERY SILTY SECTION THE POROSITY WAS VERY POOR AND NO SHOW WAS RATED DUE TO THE NON-RESERVIOR ROCK PRESENT THE SILTSTONE, IN THE LOWER WEST SAK (12400'MD), EXHIBITED A BRIGHTER SAMPLE FLUORESCENCE AND A MILKY YELLOW TO BLUE WHITE CUT FLUORESCENCE ALONG WITH AN INCREASE IN THE BACKGROUND GAS TO THE BASE OF THE SECTION. NO VISIBLE CUT WAS SEEN IN THIS INTERVAL, POSSIBLY INDICATING A CONDENSATE OIL OR GAS CAP SHOW. NO SHOW REPORTS WERE DONE DUE TO THE LACK OF SHOW OR RESERVOIR ROCK PRESENT. -5- HUE SHALE SECTION (K-10, STI~P ISLAND, K5, HRZ) LITHOLOGY THE HUE SHALE CONTAINING THE K-lO, STI~P ISLAND K-5, AND HRZ WAS ENCOUNTERED AT APPROXIMATELY 8037' TVD (13325' MD) AND CONTINUED TO THE KINGAK SHALE AT 8326' TVD (13974' MD). THE TOP OF THE K-lO WAS VERY SILTY BUT HAD BEGUN TO TURN TO SHALE BY 8100' TVD, THE SHALES WERE PREDOMINATELY MEDIt~ TO DARK GRAY, AND WERE SILTY TO VERY SILTY, WITH AN ABUNDANCE OF MICRO CARBONACEOUS PARTICLES. FOLLOWED BY THE APPEARANCE OF DARK GRAY TO BLACK OCCASSIONALLY FISSILE AND NON CALCAREOUS SHALE. THE SHALES WERE ACCOMPANIED BY THE PRESENCE OF DARK GRAY TO GRAY BROWN OCCASSIONALLY PLATEY SILTSONES. AT 8135' TVD, THE CUTTINGS BECAME VERY SILTY TO A VERY SILTY VERY FINE GRAINED SAND, PROBABLY THE ST[~P ISLAND MEMBER, BUT ONLY 5 - 10 FOOT APPEARED TO BE PRESENT, WITH ONLY A SLIGHT INCREASE IN GAS, UNTIL 8170' TVD, WHERE A POSSIBLE SECOND SAND TO THIS MEMBER WAS CUT, AGAIN IT WAS ONLY 10 FOOT THICK, BUT SLIGHTLY LESS SILTY, A SLIGHT INCREASE IN OIL STAINING OCCURED AND AN IMPROVED CUT WAS SEEN. DARK GRAY TO BLACK SUB FISSILE SHALES AND DARK GRAY TO DARK GRAY BROWN SlLTSTONES PERSISTED THROUGHOUT THE REST OF THE SECTION. THE HRZ ZONE WAS ENCOUNTERED AT'APPROXIMATELY 8315' TVD (13950'ND), AND WAS ONLY 10 TO 15 FOOT THICK. THE HRZ WAS CHARACTERIZED BY VERY FISSILE DARK GRAY SHALES (PAPER SHALE) WITH MINOR SILTSTONE INTERVALS. BOTH THE K-10 AND HRZ ZONES ARE VERY ORGANIC RICH SHALES WITH COMMON CARBONACEOUS SPECKS OR LAMINAE. AN ABUNDANCE OF PYRITE WAS PRESENT. CUTTINGS SAMPLES ARE SOMEWHAT DISTINCTIVE, A MORE EXACT METHOD FOR DETERMINING THE TOPS OF THE K-10 AND HRZ IS BY USING THE MWD GAMMA RAY. DRILL RATE AND GAS DATA THE DRILL RATES RANGED FROM 25 TO 100 FEET PER HOUR IN THIS HOLE SECTION, WITH AN AVERAGE RATE OF PENETRATION OF 45 FEET PER HOUR. DITCH GAS RANGED FROM 45 TO 866 UNITS, AND AVERAGED 75 UNITS. C1 THROUGH C4 WERE PRESENT THROUGHOUT THIS INTERVAL. AN INCREASE IN THE HEAVIER GASES (C3+) CAN BE ATTRIBUTED TO THE HIGH ORGANIC CONTENT OF THESE SHALES. HIGH CUTTINGS / BLENDER GAS WAS ALSO DETECTED (16 - 85 UNITS), SUBSTANTIATING THE HIGH ORGANIC CONTENT, YET LOW PERMEABILITY, OF THESE SHALES. OIL AND GAS SHOWS DULL GOLD TO GREEN SAMPLE FLUORESCENCE AND MILKY YELLOW SOLVENT CUT WERE PRESENT THROUGHOUT MOST OF THIS SECTION. A SHOW RATING OF POOR WAS GIVEN THE INTERVAL DUE TO THE POOR PERMEABILITY AND RESERVOIR CHARACTER OF THE ROCK, NO SHOW REPORT WAS WRITTEN FOR THIS INTERVAL. -6- KINGAK FORMATION LITHOLOGY THE KINGAK FORMATION WAS ENCOUNTERED AT APPROXIMATELY 8326' TVD (13974' MI)) AND CONTINUED DOWN TO ABOUT 9205' TVD (16003' MI)). THE KINGAK WAS CHARACTERIZED BY GRAY TO DARK GRAY SHALE AND SILTSTONE. LOCAL BROWNISH HUES WERE PRESENT ON THE CUTTINGS. TRACES OF FINE SAND WERE PRESENT WITH OCCASSIONAL LOOSE ROUNDED AND FRACTURED COARSE QUARTZ, POSSIBLE CHERT GRAINS. TRACES OF TUFF, SOME BENTONITIC, APPEARED LOCALLY IN THE SECTION. THE TUFF WAS LIGHT GRAY TO WHITE TO TAN BROWN TO ORANGE IN COLOR. FRIABLE AND SILTY VERY FINE GRAIN SANDSTONE APPEARED LOCALLY IN THE SECTION. THE SANDSTONE WAS TIGHT, SILTY WITH A CLAY MATRIX, AND PYRITIC. TRACES OF GLAUCONITE WERE PRESENT, BUT MAY HAVE BEEN FROM UPHOLE. SHALE, ARGILLACEOUS SILTS, AND SILTSTONE WERE PRESENT IN VARYING AMOUNTS. THE LITHOLOGY TENDED TO VARY BETWEEN PREDOMINATE SHALES TO PREDOMINATE SILTS DOWN THE SECTION TO ABOUT 8925' TVD (153§§' MD) WHERE SILTSTONE WAS DOMINATE TO THE BOTTOM OF THE SECTION. THE SECTION WAS DRILLED WITH A PDC BIT AND THE CUTTINGS WERE CHARACTERIZED BY SPLINTERY TO SUB-PLATEY SHALES AND SUB-PLATEY SILTSTONES. FISSILE SHALE WAS PRESENT LOCALLY IN THE TOP HALF OF THE SECTION. THE SHALES AND SILTS WERE CARBONACEOUS WITH LOCAL CARBONACEOUS LAMINATIONS AND LOCAL FREE CARBONACEOUS MATERIAL IN THE SAMPLES. THE SHALES AND SILTS WERE VARIABLY MICRO-MICACEOUS. DRILL RATE AND GAS DATA DRILL RATES VARIED FROM 10 TO 160 FEET PER HOUR; THROUGHOUT THE SECTION, WITH AN AVERAGE RATE OF 45 FEET PER HO[~ FOR THE SECTION WHEN THE PDC BIT WAS USED. BIT WEIGHTS OF 4000 TO 9000 POUNDS WERE USED ON THE PI){] BIT, AND 25000 TO ~§000 POUNDS ON THE STANDARD CONE BITS. DITCH GAS RANGED FROM 2§ TO 180 UNITS AND AVERAGED ATABOUT 50 UNITS. METHANE, ETHANE, PROPANE, AND BUTANE WAS RECORDED, AT RELATIVELY CONSISTENT VALUES OVER THE ENTIRE INTERVAL, Bt~ANE DID DROP OUT TOWARDS THE END OF THE SECTION WITH THE REDUCTION IN TOTAL GAS. AFTER CASING WAS SET AT 14641', AND THE USE OF SFT DRILLING FLUID WAS USED TO TRY AND MOVE CASING TO TD, THE MUD BECAME CONTAMINATED WITH HEAVY GASES, WHICH LEFT THE BACKGROUND RUNNING 80 TO 90 UNITS HIGI~. OIL AND GAS SHOWS THE KINGAK SECTION WAS CHARACTERIZED BY NONE TO TRACES OF I~lLL GOLD TO DULL YELLOW GREEN SAMPLE FLUORESCENCE AND NONE TO RARE WEAK LIGHT BLUE AND BLUE WHITE STREAMING FLUORESCENT CUT. NO VISIBLE SOLVENT CUTS OR RESIDUAL STAIN WAS OBSERVED OVER THE KINGAK INTERVAL. THE WEAK STREAMING CUTS MAY BE ATTRIBUTED TO THE HIGH CARBONACEOUS CONTENT OF THIS SECTION. SADLEROCHIT GROUP (SAG RIVER, SHUBLIK, SADLEROCHIT) L I THOLOGY THE SAG RIVER SECTION CAME IN AT 16003' MD, 9206' TVD, THIS SECTION WAS A VERY SILTY FINE GRAINED SANDSTONE WITH CALCAREOUS CEMENTING. THE ENTIRE SECTION WAS GRADATIONAL BETWEEN A SILTSTONE AND A VERY FINE GRAINED SAND. ABUNDANT DISSEMINATED PYRITE WAS PRESENT, AND A SLIGHT TRACE OF GLAUCONITE WAS ALSO PRESENT. THE SHUBLICK SECTION CAME IN AT 16045' MD, 9226' TVD. THIS SECTION WAS PRIMARILY A MEDIUM TO DARK BROWN LIMESTONE, WITH A FEW SILTY SAND SECTIONS. THE LINESTONES WERE PREDOMINATELY VERY FINE TO OCCASIONALY MICRO CRYSTALINE. THERE WAS ABUNDANT SAND AND SILT IN THE LIMESTONE, WITH PYRITE AND A TRACE OF GLAUCONITE NODULES. THERE WERE NO SHOWS IN THIS SECTION, THERE WAS MINERAL FLOURESENCE THROUGH OUT. THE SADLEROCHIT SANDS CAME IN AT 16185' MD, 9300' TVD. THIS SECTION WAS MADE UP PRIMARILY OF A CHERT/SAND CONGLOMERATE, BUT WAS PRIMARILY CHERT IN ITS MAKEUP, UNTIL THE LAST 50 FEET MD OF THE SECTION WERE IT BECAME A SILTSTONE. THE CHERT CONGLOMERATE WAS MEDII~ TO DARK GRAY, BROWN, TRANSLUCENT, FINE TO VERY COARSE, THE COARSE MATERIAL APPEARED TO BE FRACTURED CHERT PEBBLE MATERIAL. THE SECTION WAS PREDOMINATELY UNCONSOLIDATED, MODERATE POROSITY, WITH A SCATTERED DULL GREEN - GOLD SAMPLE FLOURESENCE, AND OCCASIONALLY A DARK BROWN OIL STAINING. CUT FLOURESENCE RANGED FROM NON TO A MODERATE MILKY GREEN - GOLD STREAMING CUT, AND OCCASIONALLY LEFT A VERY WEAK PALE STRAW VISUAL CUT. SEE SHOW REPORT IN APPENDIX. THERE WAS ALSO A FLOOD OF WHITE TO LIGHT GRAY TRIPOLITIC CHERT IN THE TOP 20 FEET OF THE SECTION. DRILL AND GAS DATA THE DRILL RATES IN THIS SECTION RANGED FROM 8 TO 200 FEET PER HOUR, WITH AN AVERAGE PENETRATION RATE OF 13 FEET PER HOUR.TVD (15511' - 15841' MD). THE GAS RANGED FROM 80 TO 165 UNITS, APPROXIAMATELY 70 TO 100 UNITS WAS DUE TO CONTAMINATION IN THE MUD FROM SFT DRILLING FLUIDS USED TO TRY AND UNSTICK THE 9 5/8" CASING. SEE APPENDIX FOR SHOW REPORT OIL AND GAS SHOWS THE SFT DRILLING FLUID USED DURING THE SETTING OF THE 9 5/8"CASING, THIS MADE SHOW EVALUATION MORE DIFFICULT. THE ONLY APPEARED TO BE SCATTERED FLOURESENCE IN THE SAMPLE, AND AT BEST THERE WAS A MODERATE STREAMING MILKY YELLOW - GREEN CUT IN THE SADLEROCHIT SAND SECTION, THERE WERE NO OBVIOUS GAS SHOWS. THE REASON FOR THE LACK OF SHOWS MAY BE THE ~JD WEIGHT MAY HAVE BEEN TO HIGH AND FLUSHED THE FORMATION OF HYDROCARBONS, BUT THEN THERE WAS NO GAS. THIS FORMATION WAS GIVEN A POOR RATING DUE TO THE SHOW QUALITY, SEE APPENDIX FOR SHOW REPORT. -8- APPENDIX I. SAMPLE DISTRIBUTION SAMPLE SHIPMENT FROM NORTH PRUDHOE BAY STATE UNIT 242, POOL RIG 7 01/17/93 WET SAMPLES SETS A, B BOX NO. W1A, WlB WZA, WZB W3A, W3B INTERVAL 10200'-11070' 11070'-12330' 12330'-13590' TOTAL 6 BOXES WET SAMPLES DRY SAMPLES SETS A, B, C, D, E(STATE OF AK SET) BOX NO. (SHIPPING) D1 INTERVAL(CARD BOXES A,B,C,D 10200'-11970' E 10200'-11970' E 11970'-13230' TOTAL 1 BOX(S) DRY SAMPLES TOTAL 7 BOXES SHIPPED TO: ARCO ALASKA INC. 619 SHIP CREEK AVE. SUITE 100 ANCHORAGE, AK 99501 ATTEN: MARTIN SANFORD (907) 265-6340 FIELD REQUISITION - MATERIALS, TOOLS, AND EQUIPMENT NO. 98256 CHARGE CDDE 730188 (NORTH PRUDHOE BAY STATE #3, LES PEAK-CO. MAN) DELIVERED TO "C" PAD 01/17/93 SHIPPED ON FLIGHT 5132 01/17/93 PICKED UP SAMPLE SHIPMENT FROM P2-48, POINT McINTYRE UNIT 242, POOL RIG 7 01/22t~3 WET SAMPLES SETS A, B BOX NO. INTERVAL WlA, WlB 13590'-14790' W2A, WMB 14790~-15470' TOTAL 04 BOXES WET SAMPLES DRY SAMPLES SETS A, B, C, D, E(STATE OF AK SET) BOX NO. (SHIPPING) INTERVAL(CARD BOXES) D2 A,B,C,D 11970'-13830' D3 A,B,C,D 13830'-15370' E 13230'-14550' E 14550'-15370' TOTAL 2 BOXES DRY SAMPLES TOTAL 06 BOXES SHIPPED TO: ARCO ALASKA INC. 619 SHIP CREEK AVE. SUITE 100 ANCHORAGE, AK 99501 ATTEN: ~4ARTIN SANFORD (907) 265-6340 FIELD REQUISITION - [4ATERIALS, TOOLS, AND EQUIPMENT NO. CHARGE CODE 730188 (NORTH PRt~HOE BAY STATE #3, T. JOHNSON) DELIVERED TO "C" PAD 01/22/93 SHIPPED TO ANCHORAGE 01/24/93 FLIGHT 132 SAMPLE SHIPMENT FROM NORTH PRUDHOE BAY STATE #3, WEST BEACH UNIT Z42, POOL RIG ? 02/01/93 WET SAMPLES SETS A, B BOX NO. INTERVAL W6A, W6B 15470'-15830' W7A, W7B 15830'-16100' WSA, WSB 16100'-16 TOTAL 6 BOXES WET SAMPLES DRY SAMPLES SETS A, B, C, D, E(STATE OF AK SET) BOX NO. (SHIPPING) D4 INTERVAL(CARD BOXES) A,B,C,D 15370'-15980' E 14550'-15370' E 15370'-158~0' D5 A,B,C,D 15980'-16465' E 15820'-16~30' E 16Z30'-16465' TOTAL 2 BOXES DRY SAMPLES SAMPLEX TRAYS 10200'-16465' TOTAL 1 BOX TOTAL 9 BOXES SHIPPED TO: ARCO ALASKA INC.. 619 SHIP CREEK AVE, ANCHORAGE, AK 99501 ATTEN: MARTIN SANFORD (907) 265-6340 FIELD REQUISITION - IqATERIALS, TOOLS, AND EQUIPlqENT NO. CHARGE CODE 730-188 (NORTH PEUDHOE BAY STATE #3, L. PEAK) DELIVERED TO "C" PAD 02/01/93 SHIPPED ON FLIGHT 32 02/02/93 APPENDIX II. SHOW REPORTS DATE: 30 JAN 93 TIME: OIL COMPANY: ARCO ALASKA INC. SHOW REPORT # 1 WELL#: N. PRUDHOE BAY STATE #3 SHOW INTERVAL: LOC, ATION: WEST BEACH NORTH SLOPE, ALASKA 16185' TO 16465' (MD) 9300' TO 9458' (TVD) BIT SIZE: 8.5" BIT TYPE: MF2DL (STC) HOURS: 40 FEET: 544 MUD WEIGHT: 10.5 ppg VISCOSITY: 44 FI LTRATE: 4.0 EST. PORE PRES: 9.8 WOB:30-35 klb RPM: 110 I~IMP PR: 3050 ppg P[~P SPM: 160 LOGGING COND: GOOD BEFORE ,. DURING AFTER TOT ROP GAS ft/hr units 8-10 125 25-35 168 lO-I4: C1 ppm 1700 2760 1500 C2 C3 ppm ppm 350 125 485 148 345 121 I OIL IN ~]D: SFT CONTAMINATION IN MUD FLUOR: MLKY BLUE - GREEN UNWASHED CUT FLUOR: DULL GOLD - GREEN WASHED CUT FLUOR: GREEN - GOLD STAIN: OC, C. DARK BROWN C4 ppm 21/69 - z4/?~ 20166 ! ! C5 :CHL ppml ppm LITHOLOGY 40% LIMESTONE 40% SILTSTONE 20% SHALE 50% CHERT CONGLOMERATE 30% FINE TO COARSE SAND 20% SILT 30% CHERT 40% SAND 30% SILTSTONE SOLVENT CUT FLUOR: WK - MOD MILKY BLUE GREEN YELLOW INTENSITY: MODERATE AT BEST TYPE & SPEED: SLOW STREAMING NAT COLOR & RESIDUE: OCC VERY WEAK PALE STRAW VISUAL POROSITY: POOR CUTTINGS DESCRIPTION: SD/CHT: MEDIL~ TO DARK GRAY, LT BROWN, CLEAR, FROSTED, WHITE, VERY TO COARSE GRAINED, PRED. COARSE, ANGULAR TO SUB ROUNDED, PRED. UNCONSOLIDATED, OCC VERY WELL CEMENTED SS, SILIC, MOD TO VERY SILTY, ARGILLACEOUS, NON CALCAREOUS, MICRO CARBONACEOUS, TRACE PYRITE, OCC DARK BROWN OIL STAINING, SCATTERED DULL GREEN TO GOLD SAMPLE FLOURESENCE, NON - WEAK MILKY GREEN TO MILKY YELLOW CUT FLOURESENCE, SLOW STREAMING CUT, RARE WEAK PALE STRAW VISUAL CUT, NO CUT RESIDUAL. POSSIBLE A CHERT CONGLOMERATE. COMMENTS: MUD CONTAMINATED WITH SFT DRILLING FLUID. OIL POSSIBLY FLUSHED FROM CUTTINGS AND FORMATION BY HIGHER MUD WEIGHTS. RATING: POOR LOGGING GEOLOGIST: FREEBURG, STEVENS, WINKLEMAN · ~PPENDIX I I Io BIT RECORD t ; ! ,' ,' ,' ,'COl)g', SI~E ', DE,II ', FT, ,ili£8', ~P ',llO00,' ',PRgS~:' ,' UO~D ..... ~ ..... ~ ........ ~ .... . ..... $ ........ ~ ...... ~ ......... ~ ......... ~ ....... ~ ..... + ....... $ ..... + ..... + ...... ~ ......... ~ ...................... ..... ~ ..... $ ........ ~ .......... ~ ........ ~ ...... ~ ......... ~ ......... ~ ....... ~ ..... ~ ....... ~ ..... ~ ..... ~ ...... $ ......... ~ ...................... ' ~ S~CgR ~, NFDS~C, 16,00 , , , ,YFA-,80~8, I~6] ~4 ' ?,0 ~, 66 ~ ',I0-40',~0/80[ ~00 ~ 181/798 ..... ~ ..... ~ ........ + .......... % ........ ~ ...... + ......... + ......... ~ ....... ~ ..... + ....... ~ ..... + ..... ~ ...... ~ ......... ~ ...................... ~ I I I ..... ~ ..... ~ ........ ~ .......... ~ ........ ~ ...... ~ ......... ~ ......... ~ ....... ~ ..... ~ ....... ~ ..... ~ ..... ~ ...... ~ ......... ~ ...................... 4 ' 4 'SECgg 'SS33SGJ4' 1600 ' ',?FA=,6680', 39~5 ', I'75',9,5'81,6 ' ' ..... ~ ..... ~ ........ ~ .......... ~ ........ ~ ...... ~ ......... ~ ......... ~ ....... ~ ..... ~ ....... ~ ..... ~ ..... ~ ...... ~ ......... ~ ...................... ' 3044 'lB,5 '164,5 ' ' ' ' ' 5 'SNI?~ ' FDSS+C 'I~5 ' ',TFA:,8~29', 4?00 , ~ , , , , ,40-50,60/80, 3000 ~00/88~ I t t I I ..... ~ ..... ~ ........ ~ .......... ~ ........ ~ ...... i ......... ~ ......... ~ ....... ~ ..... { ....... ~ ..... ~ ..... ~ ...... { ......... , ...................... , , ' ,55-65, 115 ', 3leo I 188/794 ' 3650 ', 188/794 ' ' ' ' I336 ',Z9,?' t5,0 ~,50-60', 155, , , i i . i t I i i' I ' 8 ~S~ITE* ~18C~ J12.Z5 , , , , ,,, ~. , , , ,TFA*I,031, 12712 1~55 39,3 37,0 ,35'60, Z~5 J 3~50 J 215/796. Z 2 ..... ~ ..... ~ ........ ~ .......... ~ ........ ~ ...... ~ ......... + ......... + ....... ~ ..... ~ ....... ~ ..... + ..... ~ ...... ~ ......... ~ ...................... '20l ' 9 ' SECUR ' 8PCZSGTXZ' 12,Z5 ' ' - ' 'lZ,Z ', 0-15', ZiS', 3850; Z12/785, 9 , , , , , ,TFA-l,086, 14197 ~ H30';33,9, ..... ~ ..... ~ ........ ~ .......... ~ ........ ~ ...... ~ ......... ~ ......... + ....... ~ ..... + ....... + ..... ~ ..... ~ ...... ~ ......... ~ ..................... l0 ,' I0 ,'S~CUR ~ 833SF ,' 8,5 '~ 116,TFA=,S430,~ ' l16Z? ,' 0~0,0~, 0,0 ',0-10~, 80', ZSOO',IIS/536'WIP~R, TRI~ ..... ~ ..... + ........ ~ .......... ~ ........ ~ ...... ~ ......... ~ ......... ~ ....... ~ ..... ~ ....... ~ ..... ~ ..... ~ ...... ~ ......... ~ ...................... ' 3050~ 160/59Z ' I1 ,' 11 ,'SNITg ,' NFZDL ,' 8,5 ,' ~TFA:,5890; 14627 ', 838',66,Z',IZ,? ',Z5-35', llO, , . - ....+ ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... +---~---+ ..... + ..... + ...... t ......... + ...................... i i f i I i t i t i t i i t I I I I I I I { I t t I I I I , - ....+ ..... ~ ........ + .......... ~ ........ ~ ...... + ......... ~ ......... + ....... ~ ..... + ....... + ..... ~ ..... + ...... + ......... + ...................... t i I I I I J I i t I I I l I I t I I I I I I I I I I I I ..... ~ ..... ~ ........ ~ .......... ~ ........ , ...... ~ ......... ~ ......... i ....... ~ ..... ~ ....... ~ ..... + ..... ~ ...... ~ ......... i ...................... APPENDIX IV. DRILLING DATA JANUARY 17, 1993 13631 ' - 14137' DRILL FROM 13631' TO 14140', WITH A 13 STAND SHORT TRIP AT 13871'. SHORT TRIP GAS 666 UNITS, NO HOLE PROBLEMS. JANUARY 18, 1993 14137' - 14197' DRILL TO 14197', CIRCULATE BOTTOMS UP AND TRIP OUT OF HOLE. DOWNLOAD MWD AND RIG UP TO TEST [ROPE. TEST BOPS, LOAD MWI) AND PICK UP NEW BIT #8, TRIP IN THE HOLE. FILL PIPE, TEST MWD AND CUT AND SLIP DRILL LINE AT THE SHOE, CONTINUE INTO HOLE. JANUARY 19, 1993 14197' - 14912' DRILL AHEAD TO 14912. JANUARY 20, 1993 14912' - 15622' DRILL TO 15472', CIRCULATE BOTTOMS UP TO CHECK FOR THE SAG RIVER CONTACT. SAMPLES STILL NOT SHOWING SAG RIVER SO IT WAS DECIDED TO DRILL AHEAD. JANUARY 21, 1993 15622' - 15627' DRILLED AHEAD TO 15627' WHERE IT WAS DECIDED TO CALL CASING POINT FROM MWD ANALYSIS. SAMPLE ANALYSIS STILL DID NOT SHOW SAG RIVER AFTER CIRCULATING BOTTOMS UP. A 17 STAND SHORT TRIP WAS PULLED TO CHECK THE KINGAK FOR HOLE PROBLEMS. THE DRILL STRING WAS PULLED WITH NO PROBLEMS AND RUN BACK TO BOTTOM TO CIRCULATE AND CONDITION THE MUD TO 10.1 PPG. SHORT TRIP GAS WAS 70 UNITS. TRIP OUT OF HOLE, PULLED TIGHT AT 18TH STAND, WORK AND CIRCULATE UP THROUGH IT. RUN TO BOTTOM AFTER PULLING 25 STANDS AND CIRCULATE A SWEEP AROUND, SHORT TRIP GAS WAS 115 UNITS. PULL OUT OF HOLE, WORKED TIGHT AT 10, 18, 19, 20, 21, 22, AND 23 STANDS OUT. JANUARY 22, 1993 15627' - 15627' CONTINUE TO TRIP OUT OF HOLE, PULLING TIGHT UNTIL STAND 25. LAYDOWN BOTTOM HOLE ASSEMBLY AND DOWN LOAD MW/). RIG UP CASING CREW, HOLD SAFETY MEETING AND START TO RUN 9 5/8" CASING IN THE HOLE. STOP AT THE 13 3/8" CASING SHOE AND BREAK CIRCULATION. CONTINUE IN THE HOLE. THE HOLE STARTED TAKING MUD AROUND 190 STANDS IN THE HOLE, ONLY APPROXIAMATELY 1/2 OF RETURNS WERE COMING BACK, SLOWED DOWN THE RUNNING SPEED. JANUARY 23, 1993 15627' - 15627' CONTINUE IN THE HOLE WITH 9 5/8" CASING, ON STAND 372 THE CASING HUNG UP. THIS PUT US AT 14642', APPROX A 1000' FROM BOTTOM. THE CASING WAS WORKED AND CIRCULATED, WHICH MUD HAD TO BE BUILT AS WE HAD LOST MOST OF OUR RETURNS AND THE PITS WERE DOWN TO 150 BBLS. CIRCULATED AND WORKED, SPOTTED A PILL OF SFT FLUID AT 17500 STROKES, AND SLACKED ALL THE WEIGHT OFF THE STRING AND LET SET. JANUARY 24, 1993 15627' - 15627' LET PILL SET, START TO WORK PIPE AROUND 03:00 AND CIRCULATE PILL EVERY HOUR. CIRCULATE PILL OUT OF HOLE, CONDITION MI~ AND CEMENT CASING IN PLACE AT 14561'. NIPPLE DOWN ROPE. JANUARY 25, 1993 15627' - 15627' NIPPLE DOWN BOPE, AND CUT OFF 9 5/8" CASING. WELD ON FLANGE AND INSERT NEW SPOOL, NIPPLE UP ROPE, REPLACE RAMS FOR 9 5/8" CASING AND TEST STACK. THAW OUT TOP DRIVE. PICK UP NEW BIT #10, AND NEW BHA, TRIP IN HOLE. STOP AND CUT AND SLIP DRILL LINE, FILL PIPE AT 3500'. CONTINUE IN HOLE. JANUARY 2§, 1993 15627' - 15627' RUN IN HOLE, LTO TOP OF FLOAT COLLAR, AND TEST CASING. DRILL OUT SHOE AND TEST CASING AGAIN ON TOP OF THE SHOE. DRILL UP SHOE AND MOVE ASSEMBLY BELOW SHOE, CIRCULATE MUD TO CONDITION FOR A PRESSURE INTEGRETY TEST. PIT = 10.5 EMW. CONDITION MUD TO DROP PH CONTENT DUE TO CEMENT CONTAMINATION. RUN TO BOTTOM OF OPEN HOLE, NO PROBLEMS, CIRCULATE, AFTER Z0 MINUTES CIRCULATION THE HOLE PACKED OFF, WORKED PIPE BACK UP TO SHOE AND CIRCULATED ML~ TO INCREASE MUD WEIGHT TO 10.3 PPG. WORK DOWN THROUGH OPEN HOLE, REAMING EACH STAND AT LEAST TWICE, ABOUT 150 FEET OFF BOTTOM THE HOLE PACKED OFF, WORKED PIPE BACK UP THROUGH SPOT AGAIN. JANUARY 27, 1993 15697' - 15627' WORK BACK DOWN THROUGH SPOT THAT WANTS TO PACK OFF, CIRCULATE BOTTOMS UP AND SHORT TRIP TO SHOE. TRIP IN, WORK SPOT A STAND OFF BOTTOM, CONTINI~ TO BOTTOM, CIRCULATE AND CONDITION MUD, RAISING WEIGHT TO 10.5 PPG. TRIP TO SHOE, WORKING PIPE BACK TO BOTTOM AT20-30 MINUTES PER STAND, CIRCULATE BOTTOMS UP AND SOME, WITH 175 UNITS SHORT TRIP GAS, PULL OUT OF OPEN HOLE VERY SLOW, MUD WEIGHT HAD RAISED TO 10.6 PPG. STOP 32 STANDS FROM BEING OUT OF HOLE TO MAKE SOME RIG REPAIRS, CONTINUE OUT OF HOLE. LAY DOWN BHA, PICK UP NEW BIT #11, AND BHA WITH MWD ON TOP OF BIT, TRIP IN HOLE. JANUARY 28, 1993 15§27' - 15856' TRIP IN HOLE, ON BOTTOM DRILLING AT 06:50. TRIP GAS 158 UNITS. DRILL AHEAD AT AN AVERAGE RATE OF 10 - 14 FT/HR. Pt~P #1 DOWN TWICE, ONCE FOR SWAB, ONC FOR WOOD IN VALVE. JANUARY Z9, 1993 15856' - 1§10§' DRILL AHEAD FROM 15856 TO 16106' NO PROBLEMS. SHORT TRIP AT 16034' WITH A SLIGHT . TIGHT SPOT AT 4 STANDS OFF BOTTOM, 179 UNITS SHORT TRIP GAS. JANUARY 30, 1993 16106' - 16317' DRILL TO 16150', CIRCULATE A SWEEP AROUND AND SHORT TRIP TO THE SHOE. CUT AND SLIP DRILL LINE AT SHOE. RUN INTO TO OF 8 1/5" HOLE, CIRCULATE A SWEEP, RUN TO BOTTOM OF HOLE, AND DRILL AHEAD TO 15317'. SHORT TRIP GAS WAS 119 UNITS. JANUARY 31, 1993 16317' - 16400' DRILL TO 16400', CIRCULATE A SWEEP AROUND AND PULL OUT OF HOLE. AT 38 STANDS OUT OF HOLE IT WAS DECIDED TO RUN BACK IN AND DRILL AHEAD, ONLY HAD'50 - 60 FEET OF HOLE TO MAKE. TRIP IN TO TOP OF 8 1/2" HOLE AND CIRCULATE A SWEEP AROUND. REAM FROM 15850' TO RELOG WITH THE MWD TOOL. FEBRUARY 01, 1993 16400' - 16465' RELOG SECTION FROM 15850' TO 16400', DRILL A}{EAD TO 16465', AND TD THE WELL, CIRCULAT} BOTTOMS UP. UNIT ~4Z RELEASED 10:30. DRILLING LOG FOR NORTH PRUDHOE BAY STATE JANUARY 10, 1993 POWER UP UNIT TO HEAT UP PANELS, DRILLING WITH BIT #5. JANUARY 11, 1993 10200' - 10481' CONTINUED TO RIG UP UNIT AND CALIBRATE. BEGAN LOGGING AT 10200' MD, 6243' TVD. CIRCULATE BOTTOMS UP, SHORT TRIP AT 10481', 42 UNITS SHORT TRIP GAS. JANUARY 12, 1993 10481' - 11313' DRILL AHEAD, INCREASE MUD WEIGHT TO 9.7 PPG. DRILL AHEAD, ROTARY DRILLING TO 11313'. JANUARY 13, 1993 11313' - 11575' DRILL TO 11406, SLIDING FROM 113~8' TO 11368'. TRIP FOR A NEW BIT AT 11406'. PICK UP NEW BIT #6, RUN IN TO SHOW,' CUT AND SLIP DRILL LINE, TRIP IN AND REAH LAST STAND. DRILL AHEAD, SLIDE FROM 11517' TO 11561'. INCREASE MUD WEIGHT TO 9.8 - 9.9 PPG. JANUARY 14, 1993 11575' - lZ350' DRILL AHEAD, SLIDING WHEN NEEDED. RAISE ~UD WEIGHT TO 9.9 TO 10.0 PPG, PUMPING HI LOW VIS SWEEPS. WASHED OUT MUD LINE AT 16:00 HRS, WORK PIPE WHILE REPAIRING LINE. DRILL TO 12~32', WASHOUT IN PUMP, PULL A TEN STAND SHORT TRIP WHILE MAKING REPAIRS. DRILL AHEAD TO 12350'. JANUARY 15, 1993 12350' - 12742' DRILL TO 12472', MUD LINE WASHED OUT, CIRCULATE BOTTOMS UP AND PULL OUT OF HOLE WHILE MAKING REPAIRS TO MUD LINE. LAY DOWN I~;D MOTOR AND PICKUP NEW ONE, AND NEW MWD TOOL. RUN IN HOLE, BREAK CIRCULATION AT SHOE. JANUARY 16, 1993 12742' - 13631' RUN PIPE IN TO 8600', CIRCULATE UNBALANCED ~tUD AROUND. RUN IN HOLE, FILL PIPE AND REPAIR POP OFF VALVE. DRILL AHEAD FROM 12742' TO 13631'. APPENDIX V. LOGS Date: Subject: From: To: ARCO Alaska, Inc. ' ' Lisburne/Point Mclntyre Engineering April 23, 1993 Transmittal #NPBS-009, North Prudhoe Bay State #3 ARCO Alaska Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please find enclosed the following data for the North Prudhoe Bay State #3 well. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log 1 blueline, 1 sepia DG~,,/EW~{FXE (2"&5" TVD) DG~(EWbt~/FXE (2"&5" MD) Run Run Date Company 6-10 2/1/93 Sperry Sun 6-10 2/1/93 Sperry Sun Diskette w/verification listing LDWG.TIF MWD -Final Run Run Date Company 4/19/93 Sperry Sun Please sign and return to. Laura S. Lahrson, ATO-409 ARCO Ai~c~ ~}1~ Gas Oo~s. P.O. BOX ~0 '~n~h0raO0 Anchorage, Alaska 99510-0360 Transmittal #NPBS-009 PLEASE S1GiN ONE COPY AND RETURN Date: Subject: From: i ARCO Alaska, Inc. ~LiSburne/POint McIntyre Engineering April 2, 1993 Transmittal #NPBS-006, North Prudhoe Bay State #3 ARCO Alaska Inc. To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please find enclosed the following data for the North Prudhoe Bay State #3 well. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log 1 blueline, 1 sepia ,'Segmented Bond Log Gamma Ray CCL 1 "Segmented Bond Log Gamma Ray CCL 1 ,-"PFC Gamma Ray (Perforating Record) 1 v""PFC Gamma Ray (Perforating Record) 1 ~'Compensated Neutron Gamma Ray (Cased Hole) 1 "'MAC Gamma Ray Correlation 1 · -'DGJ~/EW~/FXE (2"&5" TVD)-FIELD 6-10 -' DG~/EW~k/FXE (2"&5" MD)-FIELD 6-10 --MAC Acoustic Filtered Waveforms 1 --Borehole Compensated MAC Computed Slowness Curves 1 '"Gyro Continuous Survey (Gyro) 1 '/LWD: CDN (Density & Neutron Porosity/Gamma Ray) 1 "Integrated Formation (2"=100' MD) - ~Integrated Formation (2"=100' TVD) - · '"Engineering Parameters (2"=100' MD) - -"Pressure Data - Run Run Date Company 2/7/93 Atlas 2/15/93 Atlas 2/7/93 Atlas 2/9/93 Atlas 2/7/93 Atlas 2/14/93 Atlas 2/1/93 Sperry Sun 2/1/93 Sperry Sun 2/14/93 Atlas 2/14/93 Atlas 2/20/93 Schlumberger 2/3/93 Scl~lumberger 1/11-3/1/93 Exlog 1/11-3/1/93 Exlog 1/11-3/1/93 Exlog 1/11-3/1/93 Exlog Report ~/'Mudlog (Exlog) Final Well Report RECEIVED APR 0 2 199,~ Alaska Oil & Gas Cons. Commission Anchorage Run Date Company 1/11-3/1/93 0Exlog PLEASE SIGN ONE COPY AND RETURN Page2 Transmittal #NPBS-006 ! Diskette w/verification listing v/MWD Survey -Final {~_I~~ ~'MAC / GR, CN / GR w/LDWG Report Run Run Date Company 2/1/93 Sperry Sun 2/14/93 Atlas ,/'CDN in LDWG format ~)~.sk4.'qCe-~ --q _.~.~,&e?:k I 1 2/3/93 Schlumberger vGCT with Sub-Surface Directional Survey 2/2O/93 Schlumberger v2MAC Waveforms (Monopole/Dipo_ Atlas Please ~,/ / Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. \ P.O. BOX 100360 Anchorage, Alaska 99510-0360] Transmittal #NPBS-006 , / ~// APR 02 1993 A/aska 0il & Gas Cons. Commission Anchorage PLEASE SIGN AND RETURN ONE COPY AOGCC COMPLIANCE REVIEW & REPORT PTD # OPERATOR INITIAL CONTACT DATE DATA REQUES~'~ED WELL NAME INTERIM CONTACT DATES COMP. DATE PHONE # ,X"Jt; .-'1 ~1.~~' FINAL COMPLIANCE DATE COMMENTS BP EXPLORATION To: Robert P. Crandall Sr. Petroleum Geologist Alaska Oil & Gas Commission From: Terry Jordan Drilling Engineer Subject: Exploratory Well North Prudhoe Bay State Well #3 Date' 02/24/93 Attached is the well summary for the above referenced well. Please be advised that this information is of a confidential nature. Mike Zanghi Well file ARCO Alaska, Inc. j Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 TO: STATE of ALASKA OIL/GAS CON. COMM. 3001 PORCUPINE ANCHORAGE, ALASKA OPERATOR: ARCO SAMPLE TYPE: DRIES DATE: 5 FEB 1993 AIRBILL: AL 646223 AFT#: 3-02-05- CHARGE CODE: AX9245 NUMBER OF BOXES: 7 SAMPLES SENT: SET E DRY DITCH SAMPLES: 10200°-11970. 15370'-15820' 11970'-13230' 15820'-16230' 13230'-14550' 16230'-16465' 14550'-15370' SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANy DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: ARCO ALASKA, INC. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 DATE: ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AF~313-6003-C AOGCC GEOLOGICAL MATEP, iALS iNYENTORY LIST PEFIMIT# ~Z. - ~L["~ WELL NAME ~, ~ ~ ~ COMPLETION DA~ _ I t.~ CO. CONTACT ~(O ~ data as it is received?list received for 407. if not reouired list as NR drillina historv survey well tests core descri core analysis ditch intervals ital data L -,-,,,,n= I ,M-r=n~rA , , ,-,_ RUN SCALE Il'MI I ....... N0.. .{to.t. hc nearest foot) . .lin. chl100'] ~ ~ ~ ~, r~l · , ......... ~ ~ , ,~ ~ ~ ,,, ,, i , i ii u ,i ii ,i i i 131 ' ........................ ~ , MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to.'-~~avid JohnCn Commissioner date: file: February 18, 1993 JOHO2102.DOS thru: Blair E Wondzell z/(~/?$ subject: Sr Petr Engineer from: Johh Spaulding Petr Inspector BOP Test-Pool :7 ARCO North Prudhoe State ~' 3 Wildcat.. PTD 92-145 Wednesday, February 10, 1993: I witnessed the BOP Test on Pool Arctic Alaska Rig #7~ the 9 5/8" casing was set to a depth of 14,619'. SUMMARY: The BOP Test on Pool Arctic Alaska Rig #7 was completed successfully with no failures. Test time 2 1/2 hours, 0 failures. OPERATION: Drlg: v'/ Drlg Contractor: P~c) L.- Operator: /~/z.~¢) Well Name: ,,d/'~/~A. ~J£H~fJ~o~" ...~¥~ '/~ ~ ~ Rep. Casing Size: ~ ~ Set ~ / ~/~eet Location: Sec. Test: In,al Weekly ~' Other STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Workover: DATE: Rig No. '~ PTD#~.-tw5 RigPh.# Rep. /_.~_.._~ ~'~,,~,~ T. /,24J R. /5""-' Merd. g/.,/H~ Test MISC. INSPECTIONS: Location Gen.: ~'/ Housekeeping: ~'~ (Gen) Reserve Pit ~//~A BOP STACK: Qua. Ann. Preventer / Pipe Rams Blind Rams Chk/Ln Valves -,2_ HCR Valves Kill Line Valves Check Valve Well Sign Drl. Rig Test Pre~,sure I P/F P .P ,o MUD SYSTEM: Light Alarm/. Tdp Tank Pit Level Indicators Flow Indicator / Gas Detectors FLOOR SAFETY VALVES: Quan. Pressure Upper Kelly I J~Sb t'~z~' o Lower Kelly l J-),St~/5000 Ball Type ~ ~0 / 5"~ o 0 Inside BOP I J ~ ='~/~'~ o ~ CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: ~ Master: ~/©0 J minutes minutes v,,-'/Remote: Nitgn. Btrs: ~>E)c:) ( 4/c~-~ Psig. Number of Failures ~)~ Test Time ~ ~.~[,lours Number of valves tested ~ Repair or Replacement of Failed Equipment shall be made within ---(~--- days. Notify the Inspector on duty and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 27'9-1433 REMARKS: Distribution: orig-Well File c - OperJRig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES ~ NO 24 HOUR NOTICE GIVEN YES / NO Waived By: W~tnessed By: FI-021L.XLT Rev. 1/93 · MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Dave W. Johnsto~ date: Commissioner thru: Blair E Wondzell Sr Petr Engineer from: ~OU Grimaldi Petr Inspector file: subject: February 9, 1993 LOU01271.DOC Rig BOPE Inspection Pool Rig 7 ARCO North Prudhoe Bay State 3 PTD 92-145 Exploratory Wednesday, January 27, 1993: I made a Rig/BOPE Inspection on Pool Rig 7 drilling the exploratory well North Prudhoe Bay State 3 for ARCO Alaska. I found all to be in compliance on the rig. Les Peak (company representative) was on the rig floor and accompanied me on the inspection. Although the outside air temperature was 44 degrees below zero (ambient) the rig was warm with adequate ventilation. The area surrounding the rig was kept neat and clean with good access provided. f in a discussion with Les Peak it appears that more emphasis is to be placed on '>(tight hole status as this will effect the inSpectors (or how) remains to be seen. ",~~~.SUMMARY: The Rig/BOPE Inspection on Pool Rig 7 revealed all /t° be in Df JUG AMOS ,?'"'~ STARE OF ALASKA ALASKA O~_,AND GAS CONSERVATION COMMISSION RIG ! BPS INSPECTION REPORT OPERATION: Drilling ,~,,~), Workover__Compl. UIC DATE: /'"'~ Welt Nome: ~ PEo~ ~ ~~ P~ OdgContmdor: p¢¢~ Rig¢ Rep. ~"7¢~{ Operator: R~C,,~ ~%~ Rep. ~ P~ .:;.:.;; ......................... :: ::~"' .... :::" :":"' ~LL:~; ...................... :' ' ' ............. ~.?, (A.) B.O.P. STACK YES NO NIA ~?; (C-) MUD SYSTEM YES NO N/A ]~;;;' Wellhead fig wkg press ~ ~.~ pit level floats installed ::~:;; Stack wkg press X ~;~¢ Flow r~le sensor :~:~3 :~ Annular preventer ~ ~;~'~Mud g~s sepemtor :~;;6.;~ Slecl* anchored ~ ~.8]~.~ G~s sensors :~:;:~7~~ Chke~;ill line size ~ ?~ Choke line connedions %.. ;~:;~';~ All turns targeted ( chke & kill Ln.)X ~:~:: Tdp lenk 'i0 bianu81 valves (chke & kill Ln.) ~ '=J::~i~{~~ (D.) RIG FLOOR YES NO i:i " ' ' ....· -onnecbons (Fled. Wl~d. cl~mped ~ ~:~ Kelly cocks (upper. lower, IBOP) ,,.~]~:~ Drilling spool ~ ~.~;;Floorv.lves (d.~ bell. ed.) ~1 ~; Flow Nipple ~ ~;; Kel~ & floor volvo wrench~¢ X ::j:;~; FJyw monitor ~ ~:~;~. Drillers console Cow monilor, :!5 Control lines fire proteded ~ flow rote indicator, pit level '~. .. :!;~:: (8.) CLOSING UNIT YES NO N/A ;~;;~:~;~;Killsheetupzto-date '!.:~, Working pressure X ;:.~:~:; Ges detedion monitors 17 Fluid level ~ (H2S & methane) ;i;~: Operating pressure X ;~:~::': Hydraulic choke p~nel :i ;~ Pressure gouges4x ~:;~:~;: Ct?k¢_~_~i~d ......................... ~ 'x ~ .,... :~:1~Regulotorbypass ;?~ ___ .~E.) MISC. EQUIPMENT YES NO N/A 2.~ ~-weyvalves (aduators) -~ ~5~ Flo, re~ent line "~'j Biind r~ms h%die cover ~ :~ ~ Al~ turns t~rgeted ~:~ ?riiier control panel~ (d°~¢re~m choke lines) :~:~:~: R. eser~e pitt~nk~ge ::~5~Remote conlrol p~nel "~ Fh'ewall :~.~:~ Personnel protedive equip, evil, ~ :~ Nibogen power source [backup) X' :.~ All Drillsile Supe~isors Trained co.ditio hoses, For P o edures .... ~;0 HES probes , :~ Rig housekeeping REMARKS: RECORDS: Dote of Lost Rig / BPS Inspection /--"-u'~'~5 Date of Last e 0 P Test/-~ ',,¢'.--~ ~ Resulting Non-Compliance Items: ~/~ ~ ~)~ ~ C~~ ~1~6~~ Non-Compliance not corroded & Reason: D~te Corredions Will Be ~mpleled: BOP Test & Results Properly Entered On Daily Record? y~ Kill Sheet Current? Distribution: kOOOO~EP: ~ ~--~~' c - Open/Rig OPE~TOR REP: ~ c- D~l~b~se c- Trip Rpt File FI-022.XLT (Rev. 12¢2) c- Inspedor /L,cC . MEMORANDUM STATE OF ALASKA to: Lsigh Griff~n~'~' Commissioner date: January 27, 1993 file: LOU01081 .DOC thru: Blair E Wondzell ~/¢_~9~ subject: Sr Petr Engineer from:~oou Grimaldi Petr Inspector BOP Test-Pool 7 North Prudhoe Bay State 3 Arco Alaska Exploratory Well PTD 92-145 Friday, January 8, 1993: I witnessed the initial BOP Test on Pool Rig 7 drilling Arco's exploratory well North Prudhoe Bay State 3. The test went very well with no failures observed. The methane and H2S detectors worke~but read higher concentrations than the calibration standards and were subsequently recalibrated before I left the location. Jimmy Grecco (Pool toolpusher) conducted a good and thorough test. I found the area surrounding the rig to be clean and to provide good access for emergency equipment. SUMMARY: I witnessed the initial BOP test on Pool Rig 7 drilling Arco's exploratory well North Prudhoe Bay State 3: test time 3 hours - 0 failures. Attachment STATE OF ALASKA ALASKA 01L AND GAS CONSERVAT ION COMM I SS ION BOP Test Report OPERATION: Drlg ~,' Wkvr TEST: Initial Well,~Jo/~J j~.~- g/~)/~-;~i~l~*.~ Permit # ~"{~/~" Location: Sec~:~ Tt~/ R/YE' M /-/~J Dr]g contrctr p~OJ- /~t'~:7'/C Rig~ 7 Rep ~/AA¢~/' G/~(~O csg set ~ ft Location (general) 6~)¢>~:~ Housekeeping (general)(~°~ Rsrve pit /J//~ MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors Well sign Rig Visual A ud i o. 1, ,,.off POPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve Test Pressure o / Weekly.__ Other Rig phone # ~~- ACCUMULATOR SYSTEM: Full charge pressure ~o~I~)0 psig Press after closure / ~ ~)~ psig Pump incr clos press 200 psig ~ min~ ~ sec Full charge press attained ~ min ~~sec Remo~eC'O0~ Blind s~J~eh cover/~ 5 KELLY A~D FLOOR SAFETY V~LVES~ Upper Kelly 0/.-~ Test pressure Lower Kelly OK Test pressure Ball type ~)~ Test pressure inside BOP ~ Test pressure Choke manifold ~ Test.pressure Number valves Number flanges Adjustable chokes Hydraulically operated choke TEST RESULTS: Fai 1 ures k_~ Test time ..~,,~ hfs Repair or replacement of failed equipment to be made within days, Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office, Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/92) STATE WITNESS REQUIRED? yes~ no 24-HR NOTICE GIVEN? yes y no Waived by: AOGCC phone 279-1433 - FAX 276-7542 WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IMISSION December 31, 1992 300'1 PORCUPINE DRIVE ANCHORAGE, ALASKA 9950'1-3192 PHONE: (907) 279-'1433 TELECOPY: (907) 276-7542 Michael Zanghi Area Drilling Engineer ARCO Alaska, Inc. P O 196612 Anchorage, AK 99519-6612 Re: North Prudhoe Bay State #3 ARCO Alaska, Inc. Permit No: 92-145 Sur. Loc. 70'FSL, 1790'FWL, Section 25. T12N, R14E, UM Btmhole Loc. 1749'FNL, 1523'FEL, Section 22, T12N, R14E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit 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 permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~ hnston ~h:}rma~ ' BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. "" STATE OF ALASKA ALASKA L)iL AND GAS CONSERVATION COIv,,vllSSlON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill r-Illb. Type of well. Exploratoryr;I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB = 52feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 3d,,82~ Z ~ ~ ~ '7 4. Location of well at surf-ace 7. Ur{it or property Name 11. TYpe Bond(see 20 AAC 25.025) 70' FSL, 1790' FWL, Section 25, T12N, R14E, UM Prudhoe Bay Unit At top of productive interval :8. Well number Number 2302' FNL, 980' FEL, Section 22, T12N, R14E, UM N. Prudhoe Bay State #3 U-630610 At total depth 9. Approximate spud date Amount 1749' FNL, 1523' FEL, Section 22, T12N, R14E, UM December 28, 1992 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandTVD) property line 70 feet West Beach State#4 ~ 450'= 30 feet 2560 16435' MD / 9522' TVD[e et 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.o3s (e)(2)) Kickoff depth soofeet Maximum hole angle6~.33 o Maximum surface 3330psig At total depth (TVD) 8800'/4390Pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 41' 41' 121' 121' 11 yds Arcticset 16" 13-3/8" 68# L'8° / K'5~- B TC 4804' 40' 40' 4844' 4000' 3679 cu fl 'E' & 464 cu ft CI 'G' ..12-1/4" 9-5/8" 47# NT80-SS NSCC 15262' 39' 39' 15301' 8982' 1031 ci ft CI 'G' 8-1/2" 7" 26# NT80-SS NSCC ~ 15151' 8911' 16435' 9522' 322 cu ft Cl 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate DEC 1 Production Liner ~!~s_kg .{,iii .~, L~a.$ ~0115, ~.0~ Perforation depth: measured , ~ji_~,~t~~''~''' true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~14~ ~ -,~, /14~'~ :~;~,~f/t;' Title Area Driiling Engineer Date ~ ~ ' - - Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~-"~'~_/,'~..,~z- . 150-O~?- Z. 2_ 3' 2.- ~.. I /~ __~ / .-~cz)__ Ifor other requirements Conditions 'of approval Sam.j:)l.es required ~ Yes [] No Mud Icg required e,]~, [] No Hydrogen sulfide measures ,!~ Yes [] No Directional survey requ~rec~ ~Yes [-1 No Required working pressure for BOPE CI2M; 1-13M; J~5M; I-il0M; I-'115M; Other: by order of Approved by Original ~i~ned E~y Commissioner me commission Date/~,.-,._~-,~ Form 10-401 Rev. ~-~1':E5 Submit in triplicate State: Well: Field: State Permit NPBS3CMT.XLS Alaska N.P.B.St. EXPLORATORY Engineer: Work Sheet: Date: M. Minder Cement Volume Calculations 12/22/92 Casing Type Casing Size - Inches Casing Length - Feet Hole Diameter - Inches Cement- Sacks Itl Cement - Yield It 1 Cement - Cubic fl #1 Cement - Cubic fi # 1 Cement - Sacks #2 Cement - Yield #2 Cement - Cubic ft /12 Cement - Cubic ft /t2 Cement- Sacks Cement - Yield /t3 Cement - Cubic ft Cement - Cubic ft Cement - Cubic ft / Vol Cement - Fill Factor Casing Type Casing Size - Inches Casing Depth - Feet Hole Diameter - Inches Cement- Sacks #1 Cement - Yield It 1 Cement - Cubic fi It 1 Cement - Cubic fi #1 Cement- Sacks Cement - Yield /12 Cement - Cubic ft 1t2 Cement - Cubic fl Cement- Sacks Cement - Yield Cement - Cubic ft /13 Cement - Cubic fl Cement - Cubic ft / Vol Cement- Interval Top of Cement - Feet Conductor 20.000 80.000 30.000 0.000 0.000 0.000 297.000 0.000 0.000 0.000 0.000 Surface 13.375 4,804.000 16.000 0.000 0.000 0.000 3,679.000 0.000 0.000 0.000 464.000 0.000 0.000 0.000 0.000 297.000 4,143.000 1.361 2.051 ok,. Intermediate It 1 Intermediate 0.000 0.000 0.000 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 #DIV/0! ItD1V/0! ItD1V/0! ItDIV/0! Liner 7.000 1,284.000 8.500 0.000 0.000 0.000 322.O0O 0.000 0.000 0.000 0.000 322.000 1.978 Production 9.725 15,301.000 12.250 0.00 0.00 0.00 1,031.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,031.00 3,406.82 11,894.2 Measured Depth ? . Printed 12/22/92 State: Alaska . Borough: Well: N. Prudhoe Bay St.#S Reid: Prudhoe Bay St. Perm ~92-145 Date Engr: NPB$ T tI3.XL$ t 2_./22__./92 M. Minder Casing interval Interval Size Bottom Top lA 13.375 151 40 2A 13.375 4000 120 3A 9.625 8982 39 4A 7 9522 8911 5A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Descriptionescriptionescription Tension Length 120 4684 15262 1284 0 0 0 0 0 0 Lbs Grade Thread Lbs 68 K-55 BTC 0 68 L-80 BTC 318512 47 NTSO-SS NSCC 0 26 NTS0-SS NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psi/It 1B 9.5 0.494 2B 9.5 0.494 3B 10.2 0.530 4B 10.4 0,541 5B 0,0 0,000 6B 0.0 0.000 7B 0.0 0.000 8B 0.0 0.000 919 0.0 0.000 I OB 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF ,9330 3450 1.0 3330 5020 1.5 3330 6870 3330 7240 0 0 #DIVIO! 0 0 #DIVIO! 0 0 #DiV/O! 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIV/O! Tension Strength K/Lbs K/Lbs lC 326.672 1069 2C 318.512 1556 3C 717.314 1086 4C 38.384 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 3.27 4.89 1.51 604 1 0 #DiV/O! 0 #DIV/0! 0 #DIVIO! 0 #DIV/O! 0 #DP, f/O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi Resist. Q:)F 75 1950 26.142 1976 2260 1.144 4764 4750 0.997 5149 5410 1.051 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIViO! 0 0 #DIVi0! 0 0 #DlVlO! 0 0 #DlV/O! WELL PLAN SUMMARY WELL NAME: N. PRUDHOE BaY STATE #3 AFE NUMBER: SURFACE LOCATION: TARGET LOCATION: - BOTTOM HOLE LOCATION: 30188 70' FSL 1790' FWL SEC 25 T1ZN R14E UM Z3OZ' FNL 980' FEL SEC 2_2 T12_N R14E UM 749'FNL 1523'FEL SEC 22 T1ZN R14EUM TOTAL DEPTH: 1 6,435' MD / 9522' TVD ESTIMATED SPUD DATE: 12/28/92 CONTRACTOR: POOL RIG #7 ELEVATIONS: PAD: 1 O' Pad TO RKB: 42' RKB: 52' DIRECTIONAL INFORMATION: KOP: 500' BUILD RATE: 1-2.°/100' EOB: 4327'/3754' AVG ANGLE: 61033' BOD: n/a DROP RATE: n/a EOD: n/a FINAL ANGLE: 61 °33' DIRECTION: DEPARTURE at TD: FORMATIONS $S Depth Permafrost 1700' K-15 4950' West Sak 6580' K-10 7180' Stump Island 8000' K-5 8100' HRZ 8125' Kingak 8150' Sag River 8930' Shublik 8990' Sadlerochit Zone 4 9050' Sadlerochit Zone 3 9210' Sadlerochit Zone 2 9250' Kavik 9370' TD 9470' CASING PROGRAM 1. Surface casing point to cover angle build and set in shale section at the T-5 marker. 2. Intermediate casing point picked by geologist on location and approved by drilling supervisor. , The casing point top set the Sag River. TD picked as 9470' ss TVD. Bit Size 30" 16" 12 1/4" 8-1/2" Casing Size Weight Grade Connection Top Bottom 20" 91.5# H-40 WELD 41' 121' 13 3/8" 68# L-80/K-55 BTC 40' 4844' 9 5/8" 47# NT-80SS NSCC 39' 15301' 7" 26# NT-80SS NSCC 15151' 16435' N44o32'W 12264' Length 80' 4804' 15262' 1284' N. Prudhoe Bay State #3 Well Plan Summary DRILLING MUD PROGRAM 1. Surface Hole: FW spud mud ?. Intermediate Hole: FW Polymer Lightly Dispersed 9.5 - 10.2 ppg 3. Production Hole: FW Polymer Lightly Dispersed 10.0 - 10.4 ppg MUD LOGGING PROGRAM 1. Mud loggers will be called out in order to be logging by 6500' TVD. MWD/OPEN HOLE LOGGING PROGRAM 1. 1 6" hole: Sperry Sun Directional MWD. 2. 12_ 1/4" hole: Sperry Sun Directional MWD, Directional/Gamma/Phase 4 Resistivity MWD at +/- 12_,800' MD for Stump Is. and to pick casing point, Western Atlas open hole wireline GR/SP/AC/CN/ZDL; SWC's and Rotary SWC's if Stump Is. present. 3. 8 1/2_" hole: Sperry Sun Directional/Gamma/Phase 4 Resistivity MWD; Western Atlas open hole wireline GR/SP/AC/CN/ZDL, SWC's, and Rotary SWC's. CASED HOLE LOGGING PROGRAM lo Checkshot Velocity survey before running tubing. 2. Western Atlas SBT (cement bond log) from TD to TOC in 9 5/8" casing before running tubing. 3. Schlumberger GCT Gyro PBTD to surface - post rig. COMPLETION PROGRAM Tubing Size Weight Grade Connection Top Bottom 4-1/2" 1 2.6# L-80 TDS 39' 1 5500' Length 15511' Single 9-5/8" packer just above 7" liner top (straddle completion with 9-5/8" packer and 7" packer if Stump Island Sandstone is logged as productive). o o . , o . 8~ . 10, 11. 12. 13. !' ,~)rudhoe Bay State #3 Operations Summary MIRU Pool 7 drilling rig. Spud well and drill 16" hole to 4844' md/4000' tvd building angle to 61 degrees. Set 13 3/8" casing and cement same, Test casing to 2500 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 12 1/4" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 15,301' md / ~8982' tvd. Run open hole logs. Make wiper trip. Set 9 5/8" casing and cement same. PU 8 1/2" BHA and test casing to 3500 psi. Drill <10' of new hole and perform formation integrity test to12.0 ppg EMW. Drill 8 1/2" hole to a total depth of 16,435' md / 9522' tvd. Run open hole logs. Make wiper trip. Set 7" liner and cement same. ' PU 6" BHA and clean out 7" liner circutaing to seawater. Test to 3500 psi for 30 minutes. Run 4-1/2" completion string. NU 4" tree and test to 5000 psi. Rig down drilling rig. Perforate well. General Purpose Worksheet -J - lOate / ~ L.ILI°w' / qoo 0 mvo I 5/$0 1 mb 9 52Z_' -'r-v~ RKB 52' KOP / BUILD 1/100 BUILD RAT[, 1.00 DCG/I00 rl VERTICAL VfEW SCALE 500 F't;, BUILD 1.5/100 BUILD RATe, 1.50 DEG/IO0 Fl BUILD 2/100 BUILD RATE, 2.00 D£O/IO0 FI 2072 END Of' BUILD PFudhoe Bay Drilling NoRrI'H PRUDHOE BAY / DIVISIBN 30. TRUE ! 17 deg. Eost Decllno~lon CRITICAL POINT DATA HD lnc AZl TVD North Eost EKB 5~'.S,S. 0 0.00 0.00 0 0 0 BUILD 1/100 500 0,00 0.00 500 0 0 BUILD 1.5/1001500 10.00 315.461495 62 -61 BUILD 2/100 2500 25.00 315.462446 ~76 -871 END DF BUILD 4327 61.55 315.463754 1154 -II35 13 3/8' CSG. PTA844 61.55 315.464000 1477 -1454 T-3 6055 61.55 315.464577 8236 -2201 K-15 6947 61.55 315.465008 2795 -2751 STATE #3 HE]RIZBNTAL SCALE 1 000 SMITHI I VIEW Ft, IE)O / DIVISIE]N ~ooo 625 DO. e 153~ MD. 8c)~2 TVD ,,, x. '--'~OOO -'-'700O I I o 500 1000 VERTICAL VEST SAK 10369 61.55 315.46 6632 4939 -4861 ~"~' 7 4844 M 4 iV K-lO 11680 61.55 315 46 7232 5789 -5637 -~---~ 13.3 5 OD, e D, ooo D SLUMP ISLAND 13349 61.55 315.46 8052 6007 -6699 ~. K-5 13559 61.55 315.46 81526939 -6828 '~. HRZ 13612 61.55 315.46 81776972 -6861 ~ --40~0 ~ K1NGAK 13664 61,55 315.46 82027005 -6893 '% ' ~ 9 5/8' CSG PI15301 61.55 315.46 89828031 -7903 ~ SHU~LIK 154~7 61,55 315.46 904~ 8110 -7980 ~ ~.~ TArGEt/lUg 15553 61.55 315.46 910~ 8189 -8058 ~ ZONE-3 15889 61.55 315.46 9~6~ 8399 -8~65 · ~ ZDNE-~ 159~3 61,55 315.46 930~845~ -8317 ~ ~-15 TOTAL ~EPIH 16435 Gl.Sq 315.4~ 9Sa~874t -860{ 39~ _.o,.. ,ooo 20 6930 B037 ~ K-ID' .g551 ~ ST~ ISL~B 973~ ~828 ~ SAG RIY[R/ 9 5/~' CSG. Pt. 112[~[~LGT. -- ZD'~ -2 '~- K&VlK "~ TOt,q. I I I 11501 12000 12500 11784 11858 12264 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 I0000 10500 IlOlO SECTIUN PLANE', 315,46,° Smith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 315.46 deg. ;urvey Reference: ~/ELLHEAD ,eference ~/or[d Coordinates: Lat. 70.21.29.72 N - Long. 148.28.31.18 N eference GRiD System: Alaska State Plane Zone: Alaska 4 eference GRID Coordinates: (feet): 5982962.00 N 687706.00 E 'ertJca[ Section Reference: WELLHEAD :losure Reference: ~/ELLHEAD orth Aligned To: TRUE NORTH Page 1 Date: 12/18/92 Net[path ID: NP-O3WP Program No: 2 Last Revision: 12/18/92 rudhoe Bay DrilLing ORTH PRUDHOE BAY STATE #3 Measured Inc[ Drift TVD Subsea T 0 T A L Geographic Coordinates Depth Dir. Depth RectanguLar Offsets Latitude / Longitude (ft) (deg.) (deg.) (fl) (fl) (ft) (ft) · K.B. ELEVATION 52.0' SS 0.00 0.00 0.00 100.00 0.00 0.00 200.00 0.00 0.00 300.00 0.00 400.00 0.00 UILD 1/100 500.00 0.00 0.00 0.00 0.00 315.46 315.46 315.46 315.46 315.46 315.46 315.46 315.46 315.46 600.00 1.00 700.00 2.00 800.00 3.00 900.00 4.00 1000.00 5.00 1100.00 ' 6.00 1200.00 7.00 1300.00 8.00 1400.00 9.00 UILD 1.5/100 1500.00 10.00 315.46 1600.00 11.50 315.46 1700.00 13.00 315.46 1800.00 14.50 315.46 1900.00 16.00 315.46 2000.00 17.50 3!5.46 2100.00 19.00 315.46 2200.00 20.50 315.46 2300.00 22.00 315.46 2400.00 23.50 315.46 ~UILD 2.0/100 2500.00 25.00 315.46 2600.00 27.00 315.46 0.00 -52.00 0.00 N 0.00 E 70.21.29.7234 N 148.28.31.1848 100.00 48.00 0.00 N 0.00 E 70.21.29.7234 N 148.28.31.1848 200.00 148.00 0.00 N 0.00 E 70.21.29.7234 N 148.28.31.1848 300.00 248.00 0.00 N 0.00 E 70.21.29.7234 N 148.28.31.1848 400.00 348.00 0.00 N 0.00 E 70.21.29.7234 N 148.28.31.1848 500.00 448.00 0.00 N 0.00 E 70.21.29.7234 N 148.28.31.1848 599.99 547.99 0.62 N 0.61 N 70.21.29.7295 N 148.28.31.2027 699.96 647.96 2.49 N 2.45 N 70.21.29.7479 N 148.28.31.2564 799.86 747.86 5.60 N 5.51 N 70.21.29.7784 N 148.28.31.3458 899.68 847.68 9.95 N 9.79 N 70.21.29.8212 N 148.28.31.4710 999.37 947.37 15.54 N 15.29 N 70.21.29.8762 N 148.28.31.6319 1098.90 1046.90 22.37 N 22.02 N 70.21.29.9434 N 148.28.31.8285 1198.26 1146.26 30.44 N 29.96 N 70.21.30.0228 N 148.28.32.0606 1297.40 1245.40 39.74 N 39.11 N 70.21.30.1143 N 148.28.32.3283 1396.30 1344.30 50.28 N 49.48 N 70.21.30.2179 N 148.28.32.6314 1494.93 1442.93 62.04 N 61.05 N 70.21.30.3336 N 148.28.32.9698 1593.17 1541.17 75.34 N 74.14 N 70.21.30.4643 N 148.28.33.3523 1690.89 1638.89 90.46 N 89.02 ~ 70.21.30.6131 N 148.28.33.7874 1788.02 1736.02 107.40 N 105.69 g 70.21.30.7797 N 148.28.34.2749 1884.50 1832.50 126.15 N 124.14 ~ 70.21.30.9641 N 148.28.34.8142 1980.26 1928.26 146.69 N 144.35 ~ 70.21.31.1661 N 148.28.35.4052 2075.22 2023.22 169.01 N 166.32 N 70.21.31.3856 N 148.28.36.0474 2169.34 2117.34 193.09 N 190.02 ~ 70.21.31.6225 N 148.28.36.7404 2262.54 2210.54 218.93 N 215.44 ~ 70.21.31.8766 N 148.28.37.4837 2354.75 2302.75 246.49 N 242.56 N 70.21.32.1476 N 148.28.38.2767 2445.93 2393.93 275.76 N 271.37 N 70.21.32.4356 N 148.28.39.1190 2535.80 2483.80 307.01 N 302.12 N 70.21.32.7428 N 148.28.40.0179 GRID Coordinates Northing Easting (ft) (ft) 5982962.00 687706.00 5982962.00 68ZZ06.00 5982962.00 6877'06.00 5982962.00 687706.00 5982962.00 687706.00 5982962.00 687706.00 5982962.61 687705.37 5982964.43 687703.49 5982967.46 687700.35 5982971.70 687695.96 5982977.16 687690.32 5982983.82 687683.43 5982991.68 687675.29 5983000.75 687665.91 5983011.03 687655.28 5983022.50 687643.41 5983035.46 687630,00 5983050.20 687614.74 5983066.72 687597.66 5983085.00 687578.74 5983105.03 687558.02 5983126.79 687535.51 5983150.27 687511.21 5983175.46 687485.15 5983202.33 687457.35 5983230.87 687427.82 5983261.34 687396.30 CLosure Dist. Dir. (ft) deg. 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.87 @ 315.46 3.49 @ 315.46 7.85 @ 315.46 13.96 @ 315.46 21.80 @ 315.46 31.39 @ 315.46 42.71 @ 315.46 55.76 @ 315.46 70.54 @ 315.46 87.05 @ 315.46 105.70 @ 315.46 126.91 @ 315.46 150.68 @ 315.46 176.98 @ 315.46 205.80 @ 315.46 237.12 @ 315.46 270.91 @ 315.46 307.15 @ 315.46 345.82 @ 315.46 386.89 @ 315.46 430.7"3 @ 315.46 Vertical Section (ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.87 3.49 7.85 13.96 21.80 31.39 42.71 55.76 70.54 87.05 105.70 126.91 150.68 176.98 205.80 237.12 270.91 307.15 345.82 386.89 430.73 DLS (dg/lOOft) 0 .'00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 ,1 1.00 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 2.00 ,rnith International, Inc. I '~ oposal Report Page Date: 12/18/92 Uettpath ID: NP-O3~P easured Inct Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) 2700.00 29.00 315.46 2624,09 2800.00 31.00 315.46 2710.69 2900.00 33;00 315.46 2795.49 3000.00 35.00 315.46 2878.39 3100.00 37.00 315.46 2959.29 3200.00 39.00 315.46 3038.08 3300.00 41.00 315.46 3114.68 3400.00 43.00 315.46 3189.00 3500.00 45.00 315.46 3260.93 3600.00 47.00 315.46 3330.39 3700.00 49.00 315.46 3397.30 3800.00 51.00 315.46 3461.57 3900.00 53.00 315.46 3523.14 4000.00 55.00 315.46 3581.91 4100.00 57.00 315.46 3637.83 4200.00 59.00 315.46 3690.82 4300.00 61.00 315.46 3740.82 ) OF BUILD 4327.47 61.55 315.46 3754.02 '4427.47 61.55 315.46 3801.66 4527.47 61.55 315.46 3849.30 4627.47 61.55 315.46 3896.94 4727.47 61.55 315.46 3944.58 4827.47 61.55 315.46 3992.22 -3/8" CSG PT 4843.80 61.55 315.4'6 4000.00 4927.47 61.55 315.46 4039.86 5027.47 61.55 315.46 4087.50 5127.47 61.55 315.46 4135.14 5227.47 61.55 315.46 4182.78 5327.47 61.55 315.46 4230.42 5427.47 61.55 315.46 4278.06 5527.47 61.55 315.46 4325.70 5627.47 61.55 315.46 4373.34 5727.47 61.55 315.46 4420.98 5827.47 61.55 315.46 4468.62 5927.47 61.55 315.46 4516.26 6027.47 61.55 315.46 4563.90 3 6054.97 61.55 315.46 4577.00 6127.47 61.55 315.46 4611.54 6227.47 61.55 315.46 4659.18 Subsea T 0 T A L Depth Rectangular Offsets (ft) (ft) (ft) 2572.09 340.47 N 335.04 2658.69 376.10 N 370.11 2743.49 413.87 N 407.28 2826.39 453.73 N 446.50 2907.29 495.62 N 487.72 2986.08 539.50 N 530.91 3062.68 585.31 N 575.99 3137.00 633.00 N 622.92 3208.93 682.51 N 671.64 3278.39 733.78 N 722.09 3345.30 786.75 N 774.22 3409.57 841.35 N 827.94 3471.14 897.51 N 883.21 3529.91 955.17 N 939.95 3585.83 1014.26 N 998.10 3638.82 1074.70 N 1057.58 3688.82 1136.42 N 1118.32 3702.02 1153.59 N 1135.22 Geographic Coordinates Latitude / Longitude 70.21.33.0719 70.21.33.4224 70.21.33.7939 70.21.34.1859 70.21.34.5979 70.21.35.0294 70.21.35,4800 70.21.35.9491 70.21.36.4360 70.21.36.9402 70.21.37.4612 70.21.37.9981 70.21.38.5505 70.21.39.1176 70.21.39.6987 N 148.28.40.9806 N 148.28.42.0060 N 148.28.43.0927 148.28.44.2394 148.28.45.4448 148.28.46.7074 N 148.28.48.0256 N 148.28.49.3978 N 148.28.50.8224 148.28.52.2976 148.28.53.8217 148.28.55.3927 148.28.57;0088 148.28.58.6679 148.29.00.3682g 70.21.40.2932 N 148.'29.02.1074 70.21.40.9003 N 148.29.03.8835 70.21.41.0691 N 148.29.04.3776 3749.66 1216.26 N 1196.89 g 70.21.41.6855 3797.30 1278.93 N 1258.56 ~ 70.21.42.3018 3844.94 1341.60 N 1320.23 g 70.21.42.9182 3892.58 1404.26 N 1381.89 3940.22 1466.93 N 1443.56 3948.00 1477.17 N 1453.64 N 148.29.06.1809 N 148.29.07.9842.g N 148.29.09.7876 70.21.43.5345 N 148.29.11.5909 70.21.44.1508 N 148.29.13.3943 70.21.44.2515 N 148.29.13.6889 ~" 3987.86 1529.60 N 1505.23 g 70.21.44.7672 4035.50 1592.27 N 1566.90 g 70.21.45.3835 4083.14 1654.94 N 1628.57 ~ 70.21.45.9999 4130.78 1717.60 N 1690.24 W 70.21.46.6162 4178.42 1780.27 N 1751.91 g 70.21.47.2326 4226.06 1842.94 N 1813.58 ~ 70.21.47.8489 4273.70 1905.61 N 1875.25 ~ 70.21.48.4653 4321.34 1968.28 N 1936.92 ~ 70.21.49.0816 4368.98 2030.94 N 1998.59 W 70.21.49.6980 4416.62 2093.61 N 2060.26 ~ 70.21.50.3143 4464.26 2156.28 N 2121.93 ~ 70.21.50.9307 4511.90 2218.95 N 2183.60 g 70.21.51.5470 4525.00 2236.18 N 4559.54 2281.61 N 4607.18. 2344.28 N 2200.56 2245.27 2306.94 N 148.29.15.1977 N 148,29.17.0011 N 148.29.18.8045 N 148.29.20.6080 N 148.29.22.4114 N 148.29.24.2149 148.29.26.0184 148.29.27.8219 148.29.29.6254 N 148.29.31.4289 N 148.29.33.2325 N 148.29.35.0360 70.21.51.7165 N 148.29.35.5320 70.21.52.1634 N 148.29.36.8396 70.21.52.7797 N 148.29.38.6432 GRID Coordinates Northing Easting (ft) (ft) 5983293.96 687362.55 5983328.71 687326.60 5983365.54 687288.50 Ctosure Dist. Dir. (ft) deg. 477.67 g 315.46 527.67 g 315.46 580.66a 315.46 5983404.40 687248.30 5983445.24 687206.04 5983488.03 687161.77 636.58 ~ 315.46 695.35 ~ 315.46 756.91 ~ 315.46 5983532.70 687115.56 5983579.20 687067.46 5983627.48 687017.51 821.19 a 315.46 888.10 g 315.46 957.56 g 315.46 5983677.47 686965.80 5983729.12 686912.37 5983782.35 686857.30 1029.49 g 315.46 1103.80 ~ 315.46 1180.40 ~ 315.46 5983837.12 686800.65 1259.20 ~ 315.46 5983893.35 686742.49 1340.10 g 315.46 5983950.96 686682.89 1423.00 ~ 315.46 5984009.90 686621.92 1507.80 ~ 315.46 5984070.09 686559.66 1594.40 ~ 315.46 5984086.83 686542.35 1618.48 ~ 315.46 5984147.94 686479.14 1706.41 g 315.46 5984209.05 686415.93 1794.33 ~ 315.46 5984270.17 686352.72 1882.25 ~ 315.46 5984331.28 686289.51 1970.18 ~ 315.46 '. 5984392.39 686226.30 2058.10 ~ 315.46 5984402.37 686215.98 2072.46 g 315.46 5984453.50 686163.10 2146.02 ~) 315.46 5984514.62 686099.89 2233~94 ~ 315.46 5984575.73 686036.69 2321.87 ~ 315.46 5984636.85 685973.48 2409.79 ~ 315.46 5984697.96 685910.27 2497.71 ~ 315.46 5984759.08 685847.07 2585.63 ~ 315.46 5984820.19 685783.87 2673.56 ~ 315.46 5984881.31 685720.66 2761.48 g315.46 5984942.43 685657.46 2849.40 ~ 315.46 5985003.54 685594.26 2937.33 ~ 315.46 5985064.66 685531.06 3025.25 ~ 315.46 5985125.78 685467.85 3113.17 ~ 315.46 5985142.59 685450.47 3137.35 ~ 315.46 5985186.90 685404.65 3201.09 g 315.46 5985248.02 685341.45 3289.02 ~ 315.46 Verticat DLS Section (ft) (dg/lOOft) 477.67 2.00 527.67 2.00 580.66 2.00 636.58 2.O0 695.35 2.00 756.91 2.00 821.19 2.00 888.10 2.00 957,56 2,00 1029.49 2,00 1103.80 2.00 1180.40 2.00 1423.00 2.00 1507.80 2.00 1594.40 2.00 1618.48 2.00 1706.41 0.00 1794.33 0.00 1882.25 0.00 1970.18 0.00 2058.10 0.00 2072.46 0.00 2146:o2 o.oo 2233.94 0.00 2321.87 O,On 2409.79 0.~. 2497.71 0.00 2585.63 0.00 2673.56 0.00 2761.48 0.00 2849.40 0.00 2937.33 0.00 3025.25 0.00 3113.17 0.00 3137.35 0.00 3201.09 0.00 3289.02 0.00 mith International, Inc. i.-'I oposal t~eport Page 3 Date: 12/18/92 Wet(path ID: NP-O3UP rasured lnct Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) 6327.47 61.55 315.46 4706.82 6427.47 61.55 315.46 4754.46 6527.47 61.55 315.46 4802.10 6627.47 61.55 315.46 4849.74 6727.47 61.55 315.46 4897.38 6827.47 61.55 315.46 4945.02 6927.47 61.55 315.46 4992.66 15 6947.07 61.55 315.46 5002.00 7027.47 61.55 315.46 5040.30 7127.47 61.55 315.46 5087.94 7227.47 61.55 315.46 5135.58 7327.47 61.55 315.46 5183.22 7427.47 61.55 315.46 5230.86 7527.47 61.55 315.46 5278.50 7627.47 61.55 315.46 5326.14 7¢27.47 61.55 315.46 5373.78 7827.47 61.55 315.46 5421.42 7927.47 61.55 315.46 5469.06 8027.47 61.55 315.46 5516.70 8127.47 61.55 315.46 5564.34 8227.47 61.55 315.46 5611.98 8327.47 61.55 315.46 5659.62 8427.47 61.55 315.46 5707.26 8527.47 61.55 315.46 5754.90 8627.47 61.55 315.46 5802.54 8727.47 61.55 315.46 5850.18 8827.47 61.55 315.46 5897.82 8927.47 61.55 315.46 5945.46 9027.47 61.55 315.46 5993.10 9127.47 61.55 315.46 6040.74 9227.47 61.55 315.46 6088.38 9327.47 61.55 315.46 6136.02 9427.47 61,55 315.46 6183.66 9527.47 61.55 315.46 6231.30 9627.47 61.55 315.46 6278.94 9727.47 61.55 315.46 6326.58 9827,47 61.55 315.46 6374.22 9927.47 61.55 315.46 6421.86 10027.47 61.55 315.46 6469.50 10127.47 61.55 315.46 6517.14 10227.47 61.55 315.46 6564.78 Subsea T 0 T A L Depth Rectangutar Offsets (ft) (ft) (ft) 4654.82 2406.95 N 2368.61 4702.46 2469.62 N 2430.28 4750.10 2532.29 N 2491.95 4797.74 2594.95 N 2553.62 4845.38 2657.62 N 2615.29 4893.02 2720.29 N 2676.96 4940~66 2782.96 N 2738.63 4950.00 2795.24 N 2750.72 4988.30 2845.63 N 2800.30 5035.94 2908.29 N 2861.97 5083.58 2970.96 N 2923.64 5131.22 3033.63 N 2985.31 5178.86 3096.30 N 3046.98 5226.50 3158.97 N 3108.65 5274.14 3221.63 N 3170.31 5321.78 3284.30 N 3231.98 5369.42 3346.97 N 3293.65 5417.06 3409.64 N 3355.32 5464.70 3472.31 N 3416.99 5512.34 3534.97 N 3478.66 5559.98 3597.64 N 3540.33 5607.62 3660.31 N 3602.00 5655.26 3722.98 N 3663.67 5702.90 3785.65 N 3725.34 5750.54 3848.31 N 3787.01 5798.18 3910.98 N 3848.68 5845.82 3973.65 N 3910.35 5893.46 4036.32 N 3972.02 5941.10 4098.98 N 4033.69 5988.74 41'61.65 N 4095.36 6036.38 4224.32 N 4157.03 6084.02 4286.99 N 4218.70 6131.66 4349.66 N 4280.37 6179.30 4412.32 N 4342.04 6226.94 4474.99 N 4403.71 6274.58 4537.66 N 4465.38 6322.22 ~600.33 N 4527.05 6369.86 4663.00 N 4588.72 6417.50 4725.66 N 4650.39 6465.14 4788.33 N 4712.06 6512.78 4851.00 N 4773.73 Geographic Coordinates Latitude / Longitude 70.21.53.3960 N 148.29,40.4468 70.21.54.0124 N 148,29,42.2504 70.21.54.6287 N 148.29,44.0540 70.21.55.2451N 148.29,45.8577 70.21.55.8614 N 148.29.47.6614 70.21.56.4778 N 148.29.49.4650 70,21.57.0941N 148.29.51.2687 70,21.57.2150 N 148.29.51.6223 70.21.57.7105 N 148.29.53.0724 70,21.58.3268 N 148.29.54.8762 70.21.58.9432 N 148.29.56.6799 70,21.59.5595 N 148.29.58.4837 70.22.00.1759 N 148.30.00.2874 70.22.00.7922 N 148.30;02.0912 70.22.01.4085 N 148.30.03.8950 70.22.02.0249 N 148.30.05.6988 70.22.02.6412 N 148.30.07.5027 70.22.03.2576 N 148.30.09.3065 70.22.03.8739 N 148.30.11.1104 70.22.04.4903 N 148.30,12.9142 70.22.05.1066 N 148.30.14.7181 70.22.05.7230 N 148.30.16.5220 70.22.06.3393 N 148.30.18.3260 70.22.06,9557 N 148.30.20.1299 70.22.07,5720 N 148.30.21.9338 70.22.08.1884 N 148.30.23.7378 70.22.08,8047 N 148.30.25.5418 70.22.09.4210 70.22.10.0374 70.22.10.6537 70.22.11.2701 70.22.11.8864 70.22.12.5028 70.22.13,1191 70.22.13.7355 70.22.14.3518 70.22.14.9682 70.22.15.5845 70.22.16.2008 70.22.16.8172 70.22.17.4335 N 148.30.27.3458 N 148.30.29.1498 N 148.30.30.9538 N 148.30.32.7579 N 148.30.34.5619 N 148.30.36.3660 N 148.30.38.1701 N 148.30.39.9742 N 148.30.41.7783 N 148.30.43.5824 N 148.30.45.3866 N 148.30.47.1907 N 148.30.48.9949 N 148.30.50.7991 GRID Coordinates Ctosure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. 5985309.14 685278.25 3376.94 a 315.46 5985370.26 685215.05 3464.86 ~ 315.46 5985431.38 685151.85 3552.79 a 315.46 5985492.50 685088.66 3640.71 a 315.46 5985553.63 685025.46 3728.63 a 315.46 5985614.75 684962.26 3816.55 ~ 315.46 5985675.87 684899.06 3904.48 ~ 315.46 5985687.85 684886.67 3921.71 ~ 315.46 5985737.00 684835.87 3992.40 a 315.46 5985798.12 684772.67 4080.32 a 315.46 5985859.24 684709.47 4168.24 a 315.46 5985920.37 684646.28 4256.17 g 315.46 5985981.50 684583.09 4344.09 g 315.46 5986042.62 684519.89 4432.01 ~ 315.46 5986103.75 684456.70 4519.94 a 315.46 5986164.88 684393.51 4607.86 a 315.46 5986226.01 684330.31 4695.78 a 315.46 5986287.13 684267.12 4783.70 a 315.46 5986348.26 684203.93 4871.63 a 315.46 5986409.39 684140.74 4959.55 a 315.46 5986470.52 684077.55 5047.47 a 315.46 5986531.65 684014.36 5135.40 a 315.46 5986592.78 683951.17 5223.32 ~ 315.46 5986653.92 683887.98 5311.24 ~ 315.46 5986715.05 683824.79 5399.16 g 315.46 5986776.18 683761.60 5487.09 a 315.46 5986837.31 683698.42 5575.01 a 315.46 5986898.45 683635.23 5662.93 a 315.46 5986959.58 683572.04 5750.86 a 315.46 5987020.72 683508.86 5838.78 a 315.46 5987081.85 683445.67 5926.70 a 315.46 5987142.99 683382.49 6014.62 a 315.46 5987204.12 683319.30 6102.55 a 315.46 5987265.26 683256.12 6190.47 ~ 315.46 5987326.40 683192.94 6278.39 ~ 315.46 '5987387.54 683129.75 6366.31 ~ 315.46 5987448.67 683066.57 6454.24 a 315.46 5987509.81 683003.39 6542.16 g 315.46 5987570.95 682940.21 6630.08 g 315.46 5987632.09 682877.03 6718.01 a 315.46 5987693.23 682813.85 6805.93 ~ 315.46 Vertica[ DLS Section (ft) (dg/lOOft) 3376.94 0.00 3464.86 0.00 3552.79 0.00 3640.71 0.00 3728.63 0.00 3816.55 0.00 3904.48 0.00 3921.71 0.00 3992.40 0.00 4080.32 0.00 4168.24 0.00 4256.17 0.00 4344.09 0.~, ,,) 4432.01 0.00 4519.94 0.00 4607.86 0.00 4695.78 0.00 4783.70 0.00 4871.63 0.00 4959.55 0.00 5047.47 0.00 5135.40 0.00 5223.32 0.00 5311.24 0.00 5399.16 0.00 5487.09 0.00 5575.01 0.00 5662.93 O, "- 5750.86 O, 5838.78 O.Ou 5926.70 0.00 6014.62 0.00 6102.55 0.00 6190.47 0.00 6278.39 0.00 6366.31 0.00 6454.24 0.00 6542.16 0.00 6630.08 0.00 6718.01 0.00 6805.93 0.00 mith International, Inc. Proposal Report Page 4 Date: 12/18/92 Wettpath ID: NP-O3WP rasured Inc[ Depth (ft) (deg.) Drift TVD Dir. (deg.) (ft) 315.46 6612.43 315.46 6632.00 315.46 6660.07 315.46 6707.71 315,46 6755,35 315,46 6802,99 315,46 6850,63 315,46 6898.27 315,46 6945,91 315,46 6993,55 315.46 7041,19 315.46 7088.83 315,46 7136.47 315,46 7184.11 315,46 1231,75 0327,47 61.55 WEST SAK 0368,56 61.55 0427,47 61,55 0527,47 61.55 0627.47 61.55 0727,47 61.55 0827.47 61,55 0927,47 61.55 1027.47 61.55 1127.47 61.55 1227.47 61.55 1327,47 61,55 1427.47 61.55 1527,47 61.55 1627.47 61,55 10 1628.00 61.55 315.46 7232.00 1727.47 61,55 315,46 7279,39 1827,47 61.55 315,46 7327,03 1927,47 61,55 315.46 7374,67 2027.47 61.55 315,46 7422.31 2127.47 61.55 315,46 7469.95 2227,47 61.55 315.46 7517.59 2327.47 61.55 315,46 7565,23 2427.47 6~,55 315,46 7612,87 Subsea T 0 T A L Depth Rectangutar Offsets (ft) (ft) (ft) 6560,43 4913,67 N 4835,40 6580,00 4939,42 N 4860.74 6608,07 4976,34 N 4897,07 6655,71 5039.00 N 4958.74 6703,35 5101,67 N 5020.40 6750,99 5164,34 N 5082.07 6798~63 5227,01N 5143,74 6846,27 5289,68 N 5205,41 6893,91 5352,34 N 5267.08 6941,55 5415.01N 5328.75 6989,19 5477.68 N 5390,42 7036,83 5540,35 N 5452.09 7084,47 5603,02 N 5513,76 7132,11 5665,68 N 5575,43 7179,75 5728,35 N 5637.10 7180,00 5728,68 N 5637.43 7227,39 5791,02 N 5698.77 7275,03 5853,69 N 5760.44 7322.67 5916,36 N 5822,11 7370.31 5979.02 N 5883.78 7417,95 6041.69 N 5945.45 7465,59 6104.36 N 6007.12 7513,23 6167,03 N 6068,79 7560,87 6229,69 N 6130.46 2527.47 61.55 315,46 7660.51 7608,51 6292.36 N 6192.13 2627.47 61,55 315,46 7708,15 7656,15 635'5,03 N 6253.80 2727,47 61.55 315,46 7755,79 7703,79 6417.70 N 6315,47 2827,47 61,55 315,46 7803,43 7751,43 6480,37 N 6377,14 2927.47 61,55 315,46 7851,07 7799,07 6543,03 N 6438,81 3027.47 61,55 315,46 7898,71 7846,71 6605,70 N 6500.48 3127,47 61,55 315,46 7946,35 7894,35 6668,37 N 6562,15 3227,47 61,55 315,46 7993,99 7941,99 6731,04 N 6623.82 3327,47 61,55 315.46 8041,63 7989.63 6793,71 N 6685.49 IMP ISLAND 3349,24 61,55 315,46 8052,00 8000.00 6807,35 N 6698.91 3427.47 61.55 315,46 8089,27 8037,27 6856,37 N 6747,16 3527,47 61,55 315.46 8136,91 8084,91 6919,04 N 6808,83 61.55 61.55 315,46 8152,00 8100,00 6938,89 N 6828,36 315.46 8177,00 8125,00 6971.78 N 6860.72 5 3559,14 3611.62 Geographic Coordinates Latitude / Longitude 70.22.18.0499 N 148,30,52,6033 70,22,18.3031 N 148,30,53,3446 70,22,18,6662 N 148,30,54,4075 70.22.19.2826 N 148,30,56.2118 70.22.19.8989 N 148.30,58,0160 70.22.20,5153 N 148.30,59,8203 70;22.21.1316 N 148,31,01,6246 70.22.21,7480 N 148,31,03,4289 70.22.22.3643 N 148,31,05,2332 70.22.22.9807 N 148.31,07.0375 70.22.23.5970 N 148,31,08.8419 70.22.24.2133 N 148,31,10,6462 70.22.24,8297 N 148,31,12,4506 70.22,25.4460 N 148,31,14,2550 70.22.26,0624 N 148,31,16,0594 70.22.26.0657 N 148,31,16,0690 70.22.26.6787 N 148,31,17,8638 70.22.27.2951 N 148.31,19.6682 70.22.27.9114 N 148,31.21,4727 70.22,28.5278 N 148.31,23.2771 70.22.29.1441 N 148.31.25.0816 70.22.29.7605 N 148.31.26.8861 70.22.30,3768 N 148.31,28,6906 70,22,30,9931 N 148,31,30,4952 70.22.31,6095 N 148.31,32.2997 70,22,32,2258 N 148.31,34,1042 70.22.32.8422 N 148,31,35,9088 70.22.33,4585 N 148,31,37,7134 70.22,34,0749 N 148.31,39,5180 70,22,34,6912 N 148,31,41,3226 70.22.35.3076 N 148,31,43,1272 70.22,35,9239 N 148,31,44,9319 70.22.36.5403 N 148.31.46.7366 70.22,36.6744 N 148,31,47,1294 70.22.37,1566 N 148,31,48,5412 70.22,37,7729 N 148,31,50,3459 70,22.37.9682 'N 148.31,50,9176 70.22.38.2916 N 148.31.51.8646 GRID Coordinates Northing Easting Dist. (ft) (ft) (ft) 5987754,37 682750,67 6893.85 5987779,50 682724,71 6929,98 5987815,51 682687,49 6981,77 5987876,66 682624.31 7069,70 5987937.80 682561,13 7157,62 5987998,94 682497,95 7245,54 5988060,09 682434,77 7333,47 5988121,23 682371,60 7421,39 5988182,37 682308,42 7509,31 5988243.52 5988304.66 5988365,81 682245.25 7597,23 682182,07 7685,16 682118,90 7773,08 5988426.96 682055.72 7861.00 5988488.10 681992.55 7948.92 5988549.25 681929.37 8036.85 Ctosure Dir. deg, ~ 315.46 a 315.46 la 315.46 la 315.46 la 315.46 la 315.46 la 315.46 la 315.46 la 315.46 , , la 315.46 ia 315.46 la 315,46 la 315,46 la 315,46 la 315,46 · 5988549,58 681929.04 8037,31 5988610.40 681866,20 8124.77 5988671,55 681803,03 8212.69 5988732,70 681739,86 8300.62 5988793.85 681676.69 8388,54 5988855.00 681613.52 8476.46 5988916.15 681550.35 5988977,30 681487,18 5989038,45 681424,01 8564.38 8652.31 8740.23 5989099.60 681360,84 8828,15 5989160,76 681297.67 8916,08 5989221,91 681234.50 9004,00 5989283,06 681171,33 9091,92 5989344,22 681108,17 9179,84 5989405,37 681045,00 9267,77 5989466,53 680981,84 9355,69 5989527,68 680918.67 9443,61 5989588.84 680855,51 9531,54 la 315,46 la 315,46 la 315,46 la 315,46 a 315.46 a 315,46 la 315,46 la 315,46 la 315.46 la 315,46 la 315,46 la 315,46 la 315,46 la 315,46 la 315,46 la 315,46 la 315,46 la 315,46 5989602,15 5989650,00 5989711,16 680841,76 9550,67 la 315,46 680792,34 9619,46 la 315,46 680729,18 9707,38 la 315,46 5989730,53 680709,17 9735.23 la 3.i5,46 5989762.62 680676.02 9781,37 a 315.46 Vertical DLS Section (ft) (dg/lOOft) 6893°85 0.00 6929.98 0.00 6981.77 0.00 7069.70 0.00 7157.62 0.00 7245,54 0.00 7333.47 0.00 7421.39 0.00 7509.31 0.00 7597.23 0.00 7685.16 O.OP · 7775.08 0.{ ) 7861.00 0.00 7948.92 0.00 8036.85 0.00 8037.31 0.00 8124.77 0.00 8212.69 0.00 8300,62 0.00 8388.54 0.00 8476.46 0.00 8564.38 0.00 8652.31 0.00 8740°23 0.00 8828.15 0.00 8916.08 0.00 9004.00 O,~ ) 9091.92 0.00 9179.84 0.00 9267.77 0.00 9355.69 0.00 9443.61 0.00 9531.54 0.00 9550.67 0.00 9619.46 0.00 9707.38 0.00 9735.23 O. O0 9781.37 0.00 Smith International, Inc. I~roposal Report Page 5 Date: 12/18/92 ~ettpath ID: #P-O3~P Measured lnc[ Drift TVO Depth Dir. (ft) (deg.) (deg.) (ft) 13627.47 61.55 315.46 8184.55 KINGAK 13664.10 61.55 315.46 8202.00 13727.47 61.55 315.46 8232.19 Subsea T 0 T A L Depth Rectangutar Offsets (ft) (ft) (ft) 8132.55 6981.71 N 6870.49 8150.00 7004.66 N 6893.08 8180.19 7044.38 N 6932.16 13827.47 61.55 315.46 8279.83 8227.83 7107.05 N 6993.83 13927.47 61.55 315.46 8327.47 8275.47 7169.71 N 7055.50 14027.47 61.55 315.46 8375.11 8323.11 7232.38 N 7117.17 14127.47 61.55 315.46 8422.75 8370.75 7295.05 N 7178.84 14227.47 61.55 315.46 8470.39 8418.39 7357.72 N 7240.51 14327.47 61.55 315.46 8518.03 8466.03 7420.39 N 7302.18 14427.47 61.55 315.46 8565.67 14527.47 61.55 315.46 8613.31 14627.47 61.55 315.46 8660.95 14727.47 61.55 315.46 8708.59 14827.47 61.55 315.46 8756.23 14927.47 61.55 315.46 8803.87 15027.47 61.55 315.46 8851.51 15127.47 61.55 315.46 8899.15 15227.47 61.55 315.46 8946.79 ~-5/8" CSG PT/SAG RI 15301.37 61.55 15327.47 61.55 ;HUBLIK 15427.32 61.55 15427.47 61.55 15527.47 61.55 tARGET- ZONE 4 15553.26 61.55 VER 315.46 8982.00 315.46 8994.43 315.46 9042.00 315.46 9042.07 315.46 9089.71 315.46 9102.00 315.46 9149.64 315.46 9197.28 315.46 9244.92 15653.26 61.55 15753.26 61.55 15853.26 61.55 ZONE 3 15889.11 61.55 15953.26 61.55 ZONE 2 15973.07 61.55 16053.26 61.55 16153.26 61.55 ;AVIK 16224.96 61.55 8513.67 7483.05 N 7363.85 8561.31 7545.72 N 7425.52 8608.95 7608.39 N 7487.19 16324.96 61.55 16424.96 61.55 FOTAL DEPTH 16434.87 61.55 8656.59 7671.06 N 7548.86 8704.23 7733.73 H 7610.53 8751.87 7796.39 N 7672.20 8799.51 7859.06 N 7733.87 8847.15 7921.73 N 7795.54 8894.79 7984.40 N 7857.21 8930.00 8030.71 N 7902.79 8942.43 8047.06 N 7918.88 8990.00 8109.64 N ~980.46 8990.07 8109.73 N 7980.55 9037.71 8172.40 N 8042.22 9050.00 8188.56 N 8058.12 9097.64 8251.23 N 8119.79 9145.28 8313.90 N 8181.46 9192.92 8376.57 N 8243.13 315.46 9262.00 9210.00 8399.04 N 8265.24 315.46 9292.56 9240.56 8439.24 N 8304.80 315.46 9302.00 9250.00 8451.65 N 8317.02 315.46 9340.20 9288'.20 8501.90 N 8366.47 315.46 9387.84 9335.84 8564.57 N 8428.14 315.46 9422.00 9370.00 8609.51 N 8472.36 315.46 9469.64 9417.64 8672.17 N 8534.03 315.46 9517.28 9465.28 8734.84 N 8595.70 315.46 9522.00 9470.00 8741.05 N 8601.81 Geographic Coordinates Latitude / Longitude 70.22.38.3893 N 148.31.52.1506 70.22.38.6151 N 148.31.52.8117 70.22.39.0056 N 148.31.53.9553 70.22.39.6220 N 148.31.55.7601 70.22.40.2383 N 148.31.57.5648 70.22.40.8547 N 148.31.59.3696 70.22.41.4710 N 148.32.01.1744 70.22.42.0874 N 148.32.02.9792 70.22.42.7037 N 148.32.04.7840 70.22.43.3201 N 148.32.06.5888 70.22.43.9364 N 148.32.08.3937 70.22.44.5527 N 148.32.10.1985 70.22.45.1691 N 148.32.12.0034 70.22.45.7854 N 148.32.13.8083 70.22.46.4018 N 148.32.15.6132 70.22.47.0181 N 148.32.17~4181 70.22.47.6345 N 148.32.19.2230 70.22.48.2508 N 148.32.21.0280 70.22.48.7063 N 148.32.22.3619 70.22.48.8672 N 148.32.22.8329 70.22.49.4826 N 148.32.24.6352 70.22.49.4835 N 148.32.24.6379 70.22.50.0998 N 148.32.26.4429 70.22.50.2588 N 148.32.26.9085 70.22.50.8752 N 148.32.28.7135 70.22.51.4915 N 148.32.30.5185 70.22.52.1079 N 148.32.32.3235 70.22.52.3288 N 148.32.32.9707 70.22.52.7242 N 148.32.34.1286 70.22.52.8463 N 148.32.34.4863 70.22.53.3405 N 148.32.35.9337 70.22.53.9569 N 148.32.37.7388 70.22.54.3988 N 148.32.39.0331 70.22.55.0152 N 148.32.40.8382 70.22.55.6315 N 148.32.42.6433 70.22.55.6926 N 148.32.42.8221 GRID Coordinates Northing Easting Dist, (ft) (ft) (ft)' ,. 5989772.31 680666.01 9795.30 5989794.72 680642.88 9827.51 5989833.47 680602.85 9883.23 5989894.63 680539.69 9971.15 ~ 5989955.79 680476.53 10059.07 5990016.95 680413.37 10146.99 ~ 5990078.11 680350.21 10234.92 5990139.27 680287.05 10322.84 5990200.43 680223.89 10410.76 5990261.60 680160.73 10498.69'~ 315.46 5990322.76 680097.57 10586.61 ~ 315.46 5990383.92 680034.41 10674.53 ~ 315.46 5990445.09 679971.25 10762.45 '~ 315.46 5990506.25 679908.10 10850.38 ~ 315.46 5990567.41 679844.94 10938.30 ~ 315.46 5990628.58 679781.78 11026.22 ~ 315.46 5990689.75 679718.63 11114.15 ~ 315.46 5990750.91 679655.47 11202.07 ~ 315.46 5990796.12 679608.80 11267.05 ~ 315.46 5990812.08 679592.32 11289.99 ~ 315.46 C[osure Vertica[ DLS Dir. Section deg. (ft) (dg/lOOft) 315.46 315.46 315.46 315.46 315.46 315.46 315.46 315.46 315.46 5990873.15 679529.26 11377,78 a 315.46 5990873.25 679529.16 11377.91 ~ 315.46 5990934.41 679466.01 11465.84 ~ 315.46 5990950.19 679449.72 11488.51 @ 315.46 5991011.36 679386.57 11576.44 ~ 315.46 5991072.53 679323.42 11664.36 ~ 315.46 5991133.70 679260.26 11752.28 ~ 315.46 5991155.63 679237.62 11783.80 a 315.46 5991194.87 679197.11 11840.21 a 315.46 5991206.99 679184.60 11857.63 ~ 315.46 5991256.04 679133.96 11928.13 ~ 315.46 5991317.21 679070.81 12016.05 ~ 315.46 5991361.07 679025.53 12079.09 a 315.46 5991422.24 678962.38 12167.02 ~ 315.46 5991483.42 678899.23 12254.94 ~ 315.46 5991489.48 678892.98 12263.65 ~ 315.46 9795.30 0.00 9827.51 0.00 9883.23 0.00 9971.15 0.00 10059.07 0.00 1O146.99 0.00 10234.92 0.00 10322.84 0.00 10410.76 0.00 10498.69 " 10586.61 10674.53 0.00 10762.45 o.oo 10850.38 0.00 1O938.30 0.00 11026.22 0.00 11114.15 0.00 11202.07 0.00 11267.05 0.00 11289.99 0.00 11377.78 0.00 11377.91 0.00 11465.84 0.00 1i488.51 0 ~q 11576.44 ~,.~o' 11664.36 0.00 11752.28 0.00 11783.80 0.00 11840.21 0.00 11857.63 0.00 11928.13 0.00 12016.05 0.00 120~.09 0.00 12167.02 0.00 12254.94 0.00 12263.65 0.00 Smith International, Inc. Travelling Cylinder Report ~rnputed by the Sii Win-CADDS System Page 1 Date: 12/17/92 Least Distance Method REFERENCE WELL: Prudhoe Say Drifting NORTH PRUDHOE BAY STATE #3 TVD, N/S and E/W are measured fro~ the UELLHEAD Yellpath SLot Distance Direction Closest Points Ref MD Ref TVD ubeach01 ~8CH01 90.51 90.69 50.00 50.00 ubeachla ~BCH01 90.51 90.69 50.00 50.00 ubeach02 ~BCH02 22.04 220.85 1000.64 1000.00 wl:x:h03 WBCH03 210.07 90.35 300.00 300.00 wbchO3a- WBCH03 210.07 90.35 300.00 300.00 wbchO3b ~8CH03 210.25 90.19 250.00 250.00 ~B-O4M~JD ~BCH04 29.80 89.53 450.00 450.00 npbst02 NPBst-02 265.94 207.36 8307.27 5650.00 P~udhoe Bo, y ]3pilLinb NI'-]~TH PIRU~HFIE ~AY STATE :t1:3 Tmeve~Lincj Cy~indeP - Lees~c Dis~cence Re~emence We~L - NP-O3~/P TVD: 0 - 9470 ~±, AL~ Dimec~cions Re~ ~co Tmwe Nom±h 1~° 3~0o 4~0 acc I ISmITHI I00 7~o 270° 255° 240° 225° 210~ 180o 165° 150° ~ ~5° 0% CLI'ISE ST I:q~llNl S ] ~¢atpolm Slot D,$tonce ,,OeocmOl ~I ~.5~ ~3 W~3 210.07 ~ W~3 2~0.07 ~ W~3 2~0.~ n~t~ ~B~-~ 265.94 ~06~ 906g 220.8~ 8953 20?.36 Ref MD 50.00 50.00 1000.64 300.00 300.00 45000 8307.27 AnchOrage N. Prudhoe Bay State #3 Casing Design Specifications SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) DEPTHS 1 069000 1300000 (0'-80' TVD) 1556000 1585000 (80'-4000' TVD) Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SIPRF_SSURE 1 4 4000 291 2 Burst S.F. 1.1 8 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt, (ppg) TVD (FT) Collapse press 9.5 4000 1976 Collapse S.F. 1.1 4 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 4844 PBYS Tension S.F. 3.80 Mud Wt. 9.5 ppg TJYS 4.62 String Wt. (#) 281564 N. Prudhoe Bay State #3 Casing Design Specifications Production Casing 9.5/8", 47#, NT-80SS, NSCC Casing GRADE BURST COLLAPSE NT-80SS 6870 4750 PBYS (#) TJYS (#) 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SR'P 3420 Burst S.F. 2.01 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 8982 0.1 3866 Collapse S.F. 1.23 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 15301 PBYS Tension S.F. 1.79 Mud Wt. 10.2 TJYS 1.91 String Wt. (#) 607032 N. Prudhoe Bay State #3 Casing Design Specifications PRODUCTION LINER 7", 26#, NT-80SS, NSCC Casing GRADE BURST NT-80SS 541 0 COLLAPSE PBYS (#) TJYS (#) 7240 604000 667000 Burst Pressure Calculation Burst rating based on 9.7 formation pressure with no backup at surface SITP Fluid wt (ppg) back up (ppg) Burst Pressure 3420 9.7 9.5 3512 Burst S.F. 1.54 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 10.2 9522 0.1 4098 Collapse S.F. 1.77 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 26 1284 10.2 28179 Tension S.F. PBYS TJYS 21.43 23.67 RECEIVED DEC 1 8 1992 Alaska 0il .& Gas Cons, ~nc!~orage N. Prudhoe Bay State #3 Tubing Design Specifications TUBING 4-1/2", 12.6#, L-80, TDS Tubing GRADE BURST COLLAPSE L-80 8430 7500 TENSION 288,000 Burst Pressure Calculation Burst rating based on formation pressure at surface SITP 3420 Burst S.F. 2.46 Collapse Calculation Collapse rating based on tubing drawdown to 0 psi with fluid weight behind the tubing at 9.7 ppg Mud Wt. (ppg) TVD (FT) 9.7 9053 Collapse S.F. 1.64 Collapse Press 4566 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 12.6 15500 Mud Wt. 9.7 String Wt. (#) 164853 Tension S.F. 1.75 N. Prudhoe Bay State #3 Cement Volumes Surface String Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor 4844 LEAD (TYPE "E" PERMAFROST) 13 3/8 Yield 2.17 68 Density 1 2 1 6 # sacks 1696 2 TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 400 (3679 Cu. Ft.) (464 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 Intermediate String Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: 9 5/8 47 12850 12 1/4 1.3 Liner LEAD Yield Density # sacks # bbls TAIL (CLASS G) Yield Density # sacks # bbls 1.98 15 0 0 1.16 15.8 889 184 (0 Cu. Ft.) (1031 Cu. Ft.) Liner Size: Liner Weight: Hole TD Bit Diameter: Excess Factor: 7 26 16435 8.5 1.4 TAIL (CLASS G) Yield Density # sacks 1.2 15.7 268 (322 Cu. Ft.) ~VIUD PROGRAM - N. Prudhoe Bay State #3 ~pUD MUD PROPERTIES 0'-4000' TVD · Density Marsh Vis Yield Pt. 10 sec gel 10 min gel Spud 8.7 300 40-60 30-60 60-80 Mud 9.5 100 20-40 15-20 20-30 9-10 9-10 APl F.Lo 15-25 15-25 Hardness · :<200 <200 INTERMEDIATE HOLE MUD PROPERTIES: 4000' TVD - 8982' TVD Lightly Dispersed FW Polymer Mud Mud Weight PV YP 10 min Gel 10 min Gel 9.5 - 10.2 10-18 8 - 15 6 - 10 10-25 PRODUCTION HOLE MUD PROPERTIES APl Fluid Loss 30-6 cc 9.5-10.0 8982' TVD - 9522' TVD Lightly Dispersed FW Polymer Mud Mud Weight PV YP 10 sec Gel 10 min Gel 10.2-10.4 1 5-20 7-1 2 4-10 10-20 APl Fluid Loss 6-4 cc 9.5-10.0 DEC 1 8 1992 A/asEa 0il & Gas Cons. Commission Anchorage PF'..,DHOE BAY DRILLING GROt.,,- 20" DIVERTER SCHEMATIC POOL 7 / FILL UP LINE J" I FLOWLINE 20" 2000 PS! DIVERTER 10" BALL VALVE 10" BALL VALVE 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 DlVERTER LINE. THE SECOND VENT LINE CAN BE REMOTELY OPENED TO ACHIEVE DOWNWIND DIVERSION. THIS IS A VARIANCE FROM 20AAC25.035. RECEIVED Alaska0ii& Gas Cons. Anchorage ~HOKE WING HCR ~ MANUAL ~cEVOY 4 1/16"-'/0 TfPE E GATE VALVE 5/8"-10,O00PSi HUB × FLANGE ADAPTOR HYDRIL 15 5/8'-5000P51 GK ANNULAR BOP LATCHED HEAD 15 5/8'-10,000PSi HUB BOTTOM CONNECTION HYDRIL I3 5/~'- I O, O00PSI MPL R/W BOP HUB CONNECTIONS ~ 1/16"- 10,000PS! SIDE OUTLETS HYDRIL 15 5/8"- I O, O00PSI YPL RAM BOP HUB CONNECTIONS ~. 1/16"-10,000PSi SIDE OUTLETS t,t~iUAL HCR LTNN INTERNA~O~£ 3 1/16'-~0,000PSI CHECK VALVE KILL WING McEVOY 5 1/16"-10,000PSI TYPE E GATE VALVE HYDRIL 13 5/8'- 10, O00PSI MPL RAM BOP HUB CONNECTIONS 4 1/16'-10,000PSi SIDE OUTLETS BLOW-OUT PREVENTER STACK PAA RiP, 7 4 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re.' The application of ARCO Alaska, Inc. for exception to 20 AAC 25.055 to allow drilling the ARCO North Prudhoe Bay State No. 3 exploratory oil well. ARCO Alaska, Inc. by correspondence dated November 24, 1992 has requested an exception to the provisions of 20 AAC 25.055(a)(1) for the drilling of an exploratory oil well in the Prudhoe Bay Field. The exception would allow drilling the ARCO North Prudhoe Bay State No. 3 exploratory oil well to a location closer than 500 feet from a quarter section line. The proposed surface location is 70 feet from the south line (FSL), 3,490 feet from the east line (FEL) of Section 25, T12N, R14E, Umiat Meridian, the proposed target location is 2301 feet from the north line (FNL), 980 feet FEL of Section 22, T12N, R14E, Umiat Meridian, and the proposed bottom-hole location is 1,856 feet FNL and 1,420 feet FEL of Section 22~ T12N, R14E, Umiat Meridian. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 pm December 21, 1992 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on January 5, 1993 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after December 21, 1992. If no protest is filed, the Commission will consider the issuance of the order without a hearing. Russell A. Douglass ~ Commissioner Alaska Oil and Gas Conservation Commission Published December 5, 1992 ARCO Alti~ka, ln¢, ' . Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 November 24, 1992 Exxon Corporation P.O. Box 2180 Houston, TX 77252-2180 Attn.: David Steingreabaer RE: Notice of Request for Exception to the Provisions of 20 ACC 25,055 ,)./~t~ ¢0 North Prudhoe Bay State No. 3 c~ Prudhoe Bay, Alaska Department of Natural Resources Oivision of Oil and Gas P,O. Box 107054 Anchorage, AK 99616 Attn: James E. Eason, Director ~ '~ '~ .,, Pursuant to the provisions of 20 AAC 25.055 (b), ARCO AlaSka, Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission (AOGCC) for an exception to the well speoing requirements of 20 AAC 25.055 for the drilling of the North Prudhoe Bay State No. 3 well. ARCO's request if approved, will permit the drilling and completion of the North Prudhoe Bay State No. 3 well as a directional hole within 250' of the following locations: · Surface Location: 70'FSL, 3490'FEL of Sec. 25, T12N, R14E, UM; · Target Location: 2301'FNL, 980'FEL of Sec. 22, T12N, R14E, UM; · Bottom Hole: 1856'FNL, 1420'FEL of Sec. 22, T12N, R14E, UM. A plat showing the location of the subject well, leasehold ownership, and all other completed and drilling wells in the area is attached as Exhibit 1. Should you have any questions, please call the undersigned at (907) 265-6914. Si ncer. eJy, /. /~///u_eni.°r ~Ftan JRW:sdb~ Exhibit 2 North Prudhoe Bay State No. 3 Well Request for Spacing Exception Worklna Interest Owners Exxon Corporation P,O, Box 2180 Houston, TX 77252-2180 Attn.: Mr, David E. Steingreaber Royalty Owners - State of Alaska Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Attn.: James E. Eason, Director Overrldina Roveltv__Owners -- - Not Applicable ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 November 24, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 30001 Porcupine Dr. Anchorage, AK 99501 RE: Request for Exception to the Provisions of 20 AAC 25.055 (Drilling units and well space) _/ ARCO- North Prudhoe Bay State No. 3 Exploratory Oil Well Prudhoe Bay Area, Alaska ~ ~'~ Dear Chairman Johnston' ;OMM ~ ;[ES ENG SR ENG SR ENG I ENG ASST I ENG ASST I SR GEOL~ GEOL AS~_~LT.~/L* GEOL ASSTI~ STAT TECH I STAT TECHt FILE I. ARCO Alaska, Inc. ("ARCO") hereby applies for an exception to the provisions of 20 AAC 25.055 for the drilling and completion of ARCO's North Prudhoe Bay State No. 3 Exploratory Oil Well (the "Well"). The Well will be drilled as a directional hole within 250' of the following locations: · Surface Location' 70'FSL, 3490'FEL of Sec. 25, T12N, R14E, UM; · Target Location:2301'FNL, 980'FEL of Sec. 22, T12N, R14E, UM; · Bottom Hole: 1856'FNL, 1420'FEL of Sec. 22, T12N, R14E, UM. A plat showing the location of the well, leasehold ownership, and all other completed and drilling wells in the area is attached as Exhibit 1. The names and addresses of all owners and operators of the governmental quarter sections directly and diagonally offsetting the proposed drilling unit for the well are set forth in Exhibit 2. Included in Exhibit 3 is the verification required by the referenced provisions. A copy of the notice sent to the owners and operators listed in Exhibit 2, with the date such notice was mailed. If you have any questions or require any additional information, please contact the undersigned at (907) 265-6914. Sincerer, // /Senior L?~an JRW:sdb~ Attachments RECEIVED NOV 2 7 199 Alaska 0il & Gas Cons. ComCSS~O~ Anchorag~ ARCO Alaska, Inc. is ~ Subsidiary of Atlantic Richfield Company ~~, ~r~ t /// ..x ~ ....... m-~.xxos --__ ~ ~'~ '~ ~ ~ ~ ___~__. A~ 862 - ~ON ~ ADL ~ ~~,, ~DHOEBAYSri l[ ~3:~4 I ~ ~~ 863 .~,. I _ , WEST BEACH,~/ ~__~ .......... ~ ..... ~ v~- ~ ~,, / / ~ . J./ ,o~~ ,,~ I ~--~~ I ~6 ~ o-2o-75 ~ '~7 ~ ~ 23 , ~i ,,o . ~ LXnlDI{ 1 t T~2N . ," , ~ SPACING LO~ON ~-o~ I T~ ~ ~ EXCEP~ON REQU~ ~ " ~ ~ I 7 ~ A~CO ALASKA INC D~te Nov, 199~ AK92 112501 AOu Exhibit 2 North Prudhoe Bay State No. 3 Well Request for Spacing Exception Workinq Interest Owners Exxon Corporation P.O. Box 2180 Houston, TX 77252-2180 Attn.: Mr. David E. Steingreaber Royalty Owners State of Alaska Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Attn.: James E. Eason, Director Overridinq Royalty Owners Not Applicable EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) Request of ARCO Alaska, Inc. for ) an Exception to the Provisions ) of 20 AAC 25.055 for North Prudhoe ) Bay State No. 3 Well VERIFICATION OF FACTS AND AFFIDAVIT OF JAMES R. WINEGARNER STATE OF ALASKA THIRD JUDICIAL DISTRICT SS. James R. Winegarner, being first duly sworn, upon oath, deposes and states as follows: 1. My name is James R. Winegarner. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Senior Landman for the well operator, ARCO Alaska, Inc. 3. I am acquainted with the facts associated with the drilling of North Prudhoe Bay State No. 3 exploratory oil well. 4. I have reviewed the application submitted for the exception to 20 ACC 25.055. To the best of my knowledge and belief all facts therein are true and accurate. 5. I have reviewed the plat attached as Exhibit I and it correctly portrays pertinent and required data. 6. Pursuant to 20 AAC 25.055 (b), ARCO Alaska, Inc. ("ARCO"), the well operator, prepared a Notice of Request for Exception to the Provision of 20 AAC 25.055. A copy of this notice is attached hereto. 7. On November 24, 1992, pursuant to 20 AAC 25.055 (b), ARCO sent a copy of said notice by certified mail to the last known address of all owners and operators of governmental quarter sections directly and diagonally offsetting the governmental quarter section of the proposed locations of ARCO's North Prudhoe Bay State No. 3 well. These names and addresses are set forth on Exhibit 2 attached to ARCO's Request for Exception to Provisions of 20 AAC 25.055 dated November 24, 1992. Subscribed and sworn to this 24th day of November, 1992. STATE OF ALASKA ~s R. Win~~-e'r T .'"' ) ss. HIRD JUDICIAL DISTRICT ,~ss. ~/' The foregoing ~.~rt~lq~t~. a.~acknowledged before me this 24th day of November, 1992, by James ~ ~L0~l~r~e~. ~ - ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 November 24, 1992 Exxon Corporation P.O. Box 2180 Houston, TX 77252-2180 Attn.' David Steingreabaer Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Attn: James E. Eason, Director RE: Notice of Request for Exception to the Provisions of 20 ACC 25.055 North Prudhoe Bay State No. 3 Prudhoe Bay, Alaska Pursuant to the provisions of 20 AAC 25.055 (b), ARCO Alaska, Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission (AOGCC) for an exception to the well spacing requirements of 20 AAC 25.055 for the drilling of the North Prudhoe Bay State No. 3 well. ARCO's request if approved, will permit the ddlling and completion of the North Prudhoe Bay State No. 3 well as a directional hole within 250' of the following locations' · Surface Location' 70'FSL, 3490'FEL of Sec. 25, T12N, R14E, UM; · Target Location: 2301'FNL, 980'FEL of Sec. 22, T12N, R14E, UM; °Bottom Hole: 1856'FNL, 1420'FEL of Sec. 22, T12N, R14E, UM. A plat showing the location of the subject well, leasehold ownership, and all other completed and ddlling wells in the area is attached as Exhibit 1. Should you have any questions, please call the undersigned at (907) 255-6914. ~l~s R. W~te'~ner f /,~enior La~d,,~an ARCO Alaska, Inc, is a Subsidiary of Atlantic Richfield Company ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE D/~TE , ( 2 ) Loc ~ ~~ '['2 thru . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. . r (3) Admi~n,, ' [9 thru 13] [10 & 13] 12. 13. [14 thru 22] 15. 16. 17. 18. 19. 20. 21. 22. [23 thru 28] 24. 25. 26. 27. 28. (5) BOPE [29 thrd'31]] 30. 31. (7) Contact ~) 12-:~1-~ 32. [32] (8) Add] /~~~,~-~-~__ 33. geology' eng i nee r i rig' MT~ RAD'~ I~')~ BEW JDH~ f~,~ LG%:-~ ~ , rev 12/92 jo/6.01! Company, YES Is permit fee attached ............................................... L Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... ~. Is sufficient Undedicated acreage available in this pool ............. /~ Is well to be deviated & is wellbore plat included ................... ~ Is operator the only affected party .................................. L Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed · DoesIS leasewell n~nberhave aappr°priateunique name ........................................ ~ AL~nber Is conductor string provided . Will surface casing protect al 1 zones reasonably expected NO REMAR'KS to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all knov~ productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter s-ystem required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter $ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~. psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE , ,, Additional MERIDIAN' remarks' 0 --I 'rZ ,-", 0 UM X SM WELL TYPE' Exp/Dev X In j,, - - Red ri 1 1 Rev 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. a:I BOROUG~ : NORTH SbOPE API Nd~.~BgR : 50-029-22~22-00 cmlumb, er~er AlasKa Computinc Center I~-~AR-]993 07:18 P~Ev!ous ~ E ~!., COS~ENT : ARCO ALASKa~, i~TC.,~XPLORA. TIO~,NORTH PRUDHOE BAY ST, ~],50-029-223 **** T.~PE NE~DE~ **** SERVICE NA~E : EDIT O~IC!U : FDIC T~PE ~'~A~E : 93055 PR F~V ~!: OU8 T ~.P~ : CO~'~UEWT : ARCO AI.ASKA, I~C.,EXPLOR~.TIOM,MORT~ PRUD~OE BAY ST. ~3,50-029-22B ThPF ~E~DER PmUCHOE B~Y UM!T LOG~!MG COMPANY: ST!RWACE LOCAT!OW SECTIOM: TI.,EV~TTO~(FT F~O~ ~S[., O) KELLY BUSHI~}Gt GROUN~ !,EVEL: CASING RECORD I ST STOl PqD ~5 70 1.790 51.90 51.90 t!.40 fl. 5(}0 6 5 !46 .0 PAGE YS Va~e Vet!fi. cation !5~.stin~ r, hlUmber,~er AlasKa Comput.!..nq Center' 12-~!A~-!. 903 07:!8 r~RODUCT.IO~ MIT TO (~ 39.I' ~IT · ~ ASHDO~; !NT~]~VAL ~IATPI~ [)ENSITY ~ 65 (GM/CC). FI, UID DENS~ R[.q, ATIO~4A{,, BULK ~E~'~SITY P~O ESSI. NG ~]SED- BARITE ADDED TO }4UD SYSTEM. DATA. FP[]~,I: DOW~'~HO[,E ~EMORY. DOWNHOLE ~OFTWa~E VERSION V.4.0C. PAGE **** FIL~ HEADE~ **** FILM bi~E ,' EOIT .001 SFRVlCE : FL!C VERSION : 00la07 DATF ~e,,X R~C SIZE : 1024 FIL~} TYPE L~ST FILE FTLS? HEADEP,. EDIT[~D *~AD PASSES Dept~ sblfted and cliDDed curves for each pass of each, run ~,~D PaSS D~PTH ! NC;~ E,~E~T 0.5000 FIb~ DBU TQnL CL')DE CURVE SHI~T DATa. (HEAS~,IRED DEPTH) ~8E!..~YNE DEPTH 16229.5 ~ 6227,0 16206.0 ~6~00.0 1606R.5 16045.0 !5950.5 ~5925.0 15~5. 646 '), 0 .......... EOUIVAI, MMT UNSHIFTED DEPTg--- ....... ~AD !6~29.0 !.6226.0 !6204.0 16146.5 16107.5 !6097.5 I6065.0 16~4~.5 !5o2n.0 .IS ~..a.~e Verl. ficatfon List,.no chlUmhero'~r Alaska ComputincJ Center 07:!8 !5~25.0 ~5~16 o ~.00.0 PBU TOOL CCD~: , .. t581n.5 t5~12.o 15778.0 94.5 ATLAS WIRELINM GR SUPPLIED BY THE CLIENT. ALL CURVES WErE CAR~!ED WITH THE GR SHIFT, $ L~S FORMAT DAT~ ** DATA FOR.*4AT SPECIFICATION RECORD ** 2 66 0 3 73 32 4 66 1. 5 66 6 73 7 65 ~ 69 0,5 9 65 1! 66 32 12 6~ J3 66 0 ~4 65 15 66 68 ~6 66 0 66 [!A,. $~RV ii,Iq' VICK ~P! A I AP:I ~PI ~ b~ [!.~g ~ P~ P~ .S ...P~ FT ~1q028 o0 000 O0 n !. ! I 4 68 0000000000 G~ uaP GaPI 6!~o2fi O0 OOO oo 0 1 ~ I 4 69 0000000000 ~o.? ~aP F/HR 6!~{.)28 O0 000 OO 9 1 I J.. 4 68 OOO0000OO0 D~HO uhD G!C3 61.0028 O0 000 O0 0 ! !. ! 4 68 0000000000 ~uOn ~AO G/C3 61,902~ O0 000 O0 0 I ~ ! 4 68 OOOO000000 :.I,~ Ta~e verification Listinq ehiumberqer AlasKa Comp:]tinq Center 993 07: ~ 8 !64:62 500 GR,~Ai"~ -99q 250 ROP-~A{:' ..... . . .......... . , .~ ~ 69,231 DR~O MA[) · . . ...... ,~' '~.~. ...... ~ ~ ..... -999,250 'PEF ~D ~999 25 .... CAL~,~AD 999 250 N'P~I ~A. 9 16:400,000 G~ ~.D 28,413 ROP,~AD 7],]72 DRMO ~AD " ~,569 DEF~fqAD 3,345 ChLg,~,~D 8.739 !6:300,000 eR, ~ 1~.~08 ROP, r~ O 6~' 811 2.3~9 PFF, ~'AD 2,702 CAE~,~q~D ~54:3 NP~I. ~!A.P r,~ ~4'~[') 21 025 ROP F~AD 76 272 DR~n..~AD 16200,000 ,.~. .... , 2,256 PEF. MAD 2:643 CALM. .... I61.00,000 (;R,?Ai) 251,I25 POP "~:AD 77 53! " ~,7)1, P~F,MA.!) 5,796 C~L~' ' ' '' .... ~.~AD 9:838 NPHI.MAD 16000,000 ~R. ~,~A[) 45, I i7 ROP, ?~.AD 68,052 2,378 PEF, I~AD 2,736 CAL~. ~tAD ~.7.!4 NP~I.~AD 15900.000 GR,~AD 62,897 ROP.HA[) 52,586 2.669 P~F.F~D ~,77~ CALf~, HAD 10.~I9 NDN'I.NAD 1580().000 ~R ~A['~ 9~.527 RO~.~A.D -999 250 D~O.~AD 2.]5© PFP~ ~.AD 4.931 CALN,~qA.D I0~855 .z83 PEF.NAD 5 318 CnLN,~a[) 10 726 NPBI ~A.O DEPT. D:~P? DEPT, DEPT D~P?. -999'250 -999'250 -0,007 -999,250 -0.003 23,600 -0 .007 24'500 . . 0,004 14,450 0.006 23.272 -0.001 20,941 -0.052 50.594 -0.038 47.100 **** FILM TRAILEP **** V!LF N~mE : EDIT ,00! SKRvlcE : WLIC V~S!0~ ~ 001~07 D~TV : 03103!~1 ~aX REC SIZE : V!LF TYPE L~$T PILE : IS Tat~e Veriflcat!,on Listl. no chlum~orcler AlasKa Com,~utino Center 0'7:1,8 PAGE: *~** FILE H~AI)E~ F!L~ NA~E : EDIT $~V!CE : ~L!C ¥~RSIO~ : 00!A07 I)aTF : 93103/11 ~t.X aEC SIZE : !0~4 Flb~ TYPE : LO FILE NU~BER 2 Cu. rves and loo header data for each bit run !n separate f{les, NAD PUN NU~EP: 1 MA9 PISS WU~{BER: ! DFP~H IMCRE'aENT: 0.5000 F!LF SUMM ~,~Y VENDO~ TOOL CODE START OEiPTN CON 1.5950,0 LOG H~ADE~ DATA DATE LOGGED $OFTWApE: SURFACE SOFTWAR~ DOWMHOLE SOFTWARe] VERSION DATA TYP~i TOm t, OG BOTTO~! LOG !NTERVab (FT): BIT ~[}TAT!~;IG SPE.~D ~O!,E tNCT,INITIO~.~ fDE~) M!N'IMU~ ANGLE: TOO[,, ST~!~,IG (TOP TO !3OTTO,':) VENDOI~ TOOL CODE TOCII, TYPE CDN N~U'~ROM/POROSITY ~(.)R'EH(,~L~ A!'{I) CASI~'JG DATA OPFr, I );OLE F~!T SIZE: (Ir'l): D~!LLERS Ct~.S!NG DEPTH ~OF{E;iOt, E Cf!~Jn !'~!O~<~S NIUD TYPE: ~!_)D DENSITY (LB/G): ~UD VISCOSITY (S): ~[tO PH: STDPDEPTH 03-FEB-93 LiP ~.2 V4.0C 16463.0 ~5850.0 16463.0 TOOL NUMBE~ biDS,.') 9 8 · 50O 14619.0 10.50 IS Ta~e Verification Li..sttn~ ch.t. un'~berQer ~!aska Comp~lti. mq Cent. er NEUTROM TOOL MATRIX: HOLM CORRECTION SA N DST~NM ~.65 500 ~EMARKS: *******.*.** RI.IN .,! ****~***** BIT T~ CR 39.1', BIT TS DEN 55,0'. BIT T~'j NM!JT 62 2' WA~'HDOt~N !NTEr~VAL 1,5950' . · 0 ROTATIONAL RLI~K '0~:NSITY P~OCESS~'G USED, B.AR~TE ADDED TO MUD SYSTE'a, DATA FRO~:~ DOWNHO[,E ~4~IMORY, St)FT',,/~RE V~jRSiON 'V4:.OC' LIS FORMAT ** DATA FOR~A.T SPECIFICATII)N PECOR[) ** 2 66 0 3 73 36 ~ 66 ! 5 66 6 73 7 65 9 65 FT 1! 66 ~6 14 65 FT 15 66 68 !6 66 ] 0 6~ I chlumberqer _Alaska Co,'~p.tino Center ORD~]R ~ LOG TYP F T 619028 00 000 GAPI 61902~ 00 OO0 F/HR 61o02~ O0 O00 G/C3 619028 O0 000 G/CB 619029 O0 009 6190~8 O0 000 Ib 6!90~8 O0 000 PU 61902~ O0 O00 PU 81902~ O0 OOO 12-MA.~-1993 07: !!~ O0 0 2 ! 1, 4 68 0000000000 O0 0 2 1 ! 4 68 0000000000 O0 0 2 i 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 00 0 2 ! ! 4 6~ 0000000000 00 0 2 1 ! 4 68 0000000000 00 0 ? 1. ! 4 68 0000000000 00 0 2 1 1 4 6~ 0000000000 OO 0 2 ! I 4 68 0000000000 T~Ptl.LW! -999,250 D~PT 16400°000 GR.LWI RM~bWI, 2.5~8 PEF.I.,wi D~PT 16300 000 Ga.!..,w!, T~PM.LWi 23.400 DFP~. 16200.0¢30 TNPH.LW! T~PP.I,N! 13,200 D~P* 16000.000 n~ bill T~P~.LWI 25.000 D~PT 15900.000 R~O~:LW'I 2.6~6 PE .!,wl TNPH.LWI ~7.500 D~pT. 15800.000 GN.bW1 9HDn'LW1 2.]79 PEF.I,WI T~P..Lwl 45.500 D~PT. 15755.000 GR.Lwl TNP~.bW! -999.250 -999 ~0 ROPg,B~I . 69'~31 -999~ 6 D~,;L'W1 999.250 DPH!.L~! 26 70! ROP'E.Lwl 73 772 DRH0.LW! ~:o24 OCAb'5~l o:~6o lg ~63 ROPE.,b~I 66.665 D~HO LW! ~1 2~ O~h.bwl O.ni4 20 .z4 ROPF,bW! 77 5~6 DRHO 617'75 DCib.bWl ·i. 1542 6!.~72 rOP~.bW!. 70.261 DRHO.[,~! 4,05~ DCIL,bz! J..834 DPH!,L~I 86,297 ~OPg,~l -999.250 4.798 DCBL.LWi ~.~40 -999.250 ROPE:.b~l -999.250 DRHO.LWI -Q99.~50 DCaI.,.LWl -999.250 -999.250 -999.250 -0.012 8.000 '0.002 20.500 00~ ~0 010 - :soo 0 000 o2ooo -0.009 -0.400 -0.033 16.500 -999.250 -999.250 IS Ta~,:e Ver~,ficatioD X, ist!nO cblu.mberqer Alaska ¢~'o~::DutfnO Center i 2-.v~AR-- ] g93 07:18 PAGE: **** FILM TRAILE? FTLM NA~E : EDIT SERVICE : FLIC V~RMION : 00~.A07 D~TK : 93103/1! ~A× REC SIZE : LaS? FILE **** TAPE TRAILER SERVICE NAN~ : EDIT D~TF : 93103111 ,~. ~:~A~.E : 9~055 P~EV!OUS TAmE : COM~EMT : ~RCO ALASKA, INC,,MXPLORATION,MORTM PRUOHOE BAY ST, #3,50-029-223 :**** REEL TRAILE~ **** SERVICE NA~E : EDIT R~B!~ NAME : 93055 CO~ENT : ARCO ALASKA, I~E,,EXP~ORATID~,NORTH PRUDHOE BAY ST, ~3,50-029-223 O ALASKA INC N. PRUDHOE BAY STATE gt3 Run 1' 14 - February - 1993 MAC/OR & (;N/OR Cased Hole 4593 16331 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD N. PRUDHOE BAY ST. 3 500292232200 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 04-MAR-93 5891.03 DAHL/HOSTBJOR PEAK/JORDAN 25 12N 14E 70 1790 51.90 51.90 11.40 MAC/GR & CN/GR GAMMA RAY RECORDED WITH MAC TOOL IS THE DEPTH REFERENCE FOR THIS WELL. MAC/GR: LOG RECORDED TO WIRELINE DEPTH USING MARKS. GAMMA RAY LOGGED TO 14600' (ABOVE 9.625" CASING SHOE) CN/GR: TIED TO MWD LOG. $ $ REMARKS: BASELINE DEPTH PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: EQUIVALENT UNSHIFTED DEPTH MAC GR 1 3 14-FEB-93 ATLAS WIRELINE SERVICES OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 12.250 9.625 14622.0 47.00 PRODUCTION STRING 8.500 7.000 16465.0 29.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS FILE HEADER FILE NUMBER: 1 EDITED CURVES PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY TOOL CODE GR MAC GRCH 2435 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS CURVE CODE: GR PASS NUMBER: 1 START DEPTH 14593.0 15785.0 15644.0 15697.0 BASELINE DEPTH DTC 14485.0 14485.0 15650.0 15660.5 15671.0 15699.5 15700.0 15723.5 15732.0 15734.0 15749.5 15750.0 15753.0 15767.5 15778.0 15789.0 15789.5 15813.5 15828.5 15829.0 15837.0 15835.0 15852.0 15850.5 15852.5 15861.0 15868.5 15880.0 15888.5 15887.0 15895.0 15896.0 15895.5 15902.5 15903.0 15920.0 15930.5 15937.5 15945.0 15944.0 15945.5 15981.5 16039.0 16042.5 16041.0 STOP DEPTH 16273.0 16250.0 16324.0 16331.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH GRCH 14485.0 15647.5 15659.0 15669.5 15698.5 15722. 15733. 15747. 15752. 15766. 15777. 15788. 15812. 15828. 15836. NPHI 14485.0 15700.0 15731.5 15748.0 15777.0 15788.5 15828.5 15852.0 15879.5 15852.0 15860.5 15868.0 15894.5 15894.5 15902.0 15919.0 15929.5 15936.5 15903.0 15945. 15980. 16038. 16041. 16041.5 i6o55.b 16055.5 16058.0 16063.0 16067.5 16071.5 16073.5 16074.0 16090.5 16096.5 16105.5 16106.0 16114.0 16129.5 16140.0 16145.0 16146.5 16163.5 16167.5 16190.5 16191.0 16204.0 16226.5 16436.0 $ REMARKS: CN WN FN COUN STAT 16055.0 16055.5 16056.5 16061.5 16062.0 16066.0 16071.0 16073.5 16074.0 16089.5 16089.5 16095.0 16095.0 16103.5 16105.0 16112.5 16129.5 16128.0 16128.5 16139.5 16143.5 16144.5 16163.0 16168.0 16167.0 16190.5 16190.0 16190.0 16203.0 16203.0 16225.0 16225.0 16436.0 16436.0 16436.0 GR FROM MAC TOOL IS DEPTH REFERENCE. FROM CN PASS. DTS & SCRA WERE SHIFTED WITH DTC. FUCT & NUCT WERE SHIFTED WITH NPHI. $ : ARCO ALASKA INC : NORTH PRUDHOE BAY ST. : WILDCAT : NORTH SLOPE : ALASKA #3 GRCH IS GAMMA RAY * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod GR MAC 68 1 GAPI DTC MAC 68 1 US/F DTS MAC 68 1 US/F SCRA MAC 68 1 GRCH 2435 68 1 GAPI NPHI 2435 68 1 PU-S NUCT 2435 68 1 CPS FUCT 2435 68 1 CPS 4 41 695 68 1 4 41 695 68 1 4 41 695 68 1 4 41 695 68 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 140 Tape File Start Depth = 16436.000000 Tape File End Depth = 14485.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35128 datums Tape Subfile: 2 289 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14593.0 MAC 15785.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE COMR ACOM CENT MACR CENT MACI MACT CENT MACE SLAM GR $ COMMON REMOTE ACOUSTIC COMMON CENTROLLER WTS MAC RECEIVER CENTROLLER WTS MAC ISOLATOR MAC TRANSMITTER CENTROLLER WTS MAC TRANS. ELE. SLAM ADAPTER GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): STOP DEPTH 16273.0 16250.0 14-FEB-93 FSYS REV. J001 VER. 1.1 1910 14-FEB-93 16292.0 16275.0 15700.0 16274.0 1200.0 YES TOOL NUMBER 3510XA 1667EA 1668MA 1668PA 1668BA 1668FA 3516XA 1309XA 8.500 16465.0 0.0 BRINE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOO'L TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : 0.0 REMARKS: MAC/GR POST PROCESSED MAIN PASS DATA. REPEAT PASS DATA WAS NOT PROCESSED & IS NOT INCLUDED ON THIS TAPE. $ CN WN FN COUN STAT : ARCO ALASKA INC : NORTH PRUDHOE BAY ST. #3 : WILDCAT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAC 68 2 DTC MAC 68 3 DTS MAC 68 4 SCRA MAC 68 1 GAPI 4 1 US/F 4 1 US/F 4 1 4 4 41 695 68 1 4 41 695 68 1 4 77 831 86 6 4 41 695 68 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 72 Tape File Start Depth = 16275.000000 Tape File End Depth = 14485.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS'representation code decoding summary: Rep Code: 68 17906 datums Tape Subfile: 3 156 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 15636.0 2435 15650.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 16381.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR CN KNJT KNJT CENT ACOM SBT CENT $ GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT CCL CENTRALIZER ACOUSTIC COMMON SEG. BOND TOOL CENTROLLER WTS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: 07-FEB-93 FSYS REV. J001 VER. 1.1 1320 07-FEB-93 16383.0 16379.0 15270.0 16331.0 1000.0 YES TOOL NUMBER 1309XA 2435XA 3921NA 3921NA 2346XA 1633EA 1424XA 8.500 16465.0 0.0 DRILLING MUD 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 5.50O BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 20 FAR COUNT RATE HIGH SCALE (CPS): 220 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 500 TOOL STANDOFF (IN): 0.0 REMARKS: CN WN FN COUN STAT CN/GR MAIN PASS. CHISM FILTERING ACTIVE. $ : ARCO ALASKA INC : NORTH PRUDHOE BAY ST. #3 : WILDCAT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 2 CNC 2435 68 1 PU-S 3 CN 2435 68 1 PU-L 4 SSN 2435 68 1 CPS 5 LSN 2435 68 1 CPS 6 CCL 2435 68 1 7 SPD 2435 68 1 F/MN 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 83 368 34 1 4 84 023 70 1 4 90 640 78 6 4 54 376 29 5 28 * DATA RECORD (TYPE# 0) Total Data Records: 252 998 BYTES * Tape File Start Depth = 16436.000000 Tape File End Depth = 14485.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 97569 datums Tape Subfile: 4 332 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 15865.0 2435 15919.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 16352.0 16355.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR CN KNJT KNJT CENT ACOM SBT CENT $ GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT CCL CENTRALIZER ACOUSTIC COMMON SEG. BOND TOOL CENTROLLER WTS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: 07-FEB-93 FSYS REV. J001 VER. 1.1 1234 07-FEB-93 16383.0 16379.0 15270.0 16331.0 1000.0 YES TOOL NUMBER 1309XA 2435XA 3921NA 3921NA 2346XA 1633EA 1424XA 8.500 16465.0 0.0 DRILLING MUD 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE MATRIX ~ENSITY: HOLE CORRECTION (IN): 0.00 5.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: CN/GR REPEAT PASS. CHISM FILTERING ACTIVE. $ CN WN FN COUN STAT 20 220 0 500 0.0 : ARCO ALASKA INC : NORTH PRUDHOE BAY ST. #3 : WILDCAT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 2 CNC 2435 68 1 PU-S 3 CN 2435 68 1 PU-L 4 SSN 2435 68 1 CPS 5 LSN 2435 68 1 CPS 6 CCL 2435 68 1 7 SPD 2435 68 1 F/MN 4 4 08 501 10 0 4 4 98 211 23 1 4 4 52 326 75 5 4 4 83 368 34 1 4 4 84 023 70 1 4 4 90 640 78 6 4 4 54 376 29 5 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 73 Tape File Start Depth = 16400.000000 Tape File End Depth = 15839.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35867 datums Tape Subfile: 5 153 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 6 is type: LIS 93/ 3/ 4 01 **** REEL TRAILER **** 93/ 3/ 7 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sun 7 MAR 93 8:59a Elapsed execution time = 37.57 seconds. SYSTEM RETURN CODE = 0 Tape Subfile: 1 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subfile 2 is type: LIS CN WN FN COUN STAT : PRUDHOE BAY DRILLING : N. PRUDHOE BAY STATE #3 : : : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 28 122 23 5 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: ! 77 Tape File Start Depth ~ 16436.000000 Tape File End Depth = 15636.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19207 datums Tape Subfile: 2 81 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER **** **** REEL TRAILER **** 93/ 2/12 01 Tape Subfile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 12 FEB 93 l:03p Elapsed execution time = 4.51 seconds. SYSTEM RETURN CODE = 0 **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** SERVICE NAME: DATE: 93/ 4/17 ORIGIN OF DATA: REEL NAME: CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: ** TAPE HEADER ** SERVICE NAME: DATE: 93/ 4/15 ORIGIN OF DATA: TAPE NAME: CONTINUATION #: O1 PREVIOUS TAPE NAME: COMMENTS: REEL SEQUENCE # 1 OHI:IDI NilAL ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: .001 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: CONFIDENTIAL ** INFORMATION RECORD ** mmmm ON COUN STAT CONTENTS ARCO,ALASKA INCORPORATED N. PRUDHOE BAY STATE #3 WILDCAT NORTH SLOPE ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE SPL REP PROCESS ID ORDER # LOG TYP CLS MOD NO. (OCTAL) DEPT GR MWD RPX MWD RPS MWD RPM MWD RPD MWD ROP MWD FET MWD F *** *** -99 -5 0 4 AAPI 91 948 38 6 0 4 OHMM *** 660 71 6 0 4 OHMM 308 217 19 1 0 4 Of IMM *** 660 71 6 0 4 OHMM *** 660 71 6 0 4 FPHR *** *** -97 -5 0 4 HR 162 202 97 6 0 4 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION (every DEPT FET 5O F 16600.000 -999.250 16550.000 -999.250 COnFIDeNTIAL 16500.000 -999.250 GR RPX RPS RPM RPD ROP 16450.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 16400.000 2.560 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 16350.000 3.040 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 16300.000 2.920 -999.250 -999.250 -999.250 -999.250 16250.000 2.750 -999.250 15.340 16200.000 1.200 20.865 12.965 14.485 14.940 17.430 25.078 16150.000 1.180 71.270 50.100 186.570 695.925 143.400 23.850 16100.000 3.930 296.030 95.590 87.610 101.410 224.340 5.780 16050.000 3.060 82.130 10.000 10.340 10.360 11.760 14.810 16000.000 1.460 48.080 11.540 13.250 13.570 14.610 24.090 15950.000 1.660 73.900 15.940 17.530 17.040 19.770 23.280 15900.000 9.770 70.150 6.980 7.330 7.250 7.690 12.356 15850.000 2.880 100.940 2.510 2.780 3.170 3.460 11.310 15800.000 3.090 102.040 2.770 3.140 3.990 3.960 16.590 15750.000 85.910 4.210 5.310 9.330 9.180 42.600 21.960 11.880 11.540 10.580 12.210 18.880 21. 530 2. 220 2. 020 1. 980 2. 020 16. 280 20.430 2.300 2.000 1.850 1.930 13.906 30.960 2.630 2.480 2.390 2.410 13.030 2.360 15700.000 2.420 15650.000 2.520 15600.000 177.300 15550.000 3.170 15500.000 2.740 15450.000 4.370 15400.000 1.290 15350.000 1.240 15300.000 1.430 15250.000 1.990 15200.000 2.050 15150.000 1.420 15100.000 1.440 15050.000 1.760 15000.000 1.540 14950.000 2.040 14900.000 1.600 14850.000 1.750 14800.000 1.180 83.410 3.050 3.520 COJ J:JDENilAL 4.810 4.560 13.260 85.370 3.480 3.910 5.090 5.030 14.430 97.860 1.550 2.040 3.800 5.480 28.582 100.480 3.450 4.410 6.180 5.600 45.120 95.400 2.830 3.350 4.520 4.190 38.520 89.440 3.550 4.330 5.480 5.750 39.360 91.280 2.990 3.610 4.680 4.280 44.570 99.310 102.995 99.530 92.700 91.850 76 200 88.450 88.990 90.640 2.540 3.020 4.050 4.250 48.930 2.800 3.290 4.500 4.480 56.860 2.350 2.760 3.640 3.720 50.240 2.430 2.890 3.710 3.330 40.230 2.250 2.520 2.760 2.500 55.710 2.970 3.280 3.640 3.830 50.290 2.370 2.650 3.030 3.370 37.830 2.600 2.960 3.850 4.050 51.650 2.750 3.300 4.360 4.510 40.230 2.430 2.980 4.070 3.900 33.300 2.560 3.160 4.490 4.400 48.260 2.560 3.030 4.220 4.210 51.940 89.730 92.390 82. 180 14750.000 86.580 2.360 2.740 3.240 3.450 32.620 2.060 14700.000 1.670 14650.000 2.080 14600.000 1.950 14550.000 1.810 14500.000 1.670 14450.000 1.640 14400.000 1.590 14350.000 .770 14300.000 1.250 14250.000 .920 14200.000 1.690 14150.000 28.420 14100.000 3.350 14050.000 3.820 14000.000 3.230 13950.000 3.100 13900.000 2.120 13850.000 4.070 13800.000 1.830 92.720 1.830 1.880 2.030 2.120 285.331 13750.000 75.390 2.350 2.490 2.570 2.610 25.000 82.290 3.250 3.750 4.320 4.480 28.070 135.050 1.260 1.280 1.050 1.300 101.570 81.640 2.400 2.640 2.650 2.980 83.910 93.420 2.280 2.420 2.790 2.640 56.580 93.290 2.330 2.510 2.910 2.990 51.220 80.700 2.320 2.530 2.830 2.890 20.380 81.510 2.040 2.280 2.700 2.730 19.050 88.060 2.030 2.280 2.480 2.620 19.680 90.140 2.140 2.470 3.050 3.170 39.358 91.680 2.090 2.390 3.070 3.200 18.090 188.400 3.030 3.880 4.980 5.460 48.520 129.550 2.830 3.290 3.800 4.180 51.580 115.670 2.680 3.010 3.180 3.790 83.660 122.490 3.350 4.070 5.340 5.890 46.750 92.580 2.600 3.070 4.050 4.080 32.050 96.470 2.490 2.820 3.530 3.400 38.630 91.790 2.560 3.090 4.210 4.020 51.138 94.809 2.380 2.760 3.640 3.540 51.000 1.890 13700.000 2.620 13650.000 2.630 13600.000 1.700 13550.000 1.460 13500.000 1.560 13450.000 1.730 13400.000 1.080 13350.000 1.260 13300.000 .970 13250.000 1.270 13200.000 1.180 13150.000 1.320 13100.000 1.320 13050.000 1.420 13000.000 1.330 12950.000 1.280 12900.000 1.340 12850.000 1.620 12800.000 1.470 72.690 2.780 2.980 3.070 3.060 26.670 12750.000 80.670 4.140 4.340 4.270 4.680 50.950 100.580 2.520 2.730 2.870 3.050 62.820 106.100 2.570 2.850 3.260 3.250 62.800 101.360 2.540 2.830 3.150 3.790 47.990 91.570 4.420 6.270 6.950 9.860 53.350 93.160 3.870 4.580 4.890 5.750 23.320 123.990 3.200 3.500 3.960 4.460 28.530 113.060 3.950 4.550 4.850 4.900 50.420 113.870 3.940 4.270 4.500 4.600 50.470 96.220 4.760 5.180 5.420 5.660 51.630 111.680 3.740 4.060 4.210 4.390 46.940 88.633 3.410 3.720 4.010 4.060 55.600 86.210 4.480 4.910 5.370 5.390 67.980 91.990 3.720 4.010 4.270 4.530 41.680 81.380 4.070 4.520 4.740 5.060 28.230 96.760 2.280 2.490 2.540 2.690 29.260 55.480 3.240 3.500 3.530 3.690 43.070 73.410 2.810 2.950 3.020 3.210 46.150 76.730 2.830 3.060 3.240 3.480 25.000 1.850 12700.000 20.130 12650.000 1.270 12600.000 1.580 12550.000 1.520 12500.000 1.060 12450.000 1.030 12400.000 1.170 12350.000 1.540 12300.000 2.120 12250.000 1.210 12200.000 3.240 12150.000 1.750 12100.000 2. 680 12050.000 1.820 12000.000 2.300 11950.000 1.520 11900.000 1.190 11850.000 1.370 11800.000 1.280 81.995 4.400 4.740 4.740 4.890 37.430 74.760 80.090 72.590 80.790 96.400 70.170 77.120 77.350 83.620 81.580 77.200 84.640 71.480 80.090 70.500 73.090 70.110 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 79.100 4.740 -999.250 5.840 -999.250 6.910 -999.250 4.390 -999.250 5.890 -999.250 4.450 -999.250 48.470 32.170 67.970 66.930 50.000 70.590 6.540 -999.250 130.960 7.520 -999.250 6.490 -999.250 4.720 -999.250 54.260 67.250 65.010 3.720 -999.250 101.350 4.240 -999.250 4.310 -999.250 3.850 -999.250 3.620 -999.250 3.510 -999.250 4.200 -999.250 3.960 -999.250 43.610 25.850 36.330 50.440 56.410 50.070 44.690 11750.000 80.090 -999.250 -999.250 3.630 -999.250 23.220 2.450 11700.000 2.230 11650.000 1.400 11600.000 1.550 11550.000 1.850 11500.000 2.330 11450.000 1.680 11400.000 16.420 11350.000 17.110 11300.000 2.850 11250.000 2.220 11200.000 2.280 11150.000 1.720 11100.000 1.960 11050.000 1.660 11000.000 1.560 10950.000 1.280 10900.000 1.590 10850.000 1.190 10800.000 2.020 76.620 72.450 69.520 71.070 66.280 49.840 66.640 64.085 63.940 73.830 71.260 70.480 79.750 64.780 68.800 75.640 54.760 52.860 60.690 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.470 -999.250 3.910 -999.250 2.470 -999.250 3.850 -999.250 4.010 -999.250 6.900 -999.250 3.870 -999.250 3.880 -999.250 4.430 -999.250 4.140 -999.250 3.600 -999.250 3.950 -999.250 3.550 -999.250 3.940 -999.250 4.760 -999.250 3.750 -999.250 3.070 -999.250 7.080 -999.250 5.170 -999.250 51.150 48.360 51.830 25.561 44.250 27.700 32.850 20.560 36.610 62.490 33.470 54.970 37.510 43.710 48.170 41.055 38.300 47.130 42.890 10750.000 56.460 -999.250 -999.250 3.990 -999.250 52.840 1.540 10700.000 2.010 10650.000 1.930 10600.000 1.050 10550.000 1.250 10500.000 .510 10450.000 4.320 10400.000 .970 10350.000 1.990 10300.000 1.490 10250.000 .950 10200.000 .990 10150.000 1.850 10100.000 1.300 10050.000 .970 10000.000 .570 9950.000 .350 9900.000 .780 9850.000 1.300 9800.000 .930 73.660 36.330 44.280 38.340 34.530 45.780 61.040 66.830 51.860 40.540 61.630 74.950 41.930 38.800 25.680 23.670 39.330 42.320 38.490 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.890 -999.250 23.020 1.660 -999.250 543.420 3.520 -999.250 39.130 2.620 -999.250 108.470 2.320 -999.250 353.800 2.830 -999.250 139.270 6.450 -999.250 28.330 5.860 -999.250 29.440 4.230 -999.250 62.430 3.520 -999.250 75.730 4.970 -999.250 39.510 6.280 -999.250 30.050 2.410 -999.250 224.758 1.780 -999.250 223.630 1.060 -999.250 368.420 1.030 -999.250 264.680 2.400 -999.250 200.950 2.120 -999.250 ,102.250 2.470 -999.250 198.910 9750.000 42.080 -999.250 -999.250 2.470 -999.250 295.850 .590 9700.000 .680 9650.000 .500 9600.000 .590 9550.000 .630 9500.000 .470 9450.000 .820 9400.000 .780 9350.00-0 .650 9300.000 .990 9250.000 1.140 9200.000 .940 9150.000 .730 9100.000 .260 9050.000 3.580 9000.000 .410 8950.000 .590 8900.OO0 1.690 8850.000 .780 88OO.OOO .290 48.560 45.080 52.360 38.910 30.390 50.800 42.790. -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.715 -999.250 123.170 3.490 -999.250 185.450 3.720 -999.250 104.040 1.540 -999.250 222.310 1.880 -999.250 502.730 3.240 -999.250 208.650 2.030 -999.250 140.990 40.490 -999.250 -999.250 15.740 -999.250 19.460 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 52.210 49.270 64.170 32.180 40.090 27.890 38.560 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 82.700 50.640 48.580 54.230 -999.25O -999.250 -999.250 -999.250 3.330 -999.250 66.670 2.880 -999.250 159.430 3.860 -999.250 76.600 1.360 -999.250 243.820 4.060 -999.250 138.460 1.190 -999.250 475.660 1.680 -999.250 190.210 5.120 -999.250 36.120 2.870 -999.250 262.920 2.320 -999.250 636.330 2.910 -999.250 80.600 8750.000 50.090 -999.250 -999.250 3.380 -999.250 120.840 .720 8700.000 .840 8650.000 .920 8600.000 .300 8550.000 .170 8500.000 .535 8450.000 .330 8400.000 .527 8350.000 .610 8300.000 .470 8250.000 .310 8200.000 .440 8150.000 .380 8100.000 .830 8O5O.OOO .730 8000.000 .430 7950.000 .643 7900.000 1.170 7850.000 .410 7800.000 .250 43.070 45.061 34.550' 38.614 42.570 70.570 34.510 53.400 39.470 42.160 42.310 62.250 66.700 26.970 25.100 83.280 43.280 34.340 40.778 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999'.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.860 -999.250 13.790 3.560 -999.250 164.320 1.650 -999.250 733.010 2.553 -999.250 2095.310 2.740 -999.250 247.270 2.850 -999.250 86.720 1.773 -999.250 127.900 2.340 -999.250 489.550 1.740 -999.250 817.730 2.040 -999.250 1039.750 4.390 -999.250 204.490 2.760 -999.250 204.520 3.130 -999.250 80.070 1.180 -999.250 422.476 1.250 -999.250 743.300 4.340 -999.250 77.823 1.770 -999.250 604.690 1.240 -999.250 725.630 1.160 -999.250 848.670 7750.000 41.168 -999.250 -999.250 1.370 -999.250 1300.780 .245 7700.000 °290 38. 420 -999. 250 -999.250 2.220 -999.250 123.461 7650.000 13.470 62.570 -999.250 -999.250 4.700 -999.250 -999.250 7600.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7550.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 588 DATA RECORDS ** FROM 16600.00 TO 7500.00 FT ** FILE TRAILER** FILE NAME: .001 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** FILE HEADER ** FILE SEQUENCE ~ 2 FILE NAME: .002 SERVICE NAME: VERSION ~: DATE: MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** INFORMATION RECORD ** MNEM CN WN FN COUN STAT CONTENTS ARCO ALASKA INCORPORATED N. PRUDHOE BAY STATE #3 WILDCAT NORTH SLOPE ALASKA ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE SPL REP PROCESS ID ORDER DEPT GR MAD RPX MAD RPS MAD RPM MAD RPD MAD RATE MAD FET MAD LOG TYP CLS MOD NO. F *** *** -99 -5 0 4 AAPI *** 433 96 6 0 4 OHMM *** *** 0 0 0 4 OHMM *** 702 77 1 0 4 OHMM *** *** 0 0 0 4 OHMM *** *** 0 0 0 4 FPHR *** *** 0 0 0 4 HR *** 688 55 6 0 4 (OCTAL) 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION (every DEPT GR RPX FET 16500.000 -999.250 50 F ) ** RPS 16450.000 -999.250 RPM RPD RATE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 16400.000 -999.250 -999.250 -999.250 16350.000 23.460 2.900 21.350 16300.000 19.220 3.030 24.620 16250.000 20.356 16.550 28.130 16200.000 21.490 11.130 29.020 16150.000 39.070 12.645 30.450 16100.000 245.870 92.580 45.560 16050.000 72.900 10.120 48.970 16000.000 45.050 10.240 51.050 15950.000 66.720 12.350 52.860 15900.000 68.570 7.180 62.700 15850.000 92.970 2.210 66.580 15800.000 -999.250 -999.250 -999.250 ** 46 DATA RECORDS ** ** FILE TRAILER** -999.250 -999.250 -999.250 80.900 2.410 2.070 2.030 95.900 2.510 2.150 2.090 108.360 15.480 13.000 11.780 106.300 11.190 11.440 14.330 114.430 136.825 81.488 83.630 106.400 101.840 107.970 301.520 100.490 10.780 10.470 12.080 113.210 10.990 11.600 14. 150 118. 850 12.780 13.710 17.290 112.720 7.880 7.710 8.140 68.920 2.740 3.610 3.840 125.840 -999.250 -999.250 -999.250 -999.250 FROM 16500.00 TO FILE NAME: SERVICE NAME: VERSION ~: .002 15800.00 FT HAX. RECORD LEMGTH: FILE NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 3) ********** ** FILE HEADER ** FILE SEQUENCE # 3 FILE NAME: .003 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** INFORMATION RECORD ** CN WN FN COUN STAT CONTENTS ARCO ALASKA INCORPORATED N. PRUDNOE BAY STATE #3 WILDCAT NORTH SLOPE ALASKA ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES ) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE SPL REP PROCESS ID ORDER # LOG TYP CLS MOD NO. (OCTAL) DEPT GR MWD RPM MWD ROP MWD FET MWD F *** *** -99 -5 0 4 AAPI 91 948 38 6 0 4 OHMM *** 660 71 6 0 4 FPHR *** *** -97 -5 0 4 HR 162 202 97 6 0 4 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION (every DEPT GR RPM 11406.000 -999.250 -999.250 11400.000 66.040 3.930 11350.000 69.980 3.680 11300.000 64.770 4.950 11250.000 68.030 4.590 11200.000 74.410 3.610 11150.000 73.630 3.620 11100.000 65.960 3.620 11050.000 66.190 4.080 11000.000 75.670 4.880 10950.000 72.890 3.640 10900.000 55.750 3.200 10850.000 68.700 6.580 10800.000 60.060 5.090 10750.000 50.790 5.780 10700.000 78.170 4.960 10650.000 33.580 1.480 10600.000 46.130 3.040 10550.000 38.120 2.950 10500.000 37.000 2.530 10450.000 46.590 2.320 10400.000 66.260 6.230 10350.000 65.060 5.960 10300.000 49.520 3.840 10250.000 50.150 3.580 10200.000 58.220 4.880 10150.000 68.390 6.820 50F) ROP -999.250 32.750 32.045 52.780 41.230 32.810 38.600 37,750 62.550 49.800 34.950 130.960 23.090 38.310 165.710 24.610 266.940 66.670 88.320 278.550 99.670 24.140 18.960 97.870 77.340 42.270 51.430 FET -999. 250 16.440 17.210 2.7O0 2.190 2.240 1.700 1.960 1.620 1.550 1.480 1.600 1.240 2.040 1.550 2.110 1.870 1.060 1.230 .500 4.320 1.040 1.990 1. 450 .940 1.020 1.860 10100.000 10050.000 10000.000 9950.000 9900.000 9850°000 9800.000 9750.000 9700.000 9650.000 9600.000 9550.000 9500.000 9450.000 9400.000 9350.000 9300.000 9250.000 9200.000 9150.000 9100.000 9050.000 9000.000 8950.000 8900.000 8850.000 8800.000 8750.000 8700.000 39.120 36.900 23.110 20.450 50.740 39.070 37.580 45.990 27.630 43.250 59.850 31.520 37.810 46.360 52.820 40.450 61.140 51.870 63.440 28.520 39.260 50.870 36.490 75.490 56.870 47.590 60.510 44.820 41.560 2.170 1.520 .960 1.100 2.58O 1.690 2.280 1.600 1.500 2.240 4.210 1.400 1.990 3.240 2.540 11.020 4.410 2.460 3.880 1.170 2.460 1.880 1.820 4.830 2.830 4.040 3.400 3.020 3.120 347.090 454.690 397.620 348.630 79.810 111.720 95.850 336.700 222.100 198.700 86.370 463.620 156.340 150.050 106.050 94.020 49.320 186.860 39.130 276.620 114.700 282.330 170.510 30.830 126.930 313.590 89.232 85.968 83.660 1.340 .950 .500 .340 .8O0 .940 .920 .540 .680 .480 .600 .630 .440 .830 .690 .78O 1.030 1. 150 .820 .700 .250 3.580 .400 .700 1.680 .730 .320 .730 1.010 8650.000 44.130 3.630 116.810 .930 8600.000 45.330 1.840 8550.000 38.565 2.093 8500.000 57.440 2.600 8450.000 73.700 3.130 8400.000 44.580 1.797 8350.000 44.250 2.290 8300.000 45.080 1.890 8250.000 41.867 1.680 8200.000 54.860 3.210 8150.000 53.810 2.240 8100.000 48.250 3.470 8050.000 26.600 1.180 8000.000 30.320 1.260 744.140 .280 1254.200 .163 1878.520 .540 81.180 .340 139.840 .543 425.740 .600 1006.350 '460 988.770 .280 136.380 .440 576.810 .360 90.700 .850 663.510 .720 889.750 .370 7950.000 83.970 4.280 73.930 1.080 7900.000 35.650 1.560 513.280 1.030 7850.000 34.770 1.240 7800.000 42.640 1.464 7750.000 48.750 1.400 7700.000 46.973 2.025 7650.000 39.340 4.840 992.290 .390 530.420 .212 1009.420 .240 99.889 .300 -999.250 13.470 7600.000 -999.250 -999.250 -999.250 -999.250 7550.000 -999.250 -999.250 -999.250 -999.250 7500.000 -999.250 -999.250 1024 157 DATA RECORDS ** ** FILE TRAILER** FILE NAME: .003 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: -999.250 -999.250 FROM 11406.00 TO 7500.00 FT ********** END OF FILE (EOF # 4) ********** ** FILE HEADER ** FILE SEQUENCE ~ 4 FILE NAME: .004 SERVICE NAME: VERSION #: DATE'. MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** INFORMATION RECORD ** mm, mm STAT CONTENTS mm~m~--mm ARCO ALASKA INCORPORATED N. PRUDHOE BAY STATE #3 WILDCAT NORTH SLOPE ALASKA ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API aPI aPI FILE SZE SPL REP PROCESS ID ORDER # LOG TYP CLS MOD NO. (OCTAL) DEPT GR MWD RPM MWD ROP MWD FET MWD F *** *** -99 -5 0 4 AAPI 91 948 38 6 0 4 OHMM *** 660 71 6 0 4 FPHR *** *** -97 -5 0 4 HR 162 202 97 6 0 4 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION DEPT 12742.000 12700.000 12650.000 12600.000 12550.000 12500.000 12450.000 12400.000 12350.000 12300.000 12250.000 12200.000 12150.000 12100.000 12050.000 12000.000 11950.000 11900.000 11850.000 11800.000 11750.000 11700.000 11650.000 11600.000 11550.000 11500.000 11450.000 GR -999.250 72.630 79.040 85.420 72.920 94.960 75.690 83.700 79.830 75.290 64.150 87.620 80.430 72.110 74.610 74.690 75.000 83.240 77.490 72.100 71.930 77.940 68.280 62.780 67.670 53.620 ( every RPM -999.250 5.000 4.910 5.860 6.750 4.220 5.550 3.830 6.430 7.590 6.560 7.000 3.680 4.180 3.970 3.790 3.400 3.550 4.070 3.940 3.600 3. 500 3.950 3.330 3.880 4.060 6.060 50F) ROP -999.250 125.230 50.440 32.460 68.870 65.650 77.750 75.000 66.780 52.480 71.140 38.400 178.370 37.320 58.030 35.890 52.240 58.630 51.510 30.167 28.120 52.580 46.570 49.860 23.624 43.190 30.230 FET -999.250 20.070 1.290 1.600 1.500 1.020 1.050 1.160 1.510 2.120 1.210 3.290 1.830 2.640 1.840 2.300 1.490 1.180 1.370 1.320 2.540 2.190 1.400 1.540 1.900 2.310 1.720 ** 54 DATA RECORDS ** FROM 12742.00 TO 11406.00 FT ** FILE TRAILER** FILE NAME: .004 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 5) ********** ** FILE HEADER ** FILE SEQUENCE # 5 FILE NAME: .005 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** INFORMATION RECORD ** CN WN FN COUN STAT CONTENTS ARCO ALASKA INCORPORATED N. PRUDHOE BAY STATE #3 WILDCAT NORTH SLOPE ALASKA ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE SPL REP PROCESS ID ORDER # LOG TYP CLS MOD NO. (OCTAL) DEPT GR MWD RPX MWD RPS MWD RPM MWD RPD l/WI) ROP MWD FET MW-D F *** *** -99 -5 0 4 AAPI 91 948 38 6 0 4 OHMM *** 660 71 6 0 4 OHMM 308 217 19 1 0 4 OHMM *** 660 71 6 0 4 OHMM *** 660 71 6 0 4 FPHR *** *** -97 -5 0 4 HR 162 202 97 6 0 4 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION (every DEPT FET GR RPX 14198.000 -999.250 50F) RPS 14150.000 28.520 14100.000 3.330 RPM 14050.000 3.940 14000.000 3.260 93.570 2.140 2.560 3.310 3.230 20.230 13950.000 3.050 146.910 3.050 3.660 4.710 4.780 15.810 13900.000 1.990 133.000 2.640 3.140 4.140 4.550 74.670 13850.000 4.220 119.190 3.260 3.950 4.790 5.060 46.747 13800.000 1.790 130.370 3.340 4.040 5.340 5.820 42.860 13750.000 1.940 73.450 2.410 2.540 2.570 2.610 24.000 13700.000 2.630 73.280 2.850 3.070 3.240 3.390 23.230 13650.000 2.620 74.530 2.940 3.240 3.420 3.590 28.800 13600.000 1.650 78.290 3.440 3.710 3.560 3.880 47.370 13550.000 1.450 56.970 2.950 3.200 3.480 3.480 43.070 13500.000 1.610 96.170 2.710 2.920 3.120 3.140 52.880 13450.000 1.690 105.000 2.550 2.730 3.070 3.030 65.010 13400.000 1.070 99.520 2.340 2.580 2.960 3.090 61.670 13350.000 98.020 3.200 3.770 4.760 5.100 69.780 86.740 2.300 2.650 3.160 3.470 13.500 81.780 2.190 2.430 2.830 2.740 18.740 78.040 1.990 2.240 2.640 2.690 18.690 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.260 13300.000 .970 94.380 5.680 7.040 9.980 13250.000 1.320 88.460 5.760 6.760 7.860 7.820 48.840 13200.000 1.180 110.790 3.350 3.670 3.800 3.790 32.660 13150.000 1.330 111.400 3.950 4.340 4.570 4.790 47.220 13100.000 1.330 106.420 4.220 4.580 4.600 4.850 68.190 13050.000 1.410 105.310 4.230 4.580 4.970 4.970 38.570 13000.000 1.340 115.670 3.880 4.240 4.490 4.580 49.510 12950.000 1.280 86.250 3.920 4.240 4.480 4.480 53.150 12900.000 1.350 83.210 4.010 4.290 4.480 4.660 54.360 12850.000 1.440 82.160 3.700 4.010 4.220 4.360 62.321 12800.000 1.470 89.120 4.120 4.610 4.690 4.680 48.000 12750.000 1.830 80.600 4.290 4.630 4.650 4.820 55.507 ** 94 DATA RECORDS ** FROM 14198.00 TO 12742.00 FT ** FILE TRAILER** FILE NAME: .005 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 6) ********** ** FILE HEADER ** FILE SEQUENCE # 6 FILE NAME: .006 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** INFORMATION RECORD ** CN WN FN COUN STAT CONTENTS ARCO ALASKA INCORPORATED N. PRUDHOE BAY STATE #3 WILDCAT NORTH SLOPE ALASKA ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE SPL REP PROCESS ID ORDER # LOG TYP CLS MOD NO. (OCTAL) DEPT GR MWD RPX MWD RPS MWD RPM MWD RPD MWD ROP MWD FET MWD F *** *** -99 -5 0 4 AAPI 91 948 38 6 0 4 OHMM *** 660 71 6 0 4 OHMM 308 217 19 1 0 4 OHMM *** 660 71 6 0 4 OHMM *** 660 71 6 0 4 FPHR *** *** -97 -5 0 4 HR 162 202 97 6 0 4 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION (every DEPT GR RPX FET 50 F ) RPS RPM RPD ROP 15627.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 15600.000 90.650 1.510 177.450 15550.000 95.090 3.500 3.150 15500.000 97.020 2.750 2.740 15450.000 91.920 4.270 4.330 15400.000 93.430 2.840 1.320 15350.000 93.130 2.550 1.250 15300.000 103.130 2.760 1.440 15250.000 97.210 2.400 1.990 15200.000 90.670 2.340 1.910 15150.000 105.390 2.120 1.420 15100.000 72.590 3.070 1.440 15050.000 83.500 2.420 1.770 15000.000 95.360 2.480 1.520 1.910 3.240 4.350 37.350 4.260 5.440 6.070 42.970 3.320 4.470 4.320 40.230 5.130 6.650 6.880 44.160 3.390 4.360 4,290 55.880 3.070 4.190 3.890 60.350 3.310 4.440 4.710 58.400 2.870 4.000 3.850 50.290 2.800 3.510 3.280 39.790 2.490 3.090 2.970 54.050 3.470 3.860 4.000 48.930 2.930 4.310 3.900 36.350 3.040 4.460 4.660 52.480 3.590 5.650 5.060 42.800 2.780 3.860 3.800 31.490 2.960 4.190 4.150 48.010 14950.000 83.510 2.840 2.040 14900.000 93.250 2.340 1.650 14850.000 98.470 2.440 1.720 14800.000 87.580 2.550 2.990 3.850 3.930 53.250 1.170 14750.000 2.090 82.810 2.260 2.530 34.160 14700.000 2.080 90.300 1.820 1.890 2.010 2.000 23.670 14650.000 1.980 94.600 2.590 3.080 3.750 4.080 54.290 14600.000 2.120 92.490 2.620 3.200 4.400 4.110 43.674 14550.000 1.840 87.300 2.550 2.990 3.930 4.080 36.590 14500.000 1.650 94.750 2.770 3.180 4.040 4.080 63.580 14450.000 1.670 87.050 2.860 3.370 3.950 3.520 54.470 14400.000 1.560 107.050 2.490 2.680 2.810 2.820 124.740 14350.000 .780 79.490 2.290 2.590 3.060 3.200 66.530 14300.000 1.230 104.800 1.950 2.130 2.500 2.510 76.500 14250.000 .930 94.870 2.330 2.550 2.990 3.030 45.830 14200.000 1.800 78.390 2.310 2.540 2.840 2.870 20.725 ** 93 DATA RECORDS'** FROM 15627.00 TO 14198.00 FT ** FILE TRAILER** FILE NAME: SERVICE NAME: VERSION #: DATE' e MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: .006 1024 ********** END OF FILE (EOF # 7) ********** ** FILE HEADER ** FILE SEQUENCE # 7 FILE NAME: .007 SERVICE NAME: VERSION #: DATE' MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** INFORMATION RECORD ** CN WN FN COUN STAT CONTENTS ARCO ALASKA INCORPORATED N. PRUDHOE BAY STATE #3 WILDCAT NORTH SLOPE ALASKA ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE SPL REP PROCESS ID ORDER # LOG TYP CLS MOD NO. (OCTAL) DEPT GR MWD RPX MWD RPS MWD RPM MWD RPD MWD ROP MWD FET MWD F *** *** -99 -5 0 4 AAPI 91 948 38 6 0 4 Of{MM *** 660 71 6 0 4 O}{MM 308 217 19 1 0 4 OHMM *** 660 71 6 0 4 OHMM *** 660 71 6 0 4 FPHR *** *** -97 -5 0 4 HR 162 202 97 6 0 4 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION (every DEPT GR RPX FET 16470.000 -999.250 -999.250 -999.250 16450.000 -999.250 -999.250 -999.250 16400.000 18.450 3.540 19.990 16350.000 20.670 2.580 3.100 16300.000 20.270 3.240 2.880 16250.000 21.300 12.810 2.570 16200.000 25.060 11.480 1.340 16150.000 83.800 27.170 12.270 16100.000 109.610 95.640 3.970 16050.000 80.800 9.380 2.640 16000.000 44.980 13.140 1.390 15950.000 226.840 10.470 1.620 15900.000 62.630 8.710 10.630 15850.000 111.250 2.890 2.810 15800.000 100.550 2.840 2.950 15750.000 108.580 3.080 2.200 15700.000 108.730 2.750 2.480 50 F ) RPS RPM RPD ROP -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12.030 3.160 2.790 2.690 11.020 2.250 2.110 2.170 13.540 3.010 2.860 2.940 11.840 12.670 12.190 13.860 17.650 12.670 13.430 17.010 28.100 26.340 25.280 25.910 11.510 88.850 81.240 123.160 21.830 10.140 10.020 11.340 7.340 14.550 14.180 14.770 24.877 11.800 12.210 15.260 22.170 8.830 9.230 10.030 4.120 3.280 4.140 4.110 13.510 3.380 4.920 4.520 27.000 3.590 4.960 4.840 15.190 3.360 5.070 4.870 15.610 15650.000 105.110 3.030 3.320 4.090 4.160 11.300 2. 550 55 DATA RECORDS ** FROM 16470.00 ** FILE TRAILER** FILE NAME: .007 SERVICE NAME: VERSION #: DATE: MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 8) ********** ** FILE HEADER ** FILE SEQUENCE # 8 FILE NAME: .008 SERVICE NAME: VERSION #: DATE' · MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** INFORMATION RECORD ** CN WN FN COUN STAT CONTENTS ARCO ALASKA INCORPORATED N. PRUDHOE BAY STATE #3 WILDCAT NORTH SLOPE ALASKA ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 12 4 68 -999.25 16 1 66 1 0 0 65 DESCRIPTION LOG DIRECTION, UP ABSENT VALUE SPECIFICATION BLOCK SUB-TYPE TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE SPL REP PROCESS ID ORDER DEFT GR MAD RPX MAD RPS MAD RPM MAD RPD MAD RATE MAD FET MAD LOG TYP CLS MOD NO. F *** *** -99 -5 0 4 AAPI *** 433 96 6 0 4 OHMM *** *** 0 0 0 4 OHMM *** 702 77 1 0 4 OHMM *** *** 0 0 0 4 OHMM *** *** 0 0 0 4 FPHR *** *** -39 -5 0 4 HR *** 688 55 6 0 4 (OCTAL) 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 1 68 ******000000 ** DATA VERIFICATION DEPT FET 16500.000 -999.250 16450.000 -999.250 16400.000 -999.250 16350.000 21.730 16300.000 24.850 16250.000 28.300 16200.000 29.240 16150.000 41.250 16100.000 46.030 16050.000 49.270 16000.000 51.210 15950.000 53.010 15900.000 63.740 15850.000 66.920 15800.000 -999.250 GR (every 50 F RPX RPS -999.250 -999.250 -999.250 RPM -999.250 RPD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 RATE -999.250 -999.250 96.960 17.780 3.470 2.870 2.390 2.260 95.200 20.830 4.150 3.490 2.920 2.890 109.620 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 89.460 2.120 2.900 4.370 4.570 130.680 65.130 8.020 8.990 10.010 10.960 51.450 ** 46 DATA RECORDS ** FROM 16500.00 TO ** FILE TRAILER** FILE NAME: SERVICE NAME: VERSION #: .008 189.750 9.410 9.750 10.090 13.280 110.430 46.790 10.520 10.980 11.830 14.500 109.520 15800.00 FT 87.620 11.250 12.870 13.380 16.550 108.250 147.700 81.360 91.850 85.770 171.730 180.880 93.910 24.390 24.860 26.120 32.230 119.340 20.840 11.090 11.570 11.810 14.670 106.400 20.820 19.640 17.530 14.610 14.490 105.270 DATE: MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 9) ********** ** TAPE TRAILER** SERVICE NAME: DATE: 93/ 4/15 ORIGIN OF DATA: TAPE NAME: CONTINUATION #: NEXT TAPE NAME: COMMENTS: 01 ** REEL TRAILER ** SERVICE NAME: DATE: 93/ 4/17 ORIGIN OF DATA: REEL NAME: CONTINUATION #: NEXT REEL NAME: COMMENTS: 01 ********** TAPE TERMINATED BY REEL TRAILER **********