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189-013
Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:189-013 6.50-029-21912-00-00 PRUDHOE BAY, PT MCINTYRE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12600 12558 9301 11834 none none 8619 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 34 - 112 34 - 112 1490 470 Surface 5167 13-3/8" 34 - 5201 33 - 4020 5020 2260 Production 11315 9-5/8" 33 - 11348 32 - 8167 6870 4760 Liner 1591 7" 11009 - 12600 7864 - 9341 8160 7020 Perforation Depth: Measured depth: 12032 - 123052 feet True vertical depth:8806 -8824 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 31 - 11929 30 - 8709 12072 - 12106 8843 - 8875 12218 - 12238 11834 8619Packers and SSSV (type, measured and true vertical depth) 8981 - 8999 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 64423587567226 69924516 2085 3075 1556 580 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Kirsty Schultz Kirsty.Shcultz@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:564 - 5258 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9340 Sundry Number or N/A if C.O. Exempt: N / A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0365548 PTM P1-03 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 55 glm straddle patch 4-1/2" Baker S-3 Perm Packer Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.08.04 15:52:14 -08'00' Bo York By Samantha Carlisle at 9:55 am, Aug 06, 2020 9.573 DSR-8/6/2020 SFD 8/10/2020 SFD 8/10/2020RBDMS HEW 8/6/2020 12,845 , ADL0028297, ADL0034622 MGR10AUG2020 SFD 8/10/2020 ACTIVITYDATE SUMMARY 7/8/2020 ***WELL S/I ON ARRIVAL*** (patch tubing / liner) PULLED P-PRONG FROM 11,871' SLM. (tbg pressure went from 750 --> 1050 psi) ATTEMPTED TO PULL PXN-PLUG BODY, S/D HIGH @ 11,871' SLM. MADE 2 RUNS TO 11,871' SLM w/ 10' x 2.5" PUMP BLR. (minimal recovery of fine scale) ***WSR CONTINUED ON 7/9/20*** 7/9/2020 ***WSR CONTINUED FROM 7/8/20*** (patch tubing / liner) RAN 5' x 2.0" DRIVE DOWN BLR TO 11,878' SLM. (1/4 cup returns) RAN 10' x 3.5" PUMP BLR TO 11,878' SLM. (no returns) RAN 4-1/2" GR TO 11,878' SLM, UNABLE TO LATCH. RAN 3.70" LIB TO 11,878' SLM. (light impression of fill) MADE 2 RUNS w/ 10' x 2.5" PUMP BLR TO 11,878' SLM. (metal marks on blr) ***WSR CONTINUED ON 7/10/20*** 7/10/2020 ***WSR CONTINUED FROM 7/9/20*** (patch tubing / liner) RAN 10' x 2.5" PUMP BLR (metal marks) PULLED 4-1/2" PX-PLUG BODY FROM 11,899' MD. DRIFTED w/ 37' x 3.78" 45KB PACKER DRIFT TO 9,500' SLM. ***WSR CONTINUED ON 7/11/20*** 7/11/2020 ***WSR CONTINUED FROM 7/10/20*** (patch tubing / liner) MADE 2 ATTEMPTS TO PULL ST# 3 @ 9,130' MD. (marks on btm of tool indicated empty pocket) RAN 1.25" LIB TO ST# 3 @ 9,130' MD TO CONFIRM EMPTY POCKET. ***WSR CONTINUED ON 7/12/20*** 7/12/2020 T/I/O= 835/785/4 Temp= S/I LRS Unit 76 Assist Slickline: Flushed TBG with 183 bbls 100* crude. Job postponed until next day. Slickline in control of well upon departure. IA OA= OTG. Final Whp's=700/720/7 7/12/2020 ***WSR CONTINUED FROM 7/11/20*** (patch tubing / liner) DEPLOYED 4-1/2" CATCHER. RATTLE MANDRELS w/ KJ, 4-1/2" BLB, KJ, KJ, 2.0" G-RING. (did not s/d) PULLED 4-1/2" CATCHER FROM XN-NIP @ 11,899' MD. (empty) LRS FLUSHED TBG w/ 180 bbls CRUDE. SET 4-1/2" NIPPLE REDUCER IN XN-NIP @ 11,899' MD. (1.875" x profile) ATTEMPTED TO SET 2-3/8" XX-PLUG IN NIP REDUCER @ 11,899' MD. ***WSR CONTINUED ON 7/13/20*** 7/13/2020 ***WSR CONTINUED FROM 7/12/20*** (patch tubing / liner) PULLED 4-1/2" NIPPLE REDUCER FROM XN-NIP @ 11,899' MD. SET 4-1/2" NIPPLE REDUCER IN XN-NIP @ 11,899' MD. (1.875" x-profile) SET 2-3/8" XX-PLUG IN NIPPLE REDUCER @ 11,899' MD. LRS PERFORMS PASSING 2,500 psi CMIT - T x IA. ***READY FOR E-LINE, WELL LEFT S/I*** ***Note: There is a 1" extended packing dglv that was not recovered*** 7/13/2020 T/I/O=700/715/7 Temp= S/I LRS Unit 76 Assist Slickline: Pumped 31 bbls 60* crude down TBG to assist SL down hole. Slickline set plug. Pressured up TBG/IA with 9 bbls crude. 15 min T/IA lost 15/14 psi. 30 min T/IA lost 7/8 psi. Bled T/IA to 1000/1000 psi and recovered 7 bbls. Slickline in control of well upon departure. IA OA= OTG. Tags hung. Final Whp's= 1000/1000/7 Daily Report of Well Operations PBU P1-03 Daily Report of Well Operations PBU P1-03 7/14/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line Set Lower Packer) SET BAKER 45KB FLO-GUARD LOWER PATCH PACKER AT 9,154' MD MID- ELEMENT (oal LIH ~ 7.73', min i.d. = 2.40", top of pkr ~9151.23). ***JOB COMPLETE ON 14-JUL-2020*** 7/14/2020 RD SV w/ stripped stem, RU Tag #36 to FC, Torqued to API specs, PT'd to 350/5000 PSI (Pass). RDMO. 7/19/2020 ***WELL S/I ON ARRIVAL*** SET 4 1/2" UPPER BAKER STRADLE PATCH / POGLM (W/ S/O GLV). TOP OF PATCH @ 9113' MD. UPPER ELEMENT DEPTH @ 9115' MD. POGLM HAS 26/64" S/O GLV INSTALLED. LRS MIT-T TO 2744 PSI (passed, see lrs wsr). SET 4 1/2" CATCHER ON POGLM ASS'Y @ 9105' SLM. ***WSR CONTINUED ON 7-20-20*** 7/19/2020 Assist Slickline w/ MIT-T (MIT-T POST PATCH) MIT-T to 2579 psi PASSED Target psi=2500 psi Max Applied psi=2750 Pumped 2.12 bbls crude down Tbg to take psi to 2744. Tbg lost 117 psi in 1st 15 mins and 48 psi in 2nd 15 mins for a total loss of 165 psi in 30 min test. Bled Tbg to 600 psi. Slickline in control of well per LRS departure. FWHP's=600/90/0 IA,OA=OTG 7/20/2020 ***WSR CONTINUED FROM 7-19-20*** PULLED DGLV FROM STA# 2 @ 6764' MD. PULLED DGLV FROM STA# 1 @ 3520' MD. MADE MULTIPLE ATTEMPTS TO SET LGLV IN STA# 1, W/O SUCCESS (having issues w/ TIC ok-1 sitting down in bal-o nipple @ 1988' md). ***WSR CONTINUED ON 7-21-20*** 7/21/2020 ***WSR CONTINUED FROM 7-20-20*** BRUSHED BAL-O NIPPLE @ 1988' MD & STA# 1 @ 3520' MD. SET LGLV IN STA# 1 @ 3520' MD. SET LGLV IN STA# 2 @ 6764' MD. (drawdown IA 700 to 400 PSI to test valves). PULLED CATCHER FROM 9093' SLM. PULLED 1.875" XX PLUG FROM 11,899' MD. ***WELL TURNED OVER TO DSO, JOB COMPLETE*** 8/1/2020 T/I/O= 700/2080/60 Temp=150* F. LRS Unit 72 Scale Inhibition Treatment (SCALE INHIBITION). Pumped 65 bbls of 15% EGMBE in 1% KCl, 288 bbls of 20% PM-9701 in 1% KCl, 290 bbls of 1% KCl 38 bbls of crude freeze protection into the TBG. Notified DSO of recomended POP time upon departure. Final T/I/O= 100/1860/60. •ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS Q 1. Operations Performed rco 13 2018 Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations s utd�. n Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Ap ='•1' •tr cd Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Pull IBP Plug 11 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 189-013 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21912-00-00 7. Property Designation(Lease Number): ADL 0365548 8. Well Name and Number: PTM P1-03 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth: measured 12845 feet Plugs measured feet true vertical 9572 feet Junk measured Unknown feet Effective Depth: measured 12558 feet Packer measured 11834 feet true vertical 9258 feet Packer true vertical 8620 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 34-112 34-112 1490 470 Surface 5167 13-3/8" 34-5201 34-4020 3450/5020 1950/2260 Intermediate 11315 9-5/8" 33-11348 33-8168 6870 4760 Liner 1592 7" 11009-12600 7864-9341 8160 7020 Perforation Depth: Measured depth: 12032-12238 feet True vertical depth: 8806-8999 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"13Cr80 31 -11929 31-8709 Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: (� sc./ANNE) Ni:4,; 2 cl [iJ I( 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 571 3097 3493 2236 649 • Subsequent to operation: 1732 2069 8999 2434 647 14.Attachments:(required per 20 AAC 25.070.25.071,Si 25.2831 15.Well Class after work: Daily Report of Well Operations WI Exploratory ❑ Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Burton,Kaity Contact Name: Burton,Kaity Authorized Title: Pad Engineer Contact Email: Kaity.Burton@bp.com Authorized Signature: (.,/t/ / / Date: 01/18/2018 Contact Phone: +1 907 564 5554 Form 10-404 Revised 04/2017 t Y V 1L 31 i/a$ 3 G •`BDIVIS 0--FLT, 1 j 2,S18Submit Original Only s a. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary January 18, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Pull IBP Plug for Well PTM P1-03, PTD #189-013. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Daily Report of Well Operations PTM P1-03 SW_NAME ACTIVITYDATE SUMMARY ****CONT.JOB FROM 10/20/17****(Hydrate removal) PULLED 3-3/8"BKR X-FLOW IBP FROM 2,417'SLM-ORIGINALLY SET @ 12,114'MD(Missing both elements,stiffener ring&1 metal band) SWAP FROM .160"C TO .125"C WIRE MADE 5 RUNS W/4-1/2"BRUSH,3.68"2 PRONG WIRE GRAB(Recovered both elements& missing metal band) DRIFTED W/20'x 3.70"DUMMY WHIPSTOCK,TEL,2-1/2"S-BAILER TO TD @ 12,466'ELMD (360'of rat hole) PERFORMED HES 40 ARM CALIPER LOG FROM 12,425'SLM TO SURFACE(Good data) ****CONT. JOB ON 10/22/17**** P1-03 10/21/2017 ***NOTE--IBP Stiffener ring&1"x.5"x.25"metal pc from JD skirt left in hole ****CONT. JOB FROM 10/21/17****(Hydrate removal) R/D SLICKLINE UNIT SWCP#4522 P1-03 10/22/2017 ****WELL LEFT S/I&DSO NOTIFIED OF STATUS UPON DEPARTURE**** Fluids Summary Bbls Type 1 Diesel 5 60/40 Methanol and Water 15 Crude TRE • MCEVOY • ' VVELLFEAD= CAN ACTUATOR= BAKER C P 1 -03 SAFETY NOTES: 4-1/2"CHROME TBG NT1AL KB,ELI 42.45' 1(L.B_EV= TI I KOP= 1000 20-CONDUCTOR — —110 )›.< j: Max Angle----• 53'@ 3400 94#,H-40, Datum M)= 12071' El=19-124" / >c Datum 1VD= 8800'SS 198W —4-1/2"CAMCO BAL-0 NIP,10=3.813" 113-3/8"CSG,68#,K-55 BTC X0 TO L-80 BTC .I— 112' nO GAS LFT MAINI3REIS [9-5/8"CSG 47#,L-80 NSCC XO TO L-80 BTC .I— 375' ST AU TVD DEV TYPE VLV LATCH FORT DATE . 1 3520 2992 52 KBG-2-LS DOW IIT 16 03/27/17 13-3/8"CSG,68#,L-80 BTC,ID=12.415" — 6201' 1-4 I k 2 6764 5005 52 KBG-2-LS DONE NT 16 03/27/17 3 9130 6515 50 KBG-2-LS DOME NT 16 03/27/17 4 10568 7496 37 KBG2-LS' SO NT 24 03/27/17 Minimum ID = 3.726" ( 11899' 5 11792 8580 21 KBG-2-LS DM' NT 0 06/01/98 4-1/2 OTIS XN NIPPLE [TOP OF 7'LNR_I— 11009' -- -- 11009' —9-5/8"X 7"BKR SHORTY HY D LIN1R HGR FBR&8'TIEBACK SLV,ID=6.25" [9_7518"CSG,47#,L-80 BTC.t =8.68r I— 11348' 1 4 k 1 I 11817' —4-1/2"OTIS X NID,ID=3.813" E X 11826' —fr x 4-1/2"BKR S-3 HYDRO SET FKR ID=3.875" 1 1 11899' —4-112'011.5 XN NIP,ID=3.725" 4-1/2'TBG, 12.6#,13CR-80 NSCT, -L 11921' -- __ i \ .0152 bpf,ID=3.958" 11921' I-14-1/2"WLEG,V=3.958' 11919' 1--I ELMO TT LOGGED 06/29/00 ] PERFORATION SLIM%RY RFEFLOG: DUSFL ON 04/17/89 _ ANGLE AT TOP PERE: 20°@ 12037 I Note:Refer to Roduction DB for historical pert data SIZE SF F INTERVAL Opn/Sqz SHOT SOZ 3-3/8' 6 12032- 12052 0 06/30/00 — 2-1/8" 6 12032- 12054 S 05/01/99 06/13/00 3-3/8' 6 12072- 12106 0 06/30/00 — 2-1/8" 6 12088- 12112 S 05/01/99 06/13/00 2-1/8" 6 12130- 12200 S 05/01/99 06/13/00 I 3-3/8" 6 12218- 12238 0 06/29/00 _ 2-1/8" 6 12220-12250 S 04/15/94 06/13/00 2-1/8" 6 12260- 12300 S 04/15/94 06/13/00 — lik I ? —FISH: 1"STFFENER RING FROM 3-3/8'BKR X-FLOW BP& 1'X 1/2"X 1/4"METAL PIECE FROM JD SKRT(10/21/17) PBTD — 12668' ........./1... 1 7"LNR,29#,L-80„0371 bpf,ID=6.184" — 12600' ..............1 DATE REV BY i COMNBITS DATE REV BY COMENTS MINT MCNTY RE UNIT 04/26/89 PAA#5 IMTIAL COMPLETION 03/28/17 CJNIJIA) RESET BP STOP(03/27/17) WELL: P1-03 06/04r98 1116 RWO 03/28/17 F3/JM) GLV 00(03/27/17) PaRMFT No:'1890130 01/05/12 PJC ( AWING UPDATES 10/25/17 18/JM) RUED 2 BPs/SET FISH AIR No: 50-029-21912-00 05/22/13 WP/Jk4) GLV 00(05/20/13) 01/11/18 D(YJM) CORRECTION TO OKB SEC 16,T12N,R14E, 1467'FSL&666'FEL 08/13/13 SET/JM) SET BKR 13P(07/21/13) 08/13/16 TBEYTU-1 IBP STOP SET _. BP Exploration(Alaska) 20- DEC -2011 Schknherger 5843 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 09 -18 BVYC -00017 SLIM CEMENT MAP TOOL 26- Nov -11 1 1 MPS -01A BY05 -00003 ISOLATION SCANNER 25- Nov -11 1 1 7)4 F -05A BINC -00084 LEAK DETECTION LOG 19- Nov -11 1 1 P1 -03 BINC -00082 PPROF W/ DEFT & GHOST /�Q - 0l3 17- Nov -11 1 1 17 -19A BJGT -00082 SBHPS 17- Nov -11 1 1 1 09 -12 BD88 -00183 MEMORY LDL 28- Nov -11 1 C -02 BYS4 -00005 PRIMARY DEPTH CONTROL 16- Nov -11 1 1 III 04 -350 BYS4 -00006 USIT 16- Nov -11 1 1 GC -2E BYS4 -00011 RST WATERFLOW 6- Dec -11 1 1 15 -09A BINC -00085 PRIMARY DEPTH CONTROL 8- Dec -11 1 1 09 -17 BAUJ -00104 MEMORY INJECTION PROFILE 30- Nov -11 1 1 MPE -12 BD88 -00185 MEMORY INJECTION PROFILE 14- Dec -11 1 1 16 -03 BG4H -00099 INJECTION PROFILE 28- Oct -11 1 1 MPL -24 BUTT-00004 MEMORY INJECTION PROFILE 6- Aug -11 1 1 2- 50/U -08 BD88 -00184 MEMORY IPROF W /DEFT GHOST 11- Dec -11 1 1 A -11 BSM4 -00018 INJECTION PROFILE 30- Oct -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~~~ ~~~ .1A1~~ ~ ~~ ~(~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~ ~~ 333 West 7t" Avenue ~ ~ ~ ~'' Anchorage, Alaska 99501 ~3 Subject: Corrosion Inhibitor Treatments of GPMA P1 ~~~ Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ff bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-06 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-08A 2021990 50029233840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040b00 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 ( ~ bp BP Exploration (Alaska) Inc. 0 Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 .... . January 10, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: P1-03 (PTD 1890130) Application to cancel Sundry #303-352 Dear Mr. Aubert: Attached is Application to Cancel Sundry form 10-404 for Sundry #303-352. This request is to cancel the sundry submitted with our proposed corrective action plan for eliminating outer annulus pressure at P1-03. Energizing the inner casing hanger packoff seals eliminated the source of the sustained casing pressure on the outer annulus at P1-03. The well was returned to production in early January 2004. Since the wells return to production, there has been no further indication of sustained casing pressure in the OA. If you require any additional information or clarification, please contact either Joe Anders or myself at (907) 659-5102. ~?7Jl John Cubbon Well Integrity Engineer Attachment: 1) Application for Sundry Cancellation form 10-404 RECEIVED JAN 1 5 2004 Alaska Oil & Gas Cons. Commission Anchorage ~CAu\~~~E[~ JJð~NI 2 @ 200¡~ ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD SuspendD Operation ShutdownD Perforate D WaiverD OtherD Alter CasingD Repair WellŒ] Plug PerforationsD Stimulate D Time ExtensionO Change Approved ProgramD Pull TubingD Perforate New PoolD Re-enter Suspended WellO 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 189-0130 Development []] ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-21912-00-00 7. KB Elevation (ft): 9. Well Name and Number: 42.50 P1-03 8. Property Designation: 10. Field/Pool(s): ADL-365548 pt Mcintyre Oil Field 1 pt Mcintyre Oil Pool 11. Present Well Condition Summary: Total Depth measured 12845 feet true vertical 9571.7 feet Plugs (measured) None Effective Depth measured 12558 feet Junk (measured) None true vertical 9300.8 feet Casing Length Size MD TVD Burst Collapse Conductor 75 20" 91.5# H-40 35 - 110 35.0 - 110.0 1490 470 Liner 1591 7" 29# L-80 11009 - 12600 7864.3 - 9340.5 8160 7020 Production 11314 9-5/8" 47# L-80 34 - 11348 34.0 - 8167.7 6870 4760 Surface 77 13-3/8" 61# K-55 35 - 112 35.0 - 112.0 3090 1540 Surface 5089 13-3/8" 68# L-80 112 - 5201 112.0 - 4020.4 4930 2270 Perforation depth: Measured depth: 12032 -12052,12072 -12088,12088 -12106,12185 -12200,12218 -12220,12220 -12238,12238 -12250 12260 - 12300 True vertical depth: 8805.62 - 8824.45,8843.27 - 8858.32,8858.32 - 8875.27,8949.56 - 8963.66,8980.58 - 8982.46,8982.46 - 8999.38 8999.38 - 9010.66, 9020.06 - 9057.69 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 22 - 11921 Packers & SSSV (type & measured depth): 4-112" Baker S-3 Hydro Set Pal @ 11826 RECE IVED 4-1/2" Cameo Balo SSV @ 1988 12. Stimulation or cement squeeze summary: Intervals treated (measured): Alaska Oil & Gas Cons. Commission Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 406 0.66 2344 10 881 Subsequent to operation: 407 0.75 1925 2000 1787 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil[]] GasD WAG D GINJD WINJD WDSPLD Daily Report of Well Operations. ! Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact 303-352 Printed Name Title Well Integrity Coordinator Signature Phone 659-5102 Date 1/12/04 Form 10-404 Revised 12/2003 0 Q I h I t\IA ,- -- aFl .IAN 2 I) 16"' ( { P1-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/29/03 TIIIO = 840/2350/1030, TEMP = 126. BLEED OA AND MONITOR BUR (DSO REPORTED HIGH OAP). OA FL NEAR SURFACE. BLED OA FROM 1030 PSI TO 0 PSI IN 45 MINUTES (ALL GAS). MONITORED PRESSURES 1 HOUR - OAP ROSE TO 35 PSI. FINAL WHPS = 830/2350/35. 10130/03 TIIIO = 860/2350/640, TEMP = 128. MONITOR WHPS POST-OA BLEED (MONITOR BUR). OAP ROSE 600 PSI OVERNIGHT. 10/31/03 TIIIO = 920/2360/1040, TEMP = 130. MONITOR WHPS POST-OA BLEED. OAP ROSE 400 PSI OVERNIGHT. 11/01/03 TIIIO = 860/2320/570, TEMP = 128. MONITOR WHPS POST-OA BLEED. DSO REPORTED OA WAS BLED FROM 1150 PSI TO 450 PSI IN 5 MINUTES LAST NIGHT (ALL GAS). OAP ROSE 120 PSI SINCE LAST NIGHTS BLEED. 11/02/03 T/I/O=960/2330/990. TEMP=128*. MONITOR WHP'S, POST OA BLEED. (MONITOR OA BUR). OAP INCREASED 320 PSI OVERNIGHT. WELL HAS AIL. 11/03/03 T/I/O=980/2330/1240. TEMP=127*. MONITOR WHP'S POST OA BLEED. (MONITOR OA BUR). OAP INCREASED 250 PSI OVERNIGHT. WELL HAS AIL, AND AN INTEGRAL IN THE IA. 11/04/03 T/I/O=960/2300/1450. BLEED OA (EVAL FOR IA X OA WAIVER). TEMP 130. OA FL @ 68'. BLED OA FROM 1450 PSI TO 10 PSI IN 1.5 HRS. OA FL NEAR SURFACE. MONITORED OAP FOR 30 MINS, OAP INCREASED 20 PSI. FINAL WHP'S 960/2300130. 11104/03 T/I/O=960/2300/1450. BLEED OA (EVAL FOR IA X OA WAIVER). TEMP 130. OA FL @ 68'. BLED OA FROM 1450 PSI TO 10 PSI IN 1.5 HRS. OA FL NEAR SURFACE. MONITORED OAP FOR 30 MINS, OAP INCREASED 20 PSI. FINAL WHP'S 960/2300130. 11106/03 T/I/O=2080/2150/890. TEMP=102*. TIFL-PASSED. (EVAL FOR IA X OA WAIVER). IA FL @ 10568' (STA #4). BLED lAP FROM 2150 PSI TO 1040 PSI IN 2 HOURS, AND 45 MINUTES. DURING BLEED TBG PRESSURE DECREASED 40 PSI, AND THE OAP DECREASED 100 PSI. MONITORED FOR 1 HOUR, OAP DECREASED 10 PSI. FINAL WHP'S=2040/1040/780. WELL HAS AN INTEGRAL ON THE IA COMPANION VALVE. 11/07/03 T/I/O=1980/980/1000. TEMP=SI. MONITOR WHP'S. POST TIFL. (WAV EVAL). lAP DECREASED 60 PSI, OAP INCREASED 220 PSI OVERNIGHT. 11/08/03 T/I/O=1940/970/980. TEMP=SI & NOT FREEZE PROTECTED. MONITOR WHP'S. POST TIFL-PASSED. (WAV EVAL). TBG PRESSURE DECREASED 40 PSI, lAP DECREASED 10 PSI, OAP DECREASED 20 PSI OVERNIGHT. WELL HAS AN INTEGRAL ON THE IA. 11/13/03 TIIIO = 185011000/1000. OA FL. (WAIVER EVAL). OA FL @ 100'. 11/15/03 TIIIO = 180011000/1000. MIT - OA FAILED. CITOA TO 3000 PSI- PASS. LLRT = 1.4 GPM @ 3000 PSI. (WAIVER EVAL). OA HAS 2" RISER COMING OFF GATE VALVE. TESTED RISER TO 3500 PSI PRIOR TO MIT - OA. GOOD TEST. PRESSURED OA TO 3000 PSI WITH 8.4 BBLS OF DIESEL. STARTED 30 MIN TEST. OA LOST 200 PSI IN 6 MIN. RE- PRESSURED OA TO 3000 PSI TWO MORE TIMES WITH THE SAME RESULTS. STARTED LLRT. LLRT - OA. PUMPED 51 GALS OF DIESEL IN 36 MIN AND ESTABLISHED A LLR OF 1.4 GPM @ 3000 PSI. BLED OA TO 400 PSI. OAP ROSE TO 980 PSI DURING RD. FINAL WHP'S = 1800/1000/980. 11116/03 TIIIO = 180011000/1000. MONITOR WHP'S. (POST MIT - OA). OAP INCREASED 600 PSI FROM PREVIOUS DAYS BLEED. . Page 1 (j " ~ ( P1-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/17/03 T/I/O = 1800/1000/1000. MONITOR WHP'S. (POST MIT - OA). NO CHANGE IN PRESSURES FROM PREVIOUS DAY. 11/18/03 TIO= 180011000/1000. MONITOR WHPS (POST MITOA). NO CHANGE IN PRESSURES. 11/21/03 T/I/O = 178011000/1000. MONITOR WHP'S. (EVAL IA X OA). 11/24/03 ***WELL SHUT IN UPON ARRIVAL*** DRIFTED WI 3.85" SWAGE TO SSSV @ 1969' SLM. PULLED CONTROL OPERATED 4-1/2" WRDP-2(HKS-43) WI 3 SETS OF OVERSIZE PACKING @ 1969' SLM. DRIFTED WI 3.76" SWAGE TO XNLN @ 11879' SLM. ATTEMPTED TO SET TTP. NO LUCK. BRUSH & FLUSH WI 3.7" GAUGE RING, 4-1/2 BRUSH. RAN 4-1/2" BRUSH, 3.8" GAUGE RING TO XNLN. RIH WI 4-1/2" XXN TTP. ***CONT ON 11-25-03 WSR*** 11/24/03 PUMPED 180 BBLS OF HOT CRUDE DOWN THE TUBING FOR WIRELlNE. 11/25/03 ***CONT FROM 11-24-03 WSR*** SET 4-1/2" XXN TTP @ 11879' SLM. GOOD TEST. RDMO. ( PPPOT -CI ) ***WELL LEFT SHUT IN & WING VALVE TAGGED*** 11/27/03 T/I/O=40/980/1000. BLEED WHP'S (PREP FOR PPPOT). TBG FL NEAR SURFACE. IA FL @ 10568' (ST # 4). OA FL NEAR SURFACE. BLED TBG FROM 40 PSI TO 0 PSI IN 45 MINS. TBG FL STAYED AT NEAR SURFACE. BLED IA FROM 980 PSI TO 360 PSI IN 3 HRS. IA FL STAYED AT 10568'. WHILE BLEEDING lA, OAP TRACKED TO 380 PSI. OA FL STAYED AT NEAR SURFACE. MONITORED WHP'S FOR 30 MINS, NO INCREASE IN IA OR OAP. TBG INCREASED 10 PSI IN 3 HRS. FINAL WHP'S 10/360/380. WILL CONTINUE LATER. 11/29103 T/I/0=10/410/410. MONITOR WHP'S (POST WHP'S BLEED). TBG REMAINED UNCHANGED, lAP INCREASED 50 PSI, OAP INCREASED 30 PSI IN 2 DAYS. 11/30103 T/I/O=10/420/420. BLEED WHP'S (PREP FOR PPPOT). TBG FL NEAR SURFACE. IA FL @ 10568' (ST # 4). OA FL NEAR SURFACE. BLED IA FROM 420 PSI TO 0 PSI IN 6 HRS. IA FL REMAINED AT 10568'. WHILE BLEEDING lA, OAP TRACKED TO 0 PSI. OA FL NEAR SURFACE. IA HAS AIL GAS LINE WITH 2400 PSI ON IT. BLED TBG FROM 10 PSI TO 0 PSI IN 20 MINS. TBG FL STAYED @ NEAR SURFACE. MONITORED WHP'S FOR 30 MINS, lAP INCREASED 2 PSI. FINAL WHP'S 0/2/0. 12101/03 TIO= 2010+10+. MONITOR WHP'S. (POST TBG & IA BLEED). TBG INCREASED 20 PSI FROM YESTERDAY. 12/02/03 T/I/O=8/6/0. BLEED IA & OA (PREP FOR PPPOT). IA FL @ 10568'. BLED IA FROM 6 PSI TO 0 PSI IN 4 HRS. HAD BLEED OPEN WHILE CAMERON DID PPPOT. MONITORED lAP FOR 30 MINS, lAP STAYED THE SAME. FINAL WHP'S 8/010. 12102/03 T/I/O = 8/5/0. PPPOT-IC (PASSED) TIGHTENED LOS AND PACKED SECONDARY SEAL. TESTED PACK-OFF VOID AND SEALS TO 3500 PSI. REMOVED INTERNAL CHECK FROM TEST PORT I INSTALLED EXTERNAL (ALEMITE) FITTING. 9 5/8 CASING SET ON SLIPS. Page 2 ( ( P1-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/06/03 T/I/0=30/1 0/1 O. NFT-OA PASSED OART (EVAL IA X OA). WELL SI. IA FL @ 10568' (ST # 4). PRESSURED IA WITH AIL GAS FROM 10 PSI TO 2000 PSI IN 1.5 HRS. IA Fl REMAINED AT 105681. WHILE PRESSUREING lA, TP INCREASED TO 1200 PSI AND GAP INCREASED TO 180 PSI. OA FL @ 60'. BLED OA FROM 180 PSI TO 4 PSI IN 45 MINS. INITIAL GAS RATE OF 90 CFPH @ 4 PSI. STARTED 3 HR TEST. FINAL GAS RATE OF 0 CFPH @ 0 PSI. MONITORED OAP FOR 30 MINS, OAP INCREASED 2 PSI. FINAL WHP'S 1200/2000/2. 12/07/03 T/I/0=1200/2000/6. (POST OART). WELL SI. OAP INCREASED 4 PSI FROM YESTERDAY. 12/08/03 T/I/O= 1140/1940/0. (POST OART) TBG PRESSURE DECREASED 20 PSI SINCE PREVIOUS DAY. lAP DECREASED 60 PSI SINCE PREVIOUS DAY. OAP DECREASED 6 PSI SINCE PREVIOUS DAY. 12/15/03 T/I/O = 1140/1960/0. (POST OART). 12/17/03 TIO= 1100/1900/0+. MONITOR WHPS (EVAL IA X OA) 12/18/03 T/I/0=1120/1900/0+. TEMP=SI. MONITOR WHP'S (EVAL IA X OA). NO CHANGE IN 24 HRS. 12/26/03 ** WELL SHUT IN UPON ARRIVAL** ATTEMPT TO EQ. TTP PLUG. RUN VARIOUS BAILERS, GETTING MOSTLY FORMATION SAND RETURNS. ** CONTINUED ONTO 12-27-03 WSR** 12/27/03 ** CONTINUED FROM 12-26-03 WSR** MADE VARIOUS BAILER RUNS, RECOVERED SMALL AMOUT OF SOLIDS. MADE EQ RUN NEVER SAW PSI CHANGE, GOT METAL MARKS ON PRONG. RAN 4 1/2" GR, LATCHED PLUG @ 11867' SLM, SHEARED GR. RAN 4-1/2" GS , LATCHED PLUG@ 11867' SLM , PULL XXN PLUG. SET WRDP-2 SER # HKS-46 UNABLE TO GAIN CONTROL PRESSURE PULL WRDP-2 SER # HKS-46 ** TURNED WELL OVER TO DSO TO POp** 01/04/04 ***WELL FLOWING ON ARRIVAL*** DRIFT THROUGH SSSV NIPPLE WI 3.80 GAUGE RING. RIG DOWN DUE TO HIGH WINDS. XXXRETURN WELL TO DSO.XXX 01/07/04 ***WELL FLOWING ON ARRIVAL*** DRIFT WI 3.83 GAUGE RING BRUSH W/4 1/2 BL BRUSH & 3.80 GAUGE RING PURGED CONTROL AND BALANCE LINES SET SSSV, NOT HOLDING PRESSURE. IN PROCESS OF PULLING SSSV. ***JOB IN PROGRESS. CONTINUED ON 01/08/04 WSR*** Page 3 P1-03 (PTD #1890130) Plan of action Pr-D '1i ISO¡ -ö\S Subject:PI-03 (PTD #1890130) Plan of action From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> . .-Z\\iO\O? Date: Mon, 15 D~c2003 16:01:30 -0900 . ...:s¥f- \ To: "AOGC.C Jim Regg (E-mail)..<Jim_Regg@admin.state.ak.us>....AO(}CC Winton Aubert (E':'mail)" <Winton ~ Aubert@adinin.'state.ak.us> . .:. ,'. ce.:' "GPB, LPC DS Oþs Lead" <GPBLPCDSOpsLead@BP.'com>, ."Rodriguez,.: Rick". <R~drigU2@BP .com>:, .."Barnes" Thomas... J" <BamesT1 @BP..com>,. "Parker, R. Andrew" <ParkerRA@BP.col11>~ "Rossberg, RSteven" , <RossbeRS@BP ..com> Hi Jim and Winton, We have completed the following diagnostics and repairs for PI-03 (PTD #1890130) . 11/24/03: Set TTP 11899' md 12/02/03: Serviced Y-seal and energized the main seal in the IC hanger packoff. PPPOT-IC Passed. 12/06/03: OART Passed - Final gas rate 0 scf/hr. The IA was left pressured up to 2000 psi with lift gas to determine if the IA will leak into the OA. Final T/I/O = 1200/2000/2. 12/08/03: T/I/O = 1140/1940/0 12/15/03: T/I/O = 1140/1960/0 Based on our diagnostic testing, the re-energizing of the IC packoff seals appears to have eliminated the communication between the IA and OA. Our plan forward for this well is as follows: 1. SL: Pull TTP. 2. 0: Return well to production. 3. DHD: Monitor OA pressure for signs of communication. If you perfer a different plan of action or if you need additional documentation, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 1 of 1 S(;A\¡~!Mft:l DEt ~ @ 2003 12/16/2003 9:48 AM BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp November 20, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: P1-03 (PTD 1890130) Application of Corrective Action Plan Dear Mr. Aubert: Attached is an Application for Sundry Approval form 10-403 for the proposed corrective action plan for well P1-03. This request documents our proposed action plan to eliminate CA repressurization. A description summary of the proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Well Integrity Coordinator Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Wellbore Schematic 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.28O Abandon r~ Suspend D Alter Casing [--~ Repair Well ['~ Change Approved Pro~lram D Pull Tubinl:l D operation Shutdown D Plug Perforations D Perforate New Pool r"l Perforate D Variance D Stimulate[~ Time ExtensionD Re-enter Suspended Wellr'"l Annular Disposalr'] Otherr'i 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 42.50 KB 4. Current Well Class: Development [] StratigraphicD Exploratory [~] Service r-~ 19. Well Name and Number/;/ I P1-03 ~' 8. Property Designation: 110. Field/Pool(s): ADL-365548 I Prudhoe Bay Field I Ptmac Oil Pool IPermit to Drill Number: 189-0130 / APl Number /x 50-029-21912-00-00 11. Total Depth MD (ft): 12845 PRESENT WELL CONDITION SUMMARY Casing Length Size Conductor 75 20" 91.5# H-40 MD top bottom 35 - 110 Plugs (md): None Junk (md): None TVD Burst Collapse top bottom 35.0 - 110.0 1490 470 Liner 1591 7" 29# L-80 11009 - 12600 7864.3 - 9340.5 8160 7020 Production 11314 9-5/8" 47# L-80 34 - 11348 34.0 - 8167.7 6870 4760 Surface 77 13-318" 61# K-55 35 - 112 35.0 - 112.0 3090 1540 Surface 5089 13-3/8" 68# L-80 112 5201 112.0 - 4930 2270 4020.4 Pedoration Depth MD (ft): 12032 - 12300 12072 - 12200 12088 - 12220 12185 - 12238 12218 12250 12220 12052 12238 12O88 1226O 12106 Perforation Depth TVD (ft): 9020 - 9057.7 8950 - 8963.7 8981 - 8982.5 8982 - 8999.4 8999 9010.7 8806 8824.5 8843 8858.3 8858 8875.3 Packers and SSSV Type: 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" Camco Balo SSV 12. Attachments: Description Summary of Proposal Detailed Operations Program [~ BOP Sketch 14. Estimated Date for Commencin~ Operation: December 1,2003 16. Verbal Approval: Date: Commission Representative: Tubing Size: 4.5" 12.6 # Tubing Grade: Tubing22MD (ft): L-80 - Packers and SSSV MD (ft): 11826 '1988 3. Well Class after proposed work: ExploratoryD Development[~] Service r"~ 5. Well Status after proposed work: Oil [~ Gas['"] PluggedD AbandonedD WAG I-I G'NJI--I W,NJr'] WDSPLD 11921 Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ,JJ~13~ ~~ Title Signature //~(~ Phone , 7' - ' ' Commission Use Only Contact John Cubbon / Joe Anders Well Inte~lrity En~lineer 659-5102 11121/03 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity [~ BOP Test~--~ aochancial Integrity Test r'] Other: Subsequent Form Required: !0 ' ('~ O ~ ..~'~% r-,. , t.,-~, ~, Approv~ ~n ~n~ o~,,;~ ~i~~:':;')~; ~ ~S~h~ ~ BY ORDER OF THE COMMISSION Sundry Numbe~ ~. ~Z P1-03 Description Summary of Proposal 11/20/03 Problem: Producer with OA Repressurization Well History and Status: Well P1-03 (PTD 1890130) is a gas lifted producer that exhibits IA x OA communication. The surface casing at P1-03 contains 13-3/8", 68#, K-55 c/asing with a rated burst pressure of 3450 psi (45% of burst pressure is 1553 psi)'. The gas lift supply pressure for the Point Mclntire Field is approximately 2500 psi. The purpose of the proposed work outlined below is to eliminate the sustained casing pressure on the OA by eliminating the leak path which is causing the IA x OA communication. The following is a brief history of well events: Brief Well History: · 11/03/03: Notified state of SCP, plan to service lC pack-offs j' · 11/06/03: TIFL - Passed · 11/15/03: CITOA to 3000 - Passed /~' · 11/20/03: Winton with the AOGCC requested a sundry outlining our plan of action. OK'd leaving well on line as long as OAP < 1550 psi. j, This sundry request is to formally submit our corrective action plan to repair the IA x OA communication. Proposed Action Plan: 1. Secure the well with a TTP.// 2. Perform a PPPOT-IC to determine if the wellhead is the source of the IA x OA communication. 3. If wellhead is the source of IA x OA communication, evaluate options to repair the wellhead and eliminate the IA x OA communication, j 4. Notify AOGCC of well status. TREE = MCEV OY GEN IV P1 03/ I I ACTUATOR = BAKER C ma KB. ELL=,/= 425' BF. ELEV = '" , KOP = 1000' Max Angle = 53 @ 3400' Datum IVD =Datum TVD = 8800'12071'SS ,--~ ---~ 1988' H 4-1/2" CAMCO BAL'O NIP' 9CR' ID = 3'813" I GAS LIFT MANDRELS k r -~_ 1 3520 2992 52 KBG-2-LS INT Minimum ID = 3,725"@ 11899' 2 6764 5005:52 KBG-2-LS INT 4-1/2" HES XN NIPPLE 3 9130 6515 50 KBG-2-LS IN]' 4 10568 7496 37 KBG-2-LS INT 5 11792 6580 21 KBG-2-LS INT I11023' ~""1 I I 11817' I-t 4'l~2"OT~SXN~P'~D--3'81"I 8 11826' I'"t 7"X4'I/2"BAKERS'OHYDROSETFKR I II I 11890' I'~ 4-11Z'OTISXNNIP, ID=3.725" 0,0152 bpf ,ID=3.958" 11919' I--~ ELMD I PERFORATION SUMMARY REF LOG: DIL/SFL ON 04/17/89 ANGLE AT TOP PEP, F: 20 @ 12032' Note: Refer to Production DB for historical F)erf data SIZE SPF NTERVAL Opn/Sqz DATE 3-3/8" 6 12032 - 12052 O 06/30/00 2-1/8" 6 12032- 12054 S 05/01/89 3-3/8" 6 12072 - 12106 O 06/30/00 2-1/8" 6 12088 - 12112 S 05/01/89 2-1/8" 6 12130- 12200 S 05/01/89 2-1/8" 6 12218- 12238 O 06/29/00 2-1/8" 6 12220- 12250 S 06/13/00 2-1/8" 6 12260- 12300 S 06/13/00 ; I mTD I--I 12558' I I H 12600, i · DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MQN'rY RE UNIT 04/26/89 ORIGINAL COIVPLErlON WELL: P1-03 06/01/98 RWO (?) PERMIT No: 1890130 01/15/01 SIS-Isl CONVERTED TO CANVAS APINo: 50-029-21912-00 02/20/01 SIS-MD RNAL SEC 16, T12N, R14E, 4849.19 FEL 4645.92 FNL 07/15/01 RN/KAK CORRECTIONS 07~29~02 DAV/KK NIPPLE CORRECTION BP Exploration (Alas ka) PERFORATION SUMMARY REF LOG: DIL/SFL ON 04/17/89 ANGLE AT TOP PERF: 20 @ 12032' Note: Refer to Production DB for historical )eft data SIZE SPF NTERVAL Opn/Sqz DATE 3-3/8" 6 12032 - 12052 O 06~30~00 2-1/8" 6 12032- 12054 S 05/01/89 3-3/8" 6 12072 - 12106 O 06/30/00 2-1/8" 6 12088 - 12112 S 05/01/89 2-1/8" 6 12130- 12200 S 05/01/89 2-1/8" 6 12218- 12238 O 06~29~00 2-1/8" 6 12220- 12250 S 06/13/00 2-1/8" 6 1 2260 - 12300 S 06/1 3/00 Pt Mclntyre Wellname Changes 5/28/02 Pt. Mclntyre 01 !177-046 Pt. Mclntyre 02 1177-065 Pt. Mclntyre 03 P1-02 i188-005 Pt. Mclntyre 04 P1-03 1189-013 Pt. Mclntyre 05 P1-25 i189-041 Pt. Mclntyre 06 Pt. Mclntyre 07 Pt. Mclntyre 08 Pt. Mclntyre 09 Pt. Mclntyre 10 Pt. Mclntyre 11 P2-58 190-008 P1-01 190-027 P1-07 189-134 P2-59 190-140 P2-57 191-079 P1-12 1191-013 Pt. Mclntyre 12 191-037 Pt. Mclntyre 13 P2-60 191-091 Pt. Mclntyre 3 DP 189-003 Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Julie Heusser, , ¢,~- DATE: Commissioner Tom Maunder, ~q~°~$UBJECT' P. I. Supervisor ~1~' ~ \ ' John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests BPX PBU LGI & PM-OI April 11, 2001: i traveled to BPX's Lisbume Gas Injection (LGI) and also on to the Point Mclntyre PM-01 location to witness Safety Valve Testing. The AOGCC SVS test reports-are attached for reference. As noted 3 failures were observed on both pads; with 2 being repaired and retested immediately. The third failure asssv and will need further attention. Mark Wysocki, lead operator was training 2 new hires. The crew did an excellent job. Summary: I witnessed the SVS tests on LGI and PM-01 LGi, 3 wells, 9 components, I failure, 11% failure rate PM-01, 11 wells, 33 components, 2 failures, 6% failure rote Attachment; Svs bpx igi 4-10-0 ljs Svs bpx prn-01 4-10-01js Non Confidential Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark WYsocki .... AoGcC Rep: John H. Spaul~ding Submitted By: ,.Jo ~hn.Spaulding Date: Field/Unit/Pad: ...Pt,. M~!n_.tyre/PBU/PM'01 Separator psi: LPS 460 HPS 4/9/01 Well Permit Separ Set L/P Test ~Test Test Date Oil, WAG, GINJ, ~Number Number PSI PSI Trip Code Code ,C,,ode Passed GAS, o,r CY,,CLr, 12 191O370 , P1-02 18800501 13F:03''~'~':?~ (* 1890130 460 350~ 310 ~ P'" P ' ' ' OiL Pl'04' .... 1930630 460 ' 700 ' 700 P' P "P .......... Pl-O5 1930870 460 350 300 P P 9 OIL Pl-06 1961370 460 700 675 P p p OiL Pi-07'" 1891340 --~ .................... Pi-08 19~0980 "' 460 ....... 1500 '"i200 ..... P .... p' 'P ............... oil :P 1-09 1961540 " 4(fi} 350 300 P P P ....... P 1-11 1920866' 460 3'50 250 P P P OIL Pl-12 1910130 Pl-13 i'930740 ..... 460 " '1500 1150 P ' '' P' P ' ~ '- OIL pi,17 ...... 1930510 '460 350 280 p p p [ OIL P1-20 1920940 460 350 "'175 ' 3 ..... P ....... P ........ 4/9/01 .... 0IL i~i-23 1961240 ............................. P1-24 1961490 PI'-Gi ..... i'921150 3600 ''2900 ' 5'850 P ...... P ........ P ...... GINJ ................... . Wells: 11 Components: 22 Failures: 2 Failure Rate: 9.09% 1-19o var Remarks: P 1-08 & P1-3 were choked' back,~hence t~he ~gherpilg,t' ~ttings , P1220 Pilot reset and.retested RJF 1/16/01 Page 1 of l 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: M~kWyS°, cid ' ' ' AOGCC Rep: John H, Spauld~g Submitted By: .,J,.o,,hn Spauld'mg Date:,.... 4/9/01 Field/Unit/Pad: Lisburne/PBU/LGI Separator psi: LPS HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GISIJ, Number Number PSI PSI TriP Code Code Code Passed GAS or CYCLE , , LGI-02 1861400 3800 2900 2300 ?~:, e P 4/9/01 GINJ LGI-04 1880130 LGI'-06 18606~0 3800 2900 2500 P ' P P G1NJ LGI-08 1860570 LGI-10 1860690 3800' 2600' 2300 P P P " GINJ LGI-12 1860540 Wells: ..... 3 Components: 6 Failures: 1 Failure Rate: Remarks: · ~LGI-02 Pilot tripped ,t,o ,10~ ~ ~ r,_e~tTr~tested and~passed RJF 1/16/01 Page 1 of 1 010409-SVS LGI Lisburne-js STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ 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 42 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 service__ Point Mclntyre Unit 4. Location of well at surface 8. Well number 3810' FNL, 665' FEL, Sec. 16, T12N, R14E, UM (asp's 674390, 5994600) P1-03 At top of productive interval 9. Permit number / approval number 4824' FNL, 5081' FEL, Sec. 11, T12N, R14E, UM (asp's 680421, 5999014) 189-013 At effective depth 10. APl number 50-029-21912 At total depth 11. Field / Pool 4646' FNL, 4849' FEL, Sec. 11, T12N, R14E, UM (asp's 680650, 5999192) Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured 12845 feet Plugs (measured) PBTD tagged (6/23/2000) @ 12332' MD. true vertical 9572 feet Effective depth: measured 12332 feet Junk(measured) true vertical 9088 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 110' 110' Surface 5159' 13-3/8" 3300 SxAS III & 700 Sx Class G 5201' 4020' Production 11305' 9-5/8" 630 sx c~ass G 11347' 8167' Liner 1535' 7" 650 sx Class G 12558' 9301' Perforation depth: measured 12032' - 12052'; 12072' - 12106'; 12218' - 12238'. RECE VE true vertical 8806' - 8824'; 8843' - 8875'; 8981' - 8999'. ,It)L 2 1 0o0 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80 Tbg @ 11921' MD. Alaska O:'~ & Packers & SSSV (type & measured depth) BAKER S-3 Hydro Set PACKER @ 11826' MD. 4-1/2" CAMCO SLVN @ 1988' 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 Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pres, sum Prior to well operation (Shut in due to water cut) Subsequent to operation 766 920 3084 758 15. Attachments 16. Status of well classification as: copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended m Service 17. I hereby certify that~,~~~~~ fo r;e~oing is true and c or re ct to the best of my knowledge. Signed . /, Ti~Je: Disposal / Rag Compliance Engineer Date Mike Bi// ~ Pre'pared b~/Pau/ Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE P1-03 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE FOR WSO / REPERFORATING OPERATIONS Date Event Summary 5/10/2000: 5/11/2000: 5/12/2000: 5/13/2000: 5/24/2000: 6/12/2000: 6/13/2000: 6/16/2000: 6/23/2000: 6/29/2000 - 6/30/2000: RIH & tagged PBTD @ 12378' MD. MIRU. PT'd equip. Fluid packed well w/2% KCL Water. RIH w/BHA & milled/drifted to 12360' MD. POOH. RIH w/Scaleblasting BHA to 9500' MD. Jetted the following perforation intervals w/Kelzan Gel & Beads to 12320': 12032'-12052' MD 12088'-12112' MD 12130'-12200' MD 12220'-12250' MD 12260'-12300' MD POOH w/Scaleblasting BHA. FP'd well. RD. RIH &tagged PBTD @ 12199' MD. MITIA to 3000 psi - passed. Attempted a CTU Cement Squeeze for Water Shutoff as follows: MIRU CTU. PT'd equip to 4000 psi. Fluid packed well w/3% KCL Water. RIH w/CT & tagged BTM @ 12270' CTM. Cleaned out soft scale to 12378'. Reciprocated across the open perforations 3% KCL Water, followed by 30 bbls of 50% Diesel - 40% Xylene - 10% Musol, followed by 3% KCL Water. Cement job aborted due to mechanical problems on CTU. POOH. FP'd well. Standby while CTU maintenance performed. PT'd equip to 4000 psi. RIH w/CT & tagged up @ 12341' MD. Pumped 30 bbls of 50% Diesel - 40% Xylene - 10% Musol, followed by 140 bbls of warm 3% KCL Water. Pumped 20 bbls of Neat LARC, followed by 50 bbls of LARC w/Nycon Fibers to squeeze the open perforations listed above. Squeezed 6 bbls of Cement behind pipe. Attained a max squeeze press of 3500 psi DP. Held 2800 psi for 30 minutes. Contaminated Cement w/Biozan & jetted Contaminated Cement f/wellbore to 12341 '. Spotted 15 bbls of TEA across perfs. POOH w/CT. FP'd well. Left 1000 psi on well. RD. WOC. RIH & tagged TOC @ 12332' MD. RIH w/dummy perf gun & tagged TOC @ 12317' MD. MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & reperforated 74' @: 12032' - 12052' MD Reference log: CBT 4/23/1989. 12072'- 12106' MD 12218' - 12238' MD Used 3-3/8" carriers & all shots @ 6 SPF. POOH w/perf guns. ASF. RD. Placed P1-03 BOL & gathered representative production data. RECEIVED Page 1 ,!UL 2 t 2000 Alaska Oi.; & Gas Cons, Commission Anchorage STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed: F-]Operation Shutdown r-J Pull Tubing 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1468' NSL, 666' WEL, SEC. 16, T12N, R14E, UM At top of productive interval 458' NSL, 198' EWL, SEC. 11, T12N, R14E, UM At effective depth 570' NSL, 346' EWL, SEC. 11, T12N, R14E, UM At total depth 632' NSL, 419' EWL, SEC. 11, T12N, R14E, UM Stimulate E~ Plugging F-I Perforate ~--~AlterCasing [~ Repair Well r--IOther Type of well: [~ Development I--] Exploratory [~ Stratigraphic E-]Service 6. Datum Elevation (DF or KB) KBE = 42.5' 7. Unit or Property Name Point Mclntyre 8. Well Number P1-03 9. Permit Number / Approval No. 89-13 10. APl Number 50- 029-21912 11. Field and Pool Point Mclntyre 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 12845 feet Plugs (measured) 9571 feet 12558 feet Junk (measured) 9300 feet Length Size Cemented Structural Conductor 75' Surface 5166' Intermediate Production 13315' Liner 1592' 20" 13-3/8" 3300 sx AS111,700 sx 'G' 9-5/8" 630 sx 'G' 7" 650 sx 'G' MD TVD 110' 110' 5200' 4019' 11348' 8161' 11008'-12600' 7863'-9339' Perforation depth: measured true vertical 12032'-12054';12088'-12112';12130'-12200';12200'-12250';12260-12300' 8805'-8826';8858'-8880';8897'-8963';8963'-9010';9019'-9057' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80 tubing to 11921' Packers and SSSV (type and measured depth) 4-1/2" Camco SVLN at 1988' ; Baker Packer S-3 at 11826' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORlg !A 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Anchorage Casing Pressure Tubing Pressure 15. Attachments r--I copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [~ Oil [~ Gas E~ Suspended Service 17. I hereby certify that the foj'egoing is true and correct to the best of my knowledge Signed ~ ?.~..~,,/ Dan Stoltz ~ ..... ~.. 5~'¢/..~- Title Drilling Superintendent Prepared By Name/Number: Date Carol W/they, 564-4114 Form 10-404 Rev. 06/15/88 Submit In Duplicate Facility Pt Mac 1 Progress Report Well P1-03(04) Rig 0m~ ~-[~ Page Date 1 13 August 98 Date/Time 22 May 98 23 May 98 24 May 98 25 May 98 26 May 98 03:00-06:00 06:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-22:00 22:00-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-10:30 10:30-11:00 11:00-11:30 11:30-12:00 12:00-16:30 16:30-18:00 18:00-18:15 18:15-21:45 21:45-23:30 23:30-23:45 23:45-01:30 01:30-01:45 01:45-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:30 08:30-12:30 12:30-15:30 15:30-16:00 16:00-16:30 16:30-18:30 18:30-18:45 18:45-19:00 19:00-19:30 19:30-21:30 21:30-22:00 22:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:00 10:00-10:30 10:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-23:45 23:45-01:00 Duration 3 hr 24 hr 1/2 hr 11-1/2 hr 1/2 hr 3-1/2 hr 4 hr lhr lhr 2 hr 1/2 hr 2hr lhr lhr 1/2 hr 1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/4 hr 3-1/2 hr 1-3/4 hr 1/4 hr 1-3/4 hr 1/4 hr 3/4 hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 4hr 3hr 1/2 hr 1/2 hr 2hr 1/4 hr 1/4 hr 1/2 hr 2hr 1/2 hr 8hr 1/2hr 1-1/2 hr lhr lhr 1/2 hr 7-1/2 hr 1/2 hr 1-1/2 hr 1 hr 2-3/4 hr 1-1/4 hr Activity Rig moved 5.00 % Rig moved 5.00 % Held safety meeting Rig moved 95.00 % Held safety meeting Rig moved 95.00 % Rig waited: Materials Rig moved 95.00 % Rig moved 100.00 % Rig moved 100.00 % Held safety meeting Rigged up Circulating head Tested Seal assembly Removed Hanger plug Held safety meeting Tested Choke manifold Monitor wellbore pressures Circulated at 10830.0 ft Monitor wellbore pressures Held safety meeting Circulated at 10830.0 ft Circulated at 12032.0 ft Flow check Circulated at 10830.0 ft Monitor wellbore pressures Tested Seal assembly Circulated at 10830.0 ft Circulated at 10830.0 ft Held safety meeting Monitor wellbore pressures Installed Hanger plug Removed Surface tree Rigged up All functions Tested All functions Removed Hanger plug Pulled Tubing on retrieval string to 30.0 ft Circulated at 10830.0 ft Held safety meeting Flow check Removed Tubing hanger Laid down 2000.0 ft of Tubing Retrieved SCSSSV Laid down 8800.0 ft of Tubing Held safety meeting Rigged down Tubing handling equipment R.I.H. to 334.0 ft Circulated at 334.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 2 Held safety meeting R.I.H. to 5600.0 ft Circulated at 5600.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 3 Progress Report Facility Pt Mac 1 Well P1-03(04) Rig (~I~ D.t ¢ Page 2 Date 13 August 98 Date/Time 27 May 98 28 May 98 29 May 98 30 May 98 31 May 98 01:00-02:00 02:00-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-10:30 10:30-11:30 11:30-15:30 15:30-18:00 18:00-18:15 18:15-18:30 18:30-19:45 19:45-20:30 20:30-20:45 20:45-22:00 22:00-23:30 23:30-00:30 00:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-11:30 11:30-12:30 12:30-14:00 14:00-16:00 16:00-18:00 18:00-19:30 19:30-21:30 21:30-04:30 04:30-06:00 06:00-06:30 06:30-10:00 10:00-10:30 10:30-11:30 11:30-12:00 12:00-15:30 15:30-16:30 16:30-17:00 17:00-20:30 20:30-23:00 23:00-00:00 00:00-01:30 01:30-04:00 04:00-06:00 06:00-06:30 06:30-13:00 13:00-17:00 17:00-17:30 17:30-21:00 21:00-02:45 02:45-03:15 03:15-06:00 Duration 1 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1 hr 4 hr 2-1/2 hr 1/4 hr 1/4 hr 1-1/4 hr 3/4 hr 1/4 hr 1-1/4 hr 1-1/2 hr lhr 2-1/2 hr lhr 2 hr 1/2 hr 1-1/2 hr 3-1/2 hr lhr 1-1/2 hr 2hr 2hr 1-1/2 hr 2hr 7hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr lhr 1/2 hr 3-1/2 hr lhr 1/2 hr 3-1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 2hr 1/2 hr 6-1/2 hr 4 hr 1/2 hr 3-1/2 hr 5-3/4 hr 1/2 hr 2-3/4 hr Activity Pulled out of hole to 0.0 ft Made up BHA no. 4 Pulled out of hole to 2000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Circulated at 5150.0 ft R.I.H. to 354.0 ft R.I.H. to 30.0 ft Rigged down Wellhead connector Installed BOP stack Held safety meeting Tested Wellhead connector R.I.H. to 30.0 ft R.I.H. to 5.0 ft Circulated at 334.0 ft Rigged up Casing handling equipment Pulled Casing on retrieval string to 334.0 ft Rigged down Casing handling equipment R.I.H. to 334.0 ft Pulled out of hole to 0.0 ft R.I.H. to 331.0 ft Pulled out of hole to 0.0 ft Rigged up Bell nipple R.I.H. to 374.9 ft Freeze protect well - 25.000 bbl of Diesel Ran Casing to 374.9 ft (9-5/8in OD) Ran Casing to 374.9 ft (9-5/8in OD) Installed Slip & seal assembly R.I.H. to 21.5 ft Rigged down BOP stack Cut Casing at 24.0 ft Rigged up Wellhead connector Rigged up Wellhead connector (cont...) Tested Tubing head spool Installed Wear bushing Repaired Standpipe manifold Tested Casing R.I.H. to 5090.0 ft Serviced Block line Tested Kelly Pulled out of hole to 0.0 ft R.I.H. to 5107.0 ft Reverse circulated at 5136.0 ft Functioned Bridge plug Pulled out of hole to 0.0 ft R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 10804.0 ft Circulated at 10804.0 ft Fished at 10804.0 ft Circulated at 10804.0 ft Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 17 R.I.H. to 5000.0 ft Progress Report Facility Pt Mac 1 Well P1-03(04) Rig ~ ~'"l ~ Page 3 Date 13 August 98 Date/Time 06:00-06:30 06:30-08:15 08:15-08:30 08:30-11:30 11:30-15:00 15:00-16:00 16:00-19:30 19:30-20:00 20:00-06:00 01 Jun 98 06:00-06:30 06:30-09:30 09:30-16:00 16:00-18:45 18:45-19:30 19:30-06:00 02 Jun 98 06:00-06:30 06:30-07:30 07:30-08:30 08:30-01:30 03 Jun 98 01:30-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-15:00 15:00-17:00 17:00-19:30 19:30-22:30 22:30-00:00 04 Jun 98 00:00-03:00 Duration 1/2 hr 1-3/4 hr 1/4 hr 3hr 3-1/2 hr 1 hr 3-1/2 hr 1/2 hr 10hr 1/2 hr 3 hr 6-1/2 hr 2-3/4 hr 3/4 hr 10-1/2 hr 1/2 hr lhr lhr 17hr lhr 3-1/2 hr 1/2 hr 1 hr 1 hr 6-1/2 hr 2hr 2-1/2 hr 3 hr 1-1/2 hr 3hr Activity Held safety meeting R.I.H. to 10832.0 ft Flow check Circulated closed in well at 10832.0 ft Circulated closed in well at 10832.0 ft Circulated closed in well at 10832.0 ft Circulated at 10832.0 ft Flow check Pulled BHA Held safety meeting Pulled out of hole to 0.0 ft R.I.H. to 11850.0 ft Circulated at 11850.0 ft Tested Liner Laid down 11850.0 ft of 5in OD drill pipe Held safety meeting Laid down 1500.0 ft of 3-1/2in OD drill pipe Rigged up Completion string handling equipment Ran Tubing to 11921.0 ft (4-1/2in OD) Functioned SCSSSV nipple assembly Ran Tubing to 11000.0 ft (4-1/2in OD) Held safety meeting Rigged up Tubing hanger Ran Tubing on landing string to 11921.0 ft Filter Brine Set packer at 11826.0 ft with 3500.0 psi Rigged down BOP stack Installed Xmas tree Freeze protect well - 10.000 bbl of Diesel Rig moved 0.00 % S BP Exploration / Arco Alaska Date: To: Attn: From: August 13, 1998 Alaska Oil & Gas Conservation Commission Steve McMains Carol Withey Technical Assistant Steve: I have recalculated the following information on this report: Top of productive interval Effective depth Total depth I used the survey attached to the well completion report which was completed and sent to AOGCC in 1989. Cc: P1-03 file Attachment: Survey dated April 23, 1989 RECEIVED Alaska OiJ & Gas Cons. Comrmssior~ Anchorage S UB-$ URFA CE DIRECTIONAL SURVEY I~UIDANCE i"~ ONTI NUOUS I-'~"] OOL Company Well Name ARCO ALASKA INC. I PT MCINTYRE ST ~4~l,46~'~666'FEL~SEC16,T12N R14E Field/Location WILDCAT, NORTH SLOPE ALASKA Job Reference No. 73301 Loo:~ By: WARNER Date · 4/23/89 Computed By: SINES SCHLUMBERGER GCT DIRECTIONAL SCRVE¥ CUSTOMER LISTIkG FOR ARCO ALASKA~ INC. PT. MCINTYRE STATE WILDCAT NORTH SLOPE, aLASKA SURVEY DALE: 23 METHODS OF COPPUT~TIOh TCOL LOCATION: I~TERFOLATI~N: ~ERTICAL SECTION: ENGINEER: O. WARNER T~NGEhTIAL- AVERAGED OEVIATIOI; ANE: AZIMUTh LINEAg HCRIZ. CIST. PROJECTED DNIO A TARGET ~ZIMbTH CF NORTH 55 £EG 10 MIN E~ST ARCO ALASKA, INC. PT. MCINTYRE STATE WILDCAT NORTE SLOPE, ALASKA £OMPLT~TION sATE: 26-MAY- 89 KELLY DATE 8CSHING OF SURVEY: ELEVATION: ENGINEER: PI~GE 1 23 42.45 FT D. WARblER TRLE ~EASUI; ED VERTICAL DEPIH DEFTH 0.00 C .00 100.00 10C .00 200.00 20C .00 300.00 30C .00 400.00 40C .00 500.00 49S .99 600.00 59S .98 700.00 69S .87 800.00 79S .37 900.00 898 .58 1000.00 992 .50 1100.00 1095.92 1ZO0.O0 1193.51 1300.00 129C .09 1400.00 1385 .?1 1500.00 1480.34 1600.00 1572 .48 1700.00 1665.50 1800.00 175( .80 1900.00 1847.46 2000.00 193( .65 2100.00 2021.89 2200.00 2102.08 2300.00 Z17S .29 2400.00 2254.78 2500.00 2325.02 2600.00 2397.47 2700.00 2464 .16 2800.00 252E .98 2900.00 2595.79 3000.00 2664.17 3100.00 2731 .96 3200.00 2793 3300.00 2859.29 3400.00 291S .07 3500.00 297S .31 3600.00 3041.08 3700.00 3103.04 3800.00 3164.26 3900.00 322( .26 INTERP£LATED V/~LL;ES FOR EVEN 100 FEET SUB-SEA COURSE VERTICAL DOGLEG VERTICAL DEVIATION ~ZIMUTH SECTION SEVERITY DEPTH BEG MIN EEC- MIN FEET DEG/1CO 0 0 N 0 0 0 15 S 21 37 C 14 S 44 22 C 11 S 66 33 0 16 S 56 6 0 36 S 66 26 1 20 S 81 59 4 21 N 81 11 6 37 N 76 6 7 46 N 75 18 0.00 0.00 -0.02 0.14 -0.04 0.21 0.11 0.10 0.29 0.16 0.58 0 1.68 1.09 5.39 4.04 14.52 1.07 26.23 0.89 -42.45 57.55 157.55 257.55 357.55 457.54 557.53 657.42 756.92 856.13 9 12 N 73 30 E 11 18 N 69 9 E 13 52 N 64 43 E 1( 5 N 63 49 E 17 54 N 63 38 E 2C 4 N 63 33 E 22 20 N 63 50 E 23 36 N 62 47 E 24 29 N 6e 4I E 25 36 N 59 53 E 955.05 1053.47 1151.06 1247.64 1343.26 1437.99 15.~1.03 1623.05 1714.35 1805.01 34 3~ 41 44 47 4S 47 54 N 60 31 E 5 N 6C 30 E 37 N 6C 42 E 1 N 61 36 E 51 N 61 11 E 28 N 58 26 E 10 N 55 8 E N 52 52 E 5 N 54 15 E 20 N 54 38 E 1894.20 1979.44 2059.63 2136.84 2212.33 2285.57 2355.02 2421.71 2486.53 2553.34 46 48 45 5 5C 24 52 50 53 17 52 25 51 38 51 58 52 5 51 33 N 54 30 E N 53 4 E N 52 6 E N 52 4 E N 52 16 E N 52 57 E N 53 11 E N 52 52 E N 52 40 E N 53 4 E 262 I. 72 2559.51 2754.88 2816.84 2876.62 2936.86 2998.63 3060.5S 3121.81 3183.81 MEASURED CEPTh RECTaNGULaR NORTF/SOLTH FEET C.O0 N C.25 S 0.64 S 0.81 S 1.03 S 1.44 S 1.87 S 1.63 S 0.46 N 3.56 hi 40.05 2.02 7.43 N 57.02 2.54 13.09 N 78.38 1.96 21.71 N 103.96 2.1~8 33.03 N 132.87 1.83 45.99 N 1~4.86 2.46 60 .'41 N 200.81 1.77 7~ .4,3 N 239.52 1.35 93.89 N 280.04 1.35 113.16 N 322.09 1.66 134.30 N 367.10 4.54 156.74 N 419.06 5.29 182.38 N 478.48 3.08 211.'77 N 541.68 1.96 242.40 N 606.83 1.93 273.53 N 674.65 4.11 301.50 N 746.54 3.12 346.99 N 821.01 1.89 391.20 N 89'7.12 2.S3 43~.60 N 971.51 1.33 479.63 N COORCINATES HORIZ. EAST/WEST DIST. FEET FEET 0.00 E 0.00 0.15 E 0.29 0.40 E 0.75 0.70 E 1.07 1.07 E 1.48 1.71 E 2.24 3.35 E 3.83 7.70 E 7.87 17.37 E 17.38 29.49 E 29.70 43.62 E 44.25 60.36 E 61.76 80.38 E 83.26 103.67 E 108.81 129.88 E 137.78 158.81 E 169.91 191.46 ~ 206.15 226.48 E 245.17 262.44 E 285.79 298.95 E 327.73 338.18 E 372.73 383.~3 E 424.78 435.57 E 484.33 491.26 E 547.81 548.97 E 613.34 (07.95 E 681.30 668.06 E 752.80 728.02 E 826.47 189.15 E 901.87 ~49.83 E 975.84 1044.48 0.90 1117.96 2.31 1193.53 2.53 1271.89 1.65 1351.95 0.56 1431.68 1.38 1510.27 0.11 1588.72 O.BO 1667.71 1.27 1746.11 0.48 521.83 N ~09.36 E 1048.45 565.19 N S68.72 E 1121.54 611.34 N 1028.67 E 1196.62 '659.60 N 1090.55 E 1274.51 708.82 N 1153.83 E 1354.16 757.25 N 1217.27 E 1433.5q 804.42 N 1280.20 E 1511.95 851.59 N 1342.94 E 1590.18 89S.52 N 1405.82 E 1668.97 946.79 N 1468.43 E 17~7.20 DEPARTURE AZIMUTH DEG MIN N 0 C E S 31 45 E S 31 58 E s 40 ~.s E ( S 46 4 E S 4955 E S 60 47 E S 78 1 E N 8828 E N 83 7 E N 80 19 E N 77 45 E N '/4 53 E N 72 19 E N 70 30 E N 69 10 E N 68 14 E N 67 28 E N 6640 E N 65 48 E N 65 '7 E N 64 34 E N 64 4 E .. N 63 44 E /" N 63 30 E[ N 63 lC E N 62 33 E N 61 44 E N 61 2 E N 60 33 E N 60 gE N 5944 E N 59 16 E N 5849 E N 5826 E N 58 6 E N 57 51 E N 57 37 E N 57 23 E N 57 11 E COMPUTATION DATE: 26-MAY-8g ARCO ALASKA, PT. I~CINTYR E WILDCAT NORTH SLOPE, INC. STAT5 ALASKA ~4 DATE KELLY BLSHING OF SURVEY: ELEVATION: ENGINEER: INIERP£L~TED V~LCES FOR EVEN 100 TRLE SUB-SEA MEASUEED ~ERT1CAL VERTZCAL DEPTH DEPTH DE PTH 4000.00 3287 .85 3245.40 4100.00 334e, .78 3307.33 4200.00 3412 .21 3369.7~ 4300.00 347] .39 3430.94 4400.00 3534 .C9 34S1.64 4500.00 3595.28 3552.83 4600.00 365~ .lO 3614.65 4700.00 3717.90 3675.45 4800.00 3777.93 3735.48 490'3.00 383E.26 3795.81 5000.00 389E .23 3855.78 5100.00 395E .51 3916.06 5200.00 401S .22 3976.T7 5300.00 4080.44 4037.95 5400.00 4142.81 4100.36 5500.00 4207.36 4164.91 5600.00 4273.09 4230.64 5700.00 4337.60 4295.15 5800.00 4402 .03 4359.5~ 5900.00 4465.98 4423.53 6 O00. O0 453C.. 31 448 7.8~ 6100.00 4594.65 4552.20 6200.00 4657 .46 4615.0C 6300.00 472C.05 4677.60 ~400.00 4781 .ST 4739.12 6500.00 4842 .94 4800.49 6600.00 4904.50 48~2.05 ~700.00 4965.70 4923.25 ~800.00 502~ .5! 4984.06 6900.00 508] .80 5045.35 7000.00 5145 .68 5107.23 7100.00 5211 .51 5169.06 7200.00 5272 .79 5230.34 7300.00 5333 .67 52S1.22 7400.00 5394 .40 5351.95 7500.00 5455 .91 5413.46 7600.00 551~.07 5475.62 7700.00 558C .45 5538.00 7800.00 564~ .56 5601.11 7900.00 5707.36 5564.91 FEET CF MEASURED £EPTF COURSE VERTICAL DCGLEG DE¥I~TION AZIMUTH SECTION SEVERITY DE6 MIN CE6 MIN FEET DEG/lOO 52 19 N 52 50 E 1824.83 51 10 N 53 9 E 1903.28 51 50 N 51 41 E 1981.32 52 33 N 50 56 E 2060.21 52 30 N 51 21 E 2139.48 52 0 N 51 44 E 2218.42 51 57 N 51 57 E 2296.89 53 2 N 52 5 E 2376.1~ 53 0 N 52 23 E 2456.03 53 1 N 53 42 E 2535.71 53 4 N 55 7 E 2615.73 52 45 N 55 27 E 2695.52 52 23 N 55 17 E 2774.98 52 5 N 55 28 E 2854.05 50 25 N 58 0 E 2932.17 4~ 21 N 58 14 E 3008.41 4~ 6 N 57 15 E 3083.69 4~ 57 N 56 48 E 3160.06 5C 9 N 56 33 E 3236.50 5C 8 N 56 15 E 3313.37 4S 43 N 56 7 E 3389.92 5C 37 N 56 18 E 3466.45 51 7 N 56 10 E 3544.25 51 49 N .55 18 E 3622.23 52 0 N 54 58 E 3701.07 52 12 N 54 11 E 3780.02 51 53 N 54 O 5 3858.81 52 37 N 53 36 ~ 3937.86 52 18 N 53 30 E 4017.22 52 0 N 5] 16 E 4096.20 51 45 N 5-: 31 E 4174.71 51 53 N 53 41 E 4253.28 52 25 N 53 58 E 4332.28 52 36 N 54 6 ~ 4411.60 52 26 N 54 12 E 4491.03 51 40 N 5~_ 50 5 4569.86 51 33 N 52 53 E 4648.16 51 9 N 51 27 E 4726.20 5(} 36 N 50 57 5 4803.57 4C~ 55 N 51 10 E 4880.38 RECTANGULAR COORC INAI':S NORTF/SOUTH EaST/WEST FEET FEET HORIZ. DIST. FEET 0.?0 0.69 1.~6 0.45 0.56 0.56 1.13 0.61 0.58 2.05 PAGE 2 23 42.45 FT D. WARNER 0.29 0.39 0 1.23 2.58 1.26 2.18 0 1.18 0.49 DEPARTURE AZIPUTH DEG MIN 0.86 1.54 0.35 1 .';2 0.36 0.83 0.~0 0.24 0.65 0.73 994.35 N 1531.25 E 1825.77 N 57 O E 1041.49 N 1594.02 E 1904.10 N 56 50 E 1088.93 N 1656.08 E 1982.01 N 56 40 E 1138.65 N 1'/17.60 E 2060.74 N 50 27 E 1181~.53 N 1779.45 E 2139.88 N 56 15 E 1231.70 N 1~41.41 E 2218.71 N 56 5 E 1286.22 N 1S03.25 E 2297.11 N 55 56 E 1335.09 N 1~65.81 E 2376.32 N 55 49 E 1384.12 N 2C29.00 E 2456.14 N 55 41 E 1432.31 N 2C92.54 E 2535.79 N 55 36 E 0.23 0.44 0.66 0.21 0.66 0.9Z 1.lB 1.13 0.51 1.00 1478.58 N 2157.83 E 2615.80 N 55 34 E 1524.00 N 2223.43 E 2695.59 h 55 34 E 156~.04 N 2288.89 E 2775.05 N 55 34 E 1614.19 N 2353.80 E 2854.12 N 55 33 E 1657.21 N 2419.04 E 2932.25 N 55 35 E 169'1.09 N 2484.17 E 3008.52 N 55 39 E 1737.24 N 2547.95 E 3083.83 N 55 42 E 1778.96 N 2611.96 E 3160.23 N 55 44 E 182~.94 N 2~75.~7 E 3236.68 N 55 45 E 186].44 N 2739.94 E 3313.56 N 55 46 E 1906.14 N 21~03.49 E 3390.12 1948.66 N 2667.14 E 3466.67 1991.87 N 2C, 31.86 E 3544.48 203,'3.66 N 2c, 96.39 E 3622.47 208C.79 N 3C61.03 E 3701.30 212~.51 N 3125.40 E 3780.23 2172.74 N 3189.22 E 3859.00 2219.48 N 3253.01 E 3938.03 2266.58 N 3316.91 E 4017.37 2313.78 N 3380.28 E 409f.32 5547 E 55 47 E 5548 E 55 48 E 55 47 E 55 46 E 5544 E 5541 E 55 3'~ E N 55 36 E 236C.62 N 3443.34 E 4174.82 N 55 34 E 2407.27 N 3506.59 E 4253.37 N 55 31 E 2453.91 N 3570.38 E 4332.35 N 55 29 E 250C.41 N 3634.65 E 4411.66 N 55 28 E 2546.99 N 3~99.02 E 4491.09 N 55 27 E 2593.17 N 3762.92 E 4569.91 N 55 25 E 263'~.83 N 3E25.84 E 4648.20 N 55 23 E 2687.78 N 31~87.55 E 472~.23 N 55 2~ E 273~.58 N 3947.85 E 4803.58 N 55 16 E 2784.94 N 4807.77 E 4880.38 N 55 12 E ARCO ALASKA, IKC. PT. ~CTNTYRE STATE kILDCAT NORTF SLaPE, ALASKA ~4 COMPUTATION CATE: 26-MAY-89 KELLY DATE BLSHING OF StJRVEY: ELEVATION: ENGINEER: PAGE 3 23 4Z.4S FT D. WARNER MEaSUrED DEPIH 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 6600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 ~900.00 10000.00 lalOO.OO lO2OO.OO 1c3oo.oo 10400.00 lO5OO.OO 10600.00 10700.00 lO8OO.OO 10900.00 11ooo.oo 111oo.oo 112oo.oo 113oo.oo 114oo.oo 11500.00 116oo.oo 117oo.oo 11800.00 11900.00 TRLE YERT1C~L DEFTP 5772.46 5836.91 5905 .B1 5972.78 6040.77 610E .37 6174.02 6236 6302.34 6366.69 6431 .04 6495.40 655S .59 6624 .08 668E .80 675_~.63 68%~ .44 6883.39 694H 7017 .09 7076 .gz 7146.50 7215.59 728E .25 7364.34 7441 .41 7520.53 7601.54 7684.81 7770.09 7855 .73 7942 .95 8032 .14 8122.92 8215 .07 8302 .71 8400.53 849': .70 8587.18 ~680.89 INIERPCLATED V~L~ES FOR SU8-SEA VERI ICAL DEPTH COURSE DE¥I~TIDN ~ZIMUTH DEf- MIN [EG MIN 5730.01 5796.46 5863.3d 5930.33 5998.32 6065.92 61.'31.57 619 5. 89 6259.89 6324.24 4H 46 N 51 32 E 4E B N 52 36 E 47 56 N 53 27 E 47 42 N 55 11 E 47 I N 55 36 E 4~ 11 N 53 35 E 4S 33 N 52 54 E 50 10 N 53 3 E 50 I N 53 10 E 50 I N 53 42 E 63~8.59 4~ 50 N 54 1 E 6452.95 50 6 N 53 54 E 6517.14 49 55 N 5) 47 E 6581.6~ 4~ 45 N 53 41 E 6646.35 4c, 39 N 54 25 E 6711.18 45 32 N 54 47 E 6775.9~ 4~ 31 N 55 7 E 6840.94 45 32 N 55 .8 E 6905.8~ 45 36 N 55 44 E 6970.64 45 22 N 57 1[ E 7036.47 7104.05 7173.14 7245.80 7321.89 7398.96 7478.08 7559.09 7642.36 7727.64 4E 10 N 57 30 E 46 57 N 57 18 E 45 1 N 58 10 E 41 40 N.5c, 53 E 4C 6 N 61 O E 3~ 34 N 60 29 E 3~ 50 N 59 29 E 34 53 N 57 56 E 32 9 N 55 I 7 E 31 10 N 55 4 E 7813.28 79(] O. 50 79~9.69 8080.47 8172.62 8265.26 8358.08 8451.25 8544.73 8638.44 36 38 N 54 58 E 27 55 N 54 49 E 25 53 N 54 58 E 23 48 N 55 39 E 22 11 N 55 6 E 22 0 N 54 58 E 21 35 N 54 44 E 21 1 N 54 2 3 E 2C 39 N .c~ 40 E 20 8 N 5~ 14 E EVEN 100 FEET CF MEASURED CEPTb VERTICAL SECTION FEET OCGLEG RECTANGULAR COORCINATES SEVERITY NORTF/SOLTH EAST/WEST DEG/ICO FEET FEET PDRIZ. DIST. FEET 4956.11 5030.73 5105.00 517 9.25 5252.57 5326.25 5401.62 5478.14 5554.92 5631.43 1.42 2832.45 N 4066.q7 E 4956.11 0.62 2878.36 N 4125.93 E 5030.73 1.27 2923.17 N 4185.23 E 5105.00 1.58 2966.43 N 4245.58 E 5179.26 1.40 3002.71 N 4]06.19 E 5252.58 2.51 3050.30 N 4_:66.31 E 5326.25 1.32 3095.68 N 4426.56 E 5401.63 0.47 3141.82 N 4487.67 E 5478.16 0.64 318'/.85 N 4549.19 E 5554.95 0.92 3233.60 N 4610.56 E 5631.46 5707.96 5784.48 5861.14 5937.54 6013.76 6089.89 6166.04 6242.09 6318.13 6394.30 0.15 3278.59 N 4672.48 E 5708.00 0.16 3323.60 N 4734.39 E 5784.53 0.41 3368.85 N 4796.29 E 5861.19 0.42 3414.08 N 4657.89 E 5937.60 0.56 3456.89 N 4519.57 E 6013.83 0.27 3502.93 N 4581.67 E 6089.96 0.65 3546.64 N 5044.04 E 6166.11 0.19 359~.11 N 5106.43 ~ 6242.16 1.24 3633.43 N 5168.93 E 6318.20 1.33 3675.56 N 5232.41 E 6394.36 6469.52 6543.16 6615.40 6683.90 6748.50 6811.87 6872.80 6931.30 6986.62 7038.84 1.67 3716.14 N 5295.81 E 6469.57 1.07 3755.75 N 5357.96 E 6543.19 4.02 3794.77 N 5418.82 E 6615.43 4.05 3829.87 N 5477.84 E 6683.91 0.63 3861.85 N 5534.30 E 6748.50 2.19 3892.66 N 5590.06 E 6811.87 1.~38 3923.31 N 5~42.96 E 6872.80 2.16 3953.61 N 5693.14 E 6931.30 2.61 3983.99 N 5739.40 E 6986.63 0.74 4014.04 N 5'/82.11 E 7038.84 7090.48 7139.36 7184.57 7226.47 7265.32 7302.96 7340.16 7376.50 7412.00 7446.88 1.96 4043.49 N 5E24.53 E 7090.48 2.23 4071.52 N 5E64.58 E 7139.36 2.19 4092.66 N 5501.47 E 715{4.58 1.76 4121.36 N 5536.0£ E 722d.48 0.59 414~.45 N 5~367.98 E 7265.33 0.27 4165.05 N 5998.81 E 7302.97 0.20 418d.39 N 6029.27 E 7340.16 0.57 4202.52 N 6(258.84 E 7376.50 0.47 4228.33 N 6087.62 E 7412.00 0.61 4245.17 N 6115.61 E 7446.89 DEPARTURE AZ IMUTH DEG k 55 E E N 55 5 E N 55 4 E N 55 3 E N 55 4 E h 55 3 E N 55 1 E N 55 0 E N 54 5~ E N 54 57 E N 54 56 E N 54 55 E N 54 54 E N 54 54 E h 54 53 E N 5z, 53 E N 54 53 E h 54 53 E N 54 53 E N 54 54 E N 5z, 56 E N 54 5E E N 54 5~ E N 55 2 E N 55 5 E h 55 8 E N 55 11 E N 55 13 E N 55 14 E N 55 13 E 55 13 E N 55 13 E 55 l_! E 5513 E N 55 13 E N 55 13 E 5513 E N 55 13 E 55 13 E 55 12 E ARCO ALASKA, PT. MCINlYRE WILDCAT )~DRTP SLOPE, INC. STATE ALASKA ~4 £OMPLT~TION MEASUREO DEPTH /'12000.00 ='.12100. O0 12200.00 12300.00 12400.00, 12500.00 CATE: 26-MAY- 89 INIERPI]L,~TED V.~LL, ES FOR EVEN 100 TRLE SUB-SEA COURSE VERTICAL YERT1CAL VERTICAL DEVIATION ~ZIMUTH SECTI'ON DEFTH DEPTH DEC- MIN £EG MIN FEET N 54 16 E'. 7481.00 N 55 3 E 7514.72 N 54 51 E 7548.75 N 53 56 E 7582.82 N 51 30 E 7616.54 N 45 13 E 7649.87 8774.88 8732.43 15 46 886c~.03 8826.58 lg 46 8962.06 8920.61 15 59 9051.08 9014.63 19 48 9151.21 ]!.;,9108.76,,9 If 41 9245.45 203.00 19 17 DAlE OF SURVE'T: KELLY BLSHING ELEVATION: ENGINEER: FEET CF ME~SU~EO CEPTf DOGLEG ~ECTANGUL AR COOREINATES SEVERITY k DR TN /SD~ TH EAST/WEST BEG/lO0 FEET FEET 0,71 0.26 0.45 0.28 0.19 2.03 4265.42 N 6143.08 E 4288.84 N 6170.64 E 4308.30 N 6198.57 E 4326.16 N 6226.25 E 434~.52 N 6253.16 E 436~.84 N 6278.93 E HORIZ. DIST. FEET P~GE 4 23 42.45 ET 0. WARNER DEPARTURE AZIMUTH DEG MI N 7481.00 N 55 12 E 7514.72 N 55 11 E 7548.75 N 55 11 E 7582,82 N 55 11 E 7616.54 N 55 11 E 7649.87 N 55 $ E ARCO A!aska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 2;'6 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, /- ~s ,~. w, ine~'~'- ' ..... .""Senior Land~,,~ //' JRW:hb Enclosures ,, CC: M. L. Bill L. D. Brown H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATO 1528 LAO 466 ATO 1918 ATO 1420 ATO 1202 ATO 496 ATO 1439 RECEIVED APR 14 1995 Alaska Oil & Gas Cons. Commission Anchora. ',' ARCO Alaska, Inc, is a Subsidiary of Atlantic Richfield Company RECEIVED Greater Pt. Mclntyre Area (ARCO Contact: George Phillips 263-4280) APR 1 4 1995 Alaska 0il & Gas Cons. Commission Anch0ra,"~ ARCO hereby requests extensions of "suspended" status for the following wells. Additionally, an exception to the surface plug requirement of AOGCC 20AAC25.110(c) is requested. All of these wells are located in safe and accessible locations on producing drill sites that are monitored daily. The individual status of each well is detailed below. West Beach State #3, APl # 50-029-20208-00,. Permit # 76-0034-0 This well was Certified Capable of Producing in Paying Quantities on February 1, 1979. The well was with suspended with a cement plug. An abandonment cap has been installed and tested. This well has the potential for use as a gas injection well to support the West Beach #4 well either by re-entering and/or sidetracking. Pt. Mclntyre P2-59 (PM-9), APl # 50-029-22096-00, Permit #90-0140-0 This well has not been tied into the facilities. It tested at a rate of 1208 BOPD from the Kuparuk formation. It was suspended with tubing and packer and with a plug in the tubing. The SSSV is closed and a back pressure valve is set. To produce this well will require a workover. This well is being evaluated as a producer. More data from offset Pt. Mclntyre wells is being used to determine the economics. Pt. Mclntyre P2-50A, APl # 50-029-22261-00, Permit # 92-0065-0 This well is being evaluated as a sidetrack to a new Pt. Mclntyre development location. The following wells have changed their status since you requested your update: Pt. Mclntyre P1-03 (PM~4), APl # 50-029-21912-00, Permit # 89-0013-0 This well was Certified Capable of Producing in Paying Quantities on February 13, 1989. This well is now a producer. Pt. Mclntyre P1-25 (PM-5), APl # 50-029-21937-00, Permit # 89-0041-0 This well was worked over in August of 1994 and converted to a water injection well. ARCO hereby requests extensions of "suspended" status for the following wells. Gull Island State #1, APl # 50-029-20151-00, Permit #.74-0057-0 This well was Certified Capable of Producing in Paying Quantities on February 1, 1977. Gull Island State #2, APl # 50-029-20195-00, Permit # 76-0013-0 This well was Certified Capable of Producing in Paying Quantities on April 26, 1977. The following wells have changed their status since you requested your update: Pt. Mcintyre P1-03 (PM-4), APl # 50-029-21912-00,.Permit #.89-0013-0 This well was Certified Capable of Producing in Paying Quantities on February 13, 1989. This well is now a producer. Pt. Mclntyre P3-01 (PM-5)., APl # 50-029-2.1937-00, .Permit # 89-0041-0 This well was worked over in August of 1994 and converted to a water injection well. Pt. Mclntyre P2-50A, APl # 50-029-22261-00, Permit # 92-0065-0 This well was suspended with a waiver for a bridge plug at 200' & 300'. This well is being evaluated as a sidetrack to a new Pt. Mclntyre development location. 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 August 19, 1994 David Sutter, Land Manager A~RCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Suspended Wells Compliance with regulations Dear Mr. Sutter: ARCO Alaska Inc. has 25 suspended wells as shown on the attached lists: ARCO SUSPENDED WELLS PRIOR TO 1980 and ARCO SUSPENDED WELL SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections this year prior to snow covering the locations. · Chairman encls c: Blair Wondzell bew/llarsusp PERMIT 00 - 0242 - 0 68-0095-0 69-0036-0 73-0027-0 74-0056-0 74 - 0057 - 0 76-0013-0 76 - 0017 - 0 76 - 0034 - 0 78 - 0017 - 0 API NUMBER 029-21821-00 029-20004-00 029-20017-00 179-20004-00 029-20150-00 029-20151-00 029-20195-00 029-20199-00 029-20208-00 029-20278-00 ARCO SUSPENDED WELLS PRIOR TO 1980 AS OF AUGUST 1994 WELL WELL WELL NAME CLASS STATUS PRUDHOE BAY UNIT OWDW-C SER SUSP DELTA ST I EXP SUSP PUT RIV ST I EXP SUSP KAVIK UNIT 3 DEV SUSP DELTA ST 2 EXP SUSP GULL IS ST 1 EXP SUSP GULL IS ST 2 EXP SUSP HIGHLAND ST 1 DEV SUSP W BEACH ST 3 EXP SUSP W MIKKELSEN ST 1 EXP SUSP STATUS DATE 6/23/73 2/27/69 7/01/69 5/02/74 5/17/75 4/01/76 4/22/77 4/12/76 7/26/76 il/11/78 SECT 11 10 O7 O8 35 28 28 24 25 32 TWP 10N 10N 1 ON 03N llN 12N 12N llN 12N 10N RNG 014E 016E 014E 023E 016E 015E 01SE 011E 014E 019E MER U U U U U U U U U U PER~IT 60 - 0041 82 - 0038 82 - 0218 83 - 0181 84 - 0156 84-0205-0 86 - 0056 89-0013-0 89 - 0041 90-0036-0 91 - 0069 92 - 0065 93 - 0174 93-0179-0 94 - 0043 API NUMBER 133-10142-00 029-20727-00 029-20888-00 029-21056-00 029-21181-00 029-21221-00 029-20138-01 029-21912-00 029-21937-00 029-22027-00 029~22173-00 029-22261-01 029-22419-00 029-22423-00 029-20614-01 ARCO SUSPENDED WELLS SINCE 1980 AS OF AUGUST 1994 WELL WELL WELL NAME CLASS STATUS SWANSON RIV UNIT 34-15 DEV SUSP KUPARUK RIVUNIT 1H-05 DEV SUSP RAVIK ST 1 EXP SUSP HEMI SPRINGS ST 1 EXP SUSP PRUDHOE BaY I/NIT DS18-11 DEV SUSP PRUDHOE BaY UNIT DSl1-15 DEV SUSP W BEACH ST 1-a SER SUSP PT MCINTYRE P1-03 EXP SUSP PT MCINTYRE P3-01 DEV SUSP KUPARUK RIV UNIT 1L-20 DEV SUSP KUPARUK RIV UNIT 1L-26 DEV SUSP PT MCINTYRE P2-50A DEV SUSP KUPARUK RIV UNIT 2E-17 DEV SUSP KUPARUK RIV UNIT 2E-05 DEV SUSP PRLIDHOE BaY UNIT DS12-13A DEY SUSP STATUS DATE 8/21/91 5118182 4/03/83 4/03/84 9/17/84 2/14/91 5/06/86 4/26/89 7/03/89 3/31/91 6/09/91 8/30/92 4/25/94 4/25/94 4/03/94 SECT 15 33 32 12 19 33 25 16 22 29 32 14 36 36 18 TWP 12N 09N 10N llN llN 12N 12N 12N llN llN 12N llN llN 1 ON RNG 009W 010E 009E 011E 01SE 015E 014E 014E 014E 010E OIOE O14E 009E 009E 01SE MER S U U U U U U U U U U U U U Date: Subject: From: To: ARCO Alaska Inc. Greater Point McIntyre Engineering May 13, 1994 Transmittal Number ARCO Alaska, Inc. Bob Crandall AOGCC S001 Porcupine Drive Anchorage, AK 99501 724 The following Greater Point McIntyre Area data are enclosed. and your cooveration in maintainine confidentiality is avvreciated: P1-03 v/FINAL LOG: Perforation Record (2 1/8 Enerjet) I 4-15-94 P2-21 v/FINAL DISKETTE: MWD Sub-Surface 4-25-94 v/Directional Survey 9q-3 P2-31 ,/r-FINAL TAPE: DLL/ZDL/CN/GR 7099 - 9806 ' 1 4-10-94 w/LIS (LDWG) Vet P2-54 '/'FINAL DISKETTE: MWD Sub-Surface 5-10-94 JDirectional Survey This information is confidential Schlumberger Sperry Sun Atlas Wireline Sperry Sun Please sign ._~ _.~~..~ and return to: Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS September 13, 1991 David W. Johnston, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Release of the data from the Pt. Mclntyre #4 well Dear Commissioner Johnston: WALTER J. HICKEL, GOVERNOR P.O. BOX 107'034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 (907)762-2547 - I granted extended confidentiality for the Pt. Mclntyre #4 well until 90 days after the unleased land within three miles of the bottom hole location of this well was offered for lease. This unleased land was offered for lease in State Sale 65 and Federal OCS Sale 124 which were held on June 4, 1991 and June 25,-1991 respectively. Therefore, the well no longer qualifies for extended confidentiality and the well data should be released on September 24, 1991. By copy of this letter I am notifying ARCO Alaska Inc., BP Exploration (Alaska) Inc. and Exxon Co. USA of the upcoming release of the Pt. Mclntyre #4 well. Sincerely, ~i?tc~ oEr. Easo. CC: James M. Davis, Senior Vice President of Exploration & Land, ARCO Alaska Inc. Eric Luttrell, Vice President of Exploration, BP Exploration (Alaska) Inc. Ed Turner, Land Supervisor for Alaska, Exxon Co. USA RECEIVED SEP 1 1 t99t Alaska Oil & Gas Cons. 6orainissio~ Anchora~le ,>, DEi'ART~NIENT OF LA%V OFFICE OF THE A TTORNEY GENERAL July 18, 1991 Shawn J. Holliday Groh, Eggers & Price 2550 Denali Street, Suite 1700 Anchorage, Alaska 99503 Billie Pirner Garde Hardy, Milutin & Johns 500 Two Houston Center 909 Fannin at McKinney Houston, Texas 77010 WALTER J. HICKEL, GOVERNOR REPLY TO: ~ 1031 w 4TH AVENUE, SUITE 200 ANCHORAGE, ALASKA 9950 I. 1994 PHONE: (907) 269-5100 FAX: (907) 276-3697 ~ KEY BANK BUILDING 100 CUSHMAN ST., SUITE 40O FAIRBANKS, ALASKA 99701-4679 PHONE: (907) 452-I568 FAX: (907) 456-1317 I~ P.O. BOX K. STATE CAPITOL JUNEAU, ALASKA 998I 1-0300 PHONE: (907) 465-3600 FAX: (907) 463-5295 Re: Exxon Corp. v. Burglin, civ. H-90-3995 Our file: 661-92-0017 Dear Mr. Holliday and Ms. Garde: I represent the Alaska Oil and Gas Conservation. Commission with respect, to the deposition subpoena that was directed to its records custodian in the above-referenced case. Some of the materials requested in that subpoena are required to be maintained confidential by AS 31.05.035(c). A review of the Commission's files shows that these materials are the reports and information required by AS 31.05.035(a) for Pt. McIntyre 3, 3 dpn, 4, 5, 6, 7, 8, 9, 10, 11, 12, and 13. Since the Commission is precluded by law from disclosing these materials, the Commission objects, pursuant to Federal Rule of Civil'Procedure 45(d) (1), to inspection or copying of these materials. I note that all of the materials in question were filed with the Commission by the owners of the wells to which they relate, and that the owners themselves are of course not subject to the constraints of AS 31.05.035(c). Perhaps you will wish to consider directing your discovery efforts to those owners. REC/ IVE,D JUL ! 91991 /~[aska ,Oil &, u~as Co,s, Sincerely, CHARLES E. COLE ATTORNEY GENERAL By: Robert E. Mintz Assistant Attorney General 03-CSLH June 10, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 9950~1-3192 PHONE: (907) 279-1433 TELECOPY: (907) 278-7542 Shawn J. Holliday Groh, Eggers & Price 2550 Denali Street, 17th Floor Anchorage, AK 99503-2796 Re: Confidentiality-Pt. McIntyre #1, #2, #3 & #4 Dear Mr. Holliday: Concerning your request about the early release of confidential information from Pt. McIntyre #1, #2, #3 & #4, AS 31.05.035 states, in part: "(c) The reports and information required in (a) of this section shall be confidential for 24 months following the 30 day filing period unless the owner of the well gives written permission to release the reports and information at an earlier date." The Commission has always interpreted this provision as authorizing the early release, with the owners written approval, of confidential well information to the general public, not a selective release to'one individual. Accordingly, if the owner(s) of Pt. McIntyre #1, #2, #3 & #4 authorize the early release of the well data, the Commission will make this data available to the general public. Sincerely, Chairman DEPT. OF NATU~AL ~~OUI~CE~ May 17, 1991 DIVISION OF OIL AND GAS Jerry L. D¢cs Vice President ARCO Alaska Inc. P.O. Box 100360 Anchorage, AK 99510-360 Subject: Request for extended confidentiality Pt. Mclntyre # 4 and #5 wells ~t~ // WALTER d. HICKEL, GOVERNOR RO. BOX 107034 ANCHORAGE, ALASKA' [!~l~-~- , h~) PHONE: (907) 762-2553 RES ENG ,1~ ENG ASST ! ENG ASST I Dear Mr. Dees: In your May 1, 1991 letters you requested extended confidentiality for the Pt. Mclntyre # 4 and #5 wells under the authority of 11AAC 83.153, which provides in pertinent part: "If the commissioner finds that reports of information required under A.S. 31.05.035(a) contain significant information relating to the valuation of unleased land within a three mile radius of the well from which these reports or information are obtained, the commissioner will upon written request of the owner of the well, keep the reports or information confidential for a reasonable time not to exceed 90 days after the disposal of the unleased land, unless the owner of the well gives permission to release the reports and information at an earlier date." The Pt. McIntyre #4 and #5 wells (bottom hole locations) lie approximately 1.8 and 2.6 miles, respectively, from unleased land which is currently included as part of the State Lease Sale 65. Lease Sale 65 is currently scheduled for June 4, 1991. Additionally, the Pt. Mclntyre #4 and #5 wells (bottom hole locations) are within 2.8 and 2.6 miles, respectively, of unleased land that is currently scheduled to be offered in Federal OCS Sale 124. OCS Sale 124 is currently scheduled for June 25, 1991. Following your request for extended confidentiality, a review of the data was made by Division of Oil and Gas technical staff. Based upon the recommendation of division technical staff and under the departmental delegation of authority, I agree to extend the confidentiality of the data from Pt. Mclntyre #4 and #5 wells until 90 days after OCS Sale 124 is held. By copy of this letter I am requesting that the Alaska Oil and Gas Conservation Commission extend the confidentiality of data from the Pt. Mclntyre # 4 and #5 wells until further notice. Sincerely, E. Eason Director cc' D. W. Johnston, Commissioner, AOGCC J. R. Winegarner, ARCO RECEIVED MAY 2 1 t99t Alaska Oil & Gas Cons. Commission Anchorage AP, CO ALASKA, INC. DEV. & [)CT GEO$CI[NC[ TkkNS"t ,rr ,o LARRY GRANT - AOGCC i · IL I · ii i A~DR~S$:_ 3001...PORCUPINE STREET lit _ ANCHORA~Erl AK 99501 _1 i i I CRAIG MOSELEY - AAI . _ ii ~)AT~:_ AUGUST 6; 1990 Transmitted herewith are the following: ONE COPY FLOW TEST ARCO: PT. MCINTYRE #4 MAY 1-6, 1989 WELL TEST DATA REPORT 1. Test Results (Tests #2 & #3) 2. Description 3. Oil Flow Rate Calculations 4~ Gas Flow Rate Calculations 5. Field Readings and Charts RECEIPT Return receipt to: RECEIVED AUG o 6 'ARCO Alaska) Zneo DEV & EXT GEOSCIENCE A~: ~uotlle Johnston P, O, Box 100360 Anchorage, Alaska 99510 ANO - 17~E Proceso~d TELECOPY NO: (907) 276-7542 April 11, 1990 Shawn J. Holliday Groh, Eggers & Price 2550 Denali Street, 17th Floor Anchorage, Alaska 99503 Dear Mr. Holliday, I am in receipt of your second letter requesting the release of certain confidential information from Pt. McIntyre #3, ~3Dpn and ~4. You indicate that your clients, CFM Corporation, Cliff Burglin and Charles Hamel, are entitled to view the requested information because of a prior limited partnership they had with Exxon covering state leases ADL 34622 and ADL 34623. Unfortunately, the Commission must deny you access to these records. Our files do not show CFM Corporation, Cliff Burglin or Charles Hamel to be owners, or part owners, of either the Pt. McIntyre ~3 and ~3Dpn or Pt. McIntyre ~4 well. Information submitted under AS 31.05.035 must remain confidential for at least 24 months, unless the owner of the well gives written permission to release the data at an earlier date. The owners of record for Pt, McIntyre ~3 and ~3Dpn, drilled to a bottom hole location on ADL 28297, are ARCO and Exxon. The owner of record for Pt. McIntyre ~4, which is drilled to a bottom hole location on ADL 365548, is BP Exploration. Although the Commission cannot now allow you access to the data from these wells, we will assist you in an appropriate ma~ner once that information becomes public. However, please be advised that the Department of Natural Resources has requested the well information from Pt. McIntyre ~3 to be kept confidential until after the disposition of unleased lands in proposed lease sales 70A and 65, scheduled for September 1990 and May 199], respectively. Shawn J. ttolliday Groh, Eggers & Price April 11, 1990 Page2 You also requested other information concerning the development of the Pt. Mclntyre area and the Gwydyr Bay Unit. A number o~ wells, which are no longer held confidential, have been drilled in the area Ih_ Commission's well files for those wells may be inspected in our offices. The Conm~ission does not possess any geophysical, chemical or paleontological data from the Pt. Mclntyre area Or the Gwydyr Bay Unit. However, some core data from area wells may be available from the Geological Material Center, 18205 F~.sh ]{;.~tc~ery Rd, Eagle River, Alaska; John Reeder, Curator. Finally, you requested the names and dates of services for former commissioners of the Commission. The Co~mnission, as it is currently structured, was formed in January ]979. The following individuals have served as commissioners since that time. Hoyle Hamilton -- January 1979 to December 1981 Harry W. Kugler -- January 1979 to May 1986 Lonnie C. Smith -- January 1979 to present C. V. Chatterton -- January 1982 to present W. W. Barnwell -- June 1986 to August 1988 David W. Johnston -- January 1989 to present If you have any questions concerning this matter, please give me a call at 279-1433. Commis sione~ jo c: Douglas B. Bally Attorney General CLIFFORD J. GROH, SR. KENNETh P. EGGERS, P.C. MICHAEL W. PRICE LANCE E. GIDCUMB SALLY KUCKO ROBERT T. PRICE DENNIS G. FENERTY DAVID A. DEVINE, P. C. REBECCA S. COPELAND RICK L. OWEN DOUGLAS a. CARSON SHAWN J. HOLLIDAY BRYAN S. m ERRELL __ Of COUNSEL MITCHELL D. GRAVO, P. C. LAW OFFICES OF GKOH, EGGEtk5 8 PIKICE 2550 DENALI STREET, 17T-.H FLOOR ANCHOR.AGE, ALASKA 99503 April 3, 1990 David W. Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RE: Our File No. 587-2 Dear Mr. Johnston: TELEPHONE (,907) :~72- 6474 TELECOPIER (907) 272- 4S,7 ' - ~'., ~. ....--I, sn 1 I received your letter dated February 20, 1990 indicating that the information we have requested, i.e., copies of the directional survey and other information, used to determine the path of the well bore Pt. McIntyre Nos. 3DPN and 4, is confidential under AS 31.05.035 and accordingly cannot be turned over to us pursuant to AS 09.25.120(4). Apparently there has been some confusion. Although this information may be confidential to the public, it is not confidential to my clients, CFM Corporation, Cliff Burglin and Charles Hamel. That company and those individuals were limited partners in Exxon MBH-Alaska, Ltd. while geological testing, geological analysis and well drilling was being undertaken on the · above-referenced wells. My clients have a legal and equitable interest in leases ADL 34622 and 34623 and oil production of the wells located thereon. Accordingly, I request, on behalf of my clients, all information which the Commission has received concerning those wells pursuant to the Commission's reporting requirements under AS 31.05.035(1) thru (3). Further, I request any and all other materials regarding development of the McIntyre oil field and the Gwyder Bay Unit, including without limitation all tests performed such as geophysical, chemical and paleontological tests, all maps, memoranda from all sources, information or knowledge concerning ' untapped formations such as, but not limited to, the Sadlerochit and Lisburne formations. My clients seek all information accumulated from the inception of exploration on the North Slope to and including all information from the 1990 drilling season whether complete or not, whether formal or informal. This request is specifically made under AS 9.25.110 and 9.25.120. ~ E C E IV APt? - 4 1990 Alaska 0ii & Cons. Ancholage '~David W. Johnston April 3, 1990 Page 2 Please also advise where I may obtain a list of all commissioners of the Commission over the last fifteen (15) years and the dates they served With the Commission. As soon as the foregoing information and/or documents are available, please notify either myself or Robert T. Price at the above address and we will come by and pick them up. Your assistance in this matter is appreciated. If you have any questions concerning the above, please feel free to contact me. Very truly yours, SJH:af GROH, EGGERS & PRICE Shawn J~liday ~ cc: Douglas B. Baily Attorney General SHC/C- Johnston February 20, 1990 TELECOPY NO ~ (907) 276-7542 Rick L. Owen Groh, Eggers & Price 2550 Dena!i Street, 17th Floor Anchorage, Alaska 99503 Dear Mr. Owen: I have received your request under AS 09.25. ]10 and AS for ceytain information from oil and gas well,.~-~. McIntyre Specifically, you requested copies of the direc-t~fodal surgeY" and ..... other information used to determine the path of the well bore. You also requested similar information for Pt. McIntyre ~3 and ~3DPM. The informmtion you have requested is held confidential under AS 31.05. 035. Accordingly, I must deny your access to these records. As you are aware, AS 09.25.120 sets out specific exceptions to the public's right to inspect the files and records of state agencies. The relevant exception in this matter is: "4) records required to be kept confidential by a federal law or regulation or state law (emphasis added)." AS 31.05.035 requires the Commission to hold the information that you requested from these wells for at least two years following the filing of'their completion report. The confidentiality period for Pt. McIntyre ~4 expires on May 27, 199!, and for Pt. McIntyre ~3 and ~3DPN on May 14, 1990 and April 9, 1991, respectively. Until then, the Commission will only release the well location, depth, status and production data and reports any), which are considered public information. If you have any questions concerning this matter, please call me at (907) 279-1433. Commiss longer dlf:DWJ CLIFFORD J. GROH, SR. KENNETH P. EGGERS, P. MICHAEL W. PRICE LANCE E. GIDCUMB SALLY KUCKO ROBERT T. PRICE DENNIS G. FENERT¥ DAVID A. DEVINE, P. C. REBECCA S. COPELAND RICK L. OWEN DOUGLAS A. CARSON SHAWN J. HOLLIDA¥ BRYAN S. MERRELL __ OF COUNSEL MITCHELL D. GRAVO, P. C. LAW OFFICES OF GR. OH, EGGER.5 g PR. ICE 2550 DENALI STREET, ITT..H FLOOR . ANCHORAGE, ALASKA 99503 February 15, 1990 Dave Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: McIntyre Field and Well Information Discovery Royalty for ADL 28297 Our File No. 587-2 Dear Commissioner Johnston: TELEPHONE (.90'7) 2?2- 6474 TELECOPIER This law firm represents CFM Corp (successor in interest to Weldtest Inc. and Thomas and Helen Miklautsch), Cliff Burglin and Charles Hamel. Our clients may have a claim, and/or interest, in the McIntyre find through ADL Numbers 34622 and 34623. On January 24, 1990, and on January 30, 1990, I met with Larry Grant at your office concerning well information on the McIntyre field, including information on McIntyre Wells 1 through 8, and Point Storkerson. After reviewing the files provided by your office there are several items of information which we would like clarified. Due to the variations between the actual bottomhole location and the drilling permit bottomhole location for McIntyre No. 4 and because McIntyre No. 4 appears to have been drilled through a portion of ADL 34622, we respectfully request copies of the Subsurface Directional Surveys or any similar documents used to determine the bottomhole location and drilling paths for that well. In addition to this information on McIntyre No. 4, we also ask that you send us the same reports and information, if any such exist, on McIntyre Well Nos. 3 and 3 dpn. The foregoing request is specifically made under A.S. 9.25.110 and 9.25.120. As soon as the foregoing information and/or documents are ,available, please notify either myself or Robert T. Price at the above address and we will come by and pick it up. Your assistance R[CEIV[!) ;::'E,[.'] 1 6 19!3'/, ', / rlchores,a Dave Johnson February 15, 1990 Page 2 in this matter is appreciated and if you have any questions regarding the above, please feel free to contact me. Very truly yours, RLO/sds SSC/C-587-2 ARCO Alaska, Inc, Legit Post Office Bo× 100360 Anchorage, Ataska 99510 Telephonic 907 2~5 6549 Senior Attorney February 8, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Notice of Produced Fluids Disposal Dear Mr. Chatterton: The purpose of this letter is to ~otify the AOGCC that ARCO Alaska, Inc., as Operator of the Pt. McIntyre #4, Pt. McIntyre #7, Pt. McIntyre #8, and the Lisburne Delineation Well 2-J, intends to take produced fluids from these wells to either the Lisburne Production Center or a facility owned by the Initial Participating Areas of the Prudhoe Bay Unit. The purpose of this procedure is to avoid wasting these fluids by injecting them into disposal wells. The AOGCC has concurred with this procedure by letter dated January 9, 1990. If you have any questions regarding this matter, please contact the undersigned. Very truly yours, A. M. Tadolini AMT:pg cc: Exxon Corporation BP Exploration (Alaska) Inc. J. D. Dayton/ATO-476 M. A. Major/ANO-1200 RECEIVED Gas Cons. Anchor~,a ARCO Alaska. ir~c. is a Subsidiary of AtlanticRichfieidCompany ARCO Alaska, Inc. Post Office~,ox 100360 Anchorage, Alaska 99510-0360 Telephone 9072761215 SAMPLE TRANSMITTAL TO: State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle OPERATOR' Arco SAMPLE TYPE: core chips & dry ditch SAMPLES SENT: DATE: October 4, 1989 AIRBILL #: n/a AFT#: n/a CHARGE CODE#: n/a NAME: P~nint Mclnt~(re #4 NUMBER OF BOXES: 26 boxes Core Chips Core Chips con't. I I 691 -1 I 728 I 2259-1 2297 11729-11766.4 12298-12333 12093-12126 12153-12187 12188-12225 12226-12258 12334-12374 12375-12416 12417-12455 12456-12494 12495-12511 (1' interval) Dry Ditch Dry Ditch con't. 115-1200 6697-7990 1200-2400 2400-4050 4050-5202 5202-6100 6100-6997 7990-9100 9100-10420 10420-11355 11360-11700 11700-12230 12230-12845 (10' interval) SENT BY: Angela Langston UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P. O. BOX 100360 ANCHORAGE, AK. 99510 ATTN: ABV-100 RECEIVED BY' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCornpany /~l~:;I~, ~;/il/~ (; ARCO AL.A~,.kA, INC~ D E V E L. 0 PM E N T G E 0.? C I E N C E T RAN,~'M I TTAL. TO' ~.;,JHiq BOYI..E 'I"F;,'AN,S:MITTI::]D t"It~]REWITH ARE] '1"HE F:'OLI..OWIN[;' ONE TAPE COI::'Y ARCO' F'T,. MC: INTYRE ~,T4 RE]CE I PT ACK NOWI...I-]]DGMt~:.:NT · R E T ti R N R E C I.']] I P T T 0: A R C 0 A L.. A S' K A, I N C,. DI""]VE]t..OF'MEN T GI':]O ~:C ! !":'iNC E ATTN: LLICI L.L.E J O I"1N."i"T' 0 N F', O, }:','OX ANCFIORAGE, AL. ASKA 995'i(') ANO'"8,¢[:. "~' ' - C ,~"' PROCi:.,~$E.D BY i..ll II..I..E .JOHN,. ION ARC~ ALASKA, olNC, ~~ DEYEI. OFMENT GEO~CIENCE TRANSMITTAL 'T'O: JOHN BOYLE AOGCC SO~t F'ORCUF'INE DR, ANCHORAGE, AK 9950t CRAIG MOSELEY - AAI AUG t6, t989 TRANSMITTED HEREWITH ARE THE FOL. L. OWING: ONE COF'Y ARCO: PT~ MC INTYRE ,~4 (KUF'ARUK ZONE) RE~'ERVOIR FLUID STUDY 6i2E-i738 WEL. L RFL. 89(~2i6 (PVT ANALYSIS) RECEIPT ACKNOWLEDGMENT: RETURN RECEIPT l'O: ARCO ALASKA, INC. DEVELOPMENT GEO$CIENCE ATTN: LLICILLE JOHN~.TON ANO--879E F'. O. BOX i04)S6Q ANCHORAGE, A:.A,?KA 995~(') PROCESSED BY: I..UCIL. I..E .JOHNSTON ~RCO AL;SKA, iNC. CEVELCPMENT GECSCir'_NC ~ TRANSMITTAL TO: JCHN ~3YLE 4CGC 3001 PGRCLPiNE DR. ANCH2RAGE, AK 995C1 CRAIG MESELEY - ~I JbLY 10, 1989 TRANSMITTEG HEREWiTh ARE ThE m2LLCWING: 1 ~LbELIN~ & I SEPIA E~CH ARCO: PT. MCINTYRE ~4 04-17-89 ~C~IL/TVG 11348-12818 RUN 2 2" & $" " ~'""~ C N L C/T V D 11348-12822 " " " ~ NGT/TVO 113~8-12750 " " ~EPT/TV'~ I1348-1277~ " " " ~A~ SNtTVD 11345-12785 " " 04-17-89 ---,-~'~ ML/TVD 11348-12778 Run 2 5" 04-17-:59 ~DiL/RHSR 9965-i2815 RUN 2 Z" 6 5" " ~AR SNIWF I0625-127~5 " " ~ AR SC~IC 9965-127~$ " 2" & 5" ', m~ ERT 11348-1277~ " $" " ~ NOT 10625-12750 " 2" 6 5" "~ CNLD 11348-12822 " " 04-13-~c3 ~ ~MS(~-P~) 11438-1259~ " 5" 04-17-~g ~ ML-GR 11348-12776 RUN 2 04-29-89 ~_ DPTH DETRM 10700-11887 RUN 1 5" RECEIPT ACKNOWLEDGMENT: RETbRN RECEIPT TO: ARCO ALASKA, iNC. DEVELOPMENT GEOSCIENCE ~TTN: LUCILLE JOHNSTON P. O. ~OX 1003o0 ANCHCR~GE, ALASKA 99~10 PROCESSED BY: LUCILLE JOHNSTON ARCO ALoASKA, INC. DEYELOF'MENT GEO$CIENCE TRANSMITTAL TO: JOHN BOYLE AOGC 30eJ F'ORCUF'INE DR. ANCHORAGE, AK 9950~ CRAIG MOSELEY - AAI JUNE TRANSMITTED HEREWITH ARE THE FOLLOWING: t BL. UEL. INE & t SEF'IA ARCO: PT. MCINTYRE ~4 e4-~7-89 R$CT CORRELATION-GR l168e-t255e RUN t 5" RECEIF'T ACKNOWLEDGMENT' _ ................ RETURN RECEIPT TO: ARCO ALASKA, INC. DEVELOPMENT GEO;~'CIENCE ATTN: LUCILL. E JOHNSTON F', O, BOX 'leO36(!) ANCHORAGE, ALASKA 995~0 DA TEAtesteew3ff..&..6~E(.?on:.;' '., ..... . Anr:ilor(.~g~ ~u~tI'T]tS$101-1 ANO-87~E PROCESSED BY: L. UCII..LE ..JOHNSTON ARCO ALASKA, INC', DEVELOPMENT GEOSCIENCE TRANSMII'TAL. 'FO: JOHN BOYLE AOGC SO(~t F'ORCLIF'INE DR. ANCHORAGE, AK 99501 .CRAIG MOSELEY-- AAI JUNE' t4, t989 TRANSMITTED HEREWITH ARE THE: FOI_I_OWING: ONE COPY ARCO: F'T~-MCINTYRE ~4 ~5-'2S-'89 $CHi..UMB GCT GYRO SURVEY ,.lOB $7SS0t (FINAL) RECEIPT ACKNOWLEDGMENT: CommJssio~ RETURN RECEIP'¥ TO: ARCO ALASKA, INC. DEVEI_OF'MENI' GEOSCIIENCE ATTN: LUCILLE dOHNSTON F', O, BOX t04)S60 ANCHORAGE, ALASKA 9951 Anchorage ANO--879E PROCESSED BY: L. LICII_I_E] JOHN$1'ON ARCO Alaska, Inc. !:~':~'-~'~ ~;¢~-J ~. ,~.,, .... ~o× 100360 ~:,~ch~:,~?a~;~e~ A~ska 9951- '-' '~"" June 5, 1989 C.V. Chatterton Chairman, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 Dear Commissioner Chatterton: Attached as required is the completion report and well summary of Point Mclntyre #4. The coring and logging summaries will be sent under seperate cover. It is requested that in accordance with the Commission's rules that all information about the well be kept confidential. Should further information be required, please contact the undersigned concerning well operations at 263-4971 and contact Craig Moseley at 265-6873 concerning geological or logging information. Yours truly, I.E. Maunder Sr. Drilling Engineer RECEIVED Alaska Oil & ~as Cons. C°n~r~l$$iott Anchorage b¢¢ B.N. Brown wo att J.B. Kewin " D.B. Stoltz " P.J. Archey " T.D. McCallister w att C.G. Moseley w att Well File w att RECEIVED JUN 1 ;~ l~g Alaska 0ii & Gas Cons. Commission ~ Anchorage CONFIDENTIAL ' ~" STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 89-13 3. Address 8. A'PI Number ........ P,0. Box 100360, Anchorage, AK 99510-0360 50- 029-21912 , , , 9. Unit or Lease Name 4. Location of welt at surface , 1468' FSL, 666' FEL, Sec.16, T12N, R14E, UN L(~..A'rl1~)NS! At Top Producing Interval ~tERIFI~D~! i0. Well Number 457' FSL, 197' FWL, Sec.11, T12N, R14E, UM ,~<~r~.~iI Pt. Mclntyre #4 At Total Depth B.H. j~_~.~l~.} '11. Field and Pool 510' FSL, 493' FWL, Sec. 11, T12N, R14E, UM '--~ Wildcat 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 35' RKB GL=+7MSL ADL 365548 12. Date Spudded 13. Date T.'D. Reached 14. Date Comp., Susp. or Aband. 1 15. Water Depth, if offshore 16. No, of Completions 03,/18/89 04/16/89 Comp1 eted 04~26/89J N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth whereSSSV set 21. Thickness Of Permafrost - 12845'/9573 12558'/9300' YES~ NO [] 2032RKB feet MD +1840MD 22. Type Electric or Other Logs Run Surface hole not log~ See Attached Listing 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" 94# H-40 35' 110' auger ~.. None 13-3/8" 68# L-80 34' 5200' 17-1/2" 3300sx ARlll 700sx ~. Nnn~_ 9,5/8" 47# L-80 33' ~1~ ~ 12-1/4" RRO~X G .7" 29# . ' L-80 11008' 12600' /' 8-1/2" 650sx G None , I / 24. Perforations open to Production (MD+TVD of Top and Bottom an 25. TUBING RECORD interval, size and number) ~1~ '~'./¢~*,/~-/4- SIZE DEPTH SET (MD) PACKER SET (MD) .... Perforate 3 intervals @6SPF, 0°~, W/2-1/8 ,¢~..~.,~. z~-!/~" 10972~ .. 10886' . Enerjet guns. ~:k,, tn{ln{nP !!R63' ... 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH" INTERVAL (MD) AMouN'I~ & KIND o'F MATERIAL 'USED MD TVD 12200 ' -12130 ' 8963 ' -8897 ' 12112 ' -1 2088 ' 8880 ' -8858 ' 12054 ' .12032 ' 8826 ' -8805, .. ,,, 27. PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) May 2, 1989I F1 owl ng Date of Test H'~ursTested PRODUCTION FOR OIL-B~L GAS-Mcr wATER-BBL CHOKE sIZE IGAS-OILRATIO iSee wel 1 .~,~mr~nr-v TEST PERIOD ]~ I .... Flow Tubing Ca~ing Pressure CALCULATED OIL-BBL GAS-MCr WATER-BBL ~)1L G'RAVITY-API (curt) Press. 24-HOUR RATE e 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description and samples will be provided under separate cover. 0 RIG IN A L JUN 'wcl/8 Alaska Oil & Gas Cons. Commission Anchorage __ ed Form 10-407 ' Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS NAME From DIL/GR Log~ Sagavanirktok Permafrost Colville Group Seabee Form. Pebble Shale Kuparuk Kingak *No resistivity Top based on Pt MEAS. DEPTH Surface 1840' 9430' 11648' 11874' 12005' 12727' logs through McIntyre #~ TRUE VERT. DEPTH Surface 1840'* 6709' 8446' 8657' 8781' 9470' :his interval. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIS]'' OF ATTACHMENTS , Report Summary, Gyro (2 copies_~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. item 21: indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~ Item 28: If no cores taken, indicate "none". Form 10-407 COMPANY: APCO ~L.~k.,A WELL: PT. McINTYRE ST, AREA: NORTH SLOPE AI...AS~A TEST: FLOW TEST [)ATE: 1989 MAY 1-6 WELL TEST DATA REPORT HALLIBURTON RESERVOIR SERVICES RECEIVED ALI~ o 61990 OA Division of Halliburton Company These calculations are based on certain data, assumptions, and applied mathematical methods. Inaccurate well data, changing well conditions, mechanical malfunctions and other factors may affect these calculations. Halliburton Reservoir Services ("HRS") makes no warranty, express or implied, as to the accuracy of the data, calcula- tions or opinions expressed herein, or of mer- chantability or fitness for a particular purpose. User agrees by its use thereof that user will release, indemnify and hold HRS harmless from any claims, losses, damages and costs related thereto arising out of or in connection with such use and incurred by user or third parties, whether due to negligence or otherwise. HALLIBURTON RESERUOIR SERUICES WELL TEST REPORT DISTRIBUTION LIST COMPANY: WELL: AREA: ARCO ALASKA INC. PT. MoINTYRE ST. ~4 NORTH SLOPE ALASKA TEST: FLOW TEST DATE: 1989 MAY 1-6 COPIES OF THIS REPORT HAUE BEEN SENT TO THE FOLLOWING INDIUIOUALS OR COMPANIES COPIES RECIPIENTS KEITH PAIGE ARCO ALASKA INC. PO BOX 100~60 ANCHORAGE ALASKA 99S10 JOHN SCHERLIN HALLIBURTON RESERUOIR SERUICES 7197 DERRICK DR. MILLS WYO. 82644 1989 MAY 17 KEITH PAIGE ARCO ALASKA INC. PO 80× 100360 ANCHORAGE ALASKA 99~10 RE: FLOW TEST TESTED: 1989 MAY PT. MclNTYRE ST. NORTH SLOPE ALASKA DEAR SIR: This report includes the ¢ield readings and calculated production o? the test. A graphic pro?ile o? the test appears on the ¢ollowing page. The ensuing test results are summarized in Four sections oF this report which includes: (1) TEST RESULTS~ (2) OIL FLOW RATE CALCULATIONS~ (3) GAS FLOW RATE CALCULATIONS~ and (4) FIELD READINGS. The well produced 2004. mscF oF gas, 3062 barrels oF oil and 187 barrels oF water during 31. hours oF Flow. A 8HP profile is included in this report. 6.1e at HRS appreciate the opportunit~ to serve ~our testing needs. IF ~ou have anw questions concerning the test or this report p]ease call me at 307-472-1040. Sincerel~ HALLIBURTON RESERUOIR SERUICES John M. Scherlin Da t a Acqu i s i t i on Eng i nee r Northern District PRODUCTION HISTORY PLOT I~SBMRY I 6h Om 0~ TO 1989MRY 3 12h lm 0~ RRCO RLRSKR PT. MclNTYRE ST.~4 ItSU ,.F4~ 388~ ~888 8 4288 4888 · o I I I I I I I NRY I 811 MIZY I 12h NRY 2 8h NRY 2 12h I'IFIY 3 811 NFIY 3 12h NFIY 4 8h TEST RESULTS O£C-BSS-~-C PT. McINTYRE ST,~4 ALASKA 1 1989MAY ARCO ALASKA ~^,R--,~ 12032--12220 14.7~ P~l~s. 60 F FLOW OR WELL HEAD WELL CHOKE SEPARA- BOTTOM HOLE BOTTOM CORRECTED CORRECTED WATER ~[ MSCF DAY SHUT-IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS FLOW RATE OIL FLOW RATE FLOW %~/ WOR WGR TiME T;MP P~ESS* ~ RAT~ T~E u.~ Qg Qo ~ O. O[ 0 F~ES~URE TH:ST L NES TO ;000~ , , 6h (m 0 ' 1 0. 0I 0 ~;CHLtJMBERGE:R R[~ I,J/TOOL'.~ 8h [m 0 ~ 1 0. 0)0 ~HORF IN E~'LINE SCHLUMBERGER ~OH ll]h~( m 0 " 1 0. 0 )0 SCHL. IJMBERG~[R 001~ RIG DO,.IN ],.Bh { m 0 , 1 0. 0)0 ~RS ~/L. INE RIH ti/TOOLS 20h2( m 0 .............. · 2 0. 0)0 IRS ~/LINE ON BE)TTOM '" 1 4[ o , 2 0.0)0 )PEN S/I T()OI_ 2h [ m ~00/ 0 . 2 O. 0 ]0 E~EGI ~ DYPA~;S FL{)I4. 2h [ m 18 " 2 .0L7 2h ,m 860 18 ,o 2 . 0~ D [ISST~UCTIOh IN [~HOKE ,o 2h ~m D00 18 __ ,, 2 .0~;D [ IES[]L 0NL~ ,, 2h ~m 100 18 9.28 ,, 2 0.0 10 [:L..OS! S/I "OOL E]ND 8YPA~SS FLObl 2h ~m 0 ,' 2 0.0)0 [)PEN S/[ TI)0L 4h ~'.m 800 0 ~ ,., ,, 2 0.0 0 [IEGI~I 8YPA~;S FL()I4. 4h ',~m ,, 2 .2 7 4hl~ m 500 18 ,, 2 0. 0 0 E]HAN~E CHO~]E. 4hl m 24 TOTAL ~ELL EDDLUENTS P~ODUCED FLO~ TI~E FLO~ TI~E NURSER ~LO~ TI~E/END NU~BE~ ~o~ 1 6h 0m ro 2 4hlSm ~O~Ar~ ~O~T~S~U~O TEST RESULTS OEC-BSS-,-C PT. Hc !NTYRE ST.4~"i ALASKA i 1989HAY 2 2 6 A~CO ALASKA ~'"='~ 120>2-12220 14.7~ DAY FLOW OR WELL HEAD WELL CHOKE SEPARA- BOTTOM HOLE BOTTOM CORRECTED CORRECTED WATER ~[ SHUT-IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS FLOW RATE OIL FLOW RATE FLOW ~~/ WOR WGR TiME TEUP PRESS- ~ RATE "~,~g u.~ O~ OD / o~. ~ ~I (BBL/PSI) (psi ) (°F) (64TH INCH ) (psis) DEPTH DEPTH ~ ~ CCOCK (HOU;S) ~ (psiS) { OF) { "SCF/m {SmD SPO) {aPO) %~/ ~ '2 .2~ 0 [ IES['.L ONL~ , 4h~{m 475 24 24[.92 I, 2 0 0I 0 [:L, OSI S/I ]'OOL. [:HECK CH~)KE 4h3[ m 0 " 2 0. 0{ 0 (~PEN S/I TCIOL , ~ 0. 0[ 0 F~ESU~IE 8YP(~SS FL.OI,J. ~h ;'m 4~0 24 3991.27 168 ...... 5h'l.( m 460 24 4012.84 ' 2 0.Ol 0 [:HAH(',E CHO~E. - ......... ~htE m 28 · 2 .210 [ [ESf:L ONL9 ...... 5h~l m 5'2~ 42 28 3998.02 ~72 9~0.04 · 2 .~3 ]'RAC[~S OF G;AS A] SURFACf[ .... ShS { m 28 , 2 .7 0 [)IESI~L ONLY' TRAI~ES OF 0IL AT ~IJRFACE 6h ~m 780 40 28 4078.08 172 1753.92 ,o 2 .7~ ~ ~}RIN~' H20 ~iT SU;~FACE ,o 6h E m 28 ,, 2 i.2 0 ,, 6h~ ~m 9~0 42 28 4~76.4~ ~ 2046.24 , ,~ 2 0. 0 0 E;ND EIYP~S FLOI~. 6h~ )m 28 ,, 2 0. 0 0 EIEGIF FLO[g TH~OL]GH UN[T 6h~ ~m 28 ,. 2 .5 0 FqJ~GI' CHOKI,. ,"'. ~~m ~000 44 28 4~24.00 ~7~ $~66.~6 2.92 2 7h ~m ,s 2 .sr. 0 F~URGE- CHOK~ . B 3111E- L i 2U~'ZE+~ 7h~l m il00 4~ ~2 404 4164.49 171 425. 16 511.56 511.~6 1 0000E+ 2.4064E+~ TOTAL WELL EFFLUENTS PRODUCED FLOW TIME FLOW TIME NUMBER FLOW TIME/END NUMBER ?.o. 2 4h tSm ~o 2 ?h~ 0m .o..AT~ ?O. ~ST UP TO O~ .AT~ 42 22 ~4 ~6 GA~ ( MSCF)' ' OIL (BBL.)' " WATER (BBLS)' [~ ' ~ ...... ' ....... _ .... - ......... __~~~ .... ___ OA~ ( ~CF): .................. OIL (BBL'): .................................. WATER (BBLS): TEST RESULTS OEC-SeS-~-C PT. McINTYRE ST.4~4 ALASKA 1 1989MAY 2 CUSTOMER 0'' GR^V'T~ @ SO°F '°^P"J G^S S"EC'F'C GR^V'~Y I 'NTERV^' T£STED ~FE=T' S~^NO^RD CONO'~'ONS ARCO ALASKA 27.10 0 . 6500 ~A~.:~ 12032--12220 14. 7~ P~s. 60 F OAY FLOW OR WELL HEAD WELL CHOKE SEPARA- BOTTOM HOLE BOTTOM CORRECTEO CORRECTED WATER SHUT-iN P~ESSUR[ HEAO SIZ~ tOR P~SSU~E ~ HOLE TE~P ~kS FLOW RATE OIL FLOW RATE FLOW ~~/ WO~ W~ T~ME TEMP PRESS- ~ RATE Ti~[ u.~ Qg Qo / kc~ocK) (.ou.s) (psis) (°Fi (64T. ,.c.) Ips'~)_ (psiS) (OF) ( .s~.,o, ,..o..o, ,..o, k "'~' / ( ""~ ) k~/ _GR (8BL/MMSCF J' 2 1, OI 0 ~ RU G[ CHOKE. 1 2376E+ 8h Im 1040 45 ~2 404 4074.77 ~72 44~.42 3~9.92 10.96 3 0457E-~ 8,3265E+2 ~ 2 1,5~ 0 8 6767E- L I 6249E+L 8h3Im 945 46 ~2 394 4073,77 172 566.69 653.12 9.21 i 4099E-'~ 1.1688E+3 ' 2 2. OI 0 i 8967E+ gh {m 120O 50 ~2 389 4046,66 172 415,83 219.24 1242,36 5 6667E+] 3.5149E+3 , ,2 O. O( 0 [',HANI;E CHOk]E. 9h I m 36 ~ 2 .5 ]0 4 1314E- ,, 9h3{m 1200 52 36 444 3979.87 172 1014.22 24~4.91 29,82 i 2146E-) 2,4499E+3 ......... ~ 2 1.0 ]0 [~L. ED CASIN~ TO ;;00~ 4,8854E- ],Oh ~m 1160 54 36 439 3890.05 173 1489.03 3042.88.4 21.49 7 0493E- ~ 2.06~3E+3 ' 2 1,5 ]0 6 5315E- ],,I)h3[m 1190 55 36 449 389~.66 173 1618.03 2477.27 7.45 3 0090E-~ 1.53~7E+3 " 2 2. 0 ~0 7 4755E-1 6~ 7221E+~ 2.4375E+1 'l].h I m] 1190 ~5 36 464 389~.81 123 1739.45 2326.82 11,69 5 0~1E-, _ 1,3444E+3 " 2 2.5 0 [~LED CASIN{~ TO ~004~ llh3Im ~190 57 36 464 3886.31 173 1728,82 2911.51 11.69 4 0161E- ~ 1.6909E+3 '0 2 3. 0 0 I~LEEI)ING C~SING 7 3568E- L 1 3606E+0 2,0882E+1 ],2h [m 118~ 58 ~6 464 3879,39 173 1718.71 2336.22 2,34 1 O010E-'; 1.3606E+3 " 2 3,5 0 I~LED CASIN~ TO ]~00~ 6 4942E- L 2.3121E+1 , i2h3im 1185 58 36 464 3877.48 123 1708.5~ 2630.88 1.5398E+3 '~ 2 4.0 0 13h Jlm '118~ ~8 36 464 3872,12 173 1708.55 2923.20 1.7109E+3 '~ 2 4.51 0 6 4942E-L 2.3114E+1 ].3h3i,m '1190 60 36 464 3877,4D 174 1708.5~ 2630.88 1.5398E+3 ,,, " 2 5. Ol 0 14h ~m 1190 60 D6 464 3879.68 174 1708.~5 2338.~6 1.3687E+3 " 2 5.5 )0 6 1524E- 14h~ Im ~195 62 36 464 3879.97 174 ~708.55 2777.04 ~.6254E+~ , ,. 2 6.0 )0 ]Sh ~m ~95 62 ~6 464 ~878.45 ~74 TO~AL WELL EFFLUENTS PRODUCED FLOW TIME FLOW TIME NUMBER FLOW TIME/END NUMBER F.O. 2 7hD0m TO 2 IDb 0m FO..ATS FO. ................................ TEST RESULTS OEC-B65-,-C PT. MclNTYRE ST.4~4 IALASKA 1 1989MAY 2 4 6 ARCO ALASKA 27.20 0.7180 <^IR--,, 12032--12220 14. 73 PS,[~s. 60 F T£MP ! ooR \ FLOW OR WELL HEAD WELL CHOKE SEPARA- BOTTOM HOLE BOTTOM CORRECTED CORRECTED WATER / MSCF J SHUT-IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS ~LOW RATE OIL FLOW RATE FLOW ~STO BBL/ WOR WGR TIME TEMP PRESS- ~ ~ATE TI~E ~ i n i ma u.~ Og OD ( CLOCK/ (HOURS) (ps~) (°F) (64TH INCH )(psis) ( MSCF/D) (STO BPD) (BPD) ~~/ eSL " 6.~[0 5 9947E-'~ 2.5047E+~ 15h~(~m ~9~ 62 ~6 464 ~877.48 ~74 ~08.55 2850.~2 ~.6682E+~ ~ :: 7. O[ 0 E~I_EE[)ING C~SING 5 ~l~4E-' 2.~4~6E+1 i6h (m ~195 ~2 ~6 464 ~874.24 174 1208.55 3215.52 1.8820E+~ ~' 2 7.~[ 0 ~)LED CASIN~ TO ;'50~ 7 5417E-. 1.9~07E+1 ].6hS[m 1~95 6~ ~6 464 387~.9~ 174 1708.55 2265.48 1.3260E+~ , 2 8.0~ 0 8 3497E- ~ 1,7476E+1 l'~'h' [m 119~ 6~ ~6 464 ~874.~8 ~74 i708.55 2046.24 i.~976E+5 · 2 8.5[ 0 6 :~187E- L 2.~040E+1 ~Th~(m 1200 64 ~6 464 ~B7~.91 174 1708.55 270~.96 1.5826E+~ ..... ~ 2~ 9. 0( 0 5 6451E- L 2.6087E+1 .... lSh (m 1200 6~ ~6 469 ~87].61 174 17~2.68 ~069.~6._f .... 1.7715E*~ · 2 9.~( 0 6 7741E- L 2.18~5E+1 18h~( m 1200 65 ~6 469 ~824.1~ 174 17~2.68 25~7.80 1.4762E+~ · 2 10.0( 0 7 86~7E- 1.854~E+1 igh t m 1200 65 ~6 469 ~87~.0~ 174 1724.05 2192.40 1.2717E+~ ' 2 10.5 0 6 2082E- 2.3346E+1 ...... 19h3 ~m 1200 65 36 469 3872.32 174 1724.05 2777.04 1.6108E+3 ..... ,o 2 11.0 0 6 7809E- 2.2163E+1 ,o 20h ~m 1205 66 36 469 3875.86 175 1734.43 2557.80 1.4747E.3 " 2 11.~ 0 6 6286E- . 2.2457E+1 20h3 Im 1205 67 36 474 3874.12 175 1743.92 2630.88 1.5086E+3 ..... " 2 12. 0[ 0 6 6286E- L 2.2867E+1 21h (Ira 1205 67 36 474 3876.22 175 1743.92 2630.88 1.5086E*3 12.5 0 6 4844E- L 2.3437E.1 m 1205 67 36 479 3875.90 175 1753.37 2703.96 1.5422E+3 ;. 2 13.0~ 0 ~)LED C~SIN~ TO ~50~ 6 4844E- L 2.2859E+1 226 [ m 1205 67 36 479 3872.98 175 1753.37 2703.96 1.5422E*3 '~ 2 13.5[ 0 6 1519E- [ 2.4644E+1 ~ m 1205 67 36 479 3875.62 175 1753.37 2850.12 1.6255E-3 ,~ 2 14. ~1 0 6 814UE- [ 2.2UU)E+i 23h ~ m 1205 67 ~6 479 3875.02 175 1742.88 2557.80 I .4676E*3 TOTAL WE~L EFFLUENTS PRODUCED FLOW TIME FLOW TIME NUMBER FLOW TIME/END NUMBER FROM ~ ~ 0m TO 2 ~h 0m FOR RATE FOR TEST UP TO OF RATE ....... GAS ( MSCF): ~ "~0 OIL (BBLS)= ~[ · ~ WATER (BBLS): 0 . 00 GAS ( MSCF): . OI~(~BLS): ______ WATER (B~ FIELD READINGS ,5111LILI: ,~ I ROE UI~II I EST NO. LL NAME OR NUMBER T UNIT DESCRIPTION I(DAY. MO.. YR.) PAGE OF OEC - 905-!-A . Mc:. ]'.NTYRE ST. :11=4 X ].0 80MM [1.989I'_1~Y [ 6 ARCO ALASKA I PT. Mc INTYRE <UPARUK _ 120..32-12220 (FT.) 12200 (FT.): [] PIPELINE FLARE 5. 761 (INS) 0--I00 [] UPSTREAM' ~, DOWNSTREAM TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL GAS METERING OIL OR CONDENSATE METERING WATER METERING I FLOW OR TUBING CASING MAN. HEATER ORIFICE STATIC DIFF. GAS # 1 TANK OR # 1 OIL OIL # ! TANK OR DAY SHUT-IN PRESS. TEMP. PRESS. B H P B H T :CHOKE CHOKE SIZE PRESS. 3HESS TEMP. ~RAVlTY ;METER READIN~ TEMP ~RAVlTY Wf METER READING SALINITY DURATION (AIR=l) TANK INCH TANK INCH ~2TA.KOR ~20~L ~2TA~KOR ~L( 2..BU. ,6.~., ,6.~., (.%) .~,,~,~,,~ ~., e~o°~ .sw -~, CLOCK (HOURS) (PSIG) (°F) (PSIG) (PSIG) (°F) IN) IN) (INS} (PSIG) 2 (°F) % H2S Tm~~H (oF, °APl (%) (INS. ORBBL) 6h On ~ = I 0. 0)~] .~_.~I_.UMf~ERGEI~ RIH I,J,'TOO S 8h 0n 0 0 ~ 0. 0 ]0 SH' IRT N Ex't_[NE SC~4LLIM ]ERGIER Rt]H ~ .... 1,0h30 n 0 0 ~ 0.0 ~1 ~ ~ OOH RIG Bi]taN ...... L..IJI_IJMI]ERGE! ~ .... I. Sh 0n 0 O " 1 0.0 ]0 HR~S E/I_INE ~IH I~I/T]OLS s: ~0h20,~ 0 0 ~ 0. O )0 HR~S E/I_INE IN BOTT )M ~: :l. h40~a 0 0 ...2 O. 0)0 OPISN S./I TOi)L 2h 0'~ 300 0 0 ." 2 O. 0 )1] BEI;IN ~YPAS~ FLOI,J. ~ -- 2h 0 n 18 0 2 2h I n 860 ~8 0 ,o 2 .053 13B'~TPIJ~]TION IN CHOi<E ,o 2h ~ n ~00 ~8 0 " 2 .093 DIESEl_ ONL. Y " - 7.00 " 2h 5 n 100 18 0 ............ 12 12 12 ~ 0.000 CLOSE S/[ TOOL END BYPASS rL. 0t,.I 2h Sn 0 0 ................ 13 t3 13 2 0.0110 OPeN Sx[ TOOL 4h 2 n 800 0 0 14 4h 2~n ]8 O ................ ,s 2 . 2 ~7 ,, 4hlD~ 24 0 w 2 .'2~0 DIESEL ONLY ~ , 4h D 0 n 4~ 24 FIELD READINGS CUSTOMER 1 PT. MclNTYRE ST.t~4 X_10 80MM I1989MAY 6 FORMATION METER RANGE ARCO AI_ASKA I PT. Mc I NTYRE (UPARUK INTERVAL TESTED IBHP SURVEY DEPTH GAS PRODUCED TO GAS METER RUN DIFF. RANGE (INS. H20) IS~rATIC PRESSURE TAKEN SIZE 12032-12220 (FT.) 12200 (FT.)I I-]PIPELINE ~, FLARE 5.76'1 (INS) 0--100 I ~ UPST"EAM' ~ DOWNST.EAM TIME WELLHEAD DATA DOWNHOL/ DATA FLOW CONTROL! GAS METERING OIL OR CONDENSATE METERING WATER METERING - ~ FLOW OR TUBING CASING MAN, HEATERI ORIFICE STATIC DIFF. GAS 8 t TANK OR 8 I OIL OIL 8 I TANK OR DAY SHUT-IN PRESS. TEMP. PRESS. B H P B H T CHOKE CHOKE SIZE PRESS. PRESS. TEMP. GRAVITY METER READING TEMP GRAVITY Wf SALINITY * 2 tank o. * 2 o,~ * ~ ta.~ o. CL (pp (64TH) (64TH) IN METER READING TEMP ~ 60°F BSW METER READING ~ 2 P ~ I]. I] ~0 CLI]SE S/I Ti]OL CHEi]K CI~OKE ' ii,00 , 4h30~ 0 0 ~ 2 0. 0 ]0 OPI~N S./I TOi]L 2 5h 7~ 450 0 0 ~ 0. 0 )1] ~E~SL..IME BYPA!SS FLOW. ,,, ~h 7~ 450 3991.3 168 24 0 5h18~ 460 4017.8 171 24 0 s' 2 0.0 )0 CH~NGE CHOK-. s s 5h~8~ 28 0 s 2 .2~0 DIESEL ONLY s - 17, 5h30,n 525 42 3998.0 172 28 0 ~ 2 .533 TR~CES OF G~S AT SJRFASE ShS0,n 28 0 ~ ~ .7)0 OISSEL ONLY TRACES OF 6h 0~ 780 40 2~0 4078.1 172 28 0 ~ 2 .7~ BRINE ~0 AT SL.IRFASE 6h ~ 28 0 ~ 2 1.2~0 ~o ~0.50178~I 6h~[l~ 910 42 27~ 4176.4 171 28 0 " 2 0.030 END 8YPASS zLOW. 6h~O~ 28 0 ---- ~: 2 0.0)0 BE]IN FLOW THROUGH UN 6h50~ 0 28 ~ 2 .~ PURGE CHOKE. 7h 0:~ ]000 44 ~00: 4124.0 17~ 0 28 1~.00 60 27.1 0.~ ~" 2 0.0~0 CHANGE CHOK-. 7h O~ 0 ~2 '~ 2 .~0 PtJ~GE CHOKE. 7h~O~ ]100 45 ~0~ 4164.~ 17'1 0 ~2 1.O00 404 ]~ 122 0,00 27.~ SO.O ~" 2 1.0~0 PIJ~GE ~HOKE. '~0.650 1,00~ 1780~ 8h O~ '104A: 45 ~90 4074.8 172 0 ~2 1.000 404 1~ 122 0.00 iS.50 60 27.'1 1.S " 2 i.~ ~0 '~ 0.650 1~. O~ --~ 1. 00[ 1~8~ 8h~O~ 945 46 450 407~.8 172 0 ~2 1.000 ~94 2~ 96 0.00 15.50 60 27.1 0.7 FIELD READINGS OIPJL1Lr' O I~L1E UlNill EST NO. LL NAME OR NUMBER T UNIT DESCRIPTION (DAY, MO., YR.) PAG OF DEC - gOS-1-A CUSTOME" . . MclNTYRE ST.~4 ' X 10 80MM 1989MAY 6 APlZO AL. ASK'A I PT. Mc. IN"YRE <UPARUK L20]'2-12220 (FT.) 12200 (FT.) [~]PIPELINE FLARE 5.761 (INS) 0--1d0 LFI_ UPSTREAM' g DOWNSTREAM TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROl. GAS METERING OIL OR CONDENSATE METERING WATER METERING FLOW OR TUBING CASING MAN. HEATER ORIFICE STATIC DIFF. GAS # 1 TANK OR # I OIL OIL # 1 TANK OR DAY SHUT-IN PRESS. TEMP. PRESS. B H P B H T CHOKE CHOKE SIZE PRESS. PRESS. TEMP. GRAVITY METER READING TEMP GRAVITY Wf METER READING SALINITY DURAT,ON (A,R=,, TANK INCH TANK [NCFI # 2 TANK OR # 2 OIL # 2 TANK OR gL ( p 24 HOUR (64TH) (64TH) ('HINo) METER READING TEMP ~ 60°F BSW METER READING P CLOCK (HOURS) (PSIG) (oF) (PSIG) (PSIG) (°F) iN) IN) (INS) (PSIG) 2 (°F) % H2S T~N~. ~ ~i~H (OF) °APl (%) (iNS. OR BBL) p~) ' 2 2.010 ']~ 1].00 60 i.000 17800 9h 0,n 1200 50 520 4046.7 172 0 .'52 1. 000 389 12 96 0.00 20.50 6t.I 27.1 85.0 2 0. 0 10 CH~%NGE ~HOK . 9h gin 0 .I__..2__ .5]0 '~95 ,, 21.50 60 1.000 1250i~ 9hi0 n 1200 52 650 ]9.~9,9 1,72 0 -.56 i. 000 444 68 110 0.00 20.50 60 27.1 1.2 ~ 1. 0 ]O EIL..I-_-D C~SING TO 700'.1~ ~].695_ ....... 21. 50 60 1.00.0 ].2506 [0h On 1160 54 960 ~890.1 175 0 56 1.250 4]9 62 '122 0.00 ]1.00 60 26.6 0..7 s 2 ~.5]0 sB.,714 ]0.00 60 1.000 ~250§ 10h..'50 n 1190 55 800 -.5895.7 1,75 0 ]6 1.250 449 76 140 0.00 ]].0O 60 26.6 0.-.5 ~ 2 2. g ]0 "~.,718 ]0..00 60 ........ 1,0gO 1250~ I.].h On ~190 55 8`7.5 ]895.8 17] 0 ]6 1..250 464 86 144 0.00 ]9.0d 60 26.6 0.5 t 2 2.5.10 BL.I--D C,%SING TO 900'1~ 70.718 40.00 60 1.000 1250J~ L].h]0n :].~90 5.7 960 ~886.] 17] 0 ]6 1.250 464 86 150 0.00 ]9.00 60 26.6 0.4 ~ 5.0]0 BL.I-_-ED I qG C~!~ ING 80.718 40,00 60 1.000 ].250J~ . , 12h 0~'n 1185 58 1.000 ]879.4 17] 0 _-56 1.2.50 464 85 150 0.00 4~.00 60 26.6 O.1 _~2._ .3.5]0 BI..I-_-D C,%SIN~: TO 700Il: s[~,718 49,00 60 !.000 1.2hE0~n 'I~I85 58 7`75 587."7.5 175 0 ]6 1.250 464 8~ 150 0.00 5.00 60 26.6 0.0 ~ 4.0 ]0 '°0.718 ]. O0 60 1. 000 L3h 0~n ]185 58 790 5877.1 17] 0 -.56 1.250 464 8~ 150 0.00 15.00 60 26.6 "2 4.5.-10 "0.718 12,00 60 l. O0O ,, 1.3h]0~'n '1190 60 820 ]877.5 174 0 -.56 1.250 464 B4 150 0.00 ]5.00 60 26.6 0.~ ~ 5.o]0 '20.718 12.00 60 1.00O ]i,~4h 0~ 1190 60 8`75 5879.7 1.74 0 ]6 1.250 464 8,~ 150 0.00 23.00 60 2.'7.2 0.0 2 5.5~0 "0.718 21.5a 60 l. OOg 14h_"fl]n 1'].95 62 910 ]880.0 174 0 ]6 1.2501 464 8~ 150 0.00 25.01'] 60 27.2 0.0 ~ 6.0~0 '"0.718 21.5~ 6t] 1.00t] 15h O n ]1.95 67 960 ,.5878.5 174 0 _'56 1.250 464 8~ 150 0.00 ]].25 60 27.2 O.0 ,s '2 6.500 's 0. 1718 ]1.25 61~ ...... 1,001] ,~" ]Eh~On i~195 62 1020 -.5877.5 174 0 ]6 1.250 464 8z 150 0.00 ]_'5.25 60 27.2 0.O 's 2 7.0L-I. 0 BLEEDING CABING '~0.718 ]1.25 61] 1.001] t6h On 1].95 62 1060 ]874.2 174 0 -.56 ].250 464 8~ 150 O.O0 44.25 60 2`7.2 0.0 '? 2 7.5110 BLED C.~SING TO 7~0:1~ '?0.718 ]9,0C 61] ........ 1.001] ,~- ].6h30n ].1195 6_'5 860 ~873.9 174 0 ~6 1.2B0 464 8~ ].50 0.O0 44.25 60 27.2 o.0 FIELD READINGS IOEC~II~ILILI' b I Rbl' UI~II I. 905-1-AI EsT NO.;~LL NAME OR NUMBER ~ST UNIT DESCRIPTION(DAy.DATE MO.. YR., ~PAG:I OF . Mc INTYRE ST. 4~,¢ X i0 80M_M 1.989MAY ' 6 ARCO ALASKA I PT. Mc INTYRE <:IJPARUK INTERVAL TESTED IBHP SURVEY DEPTH GAS PRODUCED TO GAS METER RUN DIFF. RANGE (INS. H20) ---I'sTATIC PRESSURE TAKEN I SIZE 1.2032-'122'20 (FT.) 1'2.200 (FT.) [] PIPELINE ~ FLARE 5 . 7,61 (INS) 0--100 [] UPSTREAM' ~ DOWNSTREAM TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL GAS METERING OIL OR CONDENSATE METERING WATER METE'RING __ FLOW OR TUBIN,, CASING MAN. HEATER ORIFICE STATIC DIFF. GAS # 1 TANK OR # , OIL OIL # , TANK OR DAY SHUT-IN PRESS. TEMP. PRESS. B HP B HT CHOKE CHOKE SIZE PRESS. =RESS TEMP. GRAVITY METER READIN,, TEMP GRAVITY Wf f~,f~ SALINITY DURAT,ON (AIR=,, TAHK ! HC.H # 2 TANK OR # 2 OIL # 2 TANK OR CL ( pp ,.,,,T., ,,,.,T., (.'%') .RTE. READ,... TEMP ~,,O°F .sw METE. READ,.G 24 HOUR (HOURS) (PSIG) (°F) (PSIG) (PSI,,) (°F) (INS) (PSIG) (OF) % H2S oApI (%) ) CLOCK ,N) ~N, 2 l'~14~!~H (°r, .NS. OR..L, .. ' .2 8.0)0 '0.718 3~.00 80 1.O00 .................. l. Th O~n 1195 63 7,'50 387'4.2 174: 0 36 1.250 464 84 150 0.00 5;1.,25 60 27.2 0,0 : 2 n.~O ')..?l.e 48.25 80 1.000 ............... !.7h30!~ 'l:~O0 64 790 3873.9 174 0 36 1.250 464 84 150 0.00 5]..2_5 60 27.2 0.0 .~ 9, 9.0)0 ~)..704 48,25 60 1.000 l, Sh 0'~ 120O 65 810 3873.6 174 0 36 1.250 469 8~ 1~0! 0.00 61.75 60 26.7 0.0 __. 4 ~. 9. ~ ]0 '~;~,,.,,?04 ~;?. O0 80 1. 000 ........ 1.8h:'50'n 1200 65 85;0 3874. I 174 0 36 1.250 469 8< 150 O. O0 61.7,5 60 26.7, O. 0 ' 2 1.0.0)0 ~3.704 57,. O0 80 1.000 ............. lgh O'n 1200 65 850 3873.1i 174 0 36 1.250 469 83 '149 0.00 69.2S 60 26.7, O.O ~ 2 1,0.~31) ~i3.704 66 5;0 60 1.000 ].gh.."5Orn 1200 6.5 900 3872.3 174 0 36 1.2t50 469 8] 149 0.00 19.25 60 26.7 0.0 ? 2 1.1.0:10 70.704 3.00 60 1.000 ~Oh On 1'20.¢;. 66 900 387.5.9 17,5 0 36 1.250i 469 ID" 149 0.00 28.00 60. 26.7 ~ 2 'I 1 . 5 .'10 "0.?04 12.00 60 1.000 s ~Oh30n 1205 67 950 387,4.'1 175 0 36 1.2~0 474 B/ 149 0.00 28.00 6fi 26.7 0.0 ___ ~ 2 12.0)0 ~0.704 12.00 60 1_..000 ~lh Oi~n 1'2..0~ 67 960 3876.2 17,5 0 36 1.250 474 8'" 149 O. O0 37. O0 6f/ 26.7 O. 0 ,o 2 12 . .B EIO '°0. 704 2'l . 25 60 1.000 21. h~ll'n 1205 67 97~ 3875.9 175 0 36 1.250 479 8< 149 O. OO 37. 01-1 60 26.'.7 O. 0 ,, 2 13.fig0 BLED Ci~ING TO 6DOtl: "D.7,04 21.25 60 1.000 ,, ;?'2h O'n '].205 67 990 3873.0 175 0 36 1.250 479 8z 149 O.O0 46.25 60 26..7 'z 2 '1..-5.~00 ,2~.704 31-.00 60--- 1.000 22h30'n 120.5 6.7 670 3875.~ 1..75 0 36 1.250 479 8" 149 0.00 46.25 60 26.7 _ _ _ '~ 2 1.4.000 '*'0.704 31.00 60 1.000 ,, 2..'5h O-n 1'206 67 700 3875.0 175 0 36 1.250 479 8~ 149i 0.00 55.00 60 26.7 0.0 ,', 2 '14..~ )0 ,,, O. ?04 39.00 6~ .............. 1.000 ?~hgOnr, .1205 67' 700 3875.8 175 0 36 1.250 479 8] 149 0.00 55.01] 6ii 26.7 ,, 3 '} .c;.. 0 10 's0.704 39.00 j..--~--O-i~ ........ Oh Orn 1_'205 68 700 387,6.1 175 0 36 1.250 479 8] 149 0.00 64.0C. 6I} 26.7, --h..C '~ 3 1.5 . ~ .'lO .... '~0.704 48.00 60 ............... 1.000 ,,, I.'lh~Om 1_~0.5 6t3 7'.2.5 3878.6 17.5 0 36 '1.2.c;.0 479 8': 1_49 0.00 64.0C 6i_'26.7 O.C_ .'? 3 ]6.0~0 ';0.704 .5.00 8~. 1.00t~ ,? 11-, O~ ]_.2_10 68 7~0 3878.8 '17.$ 0 36 1.2~;0 479 8'; 149 0.00 73.01'_ 6I~ 26.7 O.l~ .................................................................. i ..................... FIELD READINGS ~)I~.LI'' ~1..!'' Ul~ll EST N©. LL NA.E O~ NU..E. T UNIT D~.IPTIONI(DA . "O..~., lI OEO - gO~-1-A . . M~TNTY~E ~T.4~4 X ~0 80MM rt989HDY ~ 6_ ~,ARCO AI__ASK~ I PT. Mc IN'FYRE (I..IPARUK NTERVAL TESTED ~0~2-1222] {FT.) 12200 (FT.) ~PIPELINE FLARE 5,761 (INS) 0--100 ~ UPSTREAM' ~ DOWNSTREAM TI~E WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL ~A~ METERING OIL OR CONDENSATE METERING WATER METERING . . FLOW OR TUBING CA~ING MAN. HEATER ORIFICE STATIC )IFF. GAS ~ I TANK OR ~ t OIL OIL ~ I TANK DAy SHUT-IN PRESS. TEMP. PRESS. B HP B HT CHOKE CHOKE SIZE PRESS. ~RESS TEMP- GRAVITY METER READiNG TEMP GRAVITY Wf ~Rf~© * 2 TANK OR * 2 OIL 82 TANK OR ]L~ pp (64TH) (64TH) IN !METER READING, TEMP ~ 60°F BSW METER READING; ~ ~ ;1.6. ~ ~0 ' ~.:., ~04 [6.00 60 [.000 , lh~O~n 1210 68 750 3878.9 175 0 36 1.250 484 8~ 149 O. O0 5. O0 60 26.7 O. 0 ' ~ ~7.0 )0 ~.,.704 1~.00 60 1.000 2h O,n ~210 68 Y75 ~878.2 175 0 ~6 1.250 484 82 149 0.00 16.00 60 26.~ 0.0 -- , ~ ~7.~ t0 '~.704 24.50 60 1,000 ~h~O~. l~tO 68 775 ~878.5 t75 0 ~ ).250 484 8~ ~49 0.00 ~6.00 60 2~.7 0.0 ~ :1,8.0 ]0 "~..'.704 .... 24.~0 60 ~. 000 ~h 0'~ ~.2~0 69 800 ~878.4~ t75 0 ~6 t.250 489 82 ~50 0.00 25.50 60 26.7 0~0 " 3 :l. 8.5 ]0 "].695 34.00 60 l. O00 ........ 3h~O:~ 12~5 69 800 3878.7 ~75 O 36 1.250 489 fig 1SO 0.00 25.50 60 26.~ 0.0 e ~ 19. O ]0 *],.,695, ~4.00 60 ~.000 4h 0 n 1215 69 825 ~878.9 ~75 0 36 ~ .250 489 82 152 O. 00 34.25 60 26.~ O. 0 ..... 4h~O n ~215 70 82~ 3878.8 175 0 36 1..250 489 8g 15~ O. go. 34.25 60 27.6 O. 0 ~ 20-0)0 "3.695 4~.00 ..... 60 ~.OOO 5h On ~2~5 70 8~0 ~878.8 ~75 0 ~6 ~.250 489 8~ ZS~ 0.00 4~.00 60 27.6 0.0 5h~O~. ~2~5 70 850 ]878.7 ~75 0 ]6 ~.250 489 8] 15~ 0.00 4~.00 60 27.6 0.0 '° ~ 21..0)0 '~..69~.. B2.25 60 1.000 6h 0~ ~2~5 7t 850 D878.8 ~75 0 ~6 ~.250 489 8] 15D 0.00 52.00: 6~ 27.6 0.0 " ~ 2]..5)0 "O.695 61.00 60 Z.O00 " ..... 6hDO'~ 12~5 7~: 850 ~878.8 Z75 0 ~6 ~.250 489 8D ~5~ O.O0 52.00 60 27.6 0.0 ~ 22.0~0 '~0.69~ 6t. O0 60 Z.OOO 7h O~ ~2~5 7t 875 D880.6 t75 0 ~6 'l.2~0 489 8g 15D O.O0 60.50 60 27.6 O.O '~ ~ 22.5)0 '~Q.695 69.50 60 ~.000 2h~O~ 1215 71 875 ~881.0 175 0 ~6 1.250 489 8; 15~ 0.00 60.50 60 27.6 O.O 69. o .... z.ooo 8h O~ 1215 71 900 ~881.0 175 0 ~6 1.2~0 489 8'2 1~ O. O0 70. O0 60 27. ~ 0.0 '" ~ 2~.5 )0 '~3.695 78.00 60 1.000 8h~O~ ~:?t5 7t 900 ~8B'1.2 ~75 0 ~6 ~.250 489 8g ~5] O.O0 70.00 61] 27.~ O.O ~* D 24.0)0 ~D.69~ 2.00 60 ~.000 9h O, 1'2'[5 72 925 D880.9 ~75 0 ~6 1.250 489 8~ 15D 0.00 79.2D 60 27.D 0.'~ ,7 ~ 24.5]0 '70.69-~ 11.2~ -~ ................ ~~ g~O, t2~5 72 925 D880.8 175 0 D.6 1.2~0J 489 8; ~5~ O.Og 2.5~ 61] 27.D 0.~"_ FIELD READINGS ~)ll~lbLl: b I/AbE UNI I EST NO. ELL NAME OR NUMBER T UNIT DESCRIPTION -(DAY, PAGE OF OIEC - 905-!-A eT. Mc INTYRE ST. S~4 X I0 80MM CUSTOMER IFIELO FORMATION lOlL METER SIZE I(BBLs)METER RANGE ARCO ALASKA I PT. Mc INTYRE (UPARUK INTERVAL TESTEDIBHPSURVEY DEPTH ' GAS PRODUCED TO GAS METER RUN DIFF. RANGE (INS. H20) ISYATIC PRESSURE TAKEN ' SIZE ] L2032-!2220 {rT.~ 12200 (F*.) I~IPIPELINE ~l~ FLARE 5.76'1 (INS) 0-11:I0 [] UPSTR'EAM' ~:] DOWNSTREAM TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL (~AS METERING OIL OR CONDENSATE METERING WATER METERING FLOW OR TUBING CASING MAN. HEATER ORIFICE STATIC DIFF # i TANK OR # SHUT'IN PRESS. TEMP. PRESS. B HP B HT CHOKE CHOKE SIZE PRESS. =RESS, TEMP. : G~A~I~Y; U£TE~REAOI~G T£MP GRAVITY ~f~)~ SALINITY DURAT,O. !^'"--' iTARK ! htlZ:H # 2 TANK OR # 2 OIL # 2 TANK OR' CL ( I~l~ 24 HOUR (64TH) (64TH) ~H-%) METER READING TEMP CLOCK (HOURS) (PSlG) (°F) (PSIG) (P$1G) (°F) IN) IN) (INS) (PSlG) 2 (°F) % H2S TI~IIII~}~ ~H (°F) °APl (%) (INS. OR BBL) LOb Or, 121~ 72 950 ~881.2 176 0 >6 1.250: 489 82 153 0.00 11.25 60 27.~ 0.0 LOh.50n 1215 72 950 5882.0 176 0 56 1.250 489 82 155 0.00 11.25 60 27.5 0,0! : o 'oo .th 0, 1215 72 ¢,o ~eet.4 t76 0 ~6 t.250 489 82 ts~ 0,00 20,25 60 27.> 0.0 : 26.530 BL1ED C%SING TO 700!~ : 29.00 60 Lth30n t2Z5 72 950 >882.4 Z76 0 >6 t,250 489 e2 155 0.00 20.25 60 27,> 0.0 ,s~3;,,,~27, 0 ]0 s ,:;,,,,,,, ,29. O0 60 1.000 ,. s 1.2h O~n 121~ 72 710 d044,~ 176 0 ~6 1,2~0 489 8~ 1~ 0.00 29.00 60 · . ~ 29. O0 ~ 0 0]0 CL_~]SE 3/I T]OL END FIR,3T TI~ST ,:, ,, t2h l~n 0 0 3'2.50 60 27.> 0.0 ........ I0 IO IC .... 11 11 11 12 12 12 !~ 13 13 ~14 14 14 16 16 16 17 17 .... TEST RESULTS OEC-BSS-,-C PT. Mc INTYRE ST.:tt:4 ALASKA 1 1989MAY 2 ARCO ALASKA 26.70 0.7040 ~^,R--~, 12032-12220 14. DAy FLOW OR WELL HEAD WELL CHOKE SEPARA- BOTTOM HOLE BOTTOM CORRECTED CORRECTED WATER ,SHUT-IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS FLOW RATE O'b FLOW RATE FLOW ~~) WOR WGR TIME URE Qg Qo ~c~oc~ (.ou.s} (psis) (°F) (64TNINCH ) {psis) (psiS) {oF) ~ .s:,,.~ ~s,o.,,~ ~""0~ ~~/ ~,o..~ ~ ..sc~ / _GR (BBL/MMSCF ' 2 14.5[ 0 7 4528E- . 2.0256E*1 2DhD[ m 1205 67 D8 479 D875.82 175 1742.88 2DDB. 56 1. ~41BE*~ ~ D 15.0[ 0 6 8247E- . 2.28DBE+l 0h Em 1205 68 ~6 479 5878.07 175 1742.88 26~0.B8 1.5095E*~ ' 15.D(0 6 8242E- 0hD[m 1205 68 D6 479 D878.59 175 1742.88 2630.88 1.5095E*D ,,, :~ ~ 18. 0[ 0 ~, lh [m 1210 88 D6 479 ~878.B2 175 1732.~D 2630.88 1.5187E*D . D ~6.5[ 0 lhDim 1210 68 D6 484 D878.91 175 1741.8~ D215.52 1.846DE*~ ...... '. ~ 17. 0[ 0 2h lm 1210 68 D6 484 ~878.17 175 1741.8~ ~215.52 i.B46DE*D ' ~ ~7.5{ 0 2h3I)m 1210 68 ~6 484 3878.46 175 1741.63 2484.72 1.4267E+~ " 5 18. 0 0 ''3h ~m' 1210 69 ~6 48~ ~878.42 175 1749.11 2777.04 1.5877E+~ ' .~ 18.5 l0 3h~ }m 1215 69 ~6 489 ~878.74 175 1758.84 2777.04 1.5789E+~ ,o 3 ~9.0 )0 6 8625E-L 2.2760E+1 4h }m 1215 69 ~6 489 ~878.89 175 1755.29 2557.80 1.4572E+~ " 3 ].9.5 }0 6 6652E-L 2.3~92E+1 4h~ }m 1215 70 ~6 489 ~878.80 175 175~.5~ 26~0.88 1.5003E+5 '= 5 20. 0 }0 6 5h }m 1215 70 ~6 489 ~878.81: 175 175~.53 25~7.80 1.4582E+~ " ~ 20.5 }0 6 5245E-L 2.4020E+1 5h3 )m 1215 70 ~6 489 ~878.70 175 1764,21 270~. 96 1.5~27E+~ " ] 21. 0 J0 6 7058E-L 2.~96E+1 6h Im 1215 71 56 489 ~878.82 ~75 1764.21 26~0.88 1.491~E+~ " ~ 21.5 0 6 8974E- 6h~ ~m 1215 71 ~6 489 ~878.82 175 1764.21 2557.80 1.4498E+~ ,, " ~ 22. 0 0 7h ~m 1215 71 ~6 489 ~880.62 175 '175~. 5~ 2484.72 1. 4170E+~ TOTAL WELL EFFLUENTS PRODUCED FLOW TIME FLOW TIME NUMBER FLOW TIME/END NUMBER r~O~ 2 2~h 0m TO ~ 7h 0m FOR RATE FOR TEST UP TO OF RATE ~.s~ ~scr~: 58~.~8 o~s~: 892.~9 w.~=.<.scs~: 0.00 ~.s ~ ~sc.~: _ .... o~ TEST RESULTS o£c-ess-,-c PT. McINTYRE ST.~4 ALASKA '1 1989MAY ~ 6 6 ARCO ALASKA 27.60 0.6950 ~;~y FLOW O. WELL HEAD WELL CHOKE SEPA.A- BOTTOM HOLE BOTTO~ CO..ECTEO CO..ECTED WATE. SHUT-IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS FLOW RATE OIL FLOW RATE FLOW % STO BeE/ WOR WGR T~.E .1 t n i ma u.= Qg Oo ( 22.5[0 7 05~2E- 2.25~E*1 7h~m 121~ 71 ~ 48~ ~88~.00 175 17~.5~ 2~84.72 1.41~0E+~ ~ ~ 1 2 ~ 0 ~ 0 8h [mm 1215 71 ~6 489 5880.95 175 175~.5~ 2777.04 1.58~7E+5 2~. ~[ 0 8h~(~m 1215 ~1 ~6 489 ~881.15 175' 1755.5~ 2484.72 1.4170E+~ ~'24. 0~ 0 6 4850E- L 9h (m 1215 Y2 ~ 489 ~880.87~ lY5 1~5~.5~ 2Y0~. ' ~ 24.5( 0 9h~[m 1215 ~2 ~6 ~89 ~880.84 175 1755.5~ 2Y0~.96 1.5~20E+5 .... ~ ~ 25.0~ 0 10h (m 1215 Y2 ~6 48~ 5881.18 17~ 175~.5~ 255Y.80~ 1.458YE+~ v 25. ~ 0 10h~m 1215 72 ~6 489 ~881.97 176 175~.5~ 2557.80 1.458YE+~ " ~ 2~ . 0[ 0 1lb ~m 1215 Y2 ~6 489 ~881.~Y 126 175~.5~ 2650.88 1.500~E+~ ' 5 26.5~ 0 ~IL. ED CASIN6 TO ;00~ ...... llh~m 1215 72 ~ 489 ~882.44 176 175~.5~ 26~0.88 1.500~E+~ '~ ~ 27.0 0 6 8556E- ,o 12h ~m 1215 Y2 ~6 489 4044.'50 176 1755.55 2557.80 1.458~E+5 ,, ~ 0.0 0 []LOS~' S/I OOL ~ND FIRS'F TEST ,, 12h .m 0 ,. 14 TOTAL HOURS OF FLOLd: 3i · 433 TOTAL WELL EFFLUENTS PRODUCED TOTAL HOURS 0F SHUT- IN: 22. 583 ~ow ~.z .~ow ~.z Nu..~. .~OW r,--~ZNO NU.n~. ~.O-- D 7h 0m TO D 12h lm ~o..Az~ .oerzszu.~oTOTAL UOLUHES: ~s~ .sc~: D65.D2 o,~.~s~: D4D.DD WA~.~.a~s~: 0.00 ~AS OTiSi METHOD USED FOR CALCULATING OIL FLOW RATES MEASUREMENT BY METER Vo = Vm Cf k (1 - BSW/100) WHERE Vo = VOLUME OF OIL AT ATMOSPHERIC PRESSURE AND TEMPERATURE (GENERALLY 60°. F) Vm = VOLUME OF OIL REGISTERED BY METER(S) SINCE LAST READING AT SEPARATOR PRESSURE AND TEMPERATURE Cf -- MEASURED CORRECTION FACTOR. IT IS OBTAINED BY CALIBRATING THE METER WITH A TANK DURING THE TEST AND INCLUDES BOTH THE METER FACTOR, M, AND THE WEATHERING FAC- TOR, Wf. Cf= MWf Wf = METER FACTOR. IT IS TO CORRECT FOR ANY METER NON LINEARITIES. = WEATHERING FACTOR = VOLUMEOF OIL AT ATMOSPHERIC PRESSURE AND 60°F +VOLUME OF OIL AT SEPARATOR CONDITIONS. NOTE: Wf =(1-Sh),WHERESh=OILSHRINKAGEFROMSEPA- RATOR TOSTOCK TANK CONDITIONS-- (VOLUME OF OIL AT SEPARATOR CONDITIONS - VOLUME OF OIL AT ATMOSPHERIC PRESSURE AND 60°F) +VOLUME OF OIL AT SEPARATOR CONDITIONS. = TEMPERATURE CORRECTION FACTOR FROM ASTM TABLES (k = 1 FOR AN OIL TEMPERATURE OF 60° F). BSW = BASIC SEDIMENT AND WATER MEASURED USING APl FIELD CENTRIFUGE METHOD = PERCENT OF BASIC SEDIMENT AND WATER VOLUME TO TOTAL VOLUME OF OIL AND BSW. Qo = CORRECTED OIL FLOW RATE = Vo --: TIME TO PRODUCE THE VOLUME, Vo. MEASUREMENT IN TANK Vo = Vt k (1 - BSW/100) Vo, k, BSW, AND Qo AS ABOVE Vt = VOLUME OF OIL MEASURED IN TANK AT TANK TEMPERATURE SINCE LAST READING OIL FLOW RATE CALCULATIONS-TANK MEASUREMENTS 1 SKA 89MAY 2 4 CUSTOMER- WELL NAME ON NUMBER STO GRAVITY (APl) · 60 o F ARCO ALASKA PT. McINTYRE ST,~P4 27.10 FIELD INCREASE IN VOLUME BY k CORRECTED CORRECTEO CORRECTEO GAS ~.. OIL TANK TANK REAOINGS TANK SINCE FROM ASTM OIL VOLUME OIL FLOW FLOW RATE DAY FLOW TANK READINGS SINCE LAST LAST READING TANK TABLES BSW VD- Vtk (1. RATE FROM GAS FLOW TIME: USED READING Vt TEMP. BSW/IO0! O~ RATE CALC FORM OGF~ TIME Q9 ! .......... ) (HOURS} (I OR 2) (INCHES) (INCHES) (BBLS) (o le) , (e4) (STO BBLI) (STO BPD) (MSClr/D) .Th ~m 2 13.130 4,00 24.36 60 1.0130 .25 24.31] 1166.36 8h3Em 1 13.00 4.50 27.41 60 1.000 .~0 27.21 653.12 5(56.69 8,677E-1 "2 2.0£0 ... 9h Em 2 20.50 5.00 30.45 60 1.000 85.00 4.57 219.24 4'15.83 1.897E+0 ' 2 .5(0 9h3Em 1 21.50 8.50 51.77 60 1.000 1.20 51.14 2454.91 1014.22 4.131E-1 7 2 1.OEO '- loin Em 2 31.00 10.50 63.9~ 60 1.000 .?0 63.50 304?.8@ 1489.03 4.885E-1 ' 2 1.5C0 .... lOh3(m 1 30.00 8.50 51.77 60 1.000 .30 51.61 2477.27 1618.03 6.531E-I , 2 2. or. 0 llh (~m 2 39.00 8.00 48.72 60 1.000 .513 48.48 2326.87~ 1739.45 7.476E-1 ,o 2 2.5(0 - ,o llh~[Im 1 40.00 10.00 60.90 60 1.000 .40 60.66 2911.51 17'28.82 5.938E-1 " 2 3.0{0 ,, 12h [tm 2 47.00 8.00 48.72 60 1.0013 .10 48.67 2336.22 1718.71 7.357E-1 12h3(Im i 49.00 9.00 54.81 60 1.O00 O.OO 54.81 2630.88 1708.55 ;6.494E-1 '] 2 4.0(0 13h (m 2 15.00 10.00 60.90 60 1.000 0.00 60.90 2923.20 1708.55 15.845E-1 '= 2 4.5( 0 13h3(im 1 12.00 9.00 54.81 60 1.000 0.00 54.81 2630.88 1708.55 6.494E-1 14h_ (m 2 23.00 8.00 48.72 60 1.0013 13.00 48.72 2_338.56 11.708..r:;~17'306E-1 16 2 5.5( 0 - 14h3fm 1 21.50 9.50 57.86 60 1.000 0.00 57.86 i277Y.04 1708.55 16.152E-1 ~7 2 6.0(0 ....... ,7 15h ~m 2 _53.25 10.25 62.42 60 1.000 0.00 62.42 2996.28 1708.55 5.70:2E-1 OIL FLOW RATE CALCULATIONS-TANK MEASUREMENTS .1 SKA I 19891'1AY 2 I 4 ,,ARCO ALASKA PT. Mc I NTYRE ST. 0114' _.,_,.,...., _.,,_.o,....,o..,,....., ...___._., .... ~11 6.09 BBL/IN 6.090 6.09 BBL/IN 6 FIELD INCREASE IN VOLUME BY k CORRECTED CORRECTED CORRECTED GAS DAY OIL TANK TANK REAOINGS TANK SINCE FROM ASTM OIL VOLUME OIL FLOW FLOW RATE FLOW TANK REAOiNGS SINCE LAST LAST READING TANK TABLES BSW vD - v t k it. RATE FROM GAS FLOW - TIME USED READING vt TEMP. ~w/tm) ~ RATE CALC FORM TIME o~ ] OGR I .......... I IHOURII Il oR Il IINCHEII (INCHES) JILLS) Jo FJ (~J (ITO ILLS) (sro .Poi (.SC.lO) (STO ~' 2 7.0(0 , - 1Ch (tm 2 44.2~ 11.00 66.99 60 1,000 0.00 66.99 ~215.~2 1Y08.~5 5.~l~E-1 '. 2 7. ~ ( 0 16h)(tm 1 )9.00 7.75 47.20 60 1.000 0.00 47.20 2265.48 1708.55 7.542E-1 '~ 2 8. O( 0 -- __ 17h (m 2 51.2~ 7.00 42.6~ 60 i. O00 0.00 42.6~ 2046.24 1708.5~ 8.~50E-1 17h](m 1 48.2~ 9.2~ ~6.]] 60 1.000 0,00 ~6.]~ 270~.96 1708.~ 6.~19E-1 · 2 9.0(0 . 18h (m 2 61.7~ 10,~0 63.94 60 1.000 0.00 6~.9~ J~069.~6 1732.68 ~.645E-1 ~ 2 9.~[0 ~Bh~m ~ ~7.00 B.7~ 5~.29 60 ~.000 0.00 5~.29 2557.B0 ~7~2.68 6.~4E-~ 7 2 10. O( 0 19h (m 2 69.2~ 7.DO 4~.67 60 1.000 0.00 4D.68 2192.40 1724.0~ 7.864E-1 ' 2 10. ~[ 0 ghm 1 66.~0 9.50 57.86 60 1.000 0.00 ~7.86 2777.04 1724.0~ 6.208E-1 2 ~]1. O{ 0 20h Cm 2 J28.00 8.7~ ~}.29 60 1.000 0.00 ~.29 2~7.80 17~4.43 6.781E-1 iD 2 11.~0 2Oh)Cra 1 12.00 9.00 ~4.81 60 1.000 0.00 ~4.81 26)0.88 174~.92 6.629E-I 'i'i 2 12.0(0,, 21h (m 2 ~7.00 9.00 D4.81 60 1.000 0.00 ~4.81 26D0.88 174).92 6.629E-1 '~ 2 12. ~( 0 21h~(~m 1 21.2~ 9.2~ ~6.~ 60 1.000 O.O0 ~6.~ 270~.96 175~.~7 ~6.484E-1 "2 13. O( 0 J 22h (~m 2 46.2~ 9.2~ ~6.33 60 1.000 0.00 ~6.33 2703.96 17~3.37J6.484E-1 " 2 13.5 ( 0 I 22h~[Jm 2~h [~m 2 ~.00 8,7~ ~,29 60 $,0~0 0,00 ~,29 2~,80 ~742,88~6,8~4E-~ ~ 2 }4, ~( 0 -- i? ~ ].~,0( O ......... ~ .... ,? Oh (m 2 64.00 9.00 ~4.81 60 1.000 0.00 54.81 26~0.88 1742.88 6.62~E-1 ~ m I ~8.00 ~ 9.00 ~4.83. 40 1.000 0.00 ~4.81 2~}0.88 1~42.88 6.62~E-~{ ..................... OIL FLOW RATE CALCULATIONS-TANK MEASUREMENTS i1 SKA J CUSTOMER WELL NAME DE NUMEEN lTD GNAVlTY (APl) O 60 ~ F ARCO ALASKA PT, Mc; NTYRE ST. ~4 26.70 FIELD INCREASE IN VOLUME BY k CORRECTED CORRECTEO CORRECTEO GAS ~Y OIL TANK TANK READINGS TANK SINCE FROM ASTM OIL VOLUME OIL FLOW FLOW RATE FLOW TANK READINGS SINCE LAST LAST READING TANK TABLES BSW vD- v t k ll- RATE FROM GAS FLOW TIME TIME USED READING Vt TEMP. ~/t~l ~ RATE CALC~ FORM I .......... ) (HOURS) I' On 2) (,NCHES) (iNCHES) (ILLS) I' ') , (~) (STO IILII (STO IPD) (MSC./DI lb~ 1 16.00 il. GO 66.99 ~0 l. O0G 0.00 6d.99 ~21~.52 1741.6~ ~.416E-1 5 ~ 18 . 0( 0 }h (m 2 2~.~0 9.50 57.86 60 1.000 0.00 57.86 2777.04 1749.11 6.298E-1 1 .ooo o.oo 3 / i9.0{0 4h ~m 2 34.2~ 8.7~ 53.29 60 ~.000 0.00 ~3.29 2~2.~0 ~755.29 6.B63E-] m 3 19.5(0 , ~h~m ~ d~.00 9.00 5d.81 60 ~.000 0.00 ~d.~ ,26~0.~ ~.5~ '6.66~E-~ 5h Em ~ ~3.00 ~.~5 5~.29 60 ~.000 0.00 5~.29 2~5~.80 1~5~.5~ ,o ~ ~0. ~ 0 - ,o ~h~m 1 ~2.2~ 9.2~ ~6.~ 60 1.OOO O.OO ~6.~ 270~,96 1764.21 6.52~E-1 " 3 21. O( 0 ,, , 6h Cm 2 ~2,00 9.00 54.8~ 60 1,000 0.00 54.81 26~0,88 1764,21 6,706E-~ , 6h~Cm 1 61,00 B.75 53.29 60 1.000 0.00 53.29 2557,80 1764.21 6.897E-1 ~ 3 22. O~ 0 7h Em 2 ]60,~0 8.50 51.77 60 ~.000 0.00 51.77 2484,72 175~,5~____LT.0~TE-1 7h~Cm 1 69,50 8.~0 51.77 60 1,000 0.00 ~1.77 2484,72 ~75~.5~ ?.057E-~ 8h {m 2 70,00 9.50 57,86 60 ~.OOO 0.00 57.86 '2777.04 175~.53]6.314E-i 8h3{~m ~ 78,00 8.~0 5~.77 60 1.000 0.00 51.77 2484.72 175~.5~ 7.057E-~ 9h (ira 2 79.2~ 9.25 56.~3 60 1. 000 O. 00 56.~ 270~.96 175~.53J6 .485E-1 ,, 3 24. ~{ 0 ,, 9h~{,m t ZZ.2~I 9.2~ ~6.~ 60 ~.000 0.00 ~6.~ 270~.96 tTS~.S~ 6.4~SE-tJ OIL FLOW RATE CALCULATIONS-TANK MEASUREMENTS 1 SKA ! 1989MAY 3 L 4 ARCO ALASKA PT. Mc INTYRE ST. $4 27. :~0114'73 PSIA .... FIELD INCREASE IN VOLUME BY k CORRECTED CORRECTED CORRECTED GAS OIL TANK TANK READINGS TANK SINCE FROM ASTM OIL VOLUME OIL FLOW FLOW RATE DAY FLOW TANK READINGS SINCE LAST LAST READING TAN K TABLES BSW VD" v t k I~. RATE FROM GAS FLOW .. TIME USED READING Vt TEMP. ~l~ml ~ RATE CALL FORM J OGR TIME ~ ' ~ 25.0[0 . lob E~m 2 11.2~ 8.7~ 5~.29 60 1.000 0.00 5~.29 2~5Y.80 17~.~ 6.8~6E-1 / l'OhD'(~m 1 20.00 8.75 5D.29 60 1.000 0.00 5D.29 2557.80 12DO.DO 6.B56E-1 :~ ~ 26. O[ 0 ~ 11h fire 2 20.25 9.00 54.81 60 1.000 0.00 54.81 2630.88 11753.53 !6.665E-1 ~.... ~ 26.5[0 1 · 3 27.0{0 . . ~2~ {m 2 29.00 8,75 5~,29 ~0 ~.000 0.00 53.2~ 255~,e0 ~753.53 , , ..... I0 I0 II 11 17 17 nTl. l METHOD OF CAL.CULATING GAS FLOW RATES BASED ON A.G.A. REPORT NO. 3 [0~ ' C 'X// hw Pf I WHERE C" Fpv X Fb X Fg X Ftf X Ftb X Fpb X Fr X Yx X Fm X UNIT CONVERSION FACTOR Og C hw Pf Fpv Fb Fg Ftf CORRECTED GAS FLOW RATE ORIFICE FLOW CONSTANT DIFFERENTIAL PRESSURE ACROSS ORIFICE IN INCHES WATER @ 60°F ABSOLUTE STATIC PRESSURE IN psi AND SUPERCOMPRESSIBILITY FACTOR (CORRECTED FOR N,, H, S, AND CO, EFFECTS ON FINAL BASIC ORIFICE FACTOR REPORT, (IF DESIRED) SPECIFIC GRAVITY FACTOR FLOWING TEMPERATURE FACTOR Ftb= TEMPERATURE BASE FACTOR Fpb = PRESSURE BASE FACTOR Fr --- REYNOLDS NUMBER FACTOR = 1 Yz = EXPANSION FACTOR FOR DOWNSTREAM PRESSURE TAP Fm -- MANOMETER FACTOR = 1 UNIT CONVERSION FACTOR -- FACTOR CHANGING FLOW RATE UNITS WE CAN UNITE Fu =Ftb X Fpb X UNIT CONVERSION FACTOR (Fu FACTORS ARE GIVEN IN TABLE BELOW FOR DIFFERENT STANDAI~D CONDITIONS AND FLOW RATE UNITS) C, = Fu X Fg (THEORETICALLY CONSTANT DURING TEST) Cz = FpvXFbX FtfXYz THENC=C, XCz TABLE OF Fu FACTORS STANDARD ~RATE OF FLOW .... Cu Ft/HOU RS Cu Ft/DAY Ms/HOU R Ms/DAY ~-.....UNITS . . CONDITIONS 14.65 psi 60°F 1.0055 24.1311 0.0285 0.6834 14.73 psi 60°F 1 24 0.0283 0.6797 760 mm Hg 0°C 0.9483 22.7604 0.0269 0.6446 .... 760 mm Hg 15°C 1.0004 24.0094 0.0283 0.6799 ,,. 750 mm Hg 15°C 1.0137 24.3295 0.0287 0.6890 .......... GAS FLOW RATE CALCULATION,' H J t~4H-~/Rlfl;. 1 IALASKA IPT, MC I NTYRE ST. ~4 1989MAY 1 i 4 " "-- ARCO ALASKA OTHER 664. 8 ~96 . ~EST. DANIEL. S SR. 5.761 ' IBARTON 202A lO-lO0 0-1500 24.00 1.176 28.226 STATIC OlFFERENTIA~I DOWN ORIFICE CORRECTED GAS DAY FLOW PRESSURE PRESSURE ~ STREAM C2 = Fb X Ftf X Fpv X Y2 TIME ~ ,. T;M*.GAS / hwPf SIZEd C FLOW RATE TIME~ qg = C ~ hw Pf ~c~o~ ~'H".~ ,,.~.. F. ~t, '.. ~z c~ (C=Cl x c~) .... (HOURS) (PSii) WATER) (OF) (INCHES) 7h~( m 418. ~ 14 122 76.57 1. 000 200.89 0,9452 1,0~49 1. 0002 196. 5624 5548. i 4. 25164E+2 : 2 1.0~0 . 8h [m 4.~8.~ ~4 122 76,~7 1,000 200.89 0.9452 1.0280 1.0002 195.2429 5510.8 4.45424E+2 8h~[m 408.~ 22 96 94.8~ 1.000 200.89 0.~671 1.0~22 1_.0004 200.6074 5662.~ 5.66691E+2 " 2 2.0[0 9h ( m :40~ .; 12 96 69 . 61 1 . 000 200,89 0 . 9671 1.0~18 1,0002 200 . 4946 5659.1 4,158~2E+2 . s 2 .5[~0 9hD[m 4~8.; 68 110 176.62 1.000 200.89 0.95~1 1.0~81 1.0010 199.~91D D6'2Y.9 1.O1422E+D ' 2 1.0(0 lob (m 45~.; 62 122 167.7~ 1.250 ~14.84 0.9452 1,0~49 1..OOlO 308.2750 8701.2 1,4890~E+~ ,, tOh3[m 46~.7 76 ~40 ~87,74 ~.250 ~4.84 0.9309 1.0~38 ~.00~ ~03,35~ 8562.~ '1.61803E+~ ' 2 2.0{0 t~h C:m 478.E 86 144 202.91 ~.250 314,84 0.9278 1.0~45 ~.001~ ~02.5802 8540.5 1.~945E+~ ' 2 2.5~0 lih~( m 478. E 86 150 202.91 1,250 ~14,84 0.92~2 1,0~) 1. 001~ ~00. 7284 8488.2 1. 72882E+~.. ,o 2 ~. O( 0 12h (m 478.~ 85 1~0 201.7~ 1.2~0 ~14.84 0.9232 1.0~3~ 1.0012 ~00.7240 8488.1 1.71871E+~ ,,, " 2 ~.5~0 12h~[m 478.~ 84 1~0 200.54 1.2~0 314.84 0.92~2 1.0~ 1.0012 ~00.7196 8488.0 1.70855E+~ ,~ 2 4.0 ~ 0 l~h [m 478.~ 84 150 200.54 1.250 ~14.84 0.92~2 1.0~3~ 1.0012 ~00.7196 8488.0 1.70855E+~ 13h~[m ~8.~ 84 150 200.~4 1.2~0 314.8~ 0.9232 1.0~3~ 1.0012 ~00.7196 8488.0 1.70855E+~ ,4 2 5.0 [ 0 ,4 14h (m 478.E 84 160 200.54 1.250 ~14.84 0.92~2 1.0~55 1,0012 ~00.7196 8488.0 1.YOBSSE+3 l~h~m 4~8.E 84 1~0 200.54 1.250 ~14.84 0.92~2 1.0~35 1.0012 300.Y196 8488.0 l.YO85~E+~ ,~ 2 6.0 [ 0 1.5h ~m 478.~ 84 150 200.54 1.~50 ~14.84 0.92~2 1.05~ 1.0012 ~00.7196 8488.0 1.70856E+~ ,, 2 6 . 5 [ 0 15h3!::m 478, E 84 150 200.54 1. 250 ~14.84 0.92D2 1. OD3D 1. 0012 ~00. 7196 8488. 0 1 16h Em 478.E 84 150 200.54 1.250 ~14.84 0.92~2 I.O~DD 1.0012 ~00.7Z96 8488.0 1.70855E+~ °Ec'"Ez"'aHIGH-STAGE 1 ' ALASKA PT. McINT~'RE ST.4~4 11989MAY 2 4 CUSTOMER S~IANDARD CONDITIONS I ~:P'~;i PC= TC= ARCO ALASKA Ix114'73psI60OF ~OTHER ' 6~',5. 0 ~94.~sT. DANIEL, sMETER TYPE S~. IMETER R'UN SIZE( ' ~, ~ ......')~ F OW RECORDER TYPEBARTON 202 10--100lhw"'" ' (,-c-.,-*---) = X 24. ooo I 1.18~] STATIC DIFFERENTIAL DOWN ORIFICE CORRECTED GAS DAY FLOW ~SSURE ~.ESSU.~ STREAM C2 = Fb X Ftf X Fpv X Y2 TIME ~, hwT[M..GAS / hwPf SIZEd C F~OW RATE TIME~ qg = C ~ hw Pf , (HOU.S) (Psla) WATER) (°F) (INCHES) ', 2- 7,5[0 ' 16h~(m '478.E 84 150 200,54 1.250 ~14.84 0.92~2 1.0~} 1.0012 ~00.7196 8517.5 1.70855E+} z 2 8.0C0 17h lm ~78.~ 84 150 200.54 1.2~0 ~14,B4 0.92~2 1.0~ ~.0012 ~00,7196 8517.5 1.70855E+~ ' 2 8.5[0 17h~ ~m478.~ 84 150 200.54 1.250 514.84 0.92~2 1.0~55 ~.0012 500.~196 8517.5 1.70855E+5 " 2 9.0[0 18h Em 485.~ 84 150 201.58 1.250 514.84 0.9252 1.0522 1.0012 D00.4126 8508.8 s 2 9.5(0 18h~[m 485.E 84 150 201,58 1,250 514,84 0.9252 1,0~'22 ~.0012 500,41;26 8508.8 ~ 2 10.0~0 lgh [m 485.E 85 149 200.~8 1.250 514.84 0.9240 1.0524 1.0012 ~00.71'19 8517.5 1.72405E+5 ~ 2 10.56 0 19hS[m 485.E 8~ 149 200.58 1.250 514.84 0.9240 1.0~24 1.0012 ~00.7119 8517.5 1.72405E+5 20h (m 485.E 84 149 201.58 1.250 514.84 0.9240 1.0~24 1.0012 500.7165 8517.4 1.75445E+5 ' 2 11.510 , , ~OhS[:m 488.~ 84 149 202.62 1.250 514.84 0.9240 1.0~28 1.0012 500.8116 8520.1 1.74592E+5 '" 2 12.0[ 0 2lb Em 488.~ ,84 149 202.62 1.250 ~14.84 0.9240 1.0528 1.0012 500.8116 8520.1 1 " 2 12.5( 0 '21h~(m 495.~ 8~ 149 20~.65 1.250 514.84 0.9240 1.0551 1.0012 500.9070 8522.8 " 2 15. O( 0 22h [m 493.E B4 149 203.65 1.250 314.84 0.9240 1.0551 1.0012 300.9070 8522.8 1.75357E+5 22hS[m 495.~ 84 149 205.65 1.250 514.84 0.9240 1.0551 1.0012 500.9070 8522.8 1.~5557E+5 ,4 2 14. O~ 0 ,4 2~h {m 495.~ 8~ 149 202.44 ~.250 5~4.84 0.9240 1.0551 1.0012 ~00.9027 8522.7 1.74288E+5 ,s 2 ]~.SEO '25h31m 495.( 83 149 202.44 1.250 314.84 0.9240 1.0331 1.0012 300.9027 8522.7 1.24288E+5_ s 3 15.0C'0's' Oh (~m 493.~ 8D 149 202.44 1.250 314.84 0.9240 1.0331 1.0012 300.9027 8522.7 1.74'288E+5 ,~ ~ 15.5 [ 0 Oh~[Im 495.~ 85 149 202.44 1.250 514.84 0.9240 1.0~51 1.0012 300.9027 852~.7 1.74288E+5_ ' 3 16. 0( O ,8 lh (m 495.~ 82 149 201.2'2 1.250 ]14.84 0.9240 1.0~51 1.0012 500.8984 8522.5 1.75~35E+5_ °"c'"e:"'"HIGH-STAGE I1 KA IPT. McINTYRE ST.'.tI=4 11989MAY D ARCO ALASKA I~1 14'73 psi 60 ° F ~OTHER li4,75 5('5-7 ~90.~EST' ~ DANIELS S~. 5.761 BARTON 202A I0-100 0-1~00 24,000 I 1.192 28.604 DAY FLOW PRESSURE PRESSURE STREAM C2 = fb X Ftf X Fpv X Y2 TIME ., .. G~s / SIZE FLOW RATE . ~M,. hwPf d C TiME~ qg = C ~ hw Pf (HOURS) (~$ia) WATER) (°F) (INCHES) , , .~ _ 16.510 l~J(~ ~98.H 82 1~9 20~.2J 1.250 ~14.8~ 0.9~40 l. OJJ5 1.0011 J00.99~0 8609.6 1.Y~16JE+J · ~ 17. OC 0 '2h (m 498.G 82 149 202.2~ 1.250 ~14.84 0.9240 1.0~5 1.0011 ~00.9940 860~.6 1.7416~E+~ ~ 3 1.7.5170 2h3(~lm 498.~ 82 149 202.2~ 1.250 314.84 0.9240 1.0~35 l_.OOll ~00..9940 8609.6 l. Y416~E+3 Dh Em 503.E .82 150 203.24 1.250 314.84 0.92~2 1.ODD6 1.O011 300.78~0 860~.6 i.74911E+3 s ~ 18.500 3hJfm 50J.E e2 150 20D.24 1.250 D14.84 0.92J2 1.OJ2Y 1.0011 300.5165 8595.9 1.75884E+~ ~ 3 19. O0 0 4h (m 50J.~ 82 152 20~.24 1.250 314.84 0.92~7 1.0~2~ i. OOti 299.910J 8578.6 1.75529E+3 4h3(m 503.~ 82 153 20J.24 1.250 314.84 0.9210 1..0321 1.OOil 299.6089 8570.0 ' 3 20. 5h Em 50J.[ 82 lSJ 20J.24 1.250 ~14.84 0.9210 1.0321 1.0011 299.6089 85Y0.0 1.YSJSJE+J 5h3~m 503.~ 83 153 204.48 1.250 ~1~.84 0.9210 1.0321 1.OOll 299.6131 8570.1 1.76421E+~ ,o 3 21. Of 0 6h ~m 503.~ 83 153 204.48 1.250 314.84 0.9210 1.0~21 1.0011 299.6131 8570.1 1.~6421E+3 6h3(m 503.E 83 153 20a.a8 1.250 31~.8~ 0.9210 1.0~21 1.0011 299.6131 8570.1 1.76a21E+3 ,~ j 22. o[ 0 7h (m 50~.[ 82 153 203,24 1,250 J14.84 0.9210 1.0321 1.0011 299.6089 8570.0 1.75353E+~ ,~ 3 22.50 0 7h3fm 503.~ 82 ~153 203.24 1,250 314.84 0.9210 1.0321 1.0011 299.6089 8570.0 1.75353E+3 ,4 3 23. O~ 0 8h Em 50~.[ 82 153 20~.24 1.250 ~14.84 0.9210 1.0~21 1.0011 299.6089 8570.0 1.75353E+~ 8h3~m 503.~ 82 15~ 203.24 1.250 314.84 0.9210 1.0321 1.0011' 299.6089 8570.0 9h t.m 50~.~ 82 15~ 20~.24 1.250 J14.84 0.9210 1.0~21 i. O011 299.6089 8570.0 1.75353E+J ~? ~ 24.5C 0 9h3C~m 503.~ 82 153 20~.24 1.250 31~.84 0.9210 1. OJ21 1. OOil 299.6089 85~0.0 'l. Oh {m 503.~ 82 153 203.24 1.250 314.84 0.9210 1.0321 1.0011 299.6089 85~0.0 GAS FLOW RATE CALCULATIONS ST NUMBER TE NUMBER AREA WEL. L. NAME OR NUMBER DATE{DAY. MO, PAGE OF °Ec'as"~'BHIGH-STAGE IALASKA IPT. Mc INTYRE ST. ~4 11989MAY 4 4 CUSTOMER $1- $'~'"r'lA N DA R D CO N D IT IOm S ARC, O ALASKA DANIE{LS SR. ~.761 IBARTON 202A 10-100 0-I~00 | 24.000 J 1.20) I 28,788 STATIC DIFFERENTIAL DOWN ORIFICE CORRECTED GAS DAY FLOW ~;[s~u.[ FR;ssu.; STREAM C2 = Fb X Ftf X Fpv X Y2 TIME .. GAS / SIZE FLOW RATE , T[M~. hwPf d C TIME ~z~ H. ~ (,NCH;S Fb Ftf Fpv Y2 C2 (C=C1 X C2) ~CLOCK/ (HOURS) (psis) WATER) (°F) (INCHES) ,(__MSC~/~) lOh~{m 50~,E 82 15~ 20~,24 1.250 ~14,B4 0,9210 1.0~21 1.0011 299.6089 8625,~ 1.75~E+~ , . llh~[m ~03,E 82 1~ 20)',24 1.2~0 ~14,84 0,9210 1.0~21 ~.,0011 299,6089 862~.} 1,7~5~E+} 3 27,0~0 ~2h {m 50~,~ .82 1~ 20~,24 1.2~0 ~14,84 0.9210 1,0~21 1,0011 299,6089 8625.~ 1,7~E+~ ~ 7 I0 !0 12 13 i14 14 6 16 17 COMPANY: WELL: AREA: TEST: DATE: ARCO ALASKA INC. PT. McINTYRE ST. ~4 NORTH SLOPE ALASKA FLOW TEST ~2 1989 MAY 1-6 1989 MAY 17 KEITH PAIGE ARCO ALASKA INC. PO 80× 100D60 ANCHORAGE ALASKA 99510 RE: FLOW TEST ~2 TESTED: 1989 MAY 1-6 PT. McINTYRE ST. ~4 NORTH SLOPE ALASKA DEAR SIR: This report includes the Field readings and calculated production o¢ the test, A graphic profile oF the test appears on the Following page. The ensuing test results are summarized in Four sections oF this report which includes: (il TEST RESULTS~ (2) OIL FLOW RATE CRLCULRTIONS~ (3) GAS FLOW RATE CALCULATIONS~ and (4) FIELD READINGS. The well produced 3.~7.5 mscF oF gas., 567. barrels oF oil and .05 barre]s oF water during 10. hours oF Flow. I,.le at HRS appreciate the opportunity to serve your testing needs. IF ..wou have any questions concerning the test or this report please call me at ~07-472-1040. Sincere]y~ HALLIBURTON RESERUOIR SERUICES 3ohn M. Scherlin Data Acquisition Engineer Northern District PRODUCTION HISTORY PLOT 1989MRY 5 16h30m 0s TO 1989MRY 6 2h35m O3 ~'t le PW1"888 RRCO RLRSKR, INC. PT. McINTYRE ST. 'L I 1889 138e llge I PN:TY 5 8h i RflY 5 12h I l, lflY 5 18h I I,~:lY 8 8h 811 TEST RESULTS ST NUM'BER WELL NAME OR NUMBER AREA RATE/BUILD-UP NUMBER DATE (DAY MO YR) PAGE OF OEC-eSs-I-c PT. Mc INTYRE ST. ~4 ALASKA I 1989MAY 5 1 2 ARCO ALASKA_., INC. ~^,R--,> 12072--122'20 14.75 PS~&~s. 60 F TtMF DAY ! FLOW OR WELL HEAD WELL CHOKE SEPARA- BOTTOM HOLE BOTTOM CORRECTED CORRECTED WATER SHUT-IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS FLOW RATE OIL FLOW RATE FLOW ~~/ WOR WGR ,, ,, , ~ TIME TEMP PRESS- ~ RATE TIME U.[ Og Qo n/ ~ 0.0 )0 NET ~L S/] PRE~;SURE , 16h~l m 1680 0 ~ 5 0. 0)~ [~EG[II FkO~ THRU UN [6h~ m 28 , 5 .1~7 f'LUI ~ AT SLIRFACI' ~6h4~ m 28 ...... ].Th }m 1180 ~9 28 4~6.29 2.19 5. 0251E-',~ ' ~ .9 :7 7 4274E- L lYh} lm 1270 42 28 ~90 89S.61 120~.82 1.3464E+} ' ~ 1.4 7 ~ 4019E- L 18h tm 1~0 44 28 4S0 110~.~ 2046.2~4 1.8~12E+~ ' S 1.9 7 6 4618E-L ].Sh~ Im 1~0 4S 28 46S 1227.79 1900.08 1.~476E+5 ' ~ 0. 0 }0 [~HAN(;E CH0~:E. ...... 18h~ ~m 24 ~ S .~)0 6 5~99E- 19h (m~ 141S 4~ 24 4S0 74~.6~ 1169.28 1.~724E+} ,o S 1.0~0 7 0877E-1 19h3lm 141~ 4~ 24 4~ 72~.16 1023.12 1.4109E+~ " S 1. S 0 20h lira 141~ 46 24 450 67~.42 9~0.04 1.406SE+} " ~ 2.0 0 "00K 4-}GAt. GAS AND 2-1~AL 011_ SAMPLE'~ 7 2775E-~ 20h~ }m 1405 46 24 4~0 691.39 9S0.04/ 1.~741E+3 21h }m 140~ 46 24 440 672.~8 9~0.04 1.412~E+} .... " ~ }.0 10 6 2490E- 2].h5 ~m 1400 46 24 43S 6~9.39 102~.12 1.6003E+~ " ~ ~.~ 10 6 1866E-[ ,~ 22h ~m 1~90 4S 24 440 632.97 1023.12 1.6164E+~ ,. S 0.0)0 (:HANI;E CHOt:E. 22h ~m 28 TOTAL WELL EFFLUENTS PRODUCED ~ow ~,.z ~ow .,.~ wu..s~ r~ow ~,.e~swo wu..~. FaO. B 16h~0m TO ~ 22h 0m rD. RATE FOR TEST UP TO OF RATE ......................... .......~*S ~ .SCr,: 185 · 52 O,~ ~e~S,' 289. 2~ TEST RESULTS o£o86s-1-c PT. Mc INTYRE ST. ~4 ALASKA 1 1989MAY 5 2 2 , ARCO ALASKA.. INC. 28.10 0.6660 c^,R--I, 12032-12220 14.75 PS.~,~s. 60 F TEMP TIME TEMP PRESS* ~ RATE T~.~ .~ i n i ma u.~ Qg Qo [ a4 HE ~ DEPTH (FT) DEPTH (FT) ~CLOCK/ (.OU.S) (psis) I"F) (64TH,.C.) (psis) (psiS) l oF) ( .SCF/D) (STO BPD) (BPD' ~~/ STO..~ / ~~/ _OR (BBL/MMSCF) .5 )0 5 9465E- ,: 22h3 im ~340 4~ 2B 440 9~2.60 ~E~4.6B ~. 0 O 2~ Im ~0 4B 2B 46~ 9~6. 0g ~60~. ~6 1 5 0 6 1799E- . · 2~h~ Im 1~60 4~ 28 465 9~B.42 1~4.6~ 1.61BlE+~ 2. ~ o Oh m 1~6~ 49 2~ 46~ 9~6.~ 1~1~.44 1.~2E+~ 0h](m 116~ ~0 28 470 961.89 1607,76 1. ~. O( 0 lh (m 1~65 50 28 470 970.02 175~.92~~ 1.8081E+~ lh~Jm l~TM ~O 2B 4~0 927.67 118B.~2 1.496BE+~ , 6 4. 0J 0 2h I~m ~400 ~O 2B 46~ 861.78 1169.28 1.~68E+~ · 6 4.~ 10 6 4410E- 2h~ ~m 1420 ~0 28 4~0 800.21 1242.~6 1.M~2~E+~ '~ 6 0.0 }0 EJEGI~t SHUT- IN 2h~m 0 1] 1~. 44 ~ ,, , , ...... TOTAL HOURS OF FLOW: 10 . 000 TOTAL WELL EFFLUENTS PRODUCED TOTAL HOURS OF SHUT- I N: .08~ ~ow ~,.~ ~ow ~,.~ NU.a~. ~OW ~,.~ZNO NU.~. ~.O. ~ 22h 0m zo 6 2h~Sm ~o..~z ~o.~s~u.~o TOTAL UOLUHES: o~ .... GAS( MSCF': 171 .98 OIL {BBLS': 278.62 WATER (BBLS): O. O0 GAS ( MSCF': ~5~.5 OIL (BBLS): FO. caLcuLat m FLOW RATES MEASUREMENT BY METER I Vo = Vm Cf k (1 - BSW/100) ! WHERE Vo = VOLUME OF OIL AT ATMOSPHERIC PRESSURE AND TEMPERATURE (GENERALLY 60°. F) Vm Cf = VOLUME OF OIL REGISTERED BY METER(S) SINCE LAST READING AT SEPARATOR PRESSURE AND TEMPERATURE = MEASURED CORRECTION FACTOR. IT IS OBTAINED BY CALIBRATING THE METER WITH A TANK DURING THE TEST AND INCLUDES BOTH THE METER FACTOR, M, AND THE WEATHERING FAC- TOR, Wt. Cf = MWf M = METER FACTOR. IT IS TO CORRECT FOR ANY METER NON LINEARITIES. Wf k~ BSW = QQ -- ., WEATHERING FACTOR = VOLUMEOF OIL AT ATMOSPHERIC PRESSURE AND 60°F .'--VOLUME OF OIL AT SEPARATOR CONDITIONS. NOTE: Wf =(1-Sh),WHERESh=OILSHRINKAGEFROMSEPA' RATOR TO STOCK TANK CONDITIONS = (VOLUME OF OIL AT SEPARATOR CONDITIONS- VOLUME OF OIL AT ATMOSPHERIC PRESSURE AND 60°F) -~VOLUME OF OIL AT SEPARATOR CONDITIONS. TEMPERATURE CORRECTION FACTOR FROM ASTM TABLES (k = 1 FOR AN OIL TEMPERATURE OF 60° F). BASIC SEDIMENT AND WATER MEASURED USING APl FIELD CENTRIFUGE METHOD = PERCENT OF BASIC SEDIMENT AND WATER VOLUME TO TOTAL VOLUME OF OIL AND BSW. CORRECTED OIL FLOW RATE = VO + TIME TO PRODUCE THE VOLUME, Vo. MEASUREMENT IN TANK Vo =Vt k (1 - BSW/100) Vo, k, BSW, AND Qo AS ABOVE Vt = VOLUME OF OIL MEASURED IN TANK AT TANK TEMPERATURE SINCE LAST READING OIL FLOW RATE CALCULATIONS-TANK MEASUREMENTS ARCO ALASKA. T ~IC. PT. Mo !NTYRE ST.' 4~4 28 . O0114'75~ PSIA FIELD INCREASE IN VOLUME 8Y k CORRECTED CORRECTED CORRECTED GAS DAY OIL TANK TANK READINGS TANK SINCE FROM ASTM OIL VOLUME OIL FLOW FLOW RATE - FLOW TANK READINGS SINCE LAST LAST READING TANK TABLES BSW vo - v t k It. RATE FROM GAS FLOW TIME USED READING Vt TEMP. ~/t~) ~ RATE CALC FORM j OGR TIME % I STO .......... ] l-ouRs) I' oR ~) (INCHES) IINCHES) IIILS) 1' Fl , (%) (STO ELLS) (STO BPD) (MSC~ID) 17h Em 1 ~.00 1.~0 9.13 60 1.000 ,~0 9,09 436,29 ~ ~ .9~ ~h~[m 2 ~.~ 8.2~ ~0.24 60 ~.000 0.00 ~0.24 ~20~.82 B9~.6~ 7.427E-~ 1.4~7 .~Sh (m ~ 12.00 7.00 42.63 60 i.000 0.00 42.63 ~2046.24 110~.3~ ~.402E-1 · ~.9~ 7 18h3[m 2 20.2~ 6.50 39.~9 60 1.000 O.OO 39.~9 1900.08 1227.79 6.462E-1 [gh (m [ ~6.00 4.00 24.36 60 [.000 0.00 24.36 [~69.28 743.65 6.360E-[ s 5 ~.0[0 s tlgh3~m. 5· 1,5(02 '23,75 3,50 21,31 60 1.000 0.00 21,32 1023.12 725,16 20h ~m i 19,25 3,2~ 19,79 60 1.000 0.00 19,79 950,04 675,47 7.110E-1 i 5 2.0C0 I 20h~m 2 27.00 ~.2~ t9,~9 60 t.000 0.00 t9,~9 950.04 69t.~9 /.2~E-Zl 2~h (m ~ 22.50 ~,25 ~9.~9 60 ~.000 0,00 ~9,~9 950,04 6~2.58 ~ 5 3. OC 0 2~h3Cm 2 ~0.50 ~.50 2}.~]. 60 ~.000 0.00 2~,~2 ~02~.~2 639.~5 16 249E-~ " ~ 3.5E0 22h Em 1 26.00 3.~0 21.31 60 1.000 0.00 21.32 1023.12 632.97 J6.187E-1 22h3(m 2 35.75 5.25 31.97 60 1.O00 0.00 31.97 1534.68 912 60 5.947E-I 23h (~m I ~1.~0 D.DO 33.49 60 1.000 0.00 3~.~0 160F.~6 916.0~ j5.698E-1 '* 5 1 . Dr 0t 23h3(rm 2 41.00 ~.25 31.97 60 1.000 0.00 31.9~ 1534.68 948.42 ?.180E-1 s 6 2.0(0 Y ,S' Oh_ [~m 1 36.00 4.50 27.41 60 1.000 0.00 27.41 1315.44 9~6.5~ , .2~2E-1 ~ 6 2.5(0 .................. T ,s Oh~(Im 2 46 50 5 50 33 49 60 1 go0 0 O0 33 ~O 1607 ~ J~ J ? 6 3'0[0-----" *'-- ~ ~h (m ~ 42.00 6,00 ~6,~4 60 ~.000 0.00 ~6.~4 j~].92 9~0.02 [~,~IE-~J "~,h~ ( m '2 5~.25 ~ 4.75 28.93 60 ~.OOO 0.00 28.9~ ~8B.52 9'27.67 681E- ~J OIL FLOW RATE CALCULATIONS-TANK MEASUREMENTS i SKA ! [989MAY 6 2 J ARCO Al_ ASKA . I f, IC. PT. Mc !NTYRE ST. :11:4 28 . 10I1'4'75 PSIA ""'". 511 6.09BELL/I N 6,090511 i 6.09BBL/l N 6.09 0 F,ELD ,NCREASE,N VOLUME BY k CORRECTED CORRECTED CORRECTED GAS k OIL TANK TANK READINGS TANK SINCE FROM ASTM OIL VOLUME OIL FLOW FLOW RATE DAY PLOW TAN K READINGS SINCE LAST LAST READING TANK TABLES BSW vo - v t k I1- RATE FROM GAS FLOW TIME USED READING Vt TEMP. BSWllOO! oD RATE CALC FORM 2h [m [ 46.00 4,00 24,36 60 1.000 0.00 24.36 ::!.169.28 861.78 ' 6 4 5(0 2h3[m 2 9.75 4.25 25.88 60 1.000 0.00 25.88 ~1242.36 800.21 6.44lE-1 2h3~.m 2 9.75 .75 4.57 60 1.000 0.00 4.57 ].315.44 , 4 $ $ ~ 8 I& 14 / 18 18 OTiS i C,,.CULATING GAS FLOW RATES BASED ON A.G.A. REPORT NO. 3 IQ~ = C ~ hvv Pf 1 WHERE C = Fpv X Fb X Fg X Ftf X Ftb X Fpb X Fr X Y, X Fm X UNIT CONVERSION FACTOR -- CORRECTED GAS FLOW RATE = ORIFICE FLOW CONSTANT = DIFFERENTIAL PRESSURE ACROSS ORIFICE IN INCHES WATER @ 60°F = ABSOLUTE STATIC PRESSURE IN psi AND = SUPERCOMPRESSIBILITY FACTOR (CORRECTED FOR N.. HzS, AND CO= EFFECTS ON FINAL = BASIC ORIFICE FACTOR REPORT, (IF DESIRED) - = SPECIFIC GRAVITY FACTOR = FLOWING TEMPERATURE FACTOR Qg C hw Pf Fpv Fb Fg Ftf Ftb = TEMPERATURE BASE FACTOR Fpb = PRESSURE BASE FACTOR Fr = REYNOLDS NUMBER FACTOR = 1 Y, = EXPANSION FACTOR FOR DOWNSTREAM PRESSURE TAP Fm = MANOMETER FACTOR = 1 UNIT CONVERSION FACTOR = FACTOR CHANGING FLOW RATE UNITS WE CAN UNITE Fu = Ftb X Fpb X UNIT CONVERSION FACTOR (Fu FACTORS ARE GIVEN IN TABLE.BELOW FOR DIFFERENT STANDAI~D CONDITIONS AND FLOW RATE UNITS) C, -- Fu X Fg (THEORETICALLY CONSTANT DURING TEST) Cz = FpvXFbXFtfXY= THENC=C, XC= . , TABLE OF Fu FACTORS STANDARD ~ RATE OF FLOW ~UNITS Cu Ft/HOURS Cu Ft/DAY MS/HOUR MS/DAY CONDITIONS 14.65 Psi 60°F 1.0055 24 '1311 0.0285 0.6834 14.73 psi 60° F 1 24 0.0283 0.6797 ...... 760 mm Hg 0°C 0.9483 22.7604 0.0269 0.6446 .. 760 mm Hg 15°C 1.0004 24.0094 0.0283 0.6799 750 mm Hg 15°C 1.0137 24.3295 0.0287 0.6890 GAS FLOW RATE CALCULATIONS ..... v,, ,,n, ~.. ~.,n,..~.,,..,,-n, ,,~,,~ EST NUMBEI~ ATE NUMBEF~ AREA WELL NAME OR NUMBER ' DATE(DAY, MD, Y~ PAGE OF 0[C'862'I'B~ T C~_~T~CF I~1 ~ IPT N~ T NTMP~ qT :CUSTOMER -- ~AN ~A RD CONDITIONS ............. J ATM.~R~SS pc= TG= MEAS. ~ GAl SPECIFIC GRAVITY~ 'MEfE~ TY~ ...... " ~ETER R,UN SIZE ( c (si FL. OW RECORDER TYPE hw RANGE {INCNES WATER) STATIC PRESS RANGE(psi) FU TABLE PREV. PAGE Fg STATIC ~ O~FFERENTIAL OOWN ORIFICE CORRECTED GAS DAY F~OW PRESSURE PRESSURE STREAM C2 = Fb X Ftf X Fpv X Y2 TIME ~, ,w G~s / SIZE FCOW RATE TIME ~[M~.~ hwPf d ~ . . C (HOURS) (pill) WATER) (TM) (INCHES) (__MSCF/D) , , , , 17h~rm ~N~ ~ 97 1~9 1N~ R~ I ~0 ~1~.49 0-9~79 I N~lq I NNNR ~N4 9N4~ qRN F~ ;~A~ ~ RR 1~ ONO ~ I NNN ONN 4~ n 9aR4 1 nzz~ 1 nNl~ 199,.74R7 5 .~00 lON~fm ~q ~ ~1 lgR l~g 7q 1 NNN 9NH ~ mN ~17~ 1.N~NR 1..NNN4 [~9_7~7& 9Nh tim ~ R ~ lfi~ 19~ ~ I _ NNN 9NN 49 N q179 I N~N9 I NNN~ IR~ ~TN~ R~R ~ 4 7~79F+9 T ~ 2.0~0 ~ 2,~0 91h ~m ~ ~ ~ :'l~n 19~ 1~ 1 NNN ~00~6~ 0,9!~ ,1.030~ 1.000~ !89 ~189 g 3.0~0 91H~m ~ ~ ~9 l~fl I lq q7 I NNfl 9Nfl 49 N qlg~ I N~fll I NNflR 1~ 99H~m ~g4,~ g~ ~gn ~q gn ~ nnn 2nn ~9 n 9~n~ ~ o~nn ~ nnnq ~94 ~3K~ ~78:7 ~_19~N~+9 12 F 1. 000 9~k~ ........... ~Tg ~ g~ !23 T66_8~ ~_nnn ~no_~9 0_9~ ~ 03~7 I NNN~ ~g~ ~" 6 2. 000 nh r~ a7o_8 ~o ~o~ 16n ~4 1 nnn ~00.69 N 9~ 1 .N~7 I NNNg !96 ~s6 2. ~00 ........... , lh Nm ~R~ R 4fl 19~ 17N R~ I flflfl 9tiff_K9 fl 9444 1 fl~K1 1 flflflg 194_47~9 ~fl R 9 7flfllRD+9 " 4 4. O0 0 " 9h Arum ~Tg fl ~R ~124 1~1~R..1 ANN ONN ~O N ~4~ I N~ 11 NAil7 1Q~ I~NN GAS FLOW RATE CALCULATIONS OEC-8~2-1 -B CUSTOMER -- N~ARD CONDITION~-- SPECIFIC ~RAVITY4 D~[r STATIC OIFFERENTIAI OOWN ORIFICE DAY FLOW CORRECTED GAS TIME ,.Es~u,[ ,.[ssu.[ STREAM~ C2 = Fb X Ftf X Fpv X Y2 hw GAS SIZE FLOW RATE T[~,. hwPf d C TIME Qg = C ( °Fl (iNCHES) .(~MSC~/Q) 9h~flm ~ 7 ~ 19~ 1~1 ~7 1 NNN 9Nfl ~9 N.9~gN I N~N I flflN~ 19~.~177 ~7_R R_NNgNT~+9 12 12 13 13 14 14 15 IG 16 17 ,,, 18 18 FIELD READINGS I (DAY. MO.. YR.) OEc'eos'I'A F~T, Mc INTYRE ST. $4 f8 X l0 (80 mm) ~[989MAY i 2 CUSTOMER [FIELD FORMATION lOlL METER SIZE I(BBLs)METER RANGE ARCO ALASKA, INC. PT, McINTYRE (UPARUK . 2032-12220 ~rT.~ (FT.) ~PIPELINE FLARE 5.761 (INS) 0--100 ~ UPSTREAM' ~ DOWNSTREAM TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL GAS METERING OIL OR CONDENSATE METERING WATER METERING PLOW OR TUBING CASING MAN. HEATER ORIFICE STATIC DIFF. GAS 8 t TANK OR ~ 1 OIL OIL ~ 1 TANK OR DAY SHUT-IN PRESS. TEMP. PRESS. B H P B H T CHOKE CHOKE SIZE PRESS. =RE~S. TEMP. GRAVITY METERREADING TEMP GRAVITY Wf METER READING SALINITY DURATION (AIR--l) TANK INCH 24 HOUR (HOURS) (PSIG) (°r) (PSIG) (PSIG) (°F) (INS) (PSIG) ( OF) % H2S GApI (%) ) CLOCK , IN) 'N) 2 F~o~N~H (o~, ..s.o. a~L) ,,~ 00l 0 ~ T%~! ~/I P~ESSUF~E ~ ~h~O~ l~eo o ~ O. 0 0 BE[~[N i'LOI4 FH~U UNIT ~ ...... ~ ,, , ~~ . 1~;7 FLIJID ~T SUI~FACE 3 . 3 ~ . 4:L7 ' . 5. O0 60 l. OOO 1~ 7h Or~ [~80 ~9 28 28.0_ 0.5 ,, 7h~Or~ 1270 42 2~ 1.250 DgO 27 iD2 0.00 1~.7~ 60 2~.0 0.0 8h Orn 1D50 44 2~ 1.000 450 ~ 14D 0.00 1D.75 60 27.9 0.0 ~ ~ 1.9 7 ~).718 12.00 60 [.000 · ............... eh~O'~0 1~0 45 2e 1.250 465 44 155 0.00 20.2~ 60 27.9 0.0 .8 5 O. 0 :10 CH¢~NGE CHOKI'. " " LSh30~n 24 " 5 .~ lO "3.218 16.00 60 I.O00 " Lgh On 1415 45 24 1.000 450 41 155 0.00 20.25 60 2?.9 0.0 ,o ~ 1..0)0 '°3.~26 16.00 dO l. O00 '~ {.gh~O ~ 1415 4~ 24 1.000 435 41 158 0.00 2~.9~ 60 27.9 0.0 ~, 5 1.5 ~0 "3.P26 19.2~ 60 ~ 1.000 ,, "~'h 0~ 1415 46 24 1.000 4~0 36 1~8 0.00 23.75 60 ~8.1 0.0 "$ 2.0)0 TOi3K 4. 3G~L G~S ~{) 2-[G~L OIL S~HPLIES '13.72d 1~.2~ dO 1.000 ,~' 'Oh~O,~ 1405 46 24 1.000 450 36 15~ 0.00 27.00 66{ ~.i 0.0 " 5 '2.5 30 '~3. 726 22.50 60 1.000 ,z < ih Or~ 1405 46 24 1.000 440 35 160 0.00 27.00 60 ~.1 0.0 '~ 5 ~.030 '~0.726 22.50{ 60 ............. 1.000 '~ ~'lh3Orn 1400 46 24 1. 000 435 3~ 160 O. O0 30.50 60 ~. i 0.0 ,. 5 ~. ~ 3o ........... ~ 3.7~ ....... ~q..O.O .... ~-0i2.00-0 ........ ,~ '~2h 0rn 1390 45 24 1.000 440 ~1 160 0.00 30.50 60 28.1 0.0 '~ D 0. 030 CH:~H6E 6HOK-. '~ .......... '~ ............ "~2h 0~n 28 ..... ??h30n ].~40 47 28 Z.O00 440 5~ 128 0.00 ~5.7~ ~0 28.~ 0.0 ............................................................................................................. FIELD READINGS bll~lbLl: b m ~bt Ul~l I EST NO. LL NAME OR NUMBER EST UNIT DESCRIPTION I[DAY. MO.. YR.) PAGE OF DEC - 905'1'A . M~[NTYRE ST. 4~4 ~i8 X ~0 (80 mm) [989MAY ARCO ALASKA. INC. . I PT. Me INTYRE }{UPARUK INTERVAL TESTED "' I~,,~U,V=~,,, GAS PRODUCED T~ GAS METER RUN SIZE DIFF' RANGE (INS' H20) liTATIC PRESSURE TAKE~ .~_~~ (FT.) (FT.) ~ PIPELINE FLARE 5,?&1 (INS) 0--100 ~ UPSTREAM* DOWNSTREAM TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL GAS METERING OIL OR CONDENSATE METERING WATER METERING : FLOW OR TUBING CASING MAN. HEATER ORIFICE STATIC DIFF. GA y 81 TANK OR SHUT-IN PRESS. TEMP. PRESS. B H P B H T CHOKE CHOKE SIZE PRESS. PRESS. TEMP. GRAVI METER READING TEMP GRAVITY Wf METER READING SALINITY ' ~ ~ DURATION (AIR--I) '~RNK [ HCH *~T*.~O. *~O,~ *~TA.~O.' ~L(pp 24 HOUR (64TH)(64TH) IN METER READING TEMP ~ 60°F BSW METER READING~ ~o~ ,.o~.~, ,~,~, ,o~, ,~,~, ,e~,~, ,o~, ,., ,., ,,.~, ,.~,~, (.~o) ,o~, ~ "~ r~~ ,o~, o~, ,~, ,,.~. o...~, p~, , ~h Or~ 1~0 ~8 28 1,000 46~ ~ 122 0.00 ~.7~ 60 28.1 0.0 3h~Or~ 1.3~0 ~8 28 1.000 ~6~ ~8 12~ 0.00 ~1.00 60 28.1 0.0 ~~ ~.o o ~[i,6s6 ~6.oo 6o_ .;oO0 . Oh Or~ 13~ ~9 28 1.000 46~ ~9 12~ 0.00 41.00 60 28.1 0.0 ~ ~.~ o '{i.6s6 . ~6.oo nh3nr~ 13As ~ ~8 1.000 470 59 12~ 0.00 ~6.~0 60 2S.1 0.0 ~ ~.0~0 "~t.~86 ~2.00 60 k.,O,O0 lh Or~ 1~6S 50 28 1.000 ~70 60 12~ 0.00 46,~0 60 28.1 0.0 ~~ ~.s~o ~..6s6 4~.oo ~o lhsO,~ 1~7~ ~0 ~e 1.O00 ~70 SS l~ 0.00 ~1.2~ 60 ~e.1 0.0 ~ 4.0~0 ~i.,.686 ~6.00 60 L.O00 2h 0,~ 1~00 ~0 28 1.000 ~6~ ~8 1~4 0.00 ~.~0 60 2S.1 0.0 ~ 4.5( 0 a).686 16.75 60 L.O00 ~h30~ ~4~0 50 ~B ~.000 4~0 43 ~6 0.00 9.~5 60 ~B.~ 0,0 ~h~ ~ 0 9.~5 60 ~,~ 0.0~ 10 10 , I1 I1 II '12 12 12 ~1~ 13 __ 1~ 16 IT 17 St METHOD OF CALCULATING GAS FLOW RATES BASED ON A.G.A. REPORT NO. 3 lt~l~l = C 'X/ hw Pf WHERE C = Fpv X Fb X Fg X Ftf X Ftb X Fpb X Fr X Y, X Fm X UNIT CONVERSION FACTOR Qg C hw Pf Fpv = Fb Fg = Ftf Ftb Fpb = Fr = Yz = = CORRECTED GAS FLOW RATE = ORIFICE FLOW CONSTANT = DIFFERENTIAL PRESSURE ACROSS ORIFICE IN INCHES WATER @ 60°F = ABSOLUTE STATIC PRESSURE IN psi AND SUPERCOMPRESSIBILITY FACTOR (CORRECTED FOR N,, HaS, AND COz EFFECTS ON FINAL BASIC ORIFICE FACTOR REPORT, (IF DESIRED) SPECIFIC GRAVITY FACTOR FLOWING TEMPERATURE FACTOR TEMPERATURE BASE FACTOR PRESSURE BASE FACTOR REYNOLDS NUMBER FACTOR -' 1 EXPANSION FACTOR FOR DOWNSTREAM PRESSURE TAP Fm -- MANOMETER FACTOR = 1 UNIT CONVERSION FACTOR = FACTOR CHANGING FLOTM RATE UNITS WE CAN UNITE Fu =Ftb X Fpb X UNIT CONVERSION FACTOR (Fu FACTORS ARE GIVEN IN TABLE.BELOW FOR DIFFERENT STANDARD CONDITIONS AND FLOW RATE UNITS) C, = Fu X Fg (THEORETICALLY CONSTANT DURING TEST) Cz = FpvXFbXFtfXYz THENC=C, XCz TABLE OF Fu FACTORS STANDARD~ RATEOFFLOW CONDITIONS~"----..,.,UNITS Cu Ft/HOU RS Cu Ft/DAY M~/HOU R M~/DAY 14.65 psi 60°F 1.0055 24.1311 0.0285 0.6834 14.73 psi 60° F 1 24 0.0283 0.6797 760 mm Hg 0°C 0.9483 22.7604 0.0269 0.6446 760 mm Hg 15°C 1.0004 24.0094 0.0283 0.6799 750 mm Hg 15°C 1.0137 24.3295 0.0287 0.6890 GAS FLOW RATE CALCULATIONS °E¢":""HI~H-ST'A~E IALASKA IPT. Mc INTYRE ST. ~k4 11989MAY ARCO ~L. ASKAr INC IXl~4.?3~siso°F ~OTHER 66~. METER TYPE STaTiC mFF~.~.T~ OOW. ORIFICE DAY FLOW CORRECTED GAS TIME ~.~u.~ ~.~ssu.~ s~.~. / hwPf FLOW RATE ,. GAS SIZE C2 = Fbi Rtl X Fpv X Y2 . TEMP. d C TIME~ qg = C (~K) ,NCHES Fb Ftf FpV Y2 C2 (C=C1 X C2) ..... (HOURS) (Gsia) WATER) ( o F) (INCHES) ,(__ MSC ~/~) l~h [ m ~84. ~ 22 110 11~. 42 1. ~00 4S4, ee o. ~l i. 0462 1. 000~ 4s4. 6690 L~271.9 i. 50~92E+3 13h3(m ~84.~ 24 1~4 1~8.47 ~.2~0 314.84 0.9518 1.0S18 1,0003 315.2604 9202.~ 1,0~682E+3 14h fl:m ~84,~ 27 ~18 125.6~ 1.250 ~14.84 0,948S 1.0448 1,0003 312.1~20 9~10,6 ~4h3Cm ~99.8 28 ~2~ 129.~9 ~.2~0 ~4.84 0.9460 ~.04~4 ~.000~ 3~.4777 9092.~ 1.~7097E+3 s 6 .8~D 15h ~m 599.8 50 124 1~4.14 1.250 514.84 0.94~6 1.0445 1.000~ 510.4208 9061.3 1.20794E+3 6 6 1.3E3 15h3Cm 599.8 32 125 138.54 1.250 314.84 0.9428 1. 0443 1. 0004 310. 0764 9051,2 1.24615E+3 8 6 2. ~8~ ~ 6 O. 000 12 12 15 IS 16 16 17 17 ~8 FIELD READINGS I (DAY. MO.. YR.) OE:C - 905-!-A FpT. Mc I NTYRE ST. 4~4 X 10 801'11't I1.989MAY I 2 ~RCO ~LC~SKA. INC I PT. 1'1o INTYRE (IJRARUK INTERVAL TESTED IBHP SURVEY DEPTH GAS PRODUCED TO GAS METER RUN DIFF. RANGE (INS. H20) STATIC PRESSURE TAKEN I SIZE 2032-]2220 (FT.) (FT.)~--~PIPELINE FLARE 5.76'1 (INS) 0--100 [] UPSTREAM' ~ DOWNSTREAM -- TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL GAS METERING OIL OR CONDENSATE METERING WATER METERING FLOW OR TUBING CASING MAN. HEATER ORIFICE STATIC DIFF. GAS # I TANK OR # I OIL OIL # I TANK OR * 2 TANK OR * 2 OIL * 2 TANK OR :L ( p p (64TH) (64TH) (~no) ~T~.~E~,~ TEMP ~ eO °F BSW METER READING 24 HOUR (HOURS) (PSIG) (°F) (PSIS) (PSIG) (°F) (INS) (PSIG) (°F) % H~$ CApI (%) CLOCK IN) IN) 2 /~OB~e~ (°F) (INS. OR BBL) p ' 6 0. 0 0 IN TIAL. SHU" IN PRI:SSUF?E ' .... ~2h 5~n 1550 0 ~ 0 0(0 BE(;IN F:LOW 'HROUGH UNI'F. :,, ...... L2htO ~ ~550 28 a ._6 '. . O~ 7 ~ L2h[4~n [200 28 ~ O. 0)0 CH~NGE CHOKf-. " L2h[4~n 40 s 6 .0 7 ~ ...... L2h~5 ~ ~0~0 40 ~ 6 . 0~;0 FLIJID ~T SU~FACE 6 L2h17~ L~hlS~a 97~ 40 ~ 6 O. 0)0 CH~NGE CHOK'. e 2hlSrn 46 .2h20 n 900 46 ,o 6 O. 0)0 CH~NGE CHOKI:. ,o L2h20~n L2h24~n 880 L2h24~n 64 '* 6 .~ ~0 ~ ~.00 60 ~.000 L2hDOn 8~ 4~ 64 27.7 '" 6 .4SD ~[SE 9~CK ~E~U~- TO 600~k '" ........... 2hD 0 n 64 LDh 0~ 9~ 5D 64 ~.~00 ~70 22 ~0 0.00 2~.2~ 60 27.7 -- [~h30~ 9~ 59 64 1.2~0 570 24 114 0.00 25.25 ,.60 27.7 ~4h O~n 965 63 280 64 1.2DOj ~70 27 118_0.00_ 42.00 60 27.7 ~~ FIELD READINGS 4R£0 4LASKA. !NC I PT, Mc IN]'YRE (URARUK 2032-1222 ~FT.~ (FT.) [] PIPELINE FLARE 5 · 761 (INS) 0--100 [] UPSTREAM' ~ DOWNSTREAM TIME WELLHEAD DATA DOWNHOLE DATA FLOW CONTROL GAS METERING OIL OR CONDENSATE METERING WATER METERING · FLOW OR TUBING CASING MAN. HEATER ORIFICE STATIC DIFF. GAS # I TANK OR # ! OIL OIL # 1 TANK DAy SHUT-IN PRESS. TEMP, PRESS. B H P B H T CHOKE CHOKE SIZE PRESS. PRESS. TEMP. GRAVITY METER READING TEMP GRAVITY Wf METER READING SALINITY , 24 HOUR (e4TH) (64TH) {~No) METER READING TEMP ~ 60°F BSW METER READING CLOCK (HOURS) (PSIG) (°F) (psIG) (PSIG) (°FI iN) IN) (INS) (PSIG) 2 (°F) % H2S [~0~ (°F) °APl (%) (iNS. OR BBL) 4h 2r~ 96~ 280 64 2 . 2 __ 6 0.0 0 CH~NGE CHOKE . L4h 2~. 80 L4H 5~n 945 300 80 ~ O. O[ 0 CHf~NGE CHOKE'. " L4h ~ ~ 90 ~ 6 .0~3 s , L4h 7~ 940 320 90 ...... " 6 O. OI 0 CH~NGE CHOK['. ' s -- k4h 7,~ 96 ~ 6 .3~3 ~.685 45.50 60 [.000 4h30 ~ 940 67 390 96 [.250 585 28 ]2[ 0.00 [6.50 60 28.5 0.0 ~~, .8t~3 ~ 3. 685 [~. 00 60 t. 000 5h 0r~ 940 7[ 590 96 [.250 585 30 [24 0.00 32.~5 60 28.5 0.0 ~ 6 [.3 ]3 ~3.685 29.00 60 [.000 5h30r~ 940 74 760 96 [.250 585 ~2 ]25 0.00 32.~5 60 28.5 0.0 ~o 6 ~.8~3 ~o3.685 29.00 60 [,000 6h 0r~ 9~5 76 850 96 [.2~0 575 32 ~25 0.00 5[.00 60 28.5 0.0 6h~0r~ 935 80 950 96 [.250 570 ~2 [25 0.00 5[.00 60 28.5 0.0 ~ 0.0~0 ENI) FLI3W ]ND OF TEST ~3.685 47.50 60 [.000 7h 0~ 93~ 80 ]060 96 [.250 570 32 [25 0.00 69.50 60 28.5 0.0 13 13 13 14 14 14 ................................. 17 17 17 ................................. COMPANY: WELL: AREA: TEST: DATE: ARCO ALASKA INC. PT. MclNTYRE ST. ~4 NORTH SLOPE ALASKA FLOW TEST 4~D 1989 MAY 1-6 MAY ~? KEITH PAIgE ARCO ALASKA INC. PO BOX 100360 ANCHORAGE ALASKA 99510 RE: FLOW TEST ~ TESTED: 1989 MAY 1-6 PT. McINTYRE ST. ~4 NORTH SLOPE ALASKA DEAR SIR: This report includes the Field readings and calculated production oF the test. A graphic profile o¢ the test appears on the Following page. The ensuing test results are summarized in Four sections o¢ this report which includes: (1) TEST RESULTS~ (2) OIL FLOW RATE CALCULATIONS~ (3) gAS FLOW RATE CALCULATIONS~ and (4) FIELD READINGS. The ,,.,ell produced 255.7 mscF oF gas, 1004 barrels oF oil and 0 barrels oF water during 4.9 hours o¢ Flow. A BHP profile was not available For inclusion in this report. We at HRS appreciate the opportunity to merve your testing needs. IF you have any questions concerning the test or this report please call me at 307-472-1040. Sincere HALLIBURTON RESERUO]R SERUICES John M. Scher 1 in Data Acquisition Engineer Northern District PRODUCTION HISTORY PLOT 1589MRY 6 12h 5m Oz TO 1989MRY 6 1?h Om O~ RRCO RLRSKR, INC PT. McINTYRE ST. ~4 !/ I ~ ~ 8h i HRY g [2h ! TEST RESULTS OEC-SSS-~-C PT. Mc INTYRE ST. CUSTOMER OIL GRAVITY ~ 60°F (°APl)I GAS SPECIFIC GRAVITY INTERVAL TESTED (FEET) STANDARD CONDITIONS I (AIR ARCO ALASKA. INC L20~2-12~20 14.7~ P~s. 60 F FLOW OR WELL HEAD WELL CHOKE SEPARA- BOTTOM HOLE BOTTOM CORRECTED CORRECTED WATER DAY SHUT*IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS FLOW RATE OIL FLOW RATE FLOW ~~/ WOR WGR T~ME TgM~ PRESS- ~ TIME U.~ Qg Oo /2,.. ~ r~inima DEPTH (FT) DEPTH (FT) IsT° ""~/ ( ..~ ' 6 0. 0]0 NiT ~L SH[JT-[N P~ESSU~: [2h }m [~0 0 : ~ 0. 030 [~EGil~ FLOI4 TH~O[.IGH UNIT. 12h1. ]m 1~0 12hl em 1200 28 ~ 6 0.0 l0 []HANI~E CHOI(E. 12h 1 ~m 40 ' 6 .0 ].2hl m 10~0 40 .............. · ~ .0~0 sLUI) AT SI~RFACI' ].2h l~,~m 40 12hl()m 9~ 40 . 6 0.0 ]0 ]HANdlE CHO~::E. 12hl(Jm 46 · 6 .0~3 12h2 }m 900 46 12h2 )m ..... 12h2 ~m ~80 '~ 6 0.0~0 ~]H~N~E ~HO~(E. 12h2 im 64 12h} ]m 855 4~ 64 24~. 49 ....................................... '~ 6 .41 3 f~AISf- 8ACK PRES~iURE TO 500~ 12h~ )m ~4 idb )m 9DS 53 64 570 1505.92 2750.47_ 1.8264E+D " 6 1.1 ]0 2 IS84E- :fDhD im 9$5 59 64 570 1056.82 4896.57 4.63D1E+3 TOTAL ~ELL EFFLUENTS PHODUCED FLOW TIME FLOW TIME NUMBER FLOW TIME/END NUMBER FROM 6 ~'~ ~m TO 6 ~ 0m FOR RATE FOR TEST UP TO GAS ( MSCF): ~9 , ~ OIL (BBLS)~ ~9 , 6~ WATER (BBLS): 0, 0 ~ GAS ( MSCF): OIL (BBI.S) WATER (BRI S): TEST RESULTS o£c-.ss-~-c 13 PT. McINTYRE ST. ~4 ALASKA I 1989MAY ARCO ALASKA., INC 27.70 0.68:~0 (^'R--~) 120:~2_.12220 14.7~ P~s. 60 F TE~,. _ : fLOW OR WELL HEAD WELL CHOKE SE"A"A- BOTTOM HOLE BOTTOM CORRECTED CORRECTED WATER ::: SHUT-IN PRESSURE HEAD SIZE TOR PRESSURE ~ HOLE TEMP GAS FLOW RATE OIL FLOW RATE FLOW ~~/ WOR WGR TIME U,E Qg Qo 1.6 i0 2 3270E-L , 14h )m 965 6~ 64 570 ~139.~B 4B96.~2 4.2974E+~ [4h :~m 965 64 0. 0 )0 i~HRNI;E CHO~E. .0~; 0 14h ~;m 94~ 80 ,,. ':: ~ ,~ 0 0 )0 ~:HANI;E CHO~E 14h ~;m 90 . o ~ 14h '~m 940 90 ~. :;~ 0.0 0 []HAN[;E CHO~E. 14h ~m 96 , ~ .~lt~ 2 2~68E-L , 14hD m 940 67 96 ~8~ ~170,97 5188.69 4.4DilE+D · 6 .8~tD 2 5429E-L l~h (m 940 71 96 ~85 1207.94 42~0.21 ....... ,o 6 1.~(~3 2 ~68~E-L ,o t~h~m 940 74 96 ~8~ ~246.1~ ~26~.22 4.2224E+~ " 6 ~.~3 2 ~147E-[ " ,, ~6~ ~}m 93~ 76 96 ~7~ 1234.~4 ~34.8~ 4.320~E+3 ,,- " 6 0.0]0 ~ND :LOH. END ()F TEST. 2 2729E-I 1Th )m 9D~ 80 96 520 1229.15 ~402.9~ 4. ..... .... TOTAL HOURS OF FLOW: 4.917 TOTALWELL EFFLUENTS PRODUCED TOTAL HOURS OF SHUT-IN: 0. 000 ~.o. 6 13h30m TO 6 1Th 0m .o..~z ~o.~zs~u.~o TOTAL UOLUMES: :~s~ ..~.~: 176.20 o~, ~..,~. 75~.16 w~z-.~--,-~: 0.00 ~ ~ ..~.~. 2~.7 ~,, ~..,.~1004.8~ w'~-.~--,-~. 0.00 .......... METHOD USED FOR CALCULATING OIL FLOW RATES OTIS', ,',o.t~.; o.=_..,.,, MEASUREMENT BY METER Vo = Vm Cf k (1 - BSW/100) I WHERE Vo = VOLUME OF OIL AT ATMOSPHERIC PRESSURE AND TEMPERATURE (GENERALLY 600F) Vm Cf = VOLUME OF OIL REGISTERED BY METER(S) SINCE LAST READING AT SEPARATOR PRESSURE AND TEMPERATURE · - MEASURED CORRECTION FACTOR. IT IS OBTAINED BY CALIBRATING THE METER WITH A TANK DURING THE TEST AND INCLUDES BOTH THE METER FACTOR, M, AND THE WEATHERING FAC- TOR, Wf. · Cf = M Wf M = METER FACTOR. IT IS TO CORRECT FOR ANY METER NON LINEARITIES. Wf , .. = WEATHERING FACTOR = VOLUMEOF OIL AT ATMOSPHERIC PRESSURE AND 60°F .'--VOLUME OF OIL AT SEPARATOR CONDITIONS. NOTE: Wf =(1-Sh),WHERESh=OILSHRINKAGE FROMSEPA- RATOR TOSTOCK TANK CONDITIONS = (VOLUME OF OIL AT SEPARATOR CONDITIONS - VOLUME OF OIL AT ATMOSPHERIC PRESSURE AND 60°F) +VOLUME OF OIL AT SEPARATOR CONDITIONS. = TEMPERATURE CORRECTION FACTOR FROM ASTM TABLES (k = 1 FOR AN OIL TEMPERATURE OF 60° F). BSW = BASIC SEDIMENT AND WATER MEASURED USING APl FIELD CENTRIFUGE METHOD = PERCENT OF BASIC SEDIMENT AND WATER VOLUME TO TOTAL VOLUME OF OIL AND BSW. Qo = CORRECTED OIL FLOW RATE = Vo --; TIME TO PRODUCE THE VOLUME, Vo. MEASUREMENT IN TANK Vo =Vt k (1 - BSW/100) Vo,k, BSW, AND Qo ' AS ABOVE 'Vt = VOLUME OF OIL MEASURED IN TANK AT TANK TEMPERATURE SINCE LAST READING OIL FLOW RATE CALCULATIONS-TANK MEASUREMENTS 1 SKA 89MAY 6 1 , ARCO ALASKA. INC PT. Mc INTYRE ST. ~4 27.70I14'7~ PSIA ""-'-"'-'-",. FIELD INCREASE IN VOLUME BY k CORRECTED CORRECTED CORRECTED GAS X OIL TANK TANK READINGS TANK SINCE FROM ASTM OIL VOLUME OIL FLOW FLOW RATE ~Y FLOW TAN K READINGS SINCE LAST LAST READING TANK TABLES BSW vo - v t k I1- RATE F ROM GAS FLOW TIME USED READING Vt TEMP. ~l~ml ~ RATE CALC FORM ] OGR TIME ~ STO .......... ) I-ou-s) (, o. {) liNe-{s} IINC--{.) Imm~s) I' Fl , (~) (STO miLS) (STO ..D) (MSCF/D) i 6 .1{0 12h~(m 1 11.00 7.00 42.6~ 60 1.000 0.00 42.6~ 2455.49 ~ 6 .6{0 1}h'"(:m~ 2 2~.2~ 17.2~ 10~.0~ 60 1.000 0.00 10~.0~ 27~0.47 I~0~.92 ~.47~E-1l ~ 6 1.1(0 13h}t~m 1 27.7~ 16.75 102.01 60 1.000 0.00 102.01 4896.~7 1056.82 2.158E-1 4' ~ 1.6(0 14h [~m 2 42.00 16.75 102.01 60 1.000 0.00 102.01 4896.~7 1139.38 2.~27E-1 14h~[mm 1 4~.~0 17.75 108.10 60 1.000 0.00 108.10 5188.69 1170.97 2.257E-1 15h [m 2 D2.7~ 16.25 98.96 60 1.000 0.00 98.96 4750.21 1207.94 2.54DE-1 t5h~[m ~ 29.00 ~8,00 ~09.62 60 1,000 0.00 ~09.62 ~261.77 ~246.~ 2. 16h (m 2 51.00 18.25 111.14 60 1.000 0.00 111.14 5534.85 1254.84 2.~15E-1 16h5 ;m 1 47.50 18.50 112.67 60 1.OOO O.O0 112.67 5407.95 1229.15 2.275E-1 ...... '" 6 O. 0 0 ,o 1Th Im 2 69.50 18.50 112.67 60 1.000 0.00 I12.67 5407.95 1229.15 2.27~E-lJ II II I , ,, ,il { I 6 Western Atlas Internationel A Litton/Dresser Company CORE LABORATORIES CORE ANALYSIS REPORT POINT MCINTYRE ~4 EXPLO~TORY NORTH SLOPE, ALAS~ CL FILE NO. BP-3-1345 Performed by: Core Laboratories 8005 Schoon St. Anchorage, AK 99518 (907) 349-3541 Final Report Presented May 17, 1989 These analysis, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (a]l errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibi]ity and make no warranty of representation as to the productivity, proper operations, profitability of any oil, gas or other mineral we]] or formation in connection with which such report is used or relied upon. RECEIVED 8005 Schoon Street, Anchorage, Alaska 99518-3045, (907) 349-3541 jU?,-I _o,= i'389 Alaska Oil & 6as Cons. C0mmissioa Anchorage : t INTRODUCTION Core Laboratories was requested to perform a core analysis study on behalf of Arco Alaska, Inc. for samples recovered from the Point McIntyre #4 exploratory well, North Slope, Alaska. Presented herein are the results of this study. Conventional cores cut with a bland mud were submitted. A service description with methodology is presented in section 1. The core analysis results, core statistical data, and surface core gamma log are presented in sections 2 and 3. Section 4 contains shipping transmittals. Also four sets of visible spectrum flash, and two sets of ultraviolet light photographs are provided in separate binders. We sincerely appreciate this opportunity to be of service and hope these data prove beneficial in your exploration efforts. Section TABLE OF CONTENTS CONVENTIONAL CORE ANALYSIS, SERVICE DESCRIPTION AND METHODOLOGY CONVENTIONAL CORE ANALYSIS AND SIDEWALL ANALYSIS, TABULAR RESULTS CONVENTIONAL CORE STATISTICAL DATA AND SURFACE CORE GAMMA LOG TRANSMITTALS SECTION 1 CONVENTIONAL CORE Field Procedures Conventional coring equipment in conjunction with a bland based drilling fluid was used to extract four inch diameter core samples from Point McIntyre #4 well during April of 1989. Four hundred and sixty-eight feet of core from Point McIntyre #4 arrived at Core Laboratories Anchorage facility. The core was shipped in three foot long fiberglass barrels sealed with rubber caps and clamps. Core Processing Surface Core Gamma Log A surface core gamma log was performed on the recovered core samples upon arrival at the Anchorage laboratory. The gamma response is graphically presented in Section 3. Sample Preparation Dean-Stark Plug Samples When the gamma log was completed the core was extruded from the fiberglass barrels onto tables. Horizontal one-inch diameter plug samples were drilled with water from each foot of core. Plugs were taken from the center of each section and parallel to the bedding strike. The plug samples were trimmed into right cylinders using water and prepared for fluid saturation measurement. Plug ends were saved and stored according to depth for each sample. Vertical Plug Samples Vertical one inch diameter plugs were drilled from every tenth foot of core. The plug samples were drilled and trimmed with water and prepared for analysis. The vertical plugs were analyzed for permeability only. Oil Gravity Samples An oil gravity sample was taken from every foot of core. Approximately one inch of whole core was selected and cut dry with a cut-off saw. The core section was then broken up into peanut sized pieces and placed into a retort bomb for retorting. Preserved Whole Core Sections A five inch whole core section was removed from the bottom of every fifth foot of core. The sections were wrapped with Saran wrap and aluminum foil, and then preserved in CoreSeal. At the completion of the conventional analysis, the whole core sections were depreserved. From each section, three 1.5 inch diameter and two 1.0 inch diameter horizontal plugs were drilled. Liquid Nitrogen was used as a drilling coolant. Ail of the plugs taken from the depreserved whole core sections were wrapped in Saran wrap and aluminum foil and dipped in CoreSeal for preservation. These plugs will be shipped out for special testing. Slabbing At the completion of the conventional plug sampling the whole core was slabbed in one-third and two-third sections using water as a blade coolant. Appropriate depths were marked on the slabbed faces of both slabbed sections. The preserved whole core sections remains were also slabbed after de-preserving and plugging was completed. The slabbed pieces were then placed back into the appropriate locations in the core. The one-third sections were put in protective plastic sleeving material and put in boxes. The two-thirds section was prepared for photography and later stored in slab boxes. State Chips One set of state chiPs were taken to represent every foot of core. The chips were marked and boxed according to depth. ~nalysis Techniques Dean-Stark Fluid Saturation Measurements Water was extracted from the plug samples by Dean-Stark technique using toluene. Samples were left in Dean-Stark for 24 hours. Recovered waters were measured and the samples were removed. The samples were then placed in a toluene centrifuge for hydrocarbon extraction a minimum of two days, or until no fluorescence was visible. Extracted samples were dried in a convection oven at 220 degrees F. for a minimum of 24 hours, and cooled in a desiccator to room temperature before porosity and permeability was measured. Saturations by Dean-Stark methods were calculated using Equations 1 and 2. Where: So = [((Wi - W2 - H20)/Do)/Vp] x 100 Sw = [H20/Vp] x 100 So = Oil Saturations, Percent Sw = Water Saturation, Percent W1 = Natural Weight W2 = Extracted and Dried Weight H20 = Extracted Water, Density Assumed 1.0 gm/cc Do = Density of Oil Vp = Pore Volume Grain Density Grain volume determinations were performed according to Boyle's Law utilizing the Small Volume Helium Porosimeter. Grain density was calculated using Equation 3. Dg = Mg/Vg (3) Where'. Dg = Grain Density Vg = Grain Volume Mg = Grain Mass Atmospheric Porosity The samples were measured for bulk volume by mercury displacement at ambient conditions. Porosity was calculated using Equation 4. P = [(Vb-Vg) / Vb)] x 100 (4) Where'. P = Porosity, Percent Vb = Bulk Volume Vg = Grain Volume Atmospheric Permeability to Air Samples were loaded into a Hassler type core holder at a confining pressure of 400 psig. Permeability calculations were performed as defined by Darcy's Equation for compressible fluids, Equation 6. Pa x v x 1000 Qa x Lx L K = x (6) (P1 - P2) (P1 +P2) Vb Where: K = Permeability v = Gas Viscosity P1 - P2 = Differential Pressure P1 + P2 = Mean Pressure Pa = Atmospheric Pressure Qa = Flow Rate L = Length Vb = Bulk Volume Oil Gravity Analysis The retort bombs containing the crushed oil gravity samples were loaded into ovens and retorted up to 1200 degrees F. The retorted oil was recovered in glass recovery tubes. The refractive index of the retorted oil was measured using a refractometer. The API gravity (60 deg. F.) was determined using correlation charts derived from previously analyzed Kuparuk River Unit crude samples, North Slope, Alaska. Sidewall Core Analysis Rotary sidewall core samples were submitted for Point McIntyre #4. A Dean-Stark core analysis was performed on the samples. Fluid saturations, porosity, grain density, and permeability were measured using the same procedures and equations as the conventional plug analysis. The samples were cleaned of any hydrocarbons in the Dean-Stark. Core Photographs The two-thirds slabbed section of each core was photographed. Approximately 15 feet of core appears in each photograph. Four sets of visible spectrum flash light and four sets of ultraviolet light photographs are provided in separate binders. Sample Disposition Both core slabs of Point McIntyre #4 along with plugs, plug ends, state chips are currently being stored at Core Laboratories, Anchorage facility awaiting further shipping instructions. The special core analysis preserved plug samples will be sent to ARCO Alaska, Inc. C 0 R E L A B 0 R A T O R I E S Point McIntyre #4 Preserved Whole Core Sections Core # 1 11695.5 - 95.9 11700.5 - 00.9 11705.5 - 05.9 Core # 2 11710 11715 11720 11725 11730 11734 11740 11745 11750 11755 11760 11765 .5 - 10.9 .4 - 16.0 .6 - 21.0 .4 - 25.9 .4 - 31.0 .4 - 34.95 .4 - 41.0 .4 - 46.0 .35 -50.8 .4 - 56.0 .4 - 61.0 .4 - 65.8 Core 12097 12103 12107 12112 12117 12121 #3 .4 - 97.8 .5 - 03.9 .4 - 07.8 .4 - 12.9 .3 - 17.8 .6 - 22.0 Core #4 12160.4 12165.5 12170.5 12175.4 12179.5 12184.2 12189.5 12193.4 12198.5 12203.5 12208.5 12213.5 - 60.9 - 66.0 - 71.0 - 75.9 - 80.0 - 84.7 - 90.0 - 93.9 - 99.0 - 04.0 - 09.0 - 14.0 Preserved Whole Core Sections Cont. 12218.5 - 19.0 12223.5 - 24.0 12228.5 - 29.0 12234.5 - 35.0 12239.5 - 40.0 Core #5 12244.5 - 45.0 12249.5 - 50.0 12254.5 - 55.0 12263.5 - 64.0 12269.55 - 70.0 12274.5 - 75.0 12279.5 - 80.0 12283.5 - 84.0 12288.5 - 87.0 12294.5 - 95.0 12298.5 - 99.0 12303.5 - 04.0 12308.5 - 09.0 12313.5 - 14.0 12318.5 - 19.0 12323.5 - 24.0 12327.5 - 29.0 12331.5 - 32.0 Core #6 12334.5 - 35.0 12339.5 - 40.0 12344.5 - 45.0 12348.55 - 49.0 12353.5 - 54.0 12359.5 - 60.0 12364.5 - 65.0 12369.5 - 70.0 12374.5 - 75.0 12379.5 - 80.0 12384.5 - 85.0 12389.4 - 90.0 12394.0 - 94.5 12399.6 - 00.0 12404.5 - 05.0 12409.5 - 10.0 12412.5 - 13.0 Preserved Whole Core Sections Cont. Core #7 12423.5 - 24.0 12428.5 - 29.0 12433.5 - 34.0 12438.5 - 39.0 12443.5 - 44.0 12448.5 - 49.0 12453.5 - 54.0 12458.5 - 59.0 12463.5 - 64.0 12468.5 - 69.0 12473.5 - 74.0 12482.5 - 83.0 12488.5 - 80.9 12494.0 - 94.5 12498 - No preserve 12503.5 - 04.0 12509.5 - 10.0 (rubble) DEAN-STARKANALYSIS RESULTS Company Well : ARCO ALASKA, INC. : POINT McINTYRE #4 ANALYTICAL PROC CORE EDU R LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY ES AND QUA L I T File No.: BP-3-1345 Date : 17-NAY- 1989 Y ASSURANCE HANDLING & CLEANING ANALYSIS Core Transportation Solvent Extraction Equipment Extraction Time Drying Equipment Drying Time Drying Temperature : AIR FREIGHT : TOLUENE : CENTRIFUGE : 24 HOURS : CONVECTION OVEN : 24 HOURS : 220 DEG. F. Grain volume measured by Boyle's Law in a matrix cup using He Bulk volume by Archimedes Principle Water saturations by Dean Stark Oil saturations by weight difference in Dean Stark Permeabilities measured on 1 in. diameter drilled plugs RENRRKS Mercury was used as the immersion fluid for Archimedes bulk volumes. CORE Company : ARCO ALASKA, INC. Well : POINT llcINTYRE #4 Location : 16-12N-14E, Fr SE cDr 1468'N 666'W{surf) Co,State : NORTH SLOPE, ALASKA CORE ANA LABORATORTES Fi el d :' EXPLORATORY Formation : EXPLORATORY Coring Fluid : BLAND HUD Elevation : LYS IS RESULTS File No.: BP-3-1345 Date : 17-MAY- lg8g API No. : Anal ysts: PLB, GAC SAMPLE NUMBER 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 201 2O2 203 204 205 206 DEPTH IPERMEABILITY t(HORIZONTAL) , Ii(~r ft PERMEABILITY (VERTICAL) KAIR POROSITY (HELIUM) SATURATION J I GRAIN OIL (POREoiL VOLUME)wATER DENSITY J GRAVITY J % % gm/cc I deg API I Core ~1 (11691.0 - 11706.2 feet) DESCRIPTION 11691.3 0.06 0.00 10.9 11692.3 0.04 9.3 11693.7 0.04 10.1 11694.4 0.03 10.0 11695.2 0.15 15.7 11696.4 0.18 11.8 11697.6 0.09 13.6 11698.2 0.06 12.6 11699.6 0.06 15.5 11700.3 0.06 14.5 11701.2 0.05 0.00 10.7 11702.4 0.67 13.5 11703.6 0.28 16.0 11704.3 0.09 11.1 11705.3 12.0 11706.1 11.6 17.0 81.9 2.61 29.8 69.0 2.58 36.1 63.7 '2.59 39.4 58.8 2.58 56.3 25.2 2.59 32.7 54.5 2.58 54.5 29.2 2.55 38.0 53.0 2.57 56.2 22.3 2.59 55.6 23.9 2.57 24.4 46.4 2.71 46.7 32.8 2.68 54.1 25.5 2.60 45.9 31.1 2.60 12.3 86.5 2.63 10.3 89.1 2.60 MDST-mgy, slty,mic,wcons,30%yelgy,vfgr,slty,bdd ss,tr calc,tr calc. SS-yelgy,vfgr,vslty,WSrtd,sbang-sbrd,wcons,tr calc,lO% ndst lams. SS-ltolvgy,vfgr,vslty,wsrtd,sbang-sbrd,wcons,sl calc,5%ndy lams. 20. SS-ltolvgy,vfgr,vslty,wsrtd,sbang-sbrd,wcons,sl calc,lO% mdst lams. 22. SS-ltolvgy,vfgr,slty,wsrtd,sbrd,wcons,tr calc. 24. SS-ltolvgy,vfgr,slty,wsrtd, sbrd,wcons,sl calc,tr arg lams. 22. SS-ltolvgy,vfgr,slty,wsrtd,sbrd,wcons,sl calc, tr carb mat. 22. SS-ltolvgy,vfgr,vslty,wsrtd,sbrd,wcons,sl calc,tr carb frags. 22. SS-ltolvgy,vfgr,slty,wsrtd,sbrd,wcons,sl calc. 22. SS-ltolvgy,vfgr,slty, wsrtd,sbrd,wcons,sl calc,carb lams. 28. SS-ltolvgy,vf-fgr,slty,wsrtd,sbang-sbrd,wcons,calc cmtd. 22. SS-ltolvgy,vf-fgr,slty,wsrtd,sbrd,sl calc,tr carb frags ** 26. SS-ltolvgy,vf-fgr,slty,wsrtd,sbrd,sl calc,2-3% carb lams. 22. SS-ltolvgy,vf-fgr,slty,wsrtd,sbrd,sl calc,3% cly frags,tr carb frags. 20. SLTST-mgy,vsdy, wcons,ndy lams,tr carb frags (broken). SLTST-mgy,arg,sdy in places,wcons,3-5%vfgr sdy lams ** Core t2 (11706.2 - 11766.4 feet) 11707.4 0.10 11708.4 5.31 11709.4 0.24 11710.1 11711.3 0.34 11712.3 15.1 0.00 10.4 9.8 88.1 2.60 12.2 4.7 93.1 2.65 13.7 7.6 91.0 2.68 14.1 3.8 95.8 2.70 11.7 3.2 93.0 2.69 10.6 3.5 92.9 2.58 SLTST-mgy,sdy,mic,wcons,5%mdy lams and vfgr scly lams. SLTST-mgy,arg,sdy,wcons,3%vfgr sdy lams,tr carb frags 21. SLTST-mgy,arg,sdy,wcons,tr carb frag$. SLTST-mgy,arg,schy, wcons,lam (broken). SLTST-mgy,arg,wcons,sl calc,20% ltolvgyvfgr, intlamss. 22. SLTST-mgy,arg,sdy,wcons,tr calc,5% dkgy mdst lam ~ 1- 1 Company : ARCO ALASKA, INC. Well : POINT HcINTYRE #4 CORE CORE LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER i't n~l md % % % gm/cc deg API 207 11713.4 14.8 31.3 58.6 2.64 22. SS-ltolvgy,vfgr,slty,,srtd,sbrd,wcons,tr calc,30% sdy sltst (broken). 208 11714.3 3.11 13.1 6.8 91.3 2.64 22. SLTST-n~jy,arg,sdy,wcons,7% ltolvg¥,vfgr,sdy lams,tr carb frags ~* 209 11715.2 0.17 12.6 18.0 78.7 2.60 24. SLTST-mgy,arg,sdy,wcons,lO% ltolvgy, vfgr,sdy lams,tr carb frags. 210 11716.7 10.1 13.4 20.5 78.3 2.62 22. SLTST-mgy,arg,sdy,wcons,tr calc,15% ltolvgy,vfgr,sdy lams ** 211 11717.3 0.41 11.8 20.0 79.3 2.63 18. SLTST-mgy,arg,sdy,wcons,sl calc,lO% ltolvgy,vfgr,sdy lams *~ 212 11718.8 0.21 13.5 29.5 GG.3 2.59 24. SS-ltgy,vfgr,vslty,wsrtd,sbrd,wcons,tr calc,40% nrjy, lam sltst. 213 11719.5 3.22 12.9 34.8 57.0 2.55 2G. SS-ltgy,vfgr,vslty,wsrtd,sbrd,wcons,tr calc,20% mgy, lam sltst ** 214 11720.5 1.53 13.2 31.7 70.8 2.59 26. SLTST-mgy,vsdy, arg,wcons,20% ltolvgy,vf-fgr,sdy lams ** 215 11721.5 0.51 0.01 13.1 10.6 88.4 2.66 26. MDST-n~lkgy,vslty,wcons,5% vthn sdy lams,abnt carb frags ** 216 11722.6 0.70 12.8 27.9 65.8 2.60 27. SLTST-mgy, arg,sdy,wcons,30% ltolvgy,vfg,sdy lams ** 217 11723.3 0.10 13.0 38.6 59.2 2.61 2G. SS-ltolvgy,vfgr,slty,wsrtd,sbrd,wcons,tr calc,20% ngy, lam nmist. 218 11724.2 0.10 13.1 29.3 68.1 2.61 27. SS-ltolvgy,vfgr,slty,wsrtd,sbang-sbrd,wcons,tr calc,40% mgy, lam mUst. 219 11725.2 0.40 14.2 11.3 88.1 2.66 26. SLTST-mgy,arg,sdy,wcons,3%' ltolvgy,vfgr,sdy lams ** 220 11726.5 13.1 20.1 78.9 2.62 SLTST-mgy,varg,wcons,tr sdy lams (broken). 221 11727.2 0.29 14.1 17.8 81.3 2.62 26. SLTST-mgy,varg,wcons,lO% ltolvgy,vfgr,sdy lams. 222 11728.2 0.10 13.5 25.5 74.1 2.62 26. MDST-mgy,slty,wcons,40% ltolvgy,vfgr,sdy lams. 223 11729.5 0.25 15.6 25.2 70.6 2.64 29. SS-ltolvgy,vfgr,slty,wsrtd,sbrd,wcons,sl calc,15% mgy,thnly lam mUst. 224 11730.2 0.25 14.8 22.1 76.5 2.64 26. SLTST-olvgy,arg,sdy,wcons,20% nrjy,thnly lam must. 225 11731.5 0.16 0.01 12.9 14.2 83.9 2.59 22. SLTST-mgy,arg,sdy, wcons,20% mgy,thnly lam n~lst. 226 11732.3 1.75 9.2 57.7 32.3 2.41 22. MDST-ltolvgy,chty, dnse,15% ltgy,vfgr,sdy lams ~* 227 11733.2 0.32' 13.1 27.7 67.2 2.59 25. MDST-olvgy,slty,wcons,15% ltgy,vfgr,thn sdy lams. 228 11734.2 0.46 13.6 19.7 78.9 2.62 25. MDST-olvgy,slty,wcons,lO% ltgy,vfgr,thn,sdy lams. 229 11735.3 14.2 26.0 65.4 2.59 25. MDST-mgy,slty,wcons,20% ltolvgy,vfgr,sdy lams (irregular spl). 230 11736.3 0.40 12.9 12.0 87.1 2.63 25. MDST-olvgy,slty,wcons,15% ltolvgy,vfgr,scly lams ** 231 11737.3 0.10 14.4 29.7 62.0 2.61 25. MDST-olvgy,slty,wcons,lO% ltolvgy,vfgr,sdy lams. 232 11738.2 0.75 11.6 26.1 71.6 2.59 26. MDST-olvgy,slty,wcons,30% ltgy,vfgr,sdy lams ** 233 11739.2 1.01 14.0 20.8 74.2 2.60 26. SLTST-olvgy, arg,sdy,wcons,tr sdy lams ** 234 11740.2 0.34 13.9 19.9 78.0 2.63 27. MDST-mdkgy,slty,wcons,20% olvgy, lam sltst,5% vfgr,sdy lams. 235 11741.4 1.20 0.03 15.1 25.3 70.1 2.63 27. MDST-mdkgy,slty,wcons,15% vltgy,vfgr,sdy lams ** 1-2 Company : ARco ALASKA,'INC. Well : POINT McINTYRE #4 CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation .- EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-HAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft nz{ md % % % gnl/cc deg API ....... 236 11742.2 0.44 14.5 14.4 84.5 2.64 27. MDST-olvgy,slty,wcons,lO% ltolvgy,slty lams. 237 11743.2 1.91 14.0 30.4 62.9 2.58 26. SLTST-olvgy,arg,sdy,vfgr,sdy,pch *~ 238 11744.3 0.73 13.4 26.3 66.6 2.60 26. SLTST-olvgy, arg,sdy,lO% ltgy,vfgr,sdy lams *~ 239 11745.2 0.41 12.9 23.5 72.2 2.60 26. SLTST-olvgy, arg,sdy,20% mgy, lam mdst,5% vfgr,sdy lams. 240 11746.3 0.24 11.8 4.8 93.6 2.64 MDST-olvgy,slty,wcons,3% ltgy,vfgr,thn sdy lams. 241 11747.3 0.08 12.1 3.6 95.2 2.63 MDST-olvgy,slty,wcons,lO% ltolvgy,thn slty lams. 242 11748.4 0.02 7.7 37.2 57.4 2.49 27. MDST-ltolvgy,slty,wcons,cinse,lO% ltgy,vfgr,sl calc,sdy lams. 243 11749.3 0.13 11.2 2.6 95.9 2.58 MDST-olvgy,s lty,nnr sd,wcons. 244 11750.0 O. 15 12.2 5.0 92.1 2.65 MDST-olvgy, s lty, sdy,wcons ,tr-1% carb frags. 245 11751.8 0.15 0.00 12.9 15.8 83.4 2.62 MDST-olvgy,slty, sdy,wcons,5% ltgy,vfgr,sdy lam, tr-1% carb frags. 246 11752.3 0.12 14.5 17.1 79.9 2.65 26. MDST-olvgy,slty, sdy,wcons,lO% ltolvgy,slty lams. 247 11753.3 0.15 12.4 38.6 51.3 2.60 25. SS-ltolvgy,vfgr,slty,wsrtd,sbrd,wcons,tr calc,1% carb frags. 248 11754.2 0.18 13.0 39.9 45.9 2.61 28. SLTST-ltolvgy,vsdy,wcons,tr calc,tr-1% carb frags. 249 11755.3 0.10 12.7 19.4 79.7 2.61 26. SLTST-olvgy,vsdy,wcons,tr calc,lO% mgy,thn,mdy lams. 250 11756.2 0.09 11.9 32.1 61.6 2.58 26. SLTST-ltolvgy,vsdy,wcons,tr calc,grds to vslty ss,5% mdy lams,l% carb frags. 251 11757.3 11.2 7.8 91.0 2.61 SLTST-olvgy,sdy, arg,cons,tr calc (broken). 252 11758.2 0.44 13.8 1.5 97.4 2.61 SLTST-olvgy, varg,nnr sd,wcons,tr calc,nnr sdy lams. 253 11759.3 0.31 12.8 3.4 96.4 2.63 SLTST-olvgy,varg,nnr sd,wcons,tr calc,nmr sdy lams. 254 11760.2 0.10 12.3 1.3 97.7 2.68 SLTST-m~(gy, varg,nnr sd,wcons,tr calc,nnr sdy lams. 255 11761.2 0.08 0.00 10.5 9.4 89.3 2.61 SLTST-mgy,vsdy, arg,wcens,tr calc,tr carb frags. 256 11762.4 0.56 11.4 9.8 89.6 2.61 SLTST-mgy,sdy,arg,wcons,tr calc,nnr $cly lams ** 257 11763.3 5.43 10.2 13.5 86.0 2.64 SLTST-mgy,sdy,arg,wcons,tr calc,nnr sdy lam,tr carb frags *'* 258 11764.4 26.8 12.2 7.5 91.9 2.60 SLTST-mgy, sdy,arg,wcons,tr calc,tr sdy lams (broken) 259 11765.2 1.69 12.0 5.9 93.7 2.60 MDST-mltgy,slty,wcons,tr calc,tr slty lams ** 260 11766.1 0.27 12.1 3.1 96.3 2.60 HDST-mltgy, s lty, wcons ,tr calc. Core f3 (12093.0 - 12126.2 feet) 301 12093.4 382. 632.00 21.7 22.1 53.6 2.97 29. SS-grngy,f-mgr,pred fgr,wsrtd,sbrd,mod cons,poss sid,3% glauc. 1-3 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft md md % % % gm/cc deg API 302 12094.5 471. 24.5 32.9 47.7 2.94 31. SS-ltolvgy,vf-mgr, pred fgr,wsrtd,sbrd-rd,sl fri,poss sid,3-5% glauc. 303 12095.3 392. 24.8 29.8 50.4 2.83 30. SS-ltolvgy,vf-ffgr,pred fgr,wsrtd,sbrd-rd,fri,poss mr sid,3-5% glau¢. 304 1209G.G 792. 27.0 30.4 47.1 2.96 31. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,fri,poss sial,3-5% glauc. 305 12097.3 1.36 13.2 17.4 7G.4 3.14 32. SS-grngy, vf-fgr,nnr mgr sd,wsrtd,sbrd-rd,wcons,poss sid,30% thn bald,rinse mdst. 30G 12098.6 24.5 20.6 22.5 60.9 3.12 32. SS-grngy,vf-mgr,pred fgr,mod wsrtd,sbrd-rd,sl fri,pos$ sid,5% glauc. 307 12099.4 56.8 23.7 24.6 70.9 3.25 29. SS-grngy,vf-cgr,pred f-mgr,slty,psrtd,sbrd,fri,poss sid,3% glauc. 308 12100.2 111. 24.7 23.8 64.0 3.09 29. SS-grngy,vf-cgr,pred fgr,mod wsrtd,sbrd,fri,poss sial,5-7% glauc. 309 12101.7 12.0 14.3 23.5 64.2 3.25 32. SS-dkgrngy,vf-mgr, pred fgr,wsrtd, sbrd,wcons,poss sid,5% glauc (irregular spl). 310 12102.2 15.9 14.2 21.5 60.8 3.22 31. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcons,dnse,poss sid,5-7% §lauc. 311 12103.2 2.58 0.36 14.7 23.1 61.9 3.19 29. SS-olvgy, vf-mgr,pred fgr,wsrtd,sbrd,wcons,dnse,poss ~id,3-5% glauc. 312 12104.2 96.2 23.1 30.0 52.2 2.99 31. SS-gyolv,vf-fgr,pred fgr,wsrtd,sbrd-rd,fri,poss sid,5% glauc. 313 12105.4 GO8. 25.G 34.6 44.9 2.89 30. SS-ltolvgy,vf-fgr, pred fgr,wsrtd,sbrd-rd,fri,poss sid,5% glauc. 314 12106.4 649. 26.9 35.2 51.6 3.10 30. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,fri,poss sid, 5% glauc. 315 12107.2 106. 15.4 28.2 52.2 3.28 28. SS-gyolv,vi'-fgr,pred fgr,wsrtd,sbrd,wcmtd-sl fri,po-~s sial,3-5% glauc. 316 12108.6 109. 18.8 26.9 49.5 3.00 29. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcmtd-sl fri,poss sid,5% glauc. 317 12109.3 5.26 15.5 20.6 63.0 3.14 27. SS-olvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wrJntd, po~ sid,1% glauc. 318 12110.0 25.4 15.6 27.3 56.5 3.13 29. SS-olvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcmtd,poss sial, 2-3% §lauc *~ 319 12111.1 497. 27.7 39.0 45.G 2.88 28. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,fri,poss mr sial,5-7% §lauc. 320 12112.1 96.7 19.8 25.2 61.3 3.15 30. SS-grngy,vf-mgr,pred fgr,wsrtd,sbrd,fri,pos$ ~id,7% glauc,20% dnse mdst lams. 321 12113.4 425. 110.00 28.4 42.4 44.3 2.90 28. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,fri,poss sid, lO% glauc. 322 12114.4 220. 23.0 34.5 '51.4 2.86 30. SS-gyolvgrn,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri-fri,poss ~id,7% glauc. 323 12115.1 219. 24.5 30.1 57.3 2.84 30. SS-olvgy,vf-fgr,pred fgr,wsrtd,$brd-rd,sl fri-fri,poss sial,5-7% glauc. 324 12116.2 4.34 16.5 18.5 66.3 3.29 2G. SS-olvgy,vf-mgr,pred fgr,wsrtd,sbrd,wcmtd,poss sid, 2% glauc. 325 12117.1 36.4 22.3 32.4 48.9 3.10 27. SS-olvgy,vf-fgr,pred fgr,slty,wsrtd,sbrd,wcm~d-sl fri,poss ~id,3% glauc. 32G 12118.2 3.56 17.8 14.8 72.7 3.20 22. SS-olvgy,vt'-fgr,pred fgr,$1ty, wsrtd, sbrd-rd,wcm~d,poss sid,1% glauc. 321 12119.2 5.63 17.6 16.9 65.0 3.19 23. SS-olvgy, vf-fgr,pred fgr,$1ty,wsrtd,sbrd-rd,wcm~d,poss $id,2% glauc. 328 12120.3 0.23 15.5 18.1 64.8 3.20 25. SS-olvgy,vf-fgr,pred fgr,slty,w~rtd,sbrd-rd,wcm~d,poss ~id,2% glauc. 329 12121.3 39.2 21.8 25.5 54.9 3.14 21. SS-olvgy, vf-fgr,pred fgr,slty,w~rtd,sbrd-rd,wcm~d-sl fri,poss sial, 2-3% glauc. 330 12122.6 0.31 10.3 8.3 73.7 3.33 29. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcm~d,poss mid,2-3% glauc. 1-4 Company : ARCO ALASKA, INC. Well : POINT NcINTYRE CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH :PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft md md % % % gm/cc deg API 331 12123.1 33.9 15.8 20.2 51.3 3.28 29. SS-ltolvgy,vf-fgr,pred fgr,wsrtd, sbrd-rd,wc~d-sl fri,poss sid, 2-3% glauc. 332 12124.4 25.5 9.0 69.6 3.18 27. SS-olvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd, sl fri,poss sid,3% glauc(irregular spl) 333 12125.3 20.8 13.2 75.7 3.23 27. SS-olvgy, vf-fgr,pred fgr,wsrtd,sbrd-rd, sl fri,poss sid,3% glauc(irregular spl) 334 12126.1 26.1 17.3 64).4 3.25 29. SS-olvgy, vf-fgr,pred fgr,wsrtd,sbrd-rd, sl fri,poss sid,3% glauc(irregular spl) Core f4 (12153.0 - 12243.5 feet) 401 12153.2 728.00 27.9 20.8 56.6 2.75 28. SS-ltolvgy,pred fgr,wsrtd,sbrd,fri,2-3% glauc (broken). 402 12154.7 29.0 28.5 50.1 2.77 28. SS-ltolvgy,pred fgr,wsrtd,sbrd,fri,2-3% glauc ** 403 12155.1 1162. 28.9 32.1 44.0 2.80 27. SS-ltolvgy,pred fgr,wsrtd,sbrd,fri,poss nnr sid,2-3% glauc. 404 12156.5 649. 27.7 34.6 43.7 2.78 29. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,fri,poss nnr sid, 5% glauc. 405 12157.2 1950. 29.3 33.5 45.7 2.79 27. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,vfri,2% glauc. 406 12158.2 1394. 28.4 36.3 43.4 2.74 29. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,vfri,2% glauc. 407 12159.0 1152. 28.0 30.1 50.0 2.85 26. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,vfri,2-3% glauc. 408 12160.2 533. 28.5 13.8 61.0 3.10 28. SS-olvgy, pred fgr,wsrtd, sbrd-rd,sl fri,poss sid,3% glauc ** 409 12161.2 125. 22.1 11.4 57.6 2.96 28. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,wcmtd-sl fri,poss sid,3-5% glauc. 410 12162.1 18.5 14.7 12.7 59.1 3.27 27. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,wcmtd,poss sid,3% glauc. 411 12163.9 59G. 226.00 28.9 16.9 50.5 2.93 26. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,fri,poss sial,3-5% glauc. 412 12164.6 28G. 22.7 13.0 53.6 3.10 27. SS-ltolvgy,vf-fgr,wsrtd,sbrd-rd,wcntd-sl fri,poss sial,3-5% glauc ** 413 12165.2 234. 26.1 13.7 53.8 2.98 27. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,sl fri,poss sid,3% glauc. 414 12166.2 163. 23.6 10.7 57.0 '3.12 28. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,wcmtd-sl fri,poss sid,3% glauc. 415 12167.1 147. 22.2 18.6 56.3 2.88 28. SS-ltolvgy,pred fgr,wsrtd,sbrd,sl fri,poss sid,3% glauc. 416 12168.2 202. 24.7 15.8 57.8 2.87 29. SS-ltolvgy,pred fgr,wsrtd,sbrd,sl fri,poss sid,2-3% glauc. 417 121G9.2 413. 25.7 15.9 51.1 2.97 30. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,sl fri,poss sid, 2% glauc. 418 12170.2 411. 24.3 16.9 50.7 2.94 29. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,sl fri,poss sid, 2% glauc. 419 12171.2 735. 26.8 22.1 47.1 2.79 30. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri,poss nnr sid,2% glauc. 420 12172.3 307. 24.4 20.8 54.1 3.01 29. SS-ltolvgy,pred fgr,wsrtd,sbrd,~cmtd-sl fri,poss sid,l-2% glauc. 421 12173.0 650. 270.00 23.8 21.8 51.9 3.02 21. SS-ltolvgy,pred fgr,wsrtd,sbrd,wcnfcd-sl fri,poss sid,1-2% glauc. 422 12174.2 94.4 20.4 26.1 45.8 3.13 28. SS-ltolvgy,pred fgr,wsrtd,sbrd,wcnfcd,poss sid,tr glauc,15% clnse mdst lams. 1-5 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE CORE LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER i(HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft md md % % % gm/cc deg API , 423 12175.0 239. 22.9 19.8 48.0 3.02 28. SS-ltolvgy,pred fgr,wsrtd,sbrd,sl fri,poss sid,tr-l% glauc. 424 12176.2 2.58 16.8 11.3 57.9 2.71 28. SS-vltgy, pred fgr,wsrtd, sbrd,vwcn~cd,2% glauc. 425 12177.2 578. 25.5 28.8 47.G 2.71 28. SS-ltolvgy,pred fgr,wsrtd,sbrd,sl fri,1% glauc. 426 12178.1 1336. 27.0 28.6 52.7 2.71 27. SS-ltolvgy,pred fgr,wsrtd,sbrd,fri,tr glauc. 427 12179.1 720. 25.0 41.4 47.2 2.69 27. SS-ltolvgy,pred fgr,vwsrtd, sbrd,vfri,3% thn arg lams. 428 12180.7 0.01 9.6 39.3 45.5 3.30 29. SS-ltolvgy,pred fgr,wsrtd,sbrd,vwcnCd,poss sid. 429 12181.3 86.7 18.5 19.7 45.5 2.97 29. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcmtd-sl fri,poss sid,1% glauc. 430 12182.7 231. 23.8 37.3 47.0 2.84 34. SS-ltolvgy,pred fgr,wsrtd,sbrd,fri,poss mr sid. 431 12183.5 0.28 208.00 9.3 28.6 47.3 3.13 25. SS-ltolvgy,pred fgr,wsrtd,sbrd,vwcmtd,poss sid. 432 12184.2 1375. 29.1 41.3 38.0 2.72 26. SS-yelgy, pred fgr, srtd,sbrd,vfri. 433 12185.7 72.8 19.2 23.6 49.7 2.91 27. SS-ltolvgy,pred fgr,wsrtd,sbrd,wcmtd-sl fri,poss sid,tr glauc. 434 12186.3 1803. 29.5 34.1 37.4 2.68 26. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,~ri. 435 12187.5 73.9 20.4 25.4 52.6 2.84 27. SS-ltolvgy,pred fgr,slty,wsrtd,sbrd-rd,sl fri,poss mr sid,2% glauc. 436 12188.3 817. 26.3 35.4 45.3 2.74 27. SS-yelgy,pred fgr,wsrtd, sbrd-rd,fri,tr mdy lams. 437 12189.2 127. 23.3 30.3 46.5 2.85 27. SS-ltolvgy,prd fgr,mr slt,wsrtd, sbrd-rd,sl fri,poss mr sid. 438 12190.2 150. 24.4 29.0 46.0 2.83 28. SS-ltolvgy,pred fgr,slty,wsrtd,sbrd-rd,sl fri,poss mr sid. 439 12191.2 8.59 10.4 17.4 66.9 3.20 27. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,vwcm~d,dnse,poss sial ** 440 12192.2 20.3 14.1 16.9 31.4 3.06 26. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,vwcm~d,grds to nad cmtd,poss sid. 441 12193.2 693. 0.12 26.7 23.1 54.3 2.72 27. SS-ltolvgy,pred fgr,wsrtd,sbrd,sl fri,tr glauc. 442 12194.6 591. 25.9 32.4 46.8 2.75 27. SS-ltolvgy,pred fgr,wsrtd,sbrd-rd,sl fri. 443 12195.2 600. 27.2 32.3 48.5 2.73 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd, sbrd,sl fri. 444 12196.3 539. 18.2 24.7 51.1 3.02 27. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcm~d,poss sid,1% glauc ** 445 12197.3 0.29 9.4 17.2 67.7 3.14 SS-ltolvgy,vf-fgr,mr mgr sd,wsrtd,sbrd,wcmtd,poss sid,2% glauc. 446 12198.2 114. 22.4 26.0 54.3 2.71 26. SS-ltolvgy,vfgr,pred fgr,wsrtd,sbrd,sl fri,tr mdy lams. 447 12199.3 45.2 22.1 25.9 56.5 2.84 26. SS-ltolvgy,vf-fgr,pred vfgr,nnr cgr sd,wsrtd,sbrd,wcm~d-sl fri,poss mr sid. 448 12200.1 0.53 12.9 18.0 75.6 2.73 26. SS-ltolvgy,pred fgr,wsrtd,sbrd,wcons,20% arg lams. 449 12201.1 22.4 19.8 23.9 57.3 2.83 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,sl fri,poss nar sid. 450 12202.1 56.6 22.9 20.7 64.5 2.79 26. SS-ltolvgy,vf-fgr, pred fgr,slty,wsrtd,sbrd,sl fri. 451 12203.3 3.01 1.44 15.6 18.4 65.6 2.73 25. SS-ltolvgy,vf-fgr,pred fgr,mr slt,wsrtd,sbrd,sl fri,15% arg lams. 1-6 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE CORE LABORATORIES Fi el d : EXPLOPJkTORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-NAY- 1989 SATURATION SAMPLE DEPTH PERMEABI LITY I PERMEABILIl~ POROSITY ..... GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft n~l n~t % % % gnl/CC deg API 452 12204.1 30.5 21.1 22.2 50.1 2.94 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcn~cd,poss sid. 453 12205.2 96.0 21.8 22.5 52.7 2.75 27. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri,I% glauc,tr arg lams. 454 12206.7 99.1 24.2 20.1 56.0 2.86 25. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri,poss n~r sid,1% glauc. 455 12207.2 74.8 22.4 21.3 52.3 2.90 2G. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcmtd,poss sid,2% glauc. 456 12208.2 197. 24.9 21.2 54.7 2.76 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,sl fri-fri,2% glauc. 457 12209.3 651. 27.4 20.8 53.8 2.71 26. SS-ltolvgy,vf-fgr, pred fgr,wsrtd, sbrd,fri,5-7% glauc ** 458 12210.2 242. 24.6 28.5 48.5 2.75 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd, sbrd,sl fri,3-5% glauc. 459 12211.3 12.8 17.8 18.8 55.0 2.99 26. SS-ltolvgy,vf-fgr, pred fgr,wsrtd,sbrd-rd,wcn/cd-sl fri,poss sid,2% glauc. 460 12212.1 1.06 7.5 8.3 78.5 3.32 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd, sbrd,vwcmtd,dnse,poss sid ** 461 12213.1 31.2 G.63 22.0 18.0 51.6 3.04 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcm~d-sl fri,poss sial, 3-5% glauc. 4G2 12214.1 65.4 22.9 21.0 56.6 2.76 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri,3% glauc,tr arg lams. 4G3 12215.2 122. 22.5 15.9 59.9 2.80 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri,5% glauc,tr arg lams. 464 12216.3 136. 21.8 19.2 50.5 3.06 26. SS-ltolvgy,vf-fgr, pred fgr,wsrtd, sbrd-rd,wcmtd-sl fri,poss sid, 5% glauc. 465 12217.2 143. 25.3 20.7 51.3 2.97 2G. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri,poss sial,3-5% 91auc. 4GG 12218.3 48.7 24.6 19.7 55.4 2.96 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcn~d,poss sid,3% glauc. 487 12219.2 108. 25.9 17.6 60.1 2.75 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,sl fri,2-3% glauc ** 468 12220.4 564. 28.1 21.6 61.2 2.74 2G. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,fri,5% glauc ** 469 12221.5 17.8 20.1 12.7 49.3 3.12 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd, sbrd,wcm~d,clnse,poss sid,3% glauc. 470 12222.2 62.5 21.8 18.6 67.7 2.83 29. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri, poss n~r sid,3% glauc. 471 12223.3 3.20 4.32 12.5 16.9 60.2 3.29 25. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd-rd,sl fri,3-5% glauc. 472 12224.4 51/. 26.9 21.7 54.8 2.80 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,sl fri,3-5% 91auc. 473 12225.4 28.5 17.9 17.8 58.6 2.83 25. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcons-sl fri,poss nnr sid, 5-10%arglam 474 12226.G 185. 22.7 16.4 55.6 2.82 25. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcons-sl fri,poss nar sial,2-3% glauc. 475 12227.3 33.9 22.0 10.0 66.3 3.02 22. SS-ltolvgy,vf-mgr,tr cgr sd,pred fgr,wsrtd,sbrd,wcmtd,poss sid, 2% glauc. 476 12228.2 0.05 13.2 13.4 70.6 3.34 24. SS-olvgy,vf-cgr,pred f-mgr,psrtd,sbrd,vwcmtd,dnse,poss sid,vug. 477 12229.5 0.39 15.7 6.2 68.6 3.15 25. SS-ltolvgy,vf-cgr,pred f-mgr,psrtd,sbrd,vwcm~d,dnse,poss sial,rug. 478 12230.5 0.69 16.7 8.7 70.9 3.13 26. SS-olvgy, vf-cgr,pred f-mgr,psrtd,sbrd,vwcm~d,dnse,poss sid,rmr vugs. 479 12231.3 190. 31.3 13.1 65.2 3.23 27. SS-grngy,vf-cgr,pred f-mgr, psrtd,sbrd,vfri,poss sid,vug,3% glauc,xln frac. 480 12232.4 26. Oil Gravity Sample Only 1-7 Company : ARCO ALASKA, INC. Well : POINT HcINTYRE //4 CORE CORE LABORATORIES Fi el d : EXPLORATORY ~ Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ..... ft n~ md % % % gm/cc deg API , , 481 12233.8 2.09 32.3 14.7 61.1 3.05 25. SS-gygrn,vf-mgr,pred fgr,mod wsrtd,sbrd,vfri,poss sid,mir vugs,5% glauc. 482 12234.2 31.8 24.4 56.9 2.94 SS-gygrn,vf-n~jr,pred fgr,mod wsrtd,sbrd,vfri,poss sial, 5-7% glauc. 483 12235.2 19.2 18.7 17.3 55.5 3.32 24. SS-gygrn,vf-mgr,pred fgr,wsrtd,sbrd,wcmtd,dnse,poss sid,3% glauc,mnr vugs. 484 12236.2 0.97 17.3 6.3 68.5 3.13 24. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcmtd,dnse,poss sid,3% glauc,nnr vugs. 485 12237.2 7.65 20.7 19.2 58.6 2.90 26. SS-ltolvgy,vf,fgr,pred fgr,wsrtd,sbrd,wcntd-sl fri,poss sid, 2-3% glauc. 486 12238.2 3.02 21.0 18.1 56.0 3.01 26. SS-ltolvgy,vf-mgr,pred fgr,mod wsrtd,sbrd,wcmtd,patchy, poss sid,2% glauc. 487 12239.1 0.32 15.9 16.3 61.8 2.93 24. SS-ltolvgy,vf-mgr,pred vfgr,mod wsrtd,sbrd,wcmtd,poss sid,2% glauc,tr arg lams 488 12240.5 24. Oil Gravity Sample Only 489 12241.7 32.5 22.3 18.2 53.4 3.00 26. SS-ltolvgy,vf-mgr,pred fgr,wsrtd,sbrd,sl fri,poss sid, 2-3% glauc,tr vugs. 490 12242.6 11.0 20.8 15.9 57.9 2.92 25. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcmtd-sl fri,poss sid, 2% glauc. 491 12243.1 52.5 327.00 20.7 17.1 54.1 3.05 28. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcmtd-sl fri,poss sid,3% glauc. Core i~5 (12243.5 - 12333.6 feet) 501 12244.3 25.3 21.9 13.5 68.5 2.97 29. SS-ltolvgy,vf-fgr, pred fgr,wsrtd,sbrd-rd,wcm~d-sl fri,poss sid, 3% glauc. 502 12245.2 698. 27.0 18.9 65.2 3.17 29. SS-grngy, vf-mgr,pred fgr,mod wsrtd,sbrd,fri,poss sid,3% glauc ** 503 12246.4 12.6 23.8 10.4 77.3 2.92 26. SS-grngy,vf-cgr,pred fgr,psrtd,sbrd,fri,poss sial,5-7% glauc. 504 12247.2 17.6 22.3 16.1 72.3 3.09 30. SS-grngy,vf-mgr,pred fgr,nmd wsrtd,sbrd-rd,wcnf~d-fri,poss sid,5-7% glauc. 505 12248.2 73.8 25.3 23.7 64.0 2.95 29. SS-grngy,vf-mgr,pred fgr,wsrtd,sbrd,wcmtd-fri,poss sid,5% §lauc,xln frac. 508 12249.2 377. 23.8 31.4 60.0 2.97 29. SS-grngy,vf-mgr,pred fgr,wsrtd,sbrd,wcm~d-fri,poss sid,3% §lauc. 507 12250.2 142. 24.1 20.3 58.0 2.81 29. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,$brd,$1 fri-fri,poss mr sid,3% glauc. 508 12251.3 41.5 19.6 15.5 61.2 3.04 28. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,wcm~d-sl fri, sial,3-5% glauc,xln fra 509 12252.2 0.95 12.7 13.9 69.9 3.14 29. SS-grngy,vf-ngr,pred fgr,mod wsrtd,sbrd,wcmtd,poss sid,5% glauc. 510 12253.3 <.01 0.72 5.4 39.4 57.9 3.19 28. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,vwcmtd,dnse,poss sial,3-5% glauc. 511 12254.2 463. 24.1 19.3 57.5 2.88 28. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,sl fri,poss sid, 3% glauc ** 512 12255.6 328. 26.4 22.2 55.0 2.83 28. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,fri,poss n~r sid,5% glauc,xln fracs. 513 12256.2 2.24 16.7 17.6 59.2 2.92 28. SS-grngy,vf-n~jr,pred fgr,wsrtd,sbrd,wca~d,poss sid, 3% glauc,abnt xln fracs. 514 12257.2 23.1 14.9 15.4 64.7 2.99 29. SS-gmgy, vf-fgr,pred fgr,wsrtd,sbrd,wcmtd,poss sid, 3% glauc,abnt xln fracs ** 515 12258.2 76.2 22.0 20.6 51.9 2.81 29. SS-ltolvgy,pred fgr,wsrtd,sbrd,wcmtd-sl fri,pos$ sid,2% glauc,abnt xln fracs. 1-8 Company : ARCO ALASKA, INC. Well : POINT NcINTYRE #4 CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-11AY- lg8g · , SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft md nx~ % % % gm/cc deg API 516 12259.2 171. 25.2 18.7 59.4 2.77 28. SS-grngy, pred fgr, wsrtd, sbrd-rd,fri,poss ~nr sid,2% glauc,xln fracs. 517 12260.4 206. 18.4 22.5 55.9 2.94 28. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd,wcmtd-sl fri,poss sid,2% glauc. 518 12261.2 12.9 18.1 23.6 54.3 2.97 28. SS-grngy,vf-cgr,pred fgr,psrtd,sbrd,grds fgr,wsrtd ss,wcmtd-sl fr~,sid,glau¢. 519 12262.2 67.1 19.5 18.7 58.1 2.84 SS-grngy, vf-fgr,pred fgr,wsrtd,sbrd,wcmtd, poss sid, 3-5% glauc,tr arg lams. 520 12263.2 71.4 0.48 20.5 15.1 65.4 2.80 28. SS-grngy, vf-fgr,pred fgr,wsrtdrsbrd,sl fri,poss mr sial,5-7% glauc,tr arg lams 521 12264.3 118. 21.9 22.7 56.6 2.82 27. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd, sl fri,poss nar sid,5% glaucrsdy burs. 522 12265.2 120. 22.5 17.4 GG.3 2.79 29. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd, sl fri,poss nnr sial,3-5% glauc. 523 12266.2 30.2 16.5 13.7 GO.3 3.19 26. SS-grngy,vf-fgr,pred fgr,wsrtd,sbrd, wcn~cd,poss sial,3-5% glauc,vug. 524 12267.3 9.02 18.2 18.9 57.0 2.79 27. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,sl fri, nnr sid, 2% glauc,vert xln fr 525 12268.2 97.2 21.8 14.7 64.7 2.89 27. SS-ltolvgy,vf-fgr,wsrtd,~brd,sl fri,poss sid,2% glauc. 526 12269.2 31.4 20.0 21.6 51.7 2.98 27. SS-ltolvgy,vf-fgr,wsrtd,sbrd,wcn~d-sl fri,poss sid,2% glau¢. 527 12270.8 11.8 16.7 20.5 51.3 2.94 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd, sbrd,wcmtd,poss sial,l-2% glauc. 528 12271.4 44.0 18.7 22.9 43.6 3.10 28. SS-ltolvgy,vi'-fgr, pred fgr,wsrtd,sbrd,wcntd,poss sid,2% glauc ** 529 12272.5 10.G 18.5 12.6 63.3 3.17 29. SS-gygrn,vf-fgr,pred fgr,wsrtd,sbrd,wcmtd,poss sid,3-5% glau¢. 530 12273.3 506. 249.00 28.6 26.1 58.1 2.72 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd, sbrd,i~ri,1-2% glau¢. 531 12274.2 591. 29.9 23.4 56.6 2.73 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,fri,tr-1% glau¢. 532 12275.1 0.18 14.0 13.8 63.5 3.13 25. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbang-sbrd,vwcn~cd,dn~e poss sid. 533 12276.2 502. 28.4 24.8 56.0 2.72 27. SS-ltolvgy,vf-fgr, pred fgr,wsrtd,sbrd-rd,fri,1% glau¢. 534 12277.2 79.3 22.5 25.8 56.3 2.81 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,wcntd-~l fri,poss nar ~id,tr arg lams 535 12278.2 245. 26.4 21.5 54.4 2.76 26. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd-rd,~l fri-fri,1% glauc. 536 12279.2 176. 25.4 23.2 54.9 2.72 26. SS-ltolvgy,vt'-fgr,pred fgr,wsrtd, sbrd-rd,sl fri,tr-1% glau¢. 537 12280.3 93.9 21.4 25.2 47.6 2.92 23. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,$brd,wrdntd-sl fri,pos$ sid. 538 12281.1 0.42 11.8 13.7 58.3 3.08 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,vwcmtd,dnse,poss ~id. 539 12282.1 0.04 160.00 10.4 14.0 52.5 3.12 26. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd,vwcm~d,clnse, poss ~id. 540 12283.4 698. 28.2 39.3 47.3 2.70 24. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd,fri. 541 12284.2 615. 28.6 44.2 37.1 2.70 26. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd,sl fri. 542 12285.2 450. 26.8 40.4 42.0 2.73 23. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd, sl fri,tr arg lams. 543 12286.2 760. 30.5 48.0 33.6 2.69 25. SS-ltolvgy,pred vfgr,wsrtd,sbrd-rd,fri. 544 12287.3 6.82 9.5 18.0 51.5 3.13 24. SS-ltolvgy,vf-fgr,pred fgr,wsrtd,sbrd,vwcmt:d,clnse,poss sid ** 1-9 Company: ARCO ALASKA, INC. Well : POINT McINTYRE /~4 CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 ,, SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBEF~ (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft ~d )nd % % % gm/cc deg API 545 12288.3 36.2 20.6 26.6 48.9 2.99 26. SS-Itolvgy,pred vfgr,wsrtd,sbrd,vwcn~d, dnse,poss sid,vug. 546 12289.3 0.81 13.3 16.7 54.4 3.07 24. SS-ltolvgy,pred vfgr,wsrtd,sbrd,vwcmtd,dnse,poss $id. 547 12290.3 504. 28.0 42.3 42.7 2.70 24. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd-rd, sl fri. 548 12291.1 53G. 29.0 38.7 43.6 2.71 2G. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,sl fri. 549 12292.1 5G6. 28.7 4G.9 43.8 2.70 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd, sl fri. 550 12293.2 630. 619.00 28.5 46.4 41.7 2.71 2G. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,sl fri. 551 12294.3 350. 24.6 43.2 39.2 2.85 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcmtd-sl fri,poss nmr sid. 552 12295.1 543. 28.9 37.2 44.3 2.75 25. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd,sl fri. 553 12296.2 403. 27.8 38.6 46.1 2.71 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,$brd,sl fri. 554 12297.4 424. 28.2 39.6 43.0 2.73 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd, sl fri. 555 12298.2 424. 27.8 39.7 40.8 2.71 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,sl fri. 556 12299.8 496. 27.9 39.9 40.6 2.69 27. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd,sl fri. 557 12300.1 469. 27.9 38.6 44.2 2.70 25. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,sl fri 558 12301.3 558. 28.5 42.1 39.8 2.70 26. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,sl fri. 559 12302.2 531. 27.9 45.8 39.2 2.68 28. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,sl fri. 560 12303.3 0.85 247.00 12.8 16.3 56.0 3.04 24. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,Wcmtd, dnse,poss sid. 561 12304.2 2.29 I4.3 18.2 55.8 3.02 24. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcn~d,dnse,poss sid. 562 12305.2 0.14 11.2 20.8 48.2 3.04 22. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcnFcd,dnse,poss sid. 563 12306.2 318. 28.4 30.7 41.9 2.78 25. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 564 12307.2 348. 26.5 48.7 33.9 2.69 24. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 565 12308.3 328. 25.6 25.2 51.6 2.74 25. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd,wcons-sl fri. 566 12309.2 223. 25.7 29.9 51.7 2.70 24. SS-yelgy, vf-fgr, pred vfgr,wsrtd,sbrd-rd,wcorm-sl fri. 567 12310.3 306. 25.5 27.3 49.7 2.67 SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd,w~orm-sl fri. 568 12311.2 360. 27.1 26.1 52.7 2.G9 24. SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd,w=ons-sl fri. 569 12312.2 57.6 21.3 25.4 55.5 2.87 25. SS-ltolvgy,vf-fgr,pred vfgr,~srtd,sbrd,wcm~d, poss sid. 570 12313.2 286. 302.00 27.0 23.7 51.0 2.72 24. SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 571 12314.1 210. 25.8 27.9 50.3 2.70 25. SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd,w:orm-sl fri. 572 12315.4 26.0 14.9 18.2 54.1 3.05 24. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcmtd, dnse,poss sid. 573 12316.2 423. 28.2 28.0 48.1 2.70 25. SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 1 - 10 Company .- ARCO ALASKA, INC. Well : POINT NcINTYRE #4 CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-NAY- 1989 , , SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL ~/ATER ft md md % % % gm/cc deg API .... 574 12317.2 59.2 23.2 20.0 57.4 2.87 23. SS-yelgy,vf-fgr,pred fgr,wsrtd,sbrd,wcmtd-sl fri,poss sid. 575 12318.1 403. 27.0 21.4 54.9 2.67 22.. SS-yelgy, vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 576 12319.2 217. 25.5 21.0 54.1 2.77 24. SS-yelgy, vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 577 12320.2 318. 2G.G 19.G 57.3 2.69 24. SS-yelgy, vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 578 12321.3 208. 2G.G 22.0 51.7 2.75 24. SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 579 12322.2 318. 27.5 31.8 49.9 2.71 24. SS-yelgy, vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 580 12323.2 191. 24.8 27.2 52.8 2.69 26. SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 581 12324.1 267. 121.00 26.7 27.7 53.6 2.69 25. SS-yelgy, vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 582 12325.2 264. 26.4 28.0 50.3 2.70 24. SS-yelgy, vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 583 12326.2 244. 26.4 29.2 47.6 2.70 . 24. SS-yelgy, vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 584 12327.3 245. 26.0 22.6 52.6 2.69 24. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 585 12328.2 122. 24.3 27.8 49.8 2.68 28. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons-sl fri. 586 12329.2 277. 26.5 23.6 52.G 2.70 25. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri ~* 587 12330.3 117. 24.0 26.5 52.8 2.69 22. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons. 588 12331.1 173. 25.0 24.5 52.4 2.69 24. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 589 12332.2 152. 24.0 23.0 51.9 2.69 22. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 590 12333.4 185. 68.30 24.5 19.2 47.7 2.70 24. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. Core ~6 (12333.6 - 12422.6 feet) G01 12334.2 81.9 23.2 17.4 58.8 2.70 22. SS-ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons,tr arg lams. 602 12335.1 127. 22.5 22.8 52.6 2.69 24. SS-ltolvgy,vf-fgr, pred vfgr,wsrtd,sbrd-rd,wcons,tr arg lams. 603 12336.2 25.G 20.8 19.9 57.4 2.70 23. SS-ltolvgy,vf-fgr,pred vfgr,slty,wsrtd,sbrd,wcons. G04 12337.2 22.7 19.1 19.9 60.3 2.72 24. SS-ltolvgy,vf-fgr,pred vfgr,slty,wsrtd,$brd,wco~s. G05 12338.2 93.5 22.8 23.6 51.4 2.69 25. SS-ltolvgy,vf-fgr, pred vfgr,mar slt,wsrtd,sbrd,wco~s. 606 12339.2 57.5 21.2 23.8 52.9 2.68 24. SS-ltolvgy,vf-fgr, pred vfgr,n~r slt,wsrtd,sbrd,wcons. 607 12340.1 1.30 14.1 17.4 62.2 2.88 23. SS-ltolvgy,vf-fgr,pred vfgr,nnr slt,w~rtd,sbrd,wcn~d,poss sid. 608 12341.2 71.2 21.6 23.0 51.2 2.71 25. SS-ltolvgy,vf-fgr,pred vfgr,nnr slt,wsrtd,sbrd,wcons. 609 12342.2 71.7 20.7 23.3 51.9 2.69 24. SS-ltolvgy,vf-fgr, pred vfgr,nnr slt,wsrtd,sbrd,wcons. 1 - 11 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE CORE LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 , , SATURATION I SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft nd nx~ % % % gm/cc I deg API 610 12343.2 71.6 33.30 21.1 22.1 50.8 2.69 24. SS-ltolvgy,vf-fgr,pred vfgr,n~r slt,wsrtd,sbrd,wcons. 611 12344.2 10.4 17.8 18.7 64.6 2.69 24. SS-ltotvgy,vf-fgr,pred vfgr,slty,~rtd, sbrd,wcons,tr arg la~. 612 12345.1 11.2 15.9 19.3 46.0 2.97 23. SS-ltolvgy,vf-fgr,pred vfgr,slty,wsrtd,sbrd,wcmtd,poss sid. 613 12347.2 2.52 18.5 19.5 62.0 2.69 24. SS-ltolvgy,vf-fgr,pred vfgr,slty,wsrtd, sbrd,wc~s,tr pyr. 614 12347.2 2.52 16.7 16.4 67.8 2.68 23. SS-ltolvgy,vf-fgr,pred vfgr,slty, wsrtd,sbrd,wcons,tr pyr. 615 12348.2 0.74 12.2 13.1 72.1 2.71 24. SS-yelgy,vfgr,slty,~q~srtd,sbrd-rd,wcons,5-10% arg lane. 616 12349.2 8.43 18.6 18.8 63.7 2.69 22. SS-ltolvgy,vf-fgr,pred vfgr,nnr slt,wsrtd,$brd,wc~s,tr pyr. GI7 12350.3 0.95 13.8 18.3 63.2 2.70 24. SS-ltolvgy,vf-fgr,pred vfgr,slty,~rtd, sbrd,wc~s,3-5% arg lans. 618 12351.2 1.41 14.9 13.8 70.9 2.69 22. SS-ltolvgy,vf-fgr,pred vfgr,slty,vmrtd,sbrd,wc~s,3% arg la~ns. 619 12352.2 7.19 16.9 15.0 67.5 2.68 24. SS-ltolvgy,vf-fgr,pred vfgr,slty,wsrtd,sbrd-rd,wc~s,tr arg lans. 620 12353.1 1.46 0.75 15.3 12.3 72.1 2.70 22. SS-ltolvgy,vf-fgr,pred vfgr,slty,wsrtd,$brd-rd,wc~s,2-3% arg lans. 621 12354.2 1.19 15.2 11.8 73.5 2.69 22. SS-ltolvgy,vf-fgr, p~d vfgr,slty,vmrtd,sbrd-rd,wc~s,2-3% arg lane. 622 12355.2 1.36 15.8 14.7 68.2 2.70 21. SS-ltolvgy,vf-fgr,pred vfgr,$1ty,~rtd,sbrd-rd,wc~s,3-5% arg lans. 623 12356.2 1.44 14.8 12.9 70.8 2.70 22. SS-ltolvgy,vf-fgr, pred vfgr,slty,wsrtd,~brd-rd,wc~s,5% arg lans. 624 12357.4 12.9 19.6 61.5 2.68 19. SS-ltolvgy,vf-fgr,pred vfgr,slty,v~rtd,sbrd-rd,wc~s,5-10% arg lams(irregular) 625 12358.4 14.7 19.5 67.0 2.62 20. SS-ltolvgy,vf-fgr,pred vfgr,$1ty,~rtd,ebrd-rd,wc~s,5-10% arg la~(irregular) 626 12359.3 1.09 14.2 16.9 68.9 2.71 22. SS-ltolvgy,vf-fgr,pred vfgr,slty,~rtd,ebrd-rd,wc~s,5-10% arg lan=. 627 12360.2 3.14 16.8 12.6 66.2 2.69 20. SS-ltolvgy,vf-fgr,pred vfgr,$1ty,~rtd,$brd-rd,~s,5% bioturb. 628 12361.2 1.42 14.6 14.8 66.8 2.70 22. SS-ltolvg¥,vf-fgr,p~d vfgr,slty,~rtd, sbrd-rd,~s,5-10% arg 1~. 629 12362.5 155. 24.0 12.3 61.7 2.68 SS-yelgy,vfgr,~q~srtd, sbrd,wc~$. 630 12363.2 370. 393.00 25.7 11.9 61.2 2.68 21. SS-yelgy,vfgr,~mrtd, sbrd,wc~s. 631 12364.3 510. 26.4 8.4 70.1 2.70 21. SS-yelgy,vfgr,~,~rtd, sbrd,~s-sl fri. 632 12365.2 501. 27.0 12.2 67.9 2.71 22. SS-yelgy,vfgr,~q~rtd,sbrd,~s-sl fri. 633 12366.2 575. 27.8 11.3 68.4 2.70 22. SS-yelgy,vfgr,~rtd,sbrd,wc~$-sl fri. 634 12367.2 563. 28.2 13.0 66.8 2.69 22. SS-yelgy,vfgr,wsrtd,sbrd,~s~l fri. 635 12368.2 480. 28.0 15.9 72.0 2.71 22. SS-yelgy,vfgr,~q~srtd,sbrd,wcms-sl fri. 636 12369.2 440. 27.7 14.3 67.6 2.71 20. SS-yelgy,vfgr,v~srtd,sbrd,~s-sl fri. 637 12370.2 266. 2/.0 7.8 75.3 2.75 21. SS-yelgy,vfgr,~rtd, sbrd,~s-sl fri. 638 12371.2 121. 24.5 9.2 74.2 2.80 20. SS-yelgy,vfgr,~rtd,sbrd,wc~s,poss mr sid. 1 - 12 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE CORE. LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft md md % % % gnl/CC deg API 639 12372.2 94.0 24.0 9.4 69.4 2.88 19. SS-yelgy, vfgr,vwsrtd, sbrd,wcons,poss nnr sid. 640 12373.2 117. 349.00 24.7 8.0 73.3 2.80 18. SS-yelgy, vfgr,vwsrtd, sbrd,wcons,poss nnr sid. 641 12374.2 380. 27,5 9.3 74.6 2.69 18. SS-yelgy, vfgr,tr cgr cly frags,wsrtd,sbrd,wcons-sl fri. 642 12375.2 448. 26.6 10.5 71.2 2.69 18. SS-yelgy,vf-fgr,pred vfgr,wsrtd,sbrd,wcons-sl fri. 643 12376.2 496. 27.7 9.7 70.3 2.69 18. SS-yelgy, vfgr,wsrtd,sbrd,wcons-sl fri. 644 12377.2 467. 27.5 8.9 73.4 2.69 21. SS-yelgy,vfgr,tr cgr cly frags,wsrtd,sbrd,wcons-sl fri. 645 12378.2 464. 27.7 10.7 69.0 2.72 19. SS-yelgy,vfgr,wsrtd,sbrd,wcons-sl fri. 646 12379.2 426. 27.4 13.5 68.1 2.71 19. SS-yelgy, vfgr,tr cgr cly frags,wsrtd,sbrd,wcons-sl fri. 647 12380.2 286. 27.1 11.1 70.8 2.75 21. SS-yelgy,vfgr,tr cgr cly frags,wsrtd,sbrd,wcons-sl fri. 648 12381.2 232. 25.6 12.7 72.5 2.72 21. SS-yelgy,vfgr,tr cgr cly frags,wsrtd, sbrd,wcons-sl fri. 649 12382.2 287. 26.5 11.8 68.6 2.72 22. SS-yelgy, vfgr,vwsrtd,sbrd,wcons-sl fri. 650 12383.2 164. 75.30 25.9 8.0 74.3 2.82 18. SS-yelgy, vfgr,vwsrtd,sbrd,wcons ** 651 12384.2 370. 26.3 4.6 73.9 2.72 19. SS-yel gy, vfgr,vwsrtd, sbrd,wcons. 652 12385.2 275. 25.0 3.5 72.6 2.71 18. SS-yelgy,vfgr,vwsrtd,sbrd,wcons,tr arg lams. 653 12386.2 596. 27.2 0.1 74.4 2.68 19. SS-yel gy, vfgr,vwsrtd, sbrd,wcons. 654 12387.2 178. 24.4 3.9 70.8 2.70 19. SS-yelgy,vf-fgr,pred vfgr,nmr slt,wsrtd,sbrd,wcons. 655 12388.2 184. 24.9 8.6 71.7 2.67 18. SS-yelgy,vfgr,vwsrtd, sbrd,wcons,tr arg mat. 656 12389.2 232. 24.7 2.5 75.4 2.68 18. SS-yelgy, vfgr,vwsrtd, sbrd, wcons. 657 12390.2 192. 25.1 4.4 76.2 2.67 21. SS-yelgy,vfgr,vwsrtd,sbrd,wcons-sl fri. 658 12391.8 165. 24.2 3.8 56.5 2.69 19. SS-yelgy, vfgr,mir slt,vwsrtd,sbrd,wcons,tr arg mat. 659 12392.9 104. 22.9 7.9 76.2 2.72 19. SS-yelgy,vfgr,mr slt,vwsrtd,sbrd,wcons,tr arg. 660 12393.7 298. 135.00 25./ 1.3 74.6 2.68 18. SS-yelgy, vfgr,mir slt,vwsrtd,sbrd,wcons-sl fri. 661 12394.6 177. 24.7 10.8 75.0 2.69 18. SS-yelgy, vfgr,nnr slt,vwsrtd,sbrd,wcons-sl fri,tr arg mat. 682 12395.6 105. 22.5 7.1 73.4 2.76 20. SS-yelgy,vfgr,nnr slt,vwsrtd,sbrd,wcons. 663 12396.4 103. 22.0 10.6 71.2 2.67 18. SS-yelgy,vfgr,nnr slt,wsrtd,sbrd,wcons,tr arg lams. 664 12397.4 96.8 22.4 13.2 70.1 2.68 18. SS-yelgy,vfgr,nnr slt,wsrtd,sbrd,wcons,tr arg lans. GG5 12398.3 171. 23.7 10.3 70.2 2.69 18. SS-yelgy,vfgr,mqr slt,wsrtd,sbrd,wcons. 666 12399.3 131. 23.5 13.4 71.2 2.67 18. SS-yelgy,vfgr,nnr slt,wsrtd,sbrd,wcons-sl fri,tr arg lams. 667 12400.3 23.1 19.0 20.0 69.3 2.68 18. SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,2-3% arg lams. I - 13 Company = ARCO ALASKA, INC. Wel 1 : POINT NcINTYRE #4 CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL ~4ATER ft n~ md % % % gm/cc deg API , ,, 668 12401.3 187. 23.9 11.0 73.2 2.69 18. SS-yelgy, vfgr,mr slt,wsrtd,sbrd,wcons. 669 12402.3 66.0 21.7 10.4 63.3 2.69 SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,tr arg lams. 670 12403.3 172. 119.00 24.3 8.8 72.4 2.72 22. SS-yelgy,vfgr,n~r slt,wsrtd,sbrd,wcons-sl fri. 671 12404.2 109. 21.9 5.5 73.6 2.72 22. SS-yelgy,vfgr,n~r slt,wsrtd,sbrd,wcons. 672 12405.2 128. 22.8 G.O 72.5 2.69 21. SS-yelgy,vfgr,mr slt,wsrtd,sbrd,wcons,tr arg mat. 673 12406.2 184. 22.4 6.3 74.0 2.72 23. SS-yelgy,vfgr,mr slt,wsrtd,sbrd,wcons. 674 12407.2 169. 23.7 5.4 74.9 2.69 22. SS-yel gy, vfgr,nnr s lt, wsrtd, sbrd, wcons. 675 12408.2 14.3 17.0 17.8 69.3 2.67 22. SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,2-3% arg lams. 676 12409.2 30.3 19.5 19.3 70.G 2.68 22. SS-yelgy,vfgr,mr slt,wsrtd,sbrd,wcons,2-3% arg lams. 677 12410.2 58.3 21.2 13.6 71.3 2.71 22. SS-yelgy,vfgr,n~r slt,wsrtd,sbrd,wcons,tr arg mat. 678 12411.1 1.73 15.3 16.2 69.7 2.71 22. SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,3-5% arg lams. 679 12412.2 8.83 17.6 19.1 69.2 2.70 22. SS-yelgy, vfgr,mlr slt,wsrtd,sbrd,wcons,tr arg lams. 680 12413.3 10.2 4.14 17.8 16.3 69.2 2.69 23. SS-yelgy,vfgr,mnr slt,wsrtd,sbrd,wcons,tr arg mat. 681 12414.2 2.52 15.7 19.4 64.7 2.72 22. SS-yelgy, vfgr,slty,wsrtd,sbrd,wcons,2-3% arg lams. 682 12415.2 10.4 17.8 20.5 65.3 2.69 22. SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,tr arg m~t. 683 12416.2 5.39 16.8 23.G 64.G 2.68 22. SS-yelgy, vfgr,slty,wsrtd,sbrd,wcons,tr arg mat. 684 12417.2 18.8 17.G 20.3 66.5 2.69 19. SS-yelgy, vfgr,slty,wsrtd,sbrd,wcons,tr arg lams. 685 12418.2 18.4 13.0 76.5 2.68 21. SS-yelgy, vfgr,nnr slt,wsrtd,sbrd,wcons,tr arg lams (irregular spl.) 686 12419.2 20.4 11.4 84.0 2.65 21. SS-yelgy,vfgr,m~r slt,wsrtd,sbrd,wcons (irregular spl.) 687 12420.2 21.3 12.4 83.G 2.65 22. SS-yelgy,vfgr,mqr slt,wsrtd,sbrd,wcons (irregular spl.) 688 12421.8 1.26 14.5 17.4 67.4 2.71 25. SS-yelgy, vfgr,slty,wsrtd,sbrd,wcons,5-10% arg lams. 689 12422.2 4.49 17.5 17.0 50.0 2.73 26. SS-yelg¥,vfgr,slty,wsrtd,sbrd,wcons,tr arg lams. Core f7 (12422.6 - 12512.0 feet) 701 12423.2 1.00 7.33 15.5 21.7 59.4 2.70 25. SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,tr arg lams. 702 12424.2 0.93 15.1 20.4 61.5 2.70 25. SS-yelgy,vfgr,$1ty,wsrtd,sbrd,wcons,3-5% arg lams. 703 12425.2 145. 17.9 2.9 73.5 2.67 22. SS-vltgy,vfgr,nnr $1t,wsrtd,sbrd,wcons. 704 12426.2 2.43 16.7 21.5 61.1 2.70 25. SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,tr arg lams. 1 - 14 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 , ,, SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft nc] md % % % g~cc deg API 705 12427.2 5.26 17.5 18.5 63.1 2.70 22. SS-yelgy, vfgr,slty,wsrtd,sbrd,wcons,tr-1% arg lams. 706 12428.1 3.71 16.7 15.2 63.6 2.70 24. SS-yelgy,vfgr,slty,wsrtd,sbrd,wcons,1-2% arg lams. 707 12429.2 257. 23.8 4.9 74.1 2.69 22. SS-yelg¥, vfgr,vwsrtd, sbrd,wcons. 708 12430.2 357. 25.1 3.7 75.8 2.68 21. SS-yel gy, vfgr, vwsrtd, s brd,wcon$. 709 12431.2 493. 27.0 5.6 71.7 2.69 21. SS-yelgy, vfgr,vwsrtd, sbrd,wcons. 710 12432.3 223. 25.7 18.2 56.3 2.84 25. SS-yelgy, vfgr,vwsrtd, sbrd,wcons. 711 12433.2 482. 513. O0 27.6 15.9 61.8 2.72 24. SS-yelgy,vfgr,vwsrtd, sbrd,wcons. 712 12434.1 75.2 22.3 23.4 52.1 2.72 25. SS-yelgy, vfgr, s lty, vwsrtd, sbrd, wcons. 713 12435.3 246. 25.7 23.1 51.7 2.75 26. SS-yelgy,vfgr,nnr slt,vwsrtd,sbrd,wcons. 714 12436.2 395. 25.7 16.7 60.3 2.66 26. SS-yelgy, vfgr,vwsrtd, s brd, wcons. 715 12437.1 101. 22.7 15.8 58.0 2.67 24. SS-yelgy,vfgr,nnr slt,vwsrtd,sbrd,wcons,tr arg lams. 716 12438.2 168. 24.1 20.7 55.6 2.67 25. SS-yelgy,vfgr,m~r slt,vwsrtd,sbrd,wcons. 717 12439.2 124. 23.9 19.G 57.1 2.68 23. SS-yelgy, vfgr,nmr slt,vwsrtd,sbrd,wcons. 718 12440.2 83.8 22.3 20.0 54.9 2.68 23. SS-yelgy, vfgr, s lty, vwsrtd,sbrd,wcons. 719 12441.2 222. 25.$ 19.3 57.9 2.67 21. SS-yelgy,vfgr,vwsrtd, sbrd,wcons-sl fri,tr carb lam. 720 12442.9 353. 26.3 19.4 53.9 2.67 21. SS-yelg¥, vfgr,vwsrtd, sbrd-rd,wcons. 721 12443.1 470. 224. O0 27.8 21.5 57.2 2.67 22. SS-yelgy,vfgr,vwsrtd,$brd-rd,wcons-sl fri. 722 12444.2 369. 27.7 19.8 58.0 2.72 22. SS-yelgy, vt~gr,vwsrtd,sbrd-rd,wcons-sl fri. 723 12445.2 400. 27.2 26.0 52.5 2.67 22. SS-yelg¥,vfgr,vwsrtd,sbrd-rd,wcons-sl fri. 724 12446.1 457. 27.9 22.6 52.6 2.67 22. SS-yelgy,vfgr,vwsrtd, sbrd-rd,wcons-sl fri. '725 12447.2 421. 27.2 21.1 57.7 2.67 24. SS-yelgy, vfgr,wsrtd,sbrd-rd,wcons-sl fri,tr' arg net. 726 12448.2 428. 27.1 21.2 54.6 2.68 22. SS-yelgy, vfgr,vwsrtd,sbrd-rd,wcons-sl fri. 727 12449.2 457. 27.9 19.6 57.9 2.68 22. SS-yelgy,vfgr,vwsrtd,sbrd-rd,wcons-sl fri. 728 12450.5 179. 24.6 22.8 51.9 2.70 21. SS-yelgy, vfgr,vwsrtd, sbrd-rd,wcons. /29 12451.9 364. 27.3 20.7 52.5 2.67 21. SS-yelgy, vfgr,vwsrtd,sbrd-rd,wcons-sl fri. 730 12452.9 423. 27.5 22.5 50.4 2.67 22. SS-yelgy,vfgr,vwsrtd,sbrd-rd,wcons-sl fri. 731 12453.2 345. 159.00 26.9 24.3 52.6 2.68 22. SS-yelgy,vfgr,vwsrtd,sbrd-rd,wcons-sl fri. 732 12454.2 286. 25.5 21.1 51.7 2.68 20. SS-yelgy,vfgr,vwsrtd, sbrd-rd,wcons. 733 12455.2 273. 25.8 21.4 54.7 2.68 20. SS-yelgy, vfgr,vwsrtd, sbrd-rd,wcons. i - 15 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE CORE LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 , , SATURATI ON SAMPLE DEPTH 'PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft n~J n~ % % % gm/cc deg API ,,, 734 12456.2 213. 25.1 18.7 51.4 2.70 22. SS-yelgy,vfgr,~nr slt,vwsrtd,sbrd-rd,wcons. 735 12457.2 46.4 20.2 17.6 46.8 2.92 18. SS-yelgy, vfgr,nnr slt,vwsrtd,sbrd-rd,wcmtd,poss sid. 736 12458.2 272. 24.1 19.3 59.2 2.69 18. SS-yelgy,vfgr,vwsrtd,sbrd-rd,wcons-sl fri,n~r arg mat. 737 12459.2 1.02 13.8 26.0 53.2 2.70 19. SS-yelgy, vfgr,vwsrtd, sbrd-rd,wcons,1-2% arg lams. 738 12460.2 350. 23.0 25.0 49.9 2.66 21. SS-yelgy,vfgr,vwsrtd, sbrd-rd,wcons-sl fri. 739 12461.2 575. 25.4 23.1 48.9 2.66 SS-yelgy, vfgr,vwsrtd, sbrd-rd,wcons-s 1 fri. 740 12462.2 356. 25.1 21.3 . 53.3 2.71 22. SS-yelgy, vfgr,vwsrtd,sbrd-rd,wcons. 741 12463.3 393. 197. O0 25.2 24. G 50.5 2.69 21. SS-yelgy, vfgr,vwsrtd, sbrd-rd,wcons-s 1 fri. 742 12464.2 364. 25.7 21.7 54.0 2.70 20. SS-yelgy,vfgr,vwsrtd,sbrd-rd,wcons-$1 fri. 743 12465.1 473. 24.9 23.5 49.4 2.68 20. SS-yelgy,vfgr,vwsrtd, sbrd-rd,wcons-sl fri. 744 12466.2 440. 24.5 23.8 50.1 2.GG 18. SS-yelgy,vfgr,vwsrtd, sbrd-rd,wcons-sl fri. 745 12467.2 343. 24.1 20.1 55.1 2.68 21. SS-yelgy,vfgr,vwsrtd, sbrd-rd,wcons-s 1 fri. 746 12468.2 52.8 21.1 16.2 57.1 2.83 18. SS-ltolvgy,vfgr,vwsrtd,sbrd-rd,wcmtd,poss nmr sid. 747 12469.5 160. 23.7 17.9 54.0 2.74 20. SS- lto lvgy,vfgr, vwsrtd, sbrd-rd, wcons. 748 12470.2 100. 22.6 19.3 54.1 2.78 20. SS-ltolvgy,vfgr,nnr slt,vwsrtd,sbrd-rd,wcons. 749 12471.1 143. 23. G 20.1 52.2 2.78 20. SS- ltolvgy,vfgr, nnr s lt, vwsrtd, sbrd-rd,wcons. 750 12472.2 137. 23.7 21.6 50.5 2.78 21. SS-ltolvgy,vfgr,nnr slt,vwsrtd,sbrd-rd,wcons. 751 12473.3 114. 125.00 23.3 25.1 46.2 2.80 20. SS-ltolvgy,vfgr,mr slt,vwsrtd,sbrd-rd,wcons,poss nnr sid. 752 12474.2 108. 22.4 24.4 48.0 2.80 21. SS-ltolvgy,vfgr,nnr slt,vwsrtd,$brd-rd,wcons,poss ,mr sid. 753 12475.3 176. 23.6 20.4 51.9 2.73 21. SS-ltolvgy,vfgr,nnr slt,vwsrtd,sbrd,wcons-$1 fri. 754 12476.2 286. 24.1 20.2 50.0 2.71 21. SS-ltolvgy,vfgr,nnr slt,vwsrtd,$brd,wcons-s'l fri. 755 12477.2 187. 21.3 19.4 48.5 2.71 20. SS-ltolvgy,vfgr,nnr $1t,vwsrtd,$brd,wcons-sl fri. 756 12478.3 223. 18.6 22.2 44.5 2.71 22. SS-ltolvgy,vfgr,nnr $1t,vwsrtd,$brd,wcon$. 757 12479.3 0.24 9.7 9.5 86.1 2.75 21. SS-clkgrngy,vfgr,vwsrtd,sbrd,wcons,10-15% glauc. 758 12480.2 0.19 9.0 13.9 85.9 2.73 SS-olvgy,vfgr,slty,wsrtd,$brd,wcons,5-7% arg lams. 759 12481.2 0.11 10.5 21.3 71.3 2.71 22. SS-olvgy,vfgr,slty,vwsrtd,sbrd,wcons,1% glauc,tr arg m~t. 760 12482.2 0.12 10.4 25.1 66.0 2.75 21. SS-olvgy,vfgr,$1ty,vwsrtd,sbrd,wcon$,3-5% bioturb arg m~t. 761 12483.2 0.35 0.24 12.7 31.5 55.0 2.69 22. SS-olvgy,vfgr,slty,vwsrtd,sbrd,wcons,3-5% bioturb arg mat. 762 12484.2 0.03 8.4 12.4 86.0 2.69 18. SS-olvg¥,vfgr,slty,arg,vwsrtd, sbrd,wcons,tr arg lams. 1 - 16 Company : ARCO ALASKA, INC. Well .- POINT McINTYRE #4 CORE CORE LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY ANALYSIS RESULTS File No.: BP-3-1345 Date : 17-MAY- 1989 SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft .d md % % % gm/cc deg API , , 763 12485.1 0.04 8.2 13.2 84.0 2.70 20. SS-olvgy, vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% arg lams. 764 12486.2 0.I7 11.1 23.4 66.0 2.69 22. SS-olvgy,vfgr,slty, arg,wsrtd,sbrd,wcons,5-7% bioturb arg lams. 765 12487.2 0.18 10.9 28.8 63.0 2.68 21. SS-olvgy,vfgr,slty, arg,wsrtd,sbrd,wcons,5-7% bioturb arg lams. 766 12488.3 0.51 10.2 18.0 74.8 2.69 19. SS-olvgy, vfgr,slty,arg,wsrt:d,sbrd,wcons,5-7% bioturb arg lams ** 767 12489.2 0.23 9.7 18.9 71.7 2.76 18. SS-olvgy, vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 768 12490.2 0.05 9.0 22.2 75.9 2.69 20. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 769 12491.1 0.16 9.8 16.3 76.9 2.70 20. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 770 12492.2 0.07 9.7 15.8 76.2 2.72 19. SS-olvgy,vfgr,slty, arg,wsrtd,sbrd,wcons,5-10~ bioturb arg lams. 771 12493.2 0.11 0.01 I0.2 21.9 GG.G 2.70 21. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 772 12494.5 0.06 10.2 24.2 GG.8 2.73 21. SS-olvgy,vfgr,slty, arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 773 12495.3 0.13 10.7 22.3 67.8 2.71 20. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 774 12496.2 0.13 10.9 23.5 67.1 2.68 17. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 775 12497.2 11.G 14.4 77.8 2.66 19. SS-olvgy, vfgr,slty, arg,wsrtd,sbrd,wcons,arg mat (irregular spl.) 776 12498.2 11.9 29.4 62.4 2.67 22. SS-olvgy,vfgr,slty, arg,wsrtd,sbrd,wcons,arg mat (irregular spl.) 777 12499.6 0.07 11.0 24.5 66.4 2.69 20. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 778 12500.2 0.07 10.4 29.2 65.8 2.69 20. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 779 12501.2 0.08 10.0 10.9 78.3 2.71 SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,~cons,5-10% bioturb arg lams. 780 12502.2 0.07 9.0 26.4 70.8 2.72 20. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,7-10% bioturb arg lams. 781 12503.2 0.11 0.00 9.6 33.7 61.4 2.71 19. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,~cons,7-10% bioturb arg lams. 782 12504.2 0.10 8.8 28.6 70.0 2.69 18. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,~cons,lO-15% bioturb arg lams. 783 12505.2 0.09 8.9 15.6 83.4 2.70 18. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,15-20% bioturb arg lams. 784 12506.2 0.46 8.3 18.8 76.9 2.88 18. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,15% bioturb arg lams,pyr ** 785 12507.2 0.07 8.G 15.2 80.1 2.69 18. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,15% bioturb arg lams. 786 12508.5 0.05 8.3 6.2 93.7 2.69 18. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,10-15% bioturb arg lams. 787 12509.2 0.06 8.2 14.6 83.7 2.69 18. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,5-10% bioturb arg lams. 788 12510.1 0.73 8.5 7.3 88.G 2.73 18. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,15% bioturb arg lams,mr pyr ** 789 12511.6 2.18 7.7 0.9 89.6 2.70 17. SS-olvgy,vfgr,slty,arg,wsrtd,sbrd,wcons,lO% bioturb arg lams ** I - 17 Company : ARCO ALASKA, INC. Well : POINT McINTYRE #4 CORE LABORATORIES Field : EXPLORATORY Formation : EXPLORATORY File No.: BP-3-1345 Date : 17-MAY- 1989 CORE ANALYSIS RESULTS SATURATION SAMPLE DEPTH PERMEABILITY PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (VERTICAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair KAIR OIL WATER ft ~d md % % % gm/cc deg API ** - Denotes Fractured Sample 1 - 18 ROTARY SIDEWALL CORE ANALYSIS CORE Company : ARCO ALASKA, INC. Well : POINT McINTYRE ~4 Location : 16-12N-14E, Fr SE cot 1468'N 666'W{surf) Co,State : NORTH SLOPE, ALASKA CORE ,AN LABORATORIES Fi el d .. EXPLORATORY Formation : EXPLORATORY Coring Fluid : Elevation : ALYS I S RESULTS File No.: BP-3-1345 Date : 17-HAY- 1989 API No. : Anal ysts: PLB, GAC SAMPLE NUMBER DEPTH ft 1 11670.0 2 11683,0 3 1200O.0 4 12027.0 5 12039.0 6 12041.0 7 12047.0 8 12065.0 9 12070.0 10 12076.0 11 120B6.0 12 12088.0 13 12O9O.0 PERMEABILITY {HORIZONTAL) Kair md POROSITY (HELIUM) SATURATION (PORE VOLUME) OIL WATER % % GRAIN DENSITY gm/cc SIDEWALL SAMPLES 0.37 1.82 38.3 51.1 4.65 0.46 0.19 374. 1050. 101. 12.4 17.0 13.8 16.7 19.5 21.1 17.3 13.3 13.3 29.0 27.1 24.1 19.2 18.8 8.5 36.2 23.1 21.8 27.0 2.6 16.1 20.0 17.8 17.7 78.5 53.0 78.2 61.6 44.3 53.2 65.7 80.4 71.1 71.4 61.4 64.7 2.58 2 51 3 29 3 18 2 74 2 67 2 67 2.95 3.05 2.84 2.89 2.87 DESCRIPTION - DEAN-STARK ANALYSIS SS olvgy,vfgr,slty,wsrtd,sbrd,wcons (irregular spl) SS ltolvgy,vfgr,stty,wsrtd,sbrd,wcons,carb tams SS olv§y,vf-fgr,stty,wsrtd,sbrd,wcmtd,poss sid,(irregular spl) SS ltolvgy,vf-mgr,pred fgr,mod wsrtd,sbrd,wcons,poss sid,7% glauc,vug SS ltolYgy,vfgr,vwsrtd,sbrd,wcons,tr arg lams SS ltolvgy,vfgr,vwsrtd,sbrd,wcons SS ttolvgy,vfgr,vwsrtd,sbrd,wcons,tr arg lams SS ttolv§y,vf-fgr,pred fgr,wsrtd,sbang-sbrd,wcons,poss sid,5-7% glauc SS dlgrng¥,vf-mgr,pred fgr,mod wsrtd,sbang-sbrd,wcons,poss sid,7% glauc SS gyblk,f-cgr,pred mgr,psrtd,sbang,fri,abnt blk carb (Disaggrega':ed Sample) SS,grngy,f-mgr,pred fgr,wsrtd,sbrd-rd,fri,poss mnr sid,7-10% glauc SS,grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,slfri,poss sid,3-5% glauc SS,grngy,vf-fgr,pred fgr,wsrtd,sbrd-rd,~cons-slfri,poss sid,3-5% glau¢ 1 - 1 Company : ARCO ALASKA, INC. Wel 1 : POINT NcINTYRE ~4 CORE LABORATORIES Fi el d : EXPLORATORY Formation : EXPLORATORY File No.: BP-3-1345 Date : 17-HAY- 1989 TABLE I SUHHARY OF CORE DATA ZONE AND CUTOFF DATA CHARACTERISTICS REMAINING AFTER CUTOFFS ZONE: Identification Top Depth ................ Bottom Depth Number of Samples EXPLORATORY 11691.0 ft 12512.0 ft 469 DATA TYPE: Porosity Permeability (HELIUM) (HORIZONTAL) Kair CUTOFFS: Porosity (Minimum) Porosity (Maximum) Permeability {Minimum) --- Permeability {Maximum) --- Water Saturation {Maximum) oil Saturation (Minimum) - Grain Density {Hinimum) -- Grain Density (Maximum) -- Lithology Excluded 0.0% 100.0 % O. 0000 md 100000. md 100.0 % 0.0% 2. O0 gm/cc 4. O0 gm/cc NONE ZONE: Number of Samples Thickness Represented - POROSITY: Storage Capacity Arithmetic Average .... Minimum Maximum ............... Median Standard Deviation .... GRAIN DENSITY: Arithmetic Average Minimum Maximum Median Standard Deviation 467 467.0 ft 9278.9 ~-ft 19.9 % 5.4% 32.3 % 21.3 % +_6.3 % 2.79 gm/cc 2.41 gm/cc 3.34 gm/cc 2.71 gm/cc +_0.18 gm/cc PERMEABILITY: Flow Capacity Arithmetic Average Geometric Average Harmonic Average Minimum Maximum Median ................ Standard Dev. {Geom) -- K-lO±1'375 79209.5 md-ft 178. md 19.0 md 0.38 md 0.01 md 1950. md 71.7 md md HETEROGENEITY (Permeability): Dykstra-Parsons Var. -- Lorenz Coefficient .... 0.977 0.559 AVERAGE SATURATIONS (Pore Volume): Oil Water 21.2 % 59.5 % Stat 1 - 1 Permeability vs, Porosity iO00oO iO0.O :iO.O 0.01 O.OOi Helium Porosity: - LE~ENO - ARCO ALASKA, ~NC. EXPLOrATOrY POINT ~cINTYRE ~4 EXPLORATORY EXPLORATORY (~i&9~,O - ~P-~f~.O ~) Pomos&~:y H&stogpmm 50 30 5.0 9O 70 9.0 i3.0 i7.0 2i.0 25.0 29.0 33.0 Helium Porosity: % ARCO ALASKA, POINT Hc INTYRE EXPLORATORY EXPLORATORY {ii69i-i25i2 feet) ~7-NAY-~g89 - LEGEND - ..... CumuZa~[ve Dapac[~y Loa~ ~00 9O 7O EO Permeability H s ogram ~0 4O ~0 0 -- .00~ Horizontal Permeability (Airl: md ,~00 ~0 ~0 ~0 .~75~. POINT NcINTYRE EXPLORATORY EXPLORATORY (t~69~-i25i2 feet) ~oPe Laberater~ee LEGEND - Cumulat[ve FPequency ...... CumuZatlve Capacity Loa~ Grain Density Histogram 90 ~0 70 ~0 ~0 2.40 gm/cc 70 40 3(} POINT Hc~NTYRE ~ ~XPLO~ATORY - LEGEND - SURFACE CORE GAMMA LOG CORE 1 AND 2 E~PL OI~AT ORY TRANSMITTALS Wo,st. om Arise International CORE LABORATORIES TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT TO' Materials received via- Items received: !).~.~ [~'~,zo,~c~ PLEASE RETURN ONE COPY Received by: for Core Lab Date- for Date - ** Please note that the items listed above are inventoried, shipped,and received in good faith, but are subject to minor adjustments because of possible unintentional human error. In such a case, both shipper and receiver agree to make a timely and bona fide ef£or~ ~;o correct any observe. ~tmcrepancies.' ARCO ALASKA, INC. POINT MclNTYRE #4 EXPLORATORY SAMPLES ANALYZED BY MINERALOG CORE 1 CORE 2 11691.3 11692.3 11693.7 11694.4 11695.2 11696.4 11697.6 11699.6 11701.2 11702.4 11703.6 11705.3 11706.1 11707.4 11708.4 11718.8 11731.5 11748.4 11763.3 11766.1 PT. MclNTYRE REPORT SUMMARY 3-18-89 Release rig from Pt. Mclntyre #3 @ 2400 3-17-89 and start move to #4. Begin NU BOP @ 0600. 3-19-89 PRESENT ACTIVITY: DRILLING @ 694' DEPTH: 694' PROGRESS: 584' MW: 8.7VIS: 65 ACCEPT RIG: 06003-18-89 SPUD: 15303-18-89 Accept rig @ 0600 3-18-89 and NU diverter system. Mix spud mud, PU BHA and spud well @ 1530 3-18-89. Drill from 110' to 500'. Circ bottoms up and TOH. Change BHA and TIH. Drill 500' to 694'. 3-20-89 PRESENT ACTIVITY: DRILLING @ 1645' DEPTH: 1645' PROGRESS: 951' MW: 9.0 VIS: 58 Dyna drill and survey 694' to 1025'. Drop survey and TOH, change BHA. PU DP and stand back while waiting on cuttings hauling equipment. Super sucker trucks down. TIH and dyna drill and survey 1025' to 1645'. 3-21-89 PRESENT ACTIVITY: DRILLING @ 2706' DEPTH: 2706' PROGRESS: 1061' MW: 9.1 VIS: 50 Dyna drill and survey 1645' to 1862'. TOH and change BHA, TIH. Rotary drill and survey 1862' to 2382', circ bottoms up and TOH and PU motor assembly. TIH, dump valve failed open on motor, TOH and change out motor. TIH and dyna drill and survey 2382' to 2706'. 3-22-89 PRESENT ACTIVITY: DRILLING @ 4130' DEPTH: 4130' PROGRESS: 1424' MW: 9.5 VIS: 46 Dyna drill/rotary and survey 2706' to 3905'. Change shaker screens and continue drill and survey 3905' to 4130'. 3-23-89 PRESENT ACTIVITY: TOH FOR 13-3/8" CASING DEPTH: 5202' PROGRESS: 1072' MW: 9.7 VIS: 42 Dyna drill/rotary 4130' to 4166'. Circ, drop survey and TOH. Change bit and TIH. Change dies and saversub in top drive. Test MWD and continue in hole. Dyna drill/rotary 4166'to 4490'. Circand change shaker screens. Continue drilling and survey 4490't~ ~E, CE.i 5202'. Circ bottoms up, drop survey and TOH SLM for surface casing. 3-24-89 PRESENT ACTIVITY: NU BOP DEPTH: 5202' PROGRESS: 0' MW: 9.7 ViS: 42 Finish TOH. RU and run 131 its 13-3/8" 68# L-80 BTC and 2 jts 684t K-55. Shoe @ 5200', collar @ 5118'. Circ casing capacity and cement with 3300 sx AS III @ 12.1 ppg and 700 sx class G with additives @ 15.8 ppg. Displace with 10 bbls water and 764 bbls mud. Did not bump plug. Had full returns throughout job, but did not circulate cement to surface. CIP 2100 3-23-89. Raise diverter and perform top job with 35 sx AS I. Set slips with 100,000 #, cut off casing and continued ND diverter. 3-25-89 PRESENT ACTIVITY: PU BHA DEPTH: 5202' PROGRESS: 0' MW: 9.7 VIS: 42 Make final cut on casing and weld on 13-5/8" braden head. Slip new drilling line while waiting on head to cool. NU BOP. Test BOP to 5000 psi, hydril to 3500 psi. Checked accumulator, OK. Install wear ring and PU BHA. 3-26-89 PRESENT ACTIVITY: DRILLING @ 5556' DEPTH: 5556' PROGRESS: 354' MW: 9.1 VIS: 35 Finish PU BHA. TIH to 1050' and circulate out heavy mud. Continue TIH and tag cement @ 4816'. Circ out thick mud and test casing to 2500 psi, OK. Drill hard cement 4816' to 5190' and test casing to 2500 psi, OK. Drill out to 5210' and perform leakoff test to 14.36 EMW. Dyna drill w/rotary 5210' to 5556'. 3-27-89 PRESENT ACTIVITY: REAMING TO BOTTOM DEPTH: 5590' PROGRESS: 34' MW: 9.2 VIS: 36 Saver sub on top drive broke. TOH to shoe and repair top drive. TIH and drill 5556' to 5590' assembly would not slide. Mixed 2 drums of mud detergent without success. TOH to E drillpipe, replace rig timbers and continue LD E pipe. Change BHA, PU new bit and TIH. Ream 155' to bottom. 3-28-89 PRESENT ACTIVITY: PREPARE TO TOH DEPTH: 6997' PROGRESS: 1407' MW: 9.3 VIS: 35 Dyna drill w/rotary 5590' to 5864'. Backed off above saver sub attempting to make connection. Screwed back in. Pipe stuck, unable to rotate or work jars. Pumped 235 bbl water down DP (approx. 135 bbl in annulus) jarred down and was able to rotate. Circ and condition mud, lower mud weight from 9.4 to 9.2. Dyna drill w/rotary 5864' to 6997'. Lowered mud weight to 9.0, unable to keep weight down due to high penetration rate. Attempt to slide bit without success, out of gauge. Prepare to trip out. 3-29-89 PRESENT ACTIVITY: TIH W/BIT#9 DEPTH: 7365' PROGRESS: 368' MW: 9.5 VIS: 38 TOH, tight 6090'-6120' and 5586'-5867'. Change BHA and bit, TIH to shoe. Cut drilling line and circ at shoe. TIH and ream 5850' to 6997~'. Rotary drill 6997' to 7365'. MWD failed. Change out screen and work with tool without success. TOH, no tight spots but had 30M drag. Change out MWD, PU motor and new bit and TIH. 3-30-89 PRESENT ACTIVITY: TOH FOR BIT DEPTH: 8007' PROGRESS: 642' MW: 9.3 VIS: 40 WL: 9.2 TIH to shoe and circ to test MWD. TIH to 7265' and log with MWD to 7364'. Drill and survey 7364' to 8007'. Circ and drop survey and TOH for bit. NOTE: MWD did not fail 3-29. A washout was found between the up and down jars. 3-31-89 PRESENT ACTIVITY: DRILLING@ 9152' DEPTH: 9152' PROGRESS: 1145' MW: 9.3 VIS: 39 WL: 8.8 Finish TIH with bit #10. Drill and survey 8007' to 9152'. 4-1-89 PRESENT ACTIVITY: DRILLING @ 9687' DEPTH: 9867' PROGRESS: 535' MW: 9.4 VIS: 42 WL: 7.4 Drill and survey 9152' to 9378'. Circ bottoms up and TOH to shoe. Install block dolly and cut and slip drill line. Finish TOH and change bits. TIH to shoe, check MWD and service top drive. Finish TIH and drill and survey 9378' to 9687'. 4-2-89 PRESENT ACTIVITY: TIH, TEST MWD DEPTH: 10068' PROGRESS: 381' MW: 9.4 VIS: 40 WL: 7.2 Drill and slide 9687' to 9814'. Change swab in pump 2. Continue drill and slide 9814' to 10068'. Drop survey and TOH. Change bit and BHA and TIH. Test MWD. 4-3-89 PRESENT ACTIVITY: DRILLING @ 10855' DEPTH: 10855' PROGRESS: 787' MW: 9.5 VIS: 41 WL: 6.1 Drill and slide 10068' to 10855'. 4-4-89 PRESENT ACTIVITY: DRILLING @ 11126' DEPTH: 11126' PROGRESS: 271' MW: 9.6 VIS: 42 WL: 5.5 Drill and slide 10855' to 10909'. Circ bottoms up and TOH. Slip and cut drilling line at shoe and continue out of hole. PU new bit and change out MWD. TIH. Drill and slide 10909' to 11126'. 4-5-89 PRESENT ACTIVITY: LOGGING DEPTH: 11355' PROGRESS: 229' MW: 9.6 VIS: 40 WL: 5.9 Drill and slide 11126' to 11355'. Circ bottoms up, TOH, LD Dynadrill and MWD. Function and pressure test BOP. RU Schlumberger and RIH with DIL/BHC/GR to 11024'. Stopped on a ledge, unable to go further. Log out, change centralizer arrangement and RIH for pass #2. 4-6-89 PRESENT ACTIVITY: RUN 9-5/8" CASING DEPTH: 11355' PROGRESS: 0' MW: 9.7 VIS: 39 WL: 6.0 Unable to get any deeper with second run, POH and PU SWC gun. RIH and attempt 24 shots, recovered 16. RD Schlumberger. TIH to shoe, cut drilling line and service rig. Continue in hole, ream 4 stands to bottom. Circ and condition well for casing. TOH, LD BHA. Change rams and bales, RU casing crew. Begin running 9-5/8" casing at 0500. 4-7-89 PRESENT ACTIVITY: TIH TO DRILLOUT DEPTH: 11355' PROGRESS: 0' MW: 9.7 VIS: 39 WL: 6.0 Continue running 9-5/8" casing. Ran 118 jts 9-5/8", 47#, L-80, BTC-AB MOD and 155 jts regular Butt. Shoe @ 11348', collar @ 11262'. Circulated 829 bbls @ 10.5 BPM. RU Dowell and cemented with 50 bbls CW 100 @ 8.3 ppg and 30 bbls Spacer 3000 @ 10.6 ppg followed with 630 sx class G with 2.0% D-46 & 0.35% D-133 mixed @ 15.8 ppg, yield 1.15. Displaced with 10 bbl water and mud @ 8-12 BPM. Bumped plug with 3000 psi. Floats held OK. ClP 2005 4-6-89. Land casing and attempt to test hanger, no test. Change rams back to 5" and ND Bop to change seal rings on hanger. NU BOP and test break to 5000 psi, OK. PU 8-1/2" BHA and TIH. 4-8-89 PRESENT ACTIVITY: MAKING UP CORE ASSY DEPTH: 11691' PROGRESS: 336' MW: 9.6 VIS: 38 WL: 5.8 Continue in hole with 8-1/2" BHA. Cut drilling line and test casing to 3000 psi, OK. Drill float collar and hard cement 11259' to 11335'. Test casing to 3000 psi, OK. Drill out 11335' to 11365'. Circ and perform leak off test to 14.4 EMW..prill and survey ! !365'_ to11691'. Circ bottoms up and TOH for coring assembly. MU 8-1/2" coring assembly. 4-9-89 PRESENT ACTIVITY: CUTTING CORE#2 DEPTH: 11718' PROGRESS: 27' MW: 9.7 VIS: 40 WL: 6.0 Continue in hole with coring assembly. Cut core #1 11691' to 11706'. Core barrel jammed. TOH and LD core. Cut 15', recovered 15.2'. Service rig and TIH for core #2. Cut drilling line at shoe and continue in hole. Cut core #2 11706' to 11718'. Coring at report time. 4-10-89 PRESENT ACTIVITY: REAMING TO BOTTOM DEPTH: 11766' PROGRESS: 48' MW: 9.7 VIS: 42 WL: 5.8 Continue cutting core #2 11718' to 11766'. TOH and LD core. Cut 60', recovered 59'. PU BHA and TIH. Test MWD and continue in hole. Ream and log 110' to bottom. 4-11-89 PRESENT ACTIVITY: RAISING MW TO 9.9 DEPTH' 12153' PROGRESS: 387' MW: 9.65 VIS' 40 WL: 5.8 Drill and survey 11766' to 12093'. Circ for samples. TOH and PU coring equipment. TIH, slip and cut 140' drill line. Finish TIH and cut core #3 12093' to 12153'. Prepare for trip, well flowing slightly with pumps off. Circ and raise MW to 9.9. 4-12-89 PRESENT ACTIVITY: TIH FOR CORE4 DEPTH: 12153' PROGRESS: 0' MW: 10.0 VIS: 38 WL: 5.4 Circ and raise MW to 10.0. Check for flow and TOH. LD core #3. Cut 60', recovered 33.5'. Service rig and PU drilling assembly to ream core interval. TIH and ream to bottom. Had 3' of fill. Circ bottoms up and TOH. Cut drill line and PU coring assembly. TIH for core 4. 4-13-89 PRESENT ACTIVITY: TOH W/CORE 5 DEPTH: 12333' PROGRESS: 180' MW: 10.0+ VIS: 38 WL: 5.6 Continue TIH with 90' core barrel. Cut core #4 12157' to 12243'. TOH and LD core #4. Cut 86', recovered 87'. Service coring equipment and TIH for core #5. Cut drill line on trip in, Break circ and wash to bottom. Cut core #5 12243' to 12333'. TOH with core #5. 4-14-89 PRESENT ACTIVITY: TIH FOR CORE 6 DEPTH: 12333' PROGRESS: 0' MW: 10.0 VIS: 45 WL: 6.0 Continue TOH with core #5. LD core. Cored 90', recovered 91'. Test BOPE. PU drilling assembly to ream out core interval. TIH. Ream and log 12143' to 12333'. Circ bottoms up and TOH. PU core assembly and TIH. 4-15-89 PRESENT ACTIVITY: LAY DOWNCORE#7 DEPTH: 12513' PROGRESS: 180' MW: 10.0 VIS: 44 WL: 5.9 Continue TIH. Slip drill line and service top drive. Continue TIH. Cut core #6 12333' to 12424'. TOH and LD core #6. Cut 91', recovered 91'. Redress core equipment and TIH. Cut core #7 12424'-12513'. TOH and LD core #7. 4-16-89 PRESENT ACTIVITY: DRILLING@ 12787' DEPTH: 12787' PROGRESS: 274' MW: 10.0 VIS: 40 WL: 6.0 Continue LD core #7. Cut 89', recovered 90'. PU drilling assembly and TIH. Slip drill line and service top drive on trip in. Ream and log cored interval 12325' to 12513'. Drill ahead 12513' to 12787'. 4-17-89 PRESENT ACTIVITY: LOGGING RUN #2 DEPTH: 12845' PROGRESS: 58' MW: 10.2 VIS: 44 WL: 5.8 Continue drill 12787' to 12845'. TD well 0900 April 16, 1989. Circ bottoms up and short trip to casing shoe. Circ and condition well for logs. TOH-SLM. LD BHA. RU Schlumberger. RIH w/log #1 D__~IL/S_.DT/N__GT/A__MS EL TD 12830'. POH. Change tools and make logging run #2_.LDT/__CNL/EP_..T/~ML/PCD/G.R. Logging at report time. 4-18-89 PRESENT ACTIVITY: LOGGING CLEANOUTTRIP DEPTH: 12845' PROGRESS: 0' MW: 10.2 VIS: 50 WL: 5.0 POH with run #2, tool failed. Change tools and make logging run #3, no problems. RD Schlumberger. LD monel DC. RU Halliburton Logging and RIH with run #4, Rotary Sidewall Core Tool. Attempted 30 cores, recovered 21. POH, RD Halliburton. PU BHA and RIH for cleanout trip. Wash 12448' to 12550'. Wash and ream 12550' to 12845'. Kingak shale running 12575' to 12845'. Raising MW to control shale. 4-19-89 PRESENT ACTIVITY: TIH FOR CLEANOUT DEPTH: 12845' PROGRESS: 0' MW: 10.5 VIS: 45 WL: 5.3 Circ and raise MW to 10.5 to control Kingak shale. TOH, cut drill line on trip out. RU SOS RIH with run #5 F._.MS/GR/TCC/AMS tool went to 12610', hole sticky. Did not go below 12500' on repeat pass. POH, change tools and RIH with run #6 RFT/GR/TCC/AMS, tool failed. POH and change tools for run #7. Did not go below 12500'. Attempted 5 pressure sets in upper sand without success. Dropped into lower sand and took 1 gallon fluid sample. 6 gallon preflush sample chamber failed, POH. RD SOS. TIH for cleanout. 4-20-89 PRESENT ACTIVITY: CEMENTING 7" LINER DEPTH: 12845' PROGRESS: 0' MW: 10.5 VIS: 45 WL: 5.3 Continue TIH for cleanout. Washed 350' to 12826'. Spotted 16 ppg pill. TOH to 12600' and circ bottoms up. TOH, rabbit DP with 2-3/8" rabbit on TOH. Change rams and RU casing crew. Run 1601' 7", 29#, L-80 liner on 5" DP to 12620'. No tight spots. Circ and condition well for cement. Begin cementing 7" liner at report time. 4-21-89 PRESENT ACTIVITY: DRILLING CEMENT PBTD: 12743' MW: 10.5 VIS: 48 WL: 5.6 Batch mix 650 sx Class G with 1 gps D600, 0.4% D60, 0.05 gps D135, 0.25% D133 and 0.05 gps D47 @ 15.8 ppg, yield 1.16, WL: 48 cc/30 min. Preceeded cement with 30 bbls CW 100 and 30 bbls Spacer 3000 @ 11.5 ppg. Displaced with mud @ 8 bpm until cement rounded shoe, then slowed rate to 4 bpm. Reciprocated casing in 30' strokes while cementing. Had good returns throughout job. Bumped plug with 3000 psi and set hydraulic liner hanger. Unable to release from setting tool hydraulicly, released by rotation. CIP 0750 April 20, 1989. TOH, well U tubed for first 3 stands out. Cut drill line on trip out. Recovered liner setting tool. Change pipe rams, PU 48 jts 3-1/2" drill pipe, LD stabilizers, PU casing scraper and TIH. Tagged cement at 10588', 420' above liner top. Drill cement out to 10900'. 4-22-89 PRESENT ACTIVITY: DISPLACING TO BRINE PBTD: 12558' MW: 10.5 BRINE Continue drilling out cement 10900' to 10927'. Fell out to top of liner. Circ well. TOH and LD BHA. Cut drill line and service top drive. PU 6" bit and scraper and TIH. Drill hard cement 11008' to 11018'. Wash to 12394'. Drill hard cement 12394' to landing collar at 12473'. Test casing to 3000 psi, OK. Drill out hard cement 12473' to float collar at 12558'. Test casing to 3000 psi, OK. Displace hole to 10.5 ppg brine. 4-23-89 PRESENT ACTIVITY: RIH WITH GRYO PBTD: 12558' MW: 10.5 BRINE Continue displacing hole to brine. Test casing to 3000 psi, OK. TOH LDDP. RU Schlumberger and run GR/CET/CBT/TCC/CCL from12552' to 8800' with 0 and 1000 psi. Excellent bond indicated. TOC behind 9-5/8" casing 9580'. POH and PU GCT tool. RIH. 4-24-89 PRESENT ACTIVITY: NUTUBING HEAD PBTD: 12558' MW: 10.5 BRINE Continue running GCT 12552' to 10'. Good agree~ment with MWD surveys. Run VSP. RD Schlumberger. Pull wear bushing, change rams to 4-1/2", ND BOP and spacer spool. NU new tubing head and BOP. NOTE: drilled ice road in 18 spots, no water and grounded. 4-25-89 PRESENT ACTIVITY: DISPLACE WITH DIESEL PBTD: 12558' MW: 10.5/6.8 SIH with completion assembly. Set packer @ 10886' RKB. Tubing tail @ 11862'. Sheared out setting ball. Set BPV, ND BOP, NU tree. Tested packoff to 5000 psi. Pull BPV and set test plug. Tested tree to 250 and 5000 psi, OK. Pulled test plug and began displacing to diesel. 4-26-89 PRESENT ACTIVITY: RIG RELEASED PBTD: 12558' MW: 6.8 DIESEL Continue displacing well to diesel. Used 36500 gallons to displace. RU slickline and pull dummy from SSSV nipple @ 2032', pulled check valve from SPM @ 10801', and set dummy valve in SPM @ 10801'. Tested dummy valve with 1500 psi, OK. Set BPV and secure tree. Hauled brine to MI and cleaned pits. Arctic packed 13-3/8" x 9-5/8" annulus with 600 bbl fresh water, 400 sx AS I, and 130 bbls arctic pack. Average rate 5 bpm @ 500 psi. Released rig 0200 4-26-89. Begin move to Pt. Mclntyre #5. 4-27-89 PRESENT ACTIVITY: CONTINUE RIG MOVE Continued to move rig. Testing activities will begin after rig move. 4-28-89 PRESENT ACTIVITY: CONTINUE RIG MOVE 4-29-89 PRESENT ACTIVITY: MOVING IN SUPPORT EQUIPMENT PBTD: 12558' MW: 6.8 DIESEL All rig modules moved off by 1200. Began cleaning location in preparation for test. Began moving in support equipment and rigging up same. 4-30-89 PRESENT ACTIVITY: RIH W/BLIND BOX & WEIGHT BAR PBTD: 12558' MW: 6.8 DIESEL Continue rigging up support equipment. RU Veco and pressure tested Arctic Pack annulus to 2000 psi. Lost 50 psi in 90 minutes. Good test. Ru FMC and pull BPV. NOTE: McEvoy/Cameron valve pulling tool is necessary. FMC is not interchangable on this well. Conduct safety meeting and RU Schlumberger to perforate. PU gun #1,24' 2-1/8" Enerjet @ 6 SPF, 0° phasing. Test lubricator to 3000 psi. RIH with gun, unable to get tool completely out of tubing tail. Make multiple attempts to go down, without success. POH and examine gun. No markings on upper part of string, but bottom of strip gun bent indicating setting down on something. Call out new Schlumberger unit due to electrical problems. RU new unit and MU tool string of weight bar and CCL. Test lubricator to 3000 psi and RIH~ Entire string exited tubing tail and set down at 11894' CBT. Logged out with CCL to SPM above packer. Ran back in and hit obstruction at 12000'/hr. Solid hit, clean pickup. POH and RD SOS. Call out Otis slickline unit and RU. Test lubricator to 3000 psi and RIH w/2.62" impression block. Tag obstruction at 11863' WLM = 11894' RKB. POH and examine block. Marks indicate expended piece of shear out sub is blocking casing. Redress WL w/2.125" impression block w/2.70" centralizer and RIH. Impression confirms shear out sub piece obstructing casing. Change tool string to 2.25" blind box w/12' 1-7/8" weight bar, and knuckle joint. Pressure test to 3000 psi and RIH. 5-1-89 PRESENT ACTIVITY: RIH W/FLOPETROL TOOL PBTD:12518' WL=12549' RKB MW: 6.8 DIESEL RIH with blind box to obstruction at 11863' WL. Jar on shear out sub, knock loose, and chase to 12518' WL = 12549' RKB and tag up. POH, RD, MO Otis. Call out Schlumberger and RU to perforate. PU gun #1 as before. Test lubricator to 3000 psi and RIH. Make tie in pass and perforate 12200'-12176'. Tubing pressure increased from 0 to 675 psi. POH and LD gun, all shots fired (ASF). PU gun #2, 24' as before. Test lubricator and RIH. Tubing pressure had increased to 900 psi. Make tie in pass and perforate. 5-1-89 CONTINUED Continue perforating as shown in the following table. RUN # GUN LENGTH DEPTH PERFORATED ASF TIME OF SHOT 1 24' 12200'-12176' X 1420 4-30 2 24' 12176'-12152' X 1700 4-30 3 22' 12152'-12130' X 1940 4-30 4 24' 12112'-12088' X 2215 4-30 5 22' 12054'-12032' X 0115 5-01 TOTAL SHOT 116' After run 4, pull into lubricator and pressure test flowline. Tightened flanged connection to wing valve. Had several swivel leaks in the chicksan from the tree. RU tioga heater and warm choke manifold and iron on the tree. Flowline successfully tested to 3000 psi following run 5. Schlumberger reheaded cable for PRST tool and MU tool string. Pressure test lubricator and flowline to 3000 psi. Held safety meeting and start in hole with PRST tool string. 5-2-89 PRESENT ACTIVITY: FLOWING WELL TO CLEANUP PBTD:12518' WL=12549' RKB MW: NA RIH with PRST string. Tool reading pressure and temperature on trip in. Stopped RIH at 0715 when it was discovered a wireline bleed tank had overflowed spilling approximately 20 gallons of diesel on the ice. Notified environmental and initiated cleanup. Continue in hole with PRST string and latch into XN nipple at 11855'. Finish cleanup activities and prepare to flow well. With PRST valve closed, bled wellhead pressure from about 870 psi to 500 psi. Well open about 30 seconds. Closed well in and pressure built up indicating PRST not locked in. Tool signal lost and SOS unable to restart tool. POH and LD tool. SOS tore down tool finding sand in mechanism. Tool had been blown up hole and electric line kinked. Attempted to clean tool and reassemble. Threads would not make up properly, apparently gauled. Consult with Anchorage and RD, MO SOS. RU Otis slickline unit, pressure test to 3000 psi and set 3-1/2" testing recepticle in XN nipple at 11819' WL=11850' RKB. POH, RD slickline unit. MI and RU Otis EL unit and crane. Pressure test BOP, lubricator, and flowline to 3000 psi. RIH with EL shut in tool and latch into recepticle. Pull 1500# tension to close tool. Draw surface pressure from 860 psi to 400 psi and shut in. BHP remained constant at 4237 psi. Open well on 18/64" choke and perform initial 5 minute flow. Had to rock choke to remove possible obstruction and flow commenced. Initial BHP=4237 psi, BHT=162.5 °F. Lowest BHP in flow period 3991 psi, flowed 6 bbl. Shut well in for pressure buildup. T~sters inspected choke and found a piece of cloth in it. Kept well shut in for about 2 hours to allow Otis to get another computer on line. Open well on 24/64" choke at 0400 May 2, 1989. Heater choke surging and acting like an obstruction present. SD to clean choke. Had flowed 24 bbl. No obstruction found in choke. Change flow control to choke manifold near tree. Reopen well on 24/64" choke at 0500. Increase choke to 28/64" at 0510 and unload well. Fluid rate 80 bbl/hr, FTP=500 psi, BHP=3998 psi, BHT=171 °F. 5-3-89 PRESENT ACTIVITY: FLOWING WELL MW: NA Continue flowing well to cleanup. Increased choke to 36/64" and lit flare at 0630. Begin stabilized flow period at 1200 May 2, 1989. Representative rates as follows: TIME/DATE OIL RATE BBL 1200/5-2 2336 1800/5-2 3069 2400/5-2 2630 0600/5-3 2630 1200/5-3 2557 GAS RATE FTP WHT BHP BHT GOR MCF PSI OF PSI OF M/BBL 1690 1185 58 3879 173 .72 1706 1200 65 3873 174 .55 1715 1205 68 3876 175 .65 1738 1215 71 3879 175 .66 1728 1215 72 3882 175 .65 CHOKE 36 36 36 36 36 TOTAL THIS FLOW PERIOD: 3109 BBL 27 o APl OIL (INCLUDES LOAD DIESEL) 2046 MCF .69 sp. gr. GAS 182 BBL WATER (BRINE AND MUD FILTRATE) NOTE 1: Oil volumes based on half hourly tank straps. Gas volumes based on measured seperator rates. Average seperator pressure during flow 465 psi. No allowance has been made for gas vented from the storage tanks. NOTE 2: Power takeoff pump on Otis truck tore up spilling approximately 4 gallons hydraulic/transmission fluid under truck. Spill reported and cleaned up. 5-4-89 PRESENT ACTIVITY: FLOWING WELL MW: NA Continue flowing well at stabilized rate until 1200. Shut well in for pressure buildup at 1200. 5-5-89 PRESENT ACTIVITY: SI FOR PRESSURE BUILDUP MW: NA ContinUeDyke arrivedPressUreon IocationbUilduP'5-4.State of Alaska Division of Oil and Gas Representative Bill/~'~ 5-6-89 PRESENT ACTIVITY: MAKING SAMPLER RUNS Continue pressure buildup until 0815. Total shutin period 44.25 hours. Equalize across~lnC/~or,. SI tool. SITP @ 0815=670 psi, SITP @ 0830=1200 psi. Work EL to release tool. POH w/EL, tool sheared leaving prong in recepticle. RD Otis EL. RU Otis slickline. SITP=1750 psi. Pressure test lubricator to 3000 psi. RIH and recover prong. Make 2nd run and recover plug body. RD slickline. RU Schlumberger for spinner log. Open well on 28/64" choke at 1630 to stabilize for spinner log. Rate at 1800, 2046 bbl oil, 1.1 MM gas. Reduce choke to 24/64", rate at 1930, 1023 oil, 727 M gas. Made dynamic and stationary passes. Stationary counts indicated bottom interval (70' of perf) contributing 86% of flow, middle interval (24') 9%, and top interval (22') 5%. Opened choke to 28/64", rate at 2230, 1534 oil, 920 M gas. Made dynamic and stationary stops as before. Stationary production split 89% from lower interval, 11% from middle interval, and 0% from top interval. POH w/spinner and PU EL sampler. RIH for bottomhole samples. Shut well in @ 0230 with sampler on bottom. Took 3 samples, had one run fail. FINAL RATE: 1242 bbl, 802 M gas, FTP: 1420 psi PRODUCTION THIS FLOW: 564 bbl oil, 340 M gas 5-7-89 PRESENT ACTIVITY: RIGGING DOWN/WELLSECURED MW: 10.3 BRINE W/DIESEL CAP Continued sampler runs. Bubble point on 1st sample 4130 psi, bubble point on 2nd sample 4150 psi. No information on third. Schlumberger tagged TD @ 12514' RKB indicating 44' of fill. RD SOS and prepare to flow well. Open well to flow @ 1210. SITP=1550 psi. Had well on 1" choke by 1225. Continue to stabilize well. At 1240 a large slug of liquid came up that resulted in some carry over to the flare. Produced black smoke for about 1 minute. Smoke quickly disipated and there were no further upsets. The following flow rates were recorded on 1" choke. TIME OIL GAS FTP WHT (33:{ 1300 5042 1.5MM 960 60° 300 1330 4896 1.0MM 955 60° 210 1400 4896 1.1MM 965 63° 230 At 1400 began to open the choke until at 1407 the well was on 96/64". The following rates were recorded. 1430 5188 1.2MM 940 67° 220 1500 4750 1.2MM 940 71 o 250 1530 5992 1.2MM 940 74° 210 1600 4750 1.2MM 935 76° 260 1630 5188 1.2MM 930 80° 240 1700 5408 1.2MM 930 80° 230 Shut well in at 1700. Average rate 1430-1700, 5349 bbl, 1.22MM gas, GOR 228. PRODUCTION THIS FLOW: 1017 bbl oil, 230 M gas NOTE 1: As before oil rates are based on half hourly tank straps and gas volumes are metered seperator rates. Average seperator pressure during this flow period 590 psi. TOTAL PRODUCTION: 4690 bbl oil, 3616 M gas, 182 bbl water (Includes load diesel) All produced oil hauled to LPC, all gas flared, all water to Pad 3. Secure well, blow down testing equipment and make final measurements. RU Dowell to kill well. Pump brine through flowline and test equipment to clear crude. Pressure test to 3000 psi. Kill well with 175 bbl 10.3 brine and followed with 8 bbl diesel cap. Well pressure 0 on completion of pumping. RD Dowell and RU Otis slickline. Pressure test lubricator to 1000 psi. Run 1 sinker bar and tattletail. Tubing tail @ 11824' WL = 11855' RKB. WLTD = 12479' = 12510' RKB. Run 2 set 2.81" XN plug body in nipple @ 11815' WL = 11846' RKB. Run 3 set extended prong @ 11813'WL = 11846' RKB. Run 4 set dummy in SSSV nipple @ 2025' WL = 2056'. RKB. RD Otis. Will top well with diesel today and set BPV. Division of Oil and Gas representative left location evening of 5-6. 5-8-89 PRESENT ACTIVITY: RIGGING DOWN/WELL SECURED MW: 10.3 BRINE W/DIESEL CAP Top tubing off with diesel and set BPV. Well secured. Continue rig down. SUB. SURFACE DIRECTIONAL SURVEY E~UIDANCE [~ONTINUOUS r~OOL Company Well Name Field/Location Job Reference No. 73301 _ Logaed By: WARNER ARCO ALASKA, INC. PT. McINTYRE. STATE NO. 4 i II 1468'FSL~666'FEL~ec.l§~Tl~N~14E.N56°l~ PRUDHOE BAY, NORTH SLOPE, ALASKA Datq Nay 23,1989 Computed B~ LUDLAN , SCHLUHBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FaR ARCO ALASKAp ZNC. PT. MCINTYRE STATE WILDCAT NORTH SLOPEr ALASKA SURVEY DATE: Z3-APR-89 ENGINEER: 0. WARNER ~ETHOOS OF COPPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORI~. OISTo PROJECTED ONTO A TARGET AZIMUTH OF NORTH 56 OEG 13 ~Iq EAST ARCO ALASKA. INC. PT. MCINTYRE STATE WILDCAT NORTH SLOeE~ ALASKA COMPUTATTON DATE: 8-JUN-89 PAGE 1 DATE OF SURVEY.' 23-APR-89 KELLY BUSHING ELEVATION: 42.50 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SU~-SE~ COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG NIN DEG MIN 0.00 0.00 -42.50 0 0 N 0 0 E 100.00 100.00 57.50 0 15 S 21 37 E 200.00 ZO0.O0 157.50 0 14 S 44 22 E 300.00 300.00 Z57.50 0 11 S 66 33 E 400.00 400.00 357.50 0 16 S 56 6 E 500.00 499.99 457.49 0 36 S 66 26 E 600.00 599.93 557.,~ I 20 S 81 59 E F q. O0 699.87 657.37 4 21 N 81 11 E J.O0 799.37 756.97 6 37 N 76 6 E 9uO.O0 898.58 856.08 7 46 N 75 18 E 1000.00 997.50 955.00 9 12 1100.00 1095.92 1053.62 11 18 1200.00 1193.51 1151.01 13 52 1300.00 1290.09 1267.59 16 5 1400.00 1385.71 134,3.21 17 54, 1500.00 1480.34 1437.8& 20 4 1600.00 1573.48 1530.98 22 20 1700.00 1665.50 1623.00 23 36 1800.00 1756.80 1714.30 24, 29 1900.00 1847.46 1804.96 25 36 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. OEPARTURE SECTION SEVERITT NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG 2000.00 1936.65 1894.15 28 54 2100.00 2021.89 1979.39 34 5 2200.00 2102.08 2059.58 38 37 oo.oo ,o , 2L ~.00 2528.98 2,86.48 ,9 5 29'00.00 2595.79 2553.29 47 20 0.00 0.00 0.00 N 0.00 E -0.01 0.14 0.25 S 0.15 E -O.OZ 0.21 0.64 S 0.40 E 0.13 0.10 0.81 S 0.70 E 0.32 0.16 1.03 S 1.07 E 0.62 0.60 1.4, S 1.71 E 1.74 1.09 1.87 S 3.35 E 5.4,9 4.04 1.63 S 7.70 E 14.70 1.07 0.46 N 17.37 E 26.49 0.89 3.56 N 29.49 E 3000.00 2664.17 2621.67 ,6 48 3100.00 2731.96 2689.46 48 5 3200.00 2797.33 2754.83 50 24 33*00.00 2859.29 2816.79 52 50 3400.00 2919.07 2876.57 53 17 3500.00 2979.31 2936.81 52 25 3600.00 3041.08 2998.58 51 38 3700.00 3103.0, 3060.54 51 58 3800.00 3164.26 3121.76 52 5 3900.00 3226.26 3183.76 51 33 N 73 30 E 40.39 2.02 N 69 9 E 57.45 N 64 43 E 78.88 1.96 N 63 49 E 104.54 2.08 N 63 38 E 133.53 1.83 N 63 33 E 165.59 2.46 N 63 50 E 201.63 1.77 N 62 47 E 240°45 1.35 N 60 4,1 E 281.05 1.35 N 59 53 E 323.15 1.66 N 60 31 E 368.23 N 60 30 E ¢20.27 N 60 42 E ,79.79 N 61 36 E 543.10 N 61 11 E 608.37 N 58 26 E 676.29 N 55 8 E 748.20 N 52 52 E 822.62 N 54 15 E 898.67 N 54 38 E 973.04 N 54, 30 E 1045.98 N 53 4 E 1119.43 N 52 6 E 1194.92 N 52 4 E 1273.18 N 52 16 E 1353.15 N 52 57 E 1432.80 N 53 11 E 1511.33 N 52 52 E 1589.71 N 52 40 E 1668.62 N 53 , E 1746.95 0.00 N 0 0 E 0.29 S 31 ,5 E 0.75 S 31 58 E 1.07 S 40 49 E 1.,8 S 46 4 E 2.24 S 49 55 E 3.83 S 60 47 E 7.87 S 75 I E 17.38 N 88 28 E 29.70 N 83 7 E 7.43 N 43.62 E ¢4.25 N 80 19 E 13.09 N 60.36 E 61.76 N 77 45 E 21.71 N 80.38 E 83.26 N 74 53 E 33.03 N 103.67 E 108.81 N 72 19 E ¢5.99 N 129.88 E 137.78 N 70 30 E 60.41 N 158.81 E 169.91 N 69 10 E 76.43 N 191.46 E 206.15 N 68 14 E 93.89 N 226.48 E 245.17 N 67 28 E 113.16 N 262.44 E 285.79 N 66 40 E 134.30 N 298.95 E 327.73 N 65 ,8 E 4.54 5.29 3.08 1.96 1.93 4.11 3.12 1.89 2.93 1.33 156.74 N 338.18 E 372.73 N 65 7 E 182.38 N 383.63 E 424.78 N 64 34 E 211.77 N 435.57 E 484.33 N 6~. 4 E 242.40 N 491.26 E 547.81 N 63 44 E 273.53 N 548.97 E 613.34 N 63 30 E 307.50 N 607.95 E 681.30 N 63 10 E 346.99 N 668.06 E 752.80 N 62 33 E 391.20 N 728.02 E 826.47 N 61 44 E 436.60 N 789.15 E 901.87 N 61 Z E 479.63 N 849.83 E 975.84 N 60 33 E 0.90 2.31 2.53 I .65 0.56 1.38 0.11 0.80 1.27 0.48 521.83 N 909.36 E 1048o45 N 60 9 E 565.19 N 968.72 E 1121.54 N 59 ~4 E 611.34 N 1028.67 E 1196.62 N 59 16 E 659.60 N 1090.55 E 1274.51 N 58 49 E 708.82 N 1153.83 E 1354.16 N 58 26 E 757.25 N 1217.27 E 1433.59 'N 58 6 E 804.42 N 1280.20 E 1511.95 N 57 51E 851.59 N 1342.94 E 1590.18 N 57 37 E 899.52 N 1405.8.2 E 1668.97 N 5'7 23 E 9a6.79 N 1468.43 E 1747.20 N 57 11 E ARCO ALASKA, INC. PT. MCINTYRE STATE WILDCAT NORTH SLOPE9 ALASKA COMPUTATION DATE: 8-JUN-89 PAGE Z DATE OF SURVEY: 23-APR-89 KELLY eUSHING ELEVATION: 42.50 FT ENGINEER: O. WARNER INTERPOLATED VALUES FOR EVEN ZOO FEET OF MEASURED DEPTH TRUE SUB-SEa COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE 'IEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN FEET OEG/ZO0 FEET FEET FEET DEG NIN 4000.00 3297.85 3245.35 52 19 4100.00 3349.78 3307.28 51 10 4100.00 3412.21 3369.71 51 50 4300.00 3473.39 3430.89 52 33 4400.00 3534.09 3491.59 52 30 4500.00 3535.28 3552.78 52 0 4600.00 3657.10 3614.60 51 57 F ~O O0 3717.90 3675.40 53 2 1:00 3777.93 3735.43 53 0 4'~0.00 3838.26 3795.76 53 I 5000.00 3898.23 3855.73 53 4 5100.00 3958.51 3916.01 52 45 5100.00 &019.ZZ 3975.72 52 23 5300.00 4080.44 4037.94 52 5 5400.00 4142.81 4100.31 50 25 5500.00 4207.36 4164.86 49 21 5600.00 4273.09 4230.59 49 6 5700.00 4337.60 4295.1_0 49 57 5800.00 4402.03 &359.53 50 9 5900.00 4465.98 4423.48 SO 8 6000.00 4530.31 4487.81 49 43 6100.00 4594.65 4552.15 50 37 6200.00 6657.46 4614.96 52 7 6300.00 4720.05 4677.55 51 49 6400. O0 478! .57 4739.07 52 0 6500.00 4842.94 4800.44 52. 12 6600.00 4904.50 4~62.00 51 53 O0 5026.5! 4984.01 51 18 -u O0 5087.80 5045.30 52 0 7000.00 5149.68 5107.18 51 45 7100.00 5211.5;! 5169.01 5! 53 7200.00 5172.79 5230.29 52 25 7300.00 5333.67 5291.17 52 36 7400.00 5394.40 5351.90 52 26 7500.00 5455.91 5413.41 51 40 7600.00 5518.07 5475.57 51 33 77.00.00 5580.45 5537.95 51 9 7800.00 5643.56 5601.06 50 36 7900.00 5707.36 5664.96 49 55 N 52 50 E 1825060 N 53 9 E !903.99 N 51 41 E 1981.94 N 50 56 E 2060.72 N 51 21 E 2139.87 N 51 44 E 2218.71 N 51 57 E 2297.08 N 52 5 E 2376.26 N 52 23 E 2456.04 N 53 42 E 2535.65 N 55 T E 2615.64 N 55 27 E 2695.42 N 55 17 E 2774.87 N 55 28 E 2853.93 N 58 0 E 2932.07 N 58 14 E 3008.38 N 57 15 E 3083.71 N 56 48 E 3160.12 N 56 33 E 3236.58 N 56 15 E 3313.46 N 56 7 E 3390.03 N 56 18 E 3466.57 N 56 10 E 3544.39 N 55 18 E 3622.37 N 54 58 E 3701.19 N 54 11 E 3780.11 N 54 0 E 3858.86 N 53 36 E 3937.87 N 53 30 E 4017.18 N 53 16 E 4096.09 N 53 31 E 4174.55 N 53 41 E 4253.06 N 53 58 E 4332.01 N 54 6 E 4411.29 N 54 12 c. 4490.69 N 53 50 E 4569.48 N 52 53 E 4647.71 N 51 27 E 4725.67 N 50 57 E 4802.92 N 51 10 E 4879.62 0.70 994.35 N 1531.25 E 1815.77 N 57 0 E 0.69 1041.49 N 1594.02 E 1904.10 N 56'50 E 1.86' 1088.93 N 1656.08 E 1982.01 N 56 40 E 0.45 1138.65 N 1717.60 E 2060.74 N 56 27 E 0.56 0.56 1.13 0.61 0.58 2.05 0.29 0.39 0.68 1.23 2.58 1.26 2.18 0.76 1.18 0.49 0.86 1.54 0.35 1.72 0.36 0.83 0.90 0.24 0.65 0.73 0.23 0.44 0.66 0.21 0.66 0.92 I .18 1.13 0.51 1.00 1188.53 N 1779.45 E Z139.88 N 56 15 E 1237.70 N 1841.41 E 1218.71 h 5& 5 E 1286.22. N 1903.Z5 E Z297.11 N 55 56 E 1335.09 N 1965.81 E 2376.32 N 55 49 E 1384.12 N 2029.00 E 2456.14 N 55 41 E 1432.3t N 2091.54 E 2535.79 N 55 36 E 1478.58 N 1157.83 E 2615.80 N 55 34 E 1524.00 N 2223.43 E 2695.59 N 55 34 E 1569.04 N 2288.89 E 1775.05 N 55 34 E 1614.19 N 2353.80 E 2854.12 N 55 33 E 1657.21 N 2419.04 E 2932.25 N 55; 35 E 1697.09 N 1484.17 E 3008.52 N 55 39 E 1737.24 N 2547.95 E 3083.83 N 55 42 E 1778.96 N 2611.96 E 3160.23 N 55 44 E 1820.94 N 2675.87 E 3236'68 N 55 45 E 1863.44 N 2739.94 E 3313.56 N 55 46 E 1906.14 N 2803.49 E 3390.12 N 55 47 E 1948.66 N 2867.14 E 3466.67 N 55 47 E 1991.87 N 2931.86 E 3544.48 N 55 48 E 2035.66 N 2996.39 E 3622.47 N 55 48 E 2080.79 N 3061.03 E 3701.30 N 55 47 E 2126.51 N 3125.40 E 3780.23 N 55 46 E 2172.74 N 3189.22 E 3859.00 N 55 44 E 2219.48 N 3253.01 E 3938.03 N 55 41 E 2266.58 N 3316.91 E 4017.37 N 55 39 E ?.313.78 N 3380.28 E 4096.32 N 55 36 E 2360.62 N 3443.34 E 4174.82 N 55 34 E 2407.27 N 3506.59 E 4253.37 N 55 31 E 2453.91 N 3570.38 E 4332.35 N 55 29 E 2500.41 N 3634065 E 4411.66 N 55 28 E 2546.99 N 3699.02 E 4491.09 N 55 27 E 2593.17 N 3762092 E 4569.91 N 55 25 E 2639.83 N 3825.84 E 4648.20 N 55 23 E 2687.78 N 3887.5;5 E 4726.23 'N 55 gO E 2736.58 N 3947.85 E 4803.58 N 55 16 E 278~.94 N 4007.77 E 4880.38 N 55 12 E Afl.CO ALASKA INC. PT NCINTYR~ STATE gZLDCAT NORTH SLOPEe ALASKA COMPUTATZON DATE: 8-JUN-89 DATE OF SURVEY: 23-APR-89 KELLY BUSHZNG ELEVATZON: ,2.50 FT ENGINEER: 0. WARNER ZNTERPCLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVZATZON AZZNUTH DEPTH DEPTH OEPTH DEG MZN DEG NZN VERTZCAL DOGLEG RECTANGULAR COORDINATES HORZZo OEPARTURE SECTZON SEVERITY NORTH/SOUTH EAST/WEST O~ST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000.00 5772o46 5729.96 ,8 46 8100.00 5838.91 5796.,1 ,8 8 8200.005905.815863.31,7,6 8300.00 5972.78 5930.18 ,7 ,2 8500°006108.376065.874811 oo.oo 9000000 6431.0, 6388054 49 50 9100.00 ' 6495.40 6452090 50 6 9200.00 *"6559059 6517.09 ,9 55 9300°0~ 6614.08 6581058 49 45 9400.00 6688080 6646030 49 39 9500o00 6753.63 6711013 49 32 9600.00 6818044 6775.94 ,9 31 9700000 6883.39 6340089 49 32 9800000 6948.33 6905.83 49 36 9900000 7013009 6970.59 ,9 21 ~0000000 7078.91 7036.¢2 48 10 ~0100000 7146.50 7104.00 46 57 :0200000 7215.59 7173o09 45 1 ~0300.00 7288025 7245075 41 40 :0400000 736403, 7321.84 40 6 ~0500.00 7441.41 7398.91 38 34 0 0.00 : · 1000.00 7855073 7813.23 30 38 1100.00 7942.95 7900.,5 27 55 1200.00 8032014 7989.64 25 53 13-00.00 8122092 8080.42 23 48 1400.00 8215.07 8172.57 22 11 1500000 ~307.71 8265.21 22 · 0 1600000 8400.53 8358.03 21 35 1700000 8493.?0 8451.~0 21 1 1800.00 8587.18 8544.68 20 39 1900.00 8680.89 8639.39 ZO 8 N 51 32 E 4955.24 N 52 36 E 5029.77 N 53 27 E 5103.97 N 55 11 E 5178.19 N 55 36 E 5251.51 N 53 35 E 5325017 N 52 54 E 5400.48 N 53 3 E 5476092 N 53 10 E 5553.65 N 53 42 E 5630.09 N 54 I E 5706.58 N 53 54 E 5783.06 N 53 47 E 5859.67 N 53 41 E 5936°02 N 54 25 E 6012.20 N 54 47 E 6088.31 N 55 7 E 6164.45 N 55 8 E 6140048 N 55 44 E 6316.51 N 57 I E 6392.70 N 57 30 E 6467.96 N 57 18 E 6541.64 N 58 10 E 6613.92 N 59 53 E 6681050 N 61 0 E 6747.20 N 60 29 E 6810.68 N 59 29 E: 6871.69 N 57 56 E 6930.25 N 5'5 17 E 6985.59 N 55 4 E 7037.79 N 54 58 E 7089.43 N 54 49 E 7138.30 N 54 58 E 7183.50 N 55 39 E 7225.40 N 55 6 E 726,.24 N 54 58 E 7301.87 N 54 4¢ E 7339.06 N 54 23 E 7375.38 q 53 40 E 7410.87 N 53 14. E 7445.72 1.42 0.62 1.27 1.58 1.40 2.51 1.32 0.47 0.64 0.92 0.15 0.16 0.41 0.42 0.56 0.27 0065 0.19 lo24 1.33 1.67 1.07 4.02 4.05 0.63 2.19 1.98 Z.16 2.61 0.74 1.96 2.23 2.19 1.76 0.59 0.27 0.70 0.57 0.47 0.61 2832o~5 N 4066.97 E 4956.11 N 55 8 E 2878.36 N 4125.93 E 5030.73 N 55 5 E 2923.17 N 4185.23 E 5105.00 N 55 4 E 2966.43 N 42,5.58 E 5179026 N 55~'3 E 300T..71 N 4306.19 E 5252058 N 55 4 E 3050.30 N 4366.31 E 5326.25 N 55 3 E 3095.68 N 4426.56 E 5401063 N 55 I E 3141.82 N 4487.67 E 5478.16 N 55 0 E 3187.85 N 4549.19 E 5554.95 N 54 58 E 3233.60 N 4610.56 E 5631.46 N 54 57 E 3Z78059 N 4672'48 E 5708000 N 54 56 E 3323.60 N 4734.39 E 5784.53 N 54 55 E 3368.85 N 4~96.29 E 5861.19 N 54 54 E 3414.08 N 4857.89 E 5937.60 N 54 54 E 3458089 N 4919.57 E 6013.83 IN 54 53 E 3502.93 N 4981.67 E 6089096 N 54 53 E 3546.6, N 5044.04 E 6166011 N 54 53 E 3590.11 N 5106043 E 6242016 N 54 53 E 3633.43 N 5168.93 E 6318.20 N 54 53 E 3675.56 N 5232.41 E 6394.36 N 54 54 E 3716.14 N 5295.81 E 6469.57 N 54 56 E 3755.75 N 5357.96 E 6543019 N 54 58 E 3794077 N 5418.82 E 5615.43 N 54 59 E 3829.87 N'5477.84 E 6683.91 N 55 2 E 3861.85 N 5534030 E 6748.50 N 55 5 E 3892.66 N 5590.06 E 6811o87 N 55 8 E 3923.31 N 5662.96 E 6872.80 N 55 11 E 3953.61 N 5693.14 E 6931.30 N 55 13 E 3983.99 N 5739.40 E 6986.63 N 55 1, E 4014.04 N 5782011 E 7038.84 N 55 13 E 4043.49 N 5824053 E 7090.48 N 55 13 E 4071.52 N 5864058 E 7139.36 N 55 13 E 4097.66 N 590104'7 E 7184.58 N 55 13 E 4121.36 N 5936002 E 7226.48 N 55 13 E 4143.45 N 5967.98 E 7265.33 N 55 13 E 4165.05 N 5998.81 E 7302097 N 55 13 E 4186.39 N 6029.27 E 7340.16 N 55 13 E 4207.51 N 6058.84 E 7376.50 N 55 13 E .4218.33 N 6087.62 E 7,12o00 N 55 13 E 4249.17 N 6115.61 E 7446.89 N 55 12 E ARCO ALASKAt INC. PT. MCINTYRE STATE WILDCAT NORTH SLOPEr ALASKA COMPUTATION DATE: 8-JUN-89 PAGE 4 DATE OF SURVEY: 23-APR-89 KELLY BUSHING ELEVATION: 4Z.50 FT ENGINEEr: 0. WARqEq T~TER~OLATE~ VaLUFS FOR EVEN 100 FEET OF MEASURED DEPTH To, UR SU3-SEA COURSE IEASUREO VERTICAL VFRT[CAL DEVIATION ~ZIMUTH DEPTH DEPTH OEDTH D~.G )lin DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/S.~UTH EAST/WEST DIST. &Z[MUTH FEET DEG/IO0 ~EET FEET FEET DES HIM zooo.oo Tzz. e ,.6 2100.00 8BSg.03 882.6.53 19 46 2200°00 g963°OS 8920.56 19 59 z oo.oo 9os .o zsoo.oo z,s. s szoz. s xe .00 9528.57 9~86.07 ~9 18 g ~.00 9571.0~ 9528.5~ 19 18 N 58 16 E 7479.8Z N 55 3 E 75[3.52 N 58 51 E 75~7.55 N 53 56 E 758[.6! N 51 30 E 7615.30 N ~9 !3 E 76~8.57 N" ~9 13 E 7681o39 N 49 13 E 7714.Z1 N 49 13 E 77~7.02 N ~9 13 E 7761.79 L._ ................. ., 0.71 0.26 0.65 0.28 0.79 2.03 0.00 0.00 0.00 0.00 4269.&Z q 6143.08 E 7~81.00 N 55 1Z E 4288°84 N 6170.68 E 751&.72 N 55 11 E 4308.30 N 6198.57 E 7548.75 N 55 11 E 4328.16 N 62Z6.25 E 7582.82 N 55 11 E ~348.5Z N 6253.16 E 7616.54 N 55 11 E 4369.84 N 6278.93 E 7649.87 N 55 9 E 4391.43 N 6303.97 E 7682.76 N 55 8 E 4413.03 N 6329.01 E 7715.65 N 55 6 E 4&34.63 N 6354.04 E 7748.5& N 55 5 E 4444.35 N 6365.31 E 7763.3~ N 55 4 E COHPUTATION DATE: 8-JUN-8**7 PAGE 5 ARCO 'ALASKAt INC. PT. ~CINTYRE STATE WILOCAT NORTH SLOP~9 ALASKA DaTE OF SURVEY: 23-APR-89 KELLY ~USHING =~LEVATZON: 42.50 FT ENGINEER: O. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TqUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG 0o00 0.00 -42.50 0 O 1000.00 997.50 955.00 9 12 2000.00 1936.65 1~94.15 28 54 3000.00 2664.17 2621.67 46 48 4000°00 3287.85 3Z45.35 52 19 5000.00 3898.23 3855.73 53 4 '; O0 5149.68 5107.18 51 45 8 O O0 5772.46 5729.96 48 46 9000.00 6431.04 6388.54 49 50 ,0000.00 7078.92 7036.42 ~8 10 ,1000.00 7855.73 7813.23 30 38 .2000.00 8774°88 8732.38 19 46 .2845.00 9571.04 9528.54 19 18 VERTICAL OOGLEG RECTANGULAR COORDTNATES HORIZ. DEPARTUR=~ SSCTION SEVERITY NOPTH/SOUTH EAST/bJE$T DIST. &ZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MTN N 0 0 E 0.00 N 73 30 E 40.39 N 60 31 E 368.23 N 54 30 ~_ 1045.98 N 52 50 E 1825.60 N 55 7 E 2615.64 N 56 7 E 3390.03 N 53 31 E 4174.55 N 51 32 ~ 4955.24 N 54 I E 5706.58 0.00 2. .02 4.54 0.90 0.70 0 0.86 0.23 1.42 0.15 0.00 N 0.00 E 0.00 N 0 0 E 7.43 N 43.62 E 44.25 N 80 19 E 156.74 N 338.18 E 372.73 N 65 T E 521.83 N 909.36 E 1048.45 N 60 9 E 994.35 N 1531.25 E 1825.77 N 57 0 E 1_.478.58 N 2157.83 E 2615.80 N 55 34 E 1906o14 N 2803.&9 E 3390.12 N 55 47 E 2360.62 N 3443.34 E 4174.82 N 55 34 E 2832.45 N 4066.97 E ¢956.11 N 55 8 E 3278.59 N 4672.48 E 5708.00 N 54 56 E N 57 30 E 6467.96 N 5~ 58 E 7089.43 N 54 16 ~ 7479.82 N 49 13 E 7761.79 1.67 1.96 0.71 0.00 3716.14 N 5295.81 E 6469.57 N 54 56 E 4043.49 N 5824.53 E 7090.48 N 55 13 E 4269.42 N 61~3.08 E 7481.00 N 55 12 E 44&~.35 N 6365.31 E 7763.34 N 55 4 E ARCO ALASKA9 ZNC. PT. MCINTYRE STATE HZLDCAT NORTH SLOPE9 ALASKA COMPUTATION DATE: 8-JUN-89 PAGE 6 DATE OF SURVEY: Z3-APR-89 KELLY BUSHING ELEVATXON: 42.50 FT ENGINEER: O. ~6RNER INTERPOLATEO VALUES FOR EVEN 100 FEET O~ SUg-SEA DEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZTMUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN 0.00 0.00 -62°50 0 0 N 0 0 E 42°50 42.50 0.00 0 15 S 44 55 E 142.50 142.50 100.00 0 15 S 31 27 E 242.50 242.50 200.00 0 12 S 61 6 E 342.50 342.50 300.00 0 16 S 56 34 E ¢42.50 462.50 400.00 0 24 S 52 59 E I 'm-.51 562.50 500.00 0 56 S 73 12 E .54 662.50 600.00 2 4 N B9 40 E .4oBO 742.50 700.00 S 36 N 77 56 E 843°44 842.50 800.00 7 4 N 75 46 E 944.35 962.50 900o00 8 18 1045.64 1062.50 1000.00 10 1 1147.60 1142.50 1100.00 12 32 1250.59 1242.50 1200o00 14 59 1354.69 1362.50 1300.00 17 5 1459.85 1442.50 1400.00 18 59 1566.56 1542.50 1500.00 21 40 1674.93 1642.50 1600.00 23 20 178~.31 1742.50 1700.00 24 22 1894.50 1842.50 1800.00 25 29 2006.75 1942.50 1900.00 29 14 2125.13 2042.50 2000.00 35 23 2252.2, Z1,2.50 2100.00 39 29 Z383.56 2242.50 2200.00 41 35 2520.57 2342.50 2300.00 45 5 2667.18 24,2.50 2400.00 ,8 27 ~-'~.64 2542.50 2500.00 48 39 41 2642.50 2600.00 66 67 3~.~ 85 2742.50 2700.00 48 25 '272.26 2842.50 2800.00 52 15 3439.13 2942.50 2900.00 53 3 360Z.29 3042.50 3000.00 51 38 3'764.37 3142.50 3100.00 52 19 3926. l& 3242.50 3200.00 51 46 ~088.42 3342.50 3300.00 51 10 r~249.30 3442.50 3400.00 52 16 ~,413.83 3542.50 3500.00 52 27 ~576.~5 3642050 3600°00 51 46 ~741.00 3742.50 3700.00 53 6 ~907.06 3842.50 3800.00 53 3 VERTZCAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SECTZON SEVERITY NORTH/SOUTH EAST/MEST OZST. AZZMUTH FEET OEG/IO0 FEET FEET FEET DEG MZN 0.00 0.00 0.00 N 0.00 E 0.05 1.74 0.03 S 0.09 E -0.03 0.08 0.43 S 0.25 E 0.03 0.16 0.74 S 0.53 E 0.20 0.31 0.90 S 0.84 E 0.40 0.33 1.18 $ 1.27 E 0.97 0.68 1.63 S 2.25 E 2.69 3.30 1.95 S 4.54 E 8.95 2.65 0.93 S 11.38 E 19.57 0.97 1.72 N 22.39 E N 76 58 E 32.34 1.54 N 71 38 E 47.69 2.56 N 66 45 E 67·06 2.56 N 63 58 E 91.36 2.51 N 63 37 E 120.01 1.97 N 63 25 E 152.27 2.92 N .53 54 E 189.16 2.35 N 63 11 E 230.56 1.23 N 61 Z E 274.62 1.27 N 59 5Z ~ 320.78 1.50 N 60 31 E 371.59 N 60 2,R E 434.61 N 61 12 E 512.77 N 61 22 E 597.50 N 57 44 E 690.90 N 53 14 E 798.01 N 56 33 E 914.26 N 56 37 E 1023.01 N 52 49 E 1131.24 N 52 2 E 1251.16 N 52 33 E 1384.42 N 53 11 E 1513.12 N 52 37 E 1640.47 N 52 58 E 1767.43 N 53 13 E 1894.99 N 51 2 E 2020.69 N 51 25 E 2150.82 N 51 56 E 2278.67 N 52 10 E 2408°98 N 53 51 E 2541.29 4.67 5.16 0.94 1.85 3.93 2 3.08 0.72 2.59 1.00 0.12 0.36 0 0.55 0.99 0 0.37 0.23 2.0~ 5.14 N 35.47 E 9.70 N 50.89 E 16.77 N 69.66 E 0.00 N 0 0 E 0.09 S 68 19 E 0.49 S 30 6 E 0.91 S 35 34 E 1.23 S 43 4 E !. 74 S ~7 2 E 2.7B S 56 5 E 4.94 S 66 44 E 11.42 S 85 ZO E 22.46 N 85 35 E 35.84 N 81 65 E 51.80 N 79 12 E 71.46' N 76 25 E 27.18 N 91.74 E 95.68 N 73 29 E 39.94 N 117.67 E 124.26 N 71 16 E 54.41 N 146.80 E 156.56 N 69 39 E 70.90 N 180.16 E 193.61 N 68 31 E 89.&0 N 217.59 E 235.24 N 67 39 E 110.05 N 256.78 E 279.37 N 66 48 E 133.10 N 296.90 E 325.37 N 65 51 E 158.39 N 341.11 E 376.09 N 65 5 E 189.47 N 396.14 E 439.12 N 64 26 E 227.85 N 464.50 E 517.38 N 63 52 E 268.32 N 539.36 E 602.42 N 63 33 E 315.32 N 620.30 E 695.84 N 63 3 E 376.31 N 708.36 E 802.12 N 62 I E 445.68 N 801.82 E 917.36 N 60 55 E 508.55 N 890.60 E 1025.57 N 60 16 E 572.34 N 978.14 E 1133.29 N 59 39 E 646.03 N 1073.14 E 1252.59 N 58 57 E 727.94 N 1178.66 E 1385.33 N S8 18 E 805.49 N 1281o63 E 1513.73 N 57 51 E 882.36 N 1383043 E 1640.86 N 57 28 E 959.14 N 1686.81 E 1767.66 N 57 8 E 1036.10 N 1586.80 E 1895.11 N 56 51 E 1113.29 N 1686.40 E 2020.73 N 56 34 E 1195.60 N 1788.02 E 2150.82 N 56 16 E 1274.84 N 1886.70 E 2278.66 N 55 58 E 1355.23 N 1991.71 E 2409.05 N 55 46 E 1435.63 N 2097.10 E 2541.43 N 55 36 E ARCO &LASKA, INC. PT,, MCINTYRE STATE WILDCAT NORTH SLOPE'~ ALASKA COMPUTATION DATE: 8-JUN-89 PAGE · DATE DF SURVEY: 23-APR-89 KELLY BUSHING ELEVATION: 42.50 FT ENGINEER: D. NARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH T~UE SUB-SEA COURSE qEASURED VERTICAL VE~T'[C~L DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG 50T3o52 3942.50 3900°00 52 50 5238.03 40¢2°50 4000.00 52 15 5399.51 4142.50 4100o00 50 25 5553.67 4242o50 4ZO0°O0 48 51 5707,.60 4342°50 &300.O0 49 56 5863.35 4442.50 &~O0.O0 50 12 .6(P" 8.78 454.2°50 4500.00 49 42 3.18 4642°50 4600.00 51 11 6~j6o54 4742.50 4700°00 52 4 6499o Z8 4842.50 4800.00 52 12 6661.75 4,942.50 4900.00 52 23 6988.40 514,2o50 5100o00 51 44 S O0.O0 00.00 8Z54o79 5942.50 5900.00 47 57 840Z.53 6042.50 6000.00 8551.69 6142.50 6100°00 48 59 8706.50 624,2.50 6200.00 50 11 8862°36 634,2.50 6300.00 49 57 9017.76 644,2.50 6400.00 49 50 9~" 3.45 6542.50 6500.00 49 59 9( }.48 6642.50 6600.00 49 41 9~uZ.85 6742.50 6700.00 49 31 9636,,97 6842.50 6800.00 49 29 9791.01 6942.50 6900. O0 4,9 34 9944°94 7042.50 7000. O0 48 55 0094.13 714Z.50 7100.00 47 0 0237.59 7242.50 7ZO0.O0 43 52 0371.43 7342.50 7300°00 40 12 0501.40 T442.50 7400.00 38 33 0627.36 7542.50 7500.00 36 21 0749.68 7642.50 7600°00 ~3 40 0867°74 7742.50 7700. O0 31 18 0984.60 7842.50 7800.00 30 53 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FE~T DEG qIN N 55 23 E 2674.33 N 55 10 E 2804.93 N 57 59 E 2931.69 N 57 45 E 3048.93 N 56 48 E 3165.92 N 56 24 E 3285.32 N 56 11 E 3404.32 N 56 13 E 3525.85 N 55 5 E 3651.20 N 54 11 E 3779.55 0.48 0.20 2.61 I .03 0.67 0.56 0.77 0.43 1.01 0.83 1512.04 N ZZ06.06 E 2674.50 N 55 34 E 1586.20 N Z313.58 E 2805.12 N 55 33 E 1657.01 N 2418.72 E g931.BT N 55: 35 E 171B.57 N 2518.59 E 3049.06 N 55 41 E 1782.14 N Z616.81 E 3166.0Z N 55 44 E 1847.85 N 2716.51 E 32.~5.42 N 55 46 E 1914.11 N Z815.35 E 3404.41 N 55 47 E 1981o56 N Z916.45 E 3525.95 N 55 48 E 2052.14 N 3020.05 E 3651.30 N 55 48 E 2126.18 N 3124.94 E 3779°66 N 55 ~,6 E N 53 41 E 3907.49 N 53 23 E 4037.77 N 53 30 E 4165.44 N 53 49 E 4,292.66 N 54 6 E 4422.84 N 53 58 E 4552°48 N 52 19 E 4678.44 N 50 57 E 4801.63 N 51 15 E' 4920o86 N 52 38 E 5033.76 N 54 26 E 5144.62 N 55 34 E 5253.36 N 52 57 E 5363.93 N 53 5 E 54'81.91 N 53 22 E 5601.29 N 54 0 E 5720.15 N 53 4~ E 5839.37 lq 53 49 E 5957.73 N 54 44 E 6075.Z7 N 55 8 E 6192.51 1.24 0°44 0.30 0.97 0.18 1.02 1.29 0.52 1.27 0.59 1 1 1°07 0.43 0.69 0.19 0.49 0.65 0.11 0.44 2201.43 N 3228.53 E 3907.64 N 55 42 E 2278.87 N 3333.47 E 4037.98 N 55 38 E 2355.20 N 3436.01 E ¢165.71 N 55 34 E 2430.68 N 3538.57 E 4292.98 N 55 30 E 2507.19 N 3644.01 E 4423.22 N 55 28 E Z583.16 N 3749.17 E 455Z.91 N 55 26 E 2658.51 N 3850.31 E 4678.95 N 55 g2 E 2735.76 N 3946.85 E 4802.29 N 55 16 E 2810.88 N 4040.04 E 4921.69 N 55 10 E 2880.78 N 4129.11 E 5034.73 N 55 5 E 2947.10 N 4218.13 E 5145.68 N 55 3 E 3008.75 N ~307.71 E 5254.42 N 55 4 E 3073.57 N 4397.38 E 5365.05 N 55 2 E 3144,.83 N 4491.66 E 5483o15 N 55 0 E 3216.45 N 4587.38 E 5602.64 N 54 57 E 3286.56 N 4683.47 E 5721.57 N 54. 56 E 3356.85 N 4779.89 E 5840.87 N S4 55 E 3&Z6.94 N ~875.41 E 5959.32 N 5~ 53 E 3495.40 N 4971.03 E 6076.92 N 54 53 E 3562°68 N 5067.07 E 6194.18 N 5~ 53 E N 55 37 E 6309.66 N 57 2Z E 6426.68 N 57 20 E 6537.34 N 59 3 E 6640.14 N 60 45 E 6728.85 N 60 27 E 6811.55 N 59 14 E 6887.99 N 56 44 E 6958°35 N 54 47 E 7021.07 FI 55 8 E 7081.53 1.11 0.96 1.05 3.09 0.67 1.71 3.99 0.58 1 3629.55 N 5163.28 E 6311.35 N 54 53 E 3693.95 N 5260,,,99 E 6428.32 N 54. 55 E 3753.43 N 5354°35 E 6538.90 N 54. 58 E 3808.39 N 5441o26 E 6661.62 N 55 0 E 3852.90 N 5518o20 E 6730.19 N 55 4, E 3893.09 N 5590.82 E 6812.74 N 55 8 E 3931.63 N 5657.00 E 6889.08 N 55 12 E 3968.71 N 5716.86 E 6959.39 N 55 13 E 4,004.4Z N 5768.43 E 7022.12 N 55 13 E 4038.97 N 5818.06 E 7082.59 N 55 13 E ARCO ALASKA, INCo PT. MCINTYRE STATE ~4 WILDCAT NORTH SLOPE9 ALASKA COMPUTATION DATE: 8-JUN-89 DATE OF SURVEY: 23-APR-89 KELLY BUSHING ELEVATION: 42.50 FT ENGINEER: O. WARNER ~NTERPDLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 1099.49 7942.50 7900.00 27 56 121,.$0 8042.50 8000.00 25 38 1321.378142.508100.00232, 14Z9.61 8242.50 8ZO0.O0 Z2 8 1537.51 8342.50 B300.O0 21 54 I[~":;.09 8442.50 8400.00 21 19 .Z3 8542.50 8500.00 ZO ,6 I .,.08 8642.50 8600.00 20 23 1965.568742.508700.001954 2071.8188,2.508800.001943 Z178.12 8942.50 8900.00 19 58 2284.50 90¢2.50 9000.00 19 50 ~390.75 9142.50 9100.00 19 41 ~496.87 9242.50 9200.00 19 18 !845.00 9571.04 9528°54 19 18 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN N 54 49 E 7138.06 N 55 7 E 7188.48 N 55 31 E 7233.96 N 55 I E 7275.38 N' 55 I E 7315.90 N 54 25 E 7355.55 N 54 7 E 7393.99 N 53 16 E 7431.58 N 53 48 E 7468.12 N 54 58 ~ 7504.00 N 55 3 E 7540.07 N 54 Z E 7576.35 N 51 44 E 7612.19 N 49 16 E 7647.54 N 49 13 E 7761o79 ' 2.22 2.30 1.91 0 0.27 0.60 0.48 0.61 0.54 O.1Z 0.40 0 0.89 1.80 0.00 4071.38 N 5864.38 E 7139.12 N 55 13 E 4100.52 N 5905.56 E 7189.56 N 55 13 E 4126.20 N 5943.09 E 7235.05 N 55 13 E 4149.84 N 5977.11 E 7276.47 N 55 13 E 4173.09 N 6010.30 E 7317.00 N 5;5 13 E 4195.97 N 6042.71 E 7356.66 N 55 13 E 4218.38 N 6073.96 E 7395.11 N 55 13 E 4240.68 N 6104.26 E 7432.73 N 55 12 E 4262.5¢ N 6133.61 E 7469.30 N 55 12 E 4283.38 N 6162.84 E 7505.19 N 55 11 E 4304.00 N 6192.44 E 7541.26 N 55 11 E ~325.07 N 62Z1.99 E 7577.56 N 55 11 E 4346.58 N 6250.7Z E 7613.43 N 55 11 E 4369.16 N 6278.15 E 7648.84 N 55 9 E 4444.35 N 6365.31 E 7763.34 N 55 4 E ARCO ALASKA, INC. PT. MCINTYRE STATE WILDCAT NORTH SLOPEr aLASKa COMPUTATION DATE: 8-JUN-89 DATE OF SURVEY: 23-APR-89 KELLY BUSHING ELEVATION: 42.50 FT ENGINEER: O. WARNER TqTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOE[Z. DEPARTURE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. aZIMUTH DEPTH DEPTH DEPTH OEG MZN OEG MIN FEET OEG/IO0 FEET FEET FEET DEG MIN ,1099.49 7942.50 7900.00 27 56 1211.50 80a2.50 8000.00 25 38 1321.37 8142.50 8100.00 23 24 1429.61 8242.50 8200.00 22 8 1537.51 8342.50 8300.00 Z1 54 1645o09 8442.50 8400.00 21 19 17~2.23 8542.50 8500.00 20 46 1[ ,.08 8642.50 8600.00 20 23 2178.12 6942.50 8900.00 19 58 2284.50 90¢2.50 9000,,00 19 50 2390.75 9142.50 9100.00 19 41 2496.87 9242.50 9200.00 19 18 2845.00 9571.04 9528.54 19 18 N 54 49 E 7138.06 N 55 7 E 7188.48 N 55 31 E 7233.96 N 55 I E 7275.38 N 55 ! E 7315.90 N 54 25 E 7355.55 N 54 7 E 7393.99 N 53 16 E 7431.58 N 53 48 E 7468.12 N 54 58 ~. 7504.00 N 55 3 E 7540.07 N 54 2 E 7576.35 N 51 44 E 7612.19 N 49 16 E 7647.54 N 49 13 E 7761.79 2.22 2.30 1.91 0.28 0.27 0.60 0.48 0.61 0.54 0.12 0.40 0.30 0.89 1.80 0.00 4071.38 N 5864.38 E 7139.12 N 55 13 E 4100.52 N 5905.56 E 7189.56 N 55 13 E 4126.20 N 5943.09 E 7235.05 N 55 13 E 4149.84 N 5977.11 E 7276.47 N 55 13 E 4173.09 N 6010.30 E 7317.00 N 55 13 E 4195.97 N 6042.71 E '7356.66 N 55 13 E 4218.38 N 6073.96 E 7395.11 N 55 13 E 4240.68 N 6104.26 E 7432.73 N 55 12 E 4262.5~ N 6133.6! E 7459.30 N 55 12 E 4283.38 N 6162.84 E 7505.19 N 55 11 E 4304.00 N 6192.44 E 7541.26 N 55 11 E 4325.07 N 6221.99 E 7577.56 N 55 11 E 4346.58 N 6250.72 E 7613.43 N- 55 11 E 4369.16 N 6278.15 E 7648.84 N 55 9 E 4444.35 N 6365.31 E 7763.34 N 55 4 E ARCO ALASKA, ZNC. PT. MCINTYRE STATE WILDCAT NORTH SLOPE, ALASKA MA~KER GCT LAST READING PBTD TO COMPUTATION DATE: 8.-JUN-B9 PAGE 9 DATE OF SURVEY: Z3-APR-89 KELLY BUSHZNG ELEVATION: &2.50 FT ENGINEER: D. ~ARNER ZNTERPOLATED VALUES FOR CHOSEN HORZZONS SURFACE LOCATION = 1468' FSL,666' FEL,SEC 16,TIZN,R14E,UM MEASUREO OEPTH TVO RECTANGULAR COORDINATES BELON KB FROM KB SUB-SE~ NORTH/SOUTH EAST/WEST 12502.00 9246.39 9203.89 4370.05 N 6279.18 E 12558.00 9300.19 9257.69 4382.36 N 6293.45 E 12845.00 9571.04 9528.54 4444.35 N 6365.31 E , SCHLUMBEROER O I REC T I ONAL SURVE Y COMPANY ARCO ALASKA. INC. WELL PT. MCINTYRE STATE ~4 FIELD WILDCAT COUNTRY USA RUN ONE DATE LOOOED 29 - APR - 89 REFERENCE '7330 j/ REF 73301 SCI~I_E = ! ! ~OOl:) I NYFT 4OO4:) sou'r. .EST 2OOO 4OOO GO00 8OOO 10000 ! 2000 ~, ~ ~ , ~ : ~ -- , . , --,-., u, u ZUO0 4000 ~ · -: ~ ~ : ~ ~ ~ ~ ~ ~ ~ m ~ ~ ~ ~ ~.'"T--T "' ~-.-~...4...~...&.~ ....... J..4..~ ~ ~ ~ : ~ ~ ~ ~ = , T'T-'? ..... z"',"-~ ...... ?'m"?'-~'" : ~: ~ : : ~? "'~"T'"TTM -'~'?'~-""~'~"--~ --~-~ ~ ~ : 2 ' t ~"-t-'T"?-~'~'T'-T'"t'"?"~"'~-t"'t'-4- '+-t"~ ~~ ~ ~~.._~: : L ~ ~ ~ {T~~-' "~-~-+-.-+...+---+ ...... +-.+..+4 ....... ~.4..~-L..4 Z 4 ~.~j-= ~ ~ Z ~ ~ TT"T"'T"'T"' ,,~ { :{{{ {{{~ {~;~ :, ~ ~S'r .... ~,'t"--~-t?-T.-+.-~-?-.r.r~.;.-..4.4.~-..~.Z~S-i j~{ ~T ' : ~ : ' ~ ~ · '"~' ~'''''' ............... ~ ' ' ' T ' ' ,~-~4-4 ...... M.~ ~ , ,_, , , ~ ~ ~ ~ ~..-~ '- · ' .-' ~ = = ...~..~_.~.~__~z ~ ~ T'T'"T'"T"T:"T"'~q?"r"i-"T ...... ~~?.4 .... ~-'.~--~.~-~~--i_ ~ ~.~: ~ : ~ ~ ] ~ ~ ~ ]~m-'~?~"~* ....... ~-e~..~.~..~*-~.~....~_,' : ~ : : : ~ ~ ~ ~ : . ~"~'~-~-~.-&*~-..&-.*..~...~-L..~...L.~_L ~ ~ ~ % ~&?'~T'T'- T~~ ~"'~'~"~-;-. -:.-~-~J.*L~.~-.' ..+~ . ~ : T ~-7""?~'~-~T~' ~T~-~-+'-'~-kf-~.-~~-&. 4-~.k~'~ [~I"T'F~-T--}"'t'¢?"~?"~-'~----++¢-4--~--:.-~-Z-., ' · . "'~"~+.-. ,--~-.-4--~4-~--~-~ ~ ~ ' · ~ ~ ~ : : : ~ ~ : ~ f : ~ : : ~'~"~"" -~-~- '-~-~- ~; : : ' ........ ~-~ .......... ~.~+ ,_~... ] .... ~ · . ~+.~ ....... ........ · .......... . t .... .~ ........ ~ .................. ~..~_~_&.~. _~ ~ · ' ' : [ ' .: : : _: ~ ~ ~ ~ ~ ~ ~ ~ T ~'~"~' '"T"~'"~'t'"t'"~?-~--+--'.--~-~ '--'..: : : ~... ~ , : ~ ~ ~ ~ ~ i ~ ..... , , .-' ~ ~ : ~ ~ ~ ~ ~'~-~ ~-.. ~. ~ ~ ~ , ~ : : : ~ ~ ~ : : T"~' '~-~'-.t.--~--~?.?.?--m-~.~-.~-4..+-+-~_ ~..4..¢...~..~ ~.~44.. ~-.~..;...~-~... ;4...~.4...LLZTZr~ ZZU?TTT'~" '-~~-- -~~.~.: ...~.-~..~_.~.....4..4...,.: _ _~ ~.~.~~..~ F t T~~7 .... ~~~ff- ---~..~-..~a..++.t ...... ;4...LL.~..ZZL~2;T;Z: ' ~ · , · ' : ~ ~ ; I : ; , ~ -~: , ~ ~...~..~ .... i ~ ~ l.~_, ..... . ~i~ ~ : ; ~ .... ~, ..... ~a- : ~.~_~ ~ ~ ~ ~'-~~m"'. i i-.~-: ; ~ ~--~-~&.-i-a-, ~ ~ ~ ~ ~ ~ T T"7 -4~._~.~_~ _:..: ; ; I ~ ~ : ~ ~ /: ~T- "T-~* ? ~ -~~-~-~.. ~...~ ~ ~ ~ + ~ ~ / : ii i i ! i ~ ~ T ~F"?'I-'rW-~-~-?-F'T'~f-~-k-~i-.-~.g4-.;-~!..i_~ ; I ~ i. ~ : : i i ~""~"':-I"~?T"vlT~'-?"~"I-T'-?ff-~-.~ .LJ i '~"-'i'-IT~'-T'"t~~ ~ t +-~~ ~--~-a~ F i.~T'T"T .... ~'T"?'Y'l'"i-ff'"t-'?q ?Oe-f..f~4.-.i.--O-. -4-..;4-..:-~4~.~- i i ' ~ ~. ; . ~'~ = ; ~-~ .... . .4~ ! ~ = i : I T ~ ? ..... ?'? ....... *"~'"?", ..... , ....... ,..., .... ....;..4..., ........ · ~ ~ ' ~ ; ~ . ' ..... +"~" -*'"*"4 4 ..... ' ' ~~ i, il ~-~T'7'7-~ ...... ~-4-5 ..... t"!'-?"*'"+ ...... ;"'+"'~... ,, : ~: ~+++~"*"'-~'"~'"~"*-~;";": '~ ~; :~:: "'?'"f~i 'fi-t-~--H.--~4--4.--+ ...... +...+...;-.;...~...+-.:...~...; .................... ~ ............................ .-~.~*-~-~-~.--&.~..~_~ ~ & . ~ ~ ~ , ~ T T ? T "7'"7'"7 ...... _, ....... , ............................. I; ................. ~ ......................... , L-~-, :. ~'~"?'s"~-r~ -~'"r~-~---r..~ ....... +.--v..;-.-;-~...+...:...; ............... :...;--4 .......... .... ; ~ ~ ; : i : ~ ~ : : ; : ' i i , · ! PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/2000 IN/FT 10000 NORTH AOGCC GEOLOGICAL MATEFUALS INVENTORY LIST .~ COMPLETION DATE K ! ''~6''1 ~ CO. CONTACT & NO. ' form ' recelx;ed received dale comments ~i]i~ ....... (/~e~ no c~mpi~ii°n repod 403 "' yes" no " sundry application ,, , 404 yes no report O~ Sunder' application , ,open .... teq0ired re'ceived Ca.ed required received ~roduclio~requhed reCeDed hole lo§ . hole Io9 I09 Mu~ ~ ~~: GC~ ~ ~ ~p ' DIUs~L"' ~ ~ ~ CNL PlIOD .... DLL , "' CUf' ~ ~ ~HESS " DHcISL CET ''~ ~ SPiHHEn " ~o~ciAc .... E~ ......... 0Y~E~ 6ATA uss ...... Pe'nF " s"~.y HEC SSS PACKER " DigilsI Y/a~( ~~" "' euc- " CHI_ l'e~ls ' ti- ' - .... u ~,_ _ _ i FDC ~WD ~equited ~eceived ~AMPLES requited tecei~ed MWD , , ML ~ ~ ~ .... core ~ , , CYHEH core LOOK , . , Anplysis ................... ~11 iii i i i ii AOGCC DETAILED WELL LOG INVENTORY PERMIT NO. dO~ - LOG TYPE RUN # INTERVAL SCALE 02) O3 ) ~1~2/~ / ~ + ,, 06) O7) ~~/~ - , 09 12) , 14) ~6) _ , , 18) AOGCC DETAILED W~,L LOG INVENTORY PERMIT NO. LOG TYPE RUN # INTERVAL SCALE 26) 27) 28) 29) 30) , , 31) 32) 33) 34 ) 35) 36) ARCO AL. ASKA, INC, DEVELOPMENT F,r. nrrlENCE=L.~,,~, TRANSMII'TAI.. TO' JOHN BOYLE AOGC SOOt F'ORCIJF'INE DR, ANCHORAGE, AK 995~t CRAIG MOXEI. EY- AAI TRANSMITTED HEREWITH ARE THE FOl..LOWING- [)NE: COF'Y ARCO' F'T~ MCINTYRE ~4 04-.25.-.89 O,H, TAF'E & L.I$1'ING RUN I = DIL/BHC/GR RUN 2 = DTE/$DT/I_DI'/CNI_ /NGT/ML. REF' ~7S29S RUN ~, :2 RECE:IF'I' ACKNOWI..EI)GMENT: RETURN RECEIPT TO' ARCO ALASKA, INC DEVELOPMENT GEOSCIENCE ATTN: LUCILLE JOHNSTON P, O, BOX ANCHORAGE, AL. ASKA 995 DATE' ANO--879E RECEIVED JUN t .3 ]989 Alaska Oil & Gas Cons. Commissio~ Anchorage PROCE,~,~ED BY' i..UCII..I..E ..JOHNSTON ARCO ALASKAt INCo DEVELOPMENT GEOSCIENCE TRANSMITTAL TO: JOHN BOYLE AOGC 3001 PORCUPINE DR. ANCHORAGE9 AK 99501 CRAIG MOSELEY- AAI JUNE 1, 1989 TRANSMITTED HEREWITH ARE THE FOLLOWING: ONE COPY ARCO: PT. MCZNTYRE ~ 05-17-89 CORE ANALYSIS REPORT CL FILE ~8P-3-13~5 1. CONV CORE ANALYSISt SERV DESCRIP & METHODOLOGY 2. CONV CORE ANALYSIS & SW ANALYSIS, TABULAR RESULTS 3. CONV CORE STATIS DATA g SURFACE CORE GAMMA LaG ~o TRANSMITTALS RECEIPT ACKNOWLEDGMENT: RETURN RECEIPT TO: ARCO ALASKA9 INC. DEVELOPMENT GEOSCZENCE ATTN: LUCILLE JOHNSTON P. OD 80X 100360 ANCHORAGE, ALASKA 99510 Ancllorage ANO-879E PROCESSED BY: LUCILLE JOHNSTON ARCO ALASKA, I#C. DEV. & EXT GEOSCIENCE TI~,ANSI, IITTAL TO: JOHN BOYI,E - AOGC ,, ADDRESS: ~001 PORCUPINE . _ , -- FROM: _. CRAIG...MOSEW,EY - .AAI DATE: MAY 31_ 1989 Transmitted herewith are the followtnE: One Copy ARCO: PT MCINTYRE #4 04-23-89 Schlumb. GCT GYRO ~Y JOB #73301 RECEIPT ACKNOWLEDGMENT: ........ - DATE: Return receipt to: ARCO Alaska, Inc. DEV & EXT GEOSCIENCE ATTN: Lucllle Johnstorl ANoz° 879E P. O. Box 100360 Anchorage, Alaska 99510 Processed By: L. Jo ,hnst, o.n ,. _ _ ARCO ALASKA, INC. DEVELGFNENT GEOSCIENCE TRANSMiTTAL TO: JOHN 60YLE ACGC 3001 PORCUPiN3 ST ANCNORAGE, AK 99501 FROM: CRAIG G. MCSELEY- A~i MAY 5, 1959 TRANSMITTE~ MER2WITH ARE THE FOLLOWING: 1 BLUELINE & 1 SEPIA EACP ARCO: PT. MCiNTYRE m4 04-23-89 CBL(CBT) 5100-12522 5" RUN 1 " CET 8500-12~46 5" " " GYRO(GOT) lO.O-1250i " 04-23-89 OSA MCN 4705-I£500 RUN I 04-i9-89 RFT i2200-i2490 5" RUN 2 RECEIPT ACKNOWLEDGMENT: RETURN RECEIPT TO: ARCO ALASKA, DEVELOPMENT ATTN: LUCILLE JOHNSTON P. O. BOX 100360 ANCHORAGE, ALASKA 99510 INC. GEOSCIENCE 4NG-8?gE PROCESSED BY: LUCILLE JOHNSTON PERIOD OF CONFIDENTIALITY / ~'Em:~:r ~ ~'9-,/.$, 30-DAY FILING DATE RELEASE DATE.. COMMENTS B.~c.02 (05/89) ARCO AL. ASKA, I DEVELOF'MEiNT GEO$CIENCC. TRANSMITTAL. F:'ROH CRAIG G., MOSE:'LEY- AAi APRIL 24, ~r~,A~.,..,MII'TED HEREWI'T'H ARE. THE] F'OL.L..OWING i BL. UELINE & ~, SEPIA EACH ARCO' F:'T~ MCiNTYRE $4 C, 4-i 6-"8T, F'HYSiCAL F'H/TVD i i ~-i 2~4:"/ '2' " F'HY$ICAt.. FM/MD ..... i i ~.-i 284:':. ,~.~' "' APR ~ 5 19~9d Alaska Oil & Gas Cons. CommissJol-, Anchorage RE:CEiPT ACKNOWLEi)GHENT' DATE RE:TURN RECEiF:T TO' ARCO ALASKA, iNC, DEVELOPMENT GEOSCIENCE Al:TN: L. LJC i LI_E JUHNS¥ON----AN0-8?gE F'., O, BOX 100360 ANCHORAGE, ALASKA 995i~ F'ROCESSE.r,, BY' LLJCIL. LE JOHNSTON MEMORAN DUM State of Alaska ALASKA OIL AND GAS CONSERVATION COM~.~ISSION To: Lonnie C Smi DATE: March 30, 1989 Co~issioner; '~' FILE NO: D. HRH. 92 THRU: Michael T Minder ~'~~ Sr Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test AAI Pt McIntyre State 4 Permit No. 89-13 Exploratory Sec 16, T12N, R14E, UM FROM: Harold R Hawkins Petroleum Inspector Friday, March 24, 1989: I left BP PBU, subject of another report, for ~_AI Pt MCIntYre State 4 to witness a BOP test. Saturday, March 25, 1989: I witnessed the BOP test on Pt McIntyre ~Ate' 4'. '"~er~'''was'''~6n~-failure. I filled out an AOGCC, report which is attached; and made a schematic of wellbore that I witnessed.' In summary, I witnessed the BOP test on Pt McIntyre State 4. The tests were performed satisfactorily with the exception of one failure. The gas detectors were not operating. ARCO ordered an expert to repair same as soon as possible, and to call AOGCC when repaired. Attachments Attn: Called Gene cooper, AAI Operator, gas detectors and alarms were repaired and working, parts arrived April 11, 1989, and gas alarms repaired and working April 12, 1989. 02-00 lA (Rev. 8/85) '"~O~G 5184 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date ~/t~t/ Well Operator Location: Sec Drillin~ Contractor Ri~ #~ Representative Permit /7 ~asing Set Representative Location, General, K~ Well Sign General Housekeeping dJY Rig Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Visual / Gas Detectors Audio BOPE Stack Test Pressure Annular Preventer Pipe Rams Blind Rams Choke Line Valves / H.C.R. Va!vey- Kill Line Valves / Check Valve Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200~psig Full charge Pressure Attained: N2 j ~ ~ 0 ~~ ~ /2 /3~P7~_~ psig Controls: Master Remote ~/f Blinds switch cover~.~ ,, ,Kelly and Flopr Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves ./ff No. flanges ~ p s i g 2 ~-~ psig/~p min~P sec. rain -- sec. Test Pressure, Test Pressure Test Pressure Test Pres sure Test Pressure,_~ Adjustable Chokes ~ a Hvdrauical!y operated ch. oke ,, Test Time ~ hrs. Repair or' Replacement of failed equipment to be made within~/b~Z~ys and Inspector/ Commission office notified. . ~ Distribution orig. - AO&GCC CC - Operator cc - Supervisor Inspector ARCO Alaska, Inc. February 8, 1989 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Mr. Russ Douglas Subject: Permit to Drill Pt. McIntyre #4 Dear Mr. Douglas: Further to your conversation with Tom Maunder, attached executed originals of the well. If further information is 26~0. J~~~~/~egional Drilling Engineer Designation of Operator form required, please contact the in duplicate are for the subject undersigned at 066/PD3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner Standard Alaska Production Company 2. Address P.O. Box 196612 Anchorage, Alaska 99519-6612 3. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Property designation' State of Alaska Oil & Gas Lease ADL-365548 (portion) Legal description of property: Township 12 North, Section 11: SW¼ Range 14 East, ~,-~ M. Property Plat Attached -- 4. Name ofDesignated Operator ARCO Alaska, Inc. Address P.O. Box 100360 Anchorage, Alaska. 99510-0360 5. Effectivedatedesignation February !, 1989 6. Acceptance of operatorship for the above described property with all attendant responsibilities and obliga- tions is ;. :," ~ .... , ~'~ ,'':-'; ,~--. hereby acknowledged ' .... ARCO Alaska, Inc. By,;/;. r r.,~L. Dees Signed/- Title Vice President Date /";//,i' , 7. The owner hereby certifies that the foregoing is true and correct Standard Alaska Production Company F'-.q ,f,,-. / '. SigneBdY: M. H. Brownhill TitleVice President, Exploration - AK Date Form 10-411, 12-1-85 Submit in Duplicate ENG February Mr. C. V. Chatterton Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 GEOL ASS' FILE Subject: Application for a spacing exception for Pt. McIntyre #4 by Arco Alaska Inc. Dear Mr. Chatterton: Trustees for Alaska has no objection to the proposed spacing exception for Pt. McIntyre #4. However there is another issue concerning these wells which falls within the purview of the AOGCC and with which we are concerned. Attached are comments submitted to the Alaska Department of Environmental Conservation in response to solid waste disposal applications submitted by ARCO to ADEC for Pt. McIntyre #3 and #4, Pt. McIntyre #5, and West Storkersen #1. Each of these sets of comments are quite similar. Please note comment number 15 on page 13 of the Pt. McIntyre 3 and 4 comments. ARCO proposes to inject waste water into aquifers located at approximately 4000 feet in these wells. To the best of our knowledge, these aquifers have not been exempted for waste injection by the EPA. Also to the best of our knowledge, there has been no sampling of these aquifers for the empirical determination of the formation waters' total dissolved solids content.. In our opinion such waste disposal cannot be permitted unless formation water samples from the aquifers proposed for injection are obtained and analyzed in a legitimate manner under EPA supervision. The substitution of a well log interpretation by the applicant in lieu of the samples required by federal regulations should not be accepted. Should the formation waters contain in excess of 10,000 ppm Total Dissolved Solids as determined by EPA method 209 B listed in 40 CFR 136, then the aquifers are not a U.S. Drinking Water. If the formation waters contain less than I0,000 ppm, then the aquifers are considered to be U.S. Drinking Waters and require aquifer exemptions. These aquifer exemptions must be applied for by ARCO and issued by the EPA prior to the commencement of waste injection. Trustees has presented similar arguments on two previous sets of comments on applications requesting permits to inject waste into ~ ....... ~'~ 99~;ii0~'~ ~:~ ..... '~"~ 276~-4244 725 Christensen Drive~ Suite 4 A~ch©ra~?e~, ?~-~-~a ........ ~ ~::-~<,~?~ .. t00% Recycied ~o~d previously unexempted aquifers, summarized as follows- 1. ARCO's application for a UIC permit for its Pad 3 Oily Waste Injection Facility at Prudhoe Bay. ARCO has not yet responded to public comments on this application and EPA has not taken action on the permit. ARCO did not apply for an aquifer exemption for this facility, even though adjacent units such as the Standard Western Operating Area, the Kuparuk River Unit, and the Milne Point Unit have all obtained such exemptions. The acceptance of ongoing injection activities at Pad 3 by EPA, AOGCC and ADEC is curious to say the least. 2. UNOCAL's application for a UIC permit and an aquifer exemption for its Lewis River D-1 well. This aquifer exemption and permit are being processed by EPA and AOGCC. AOGCC and EPA are obligated to ensure that waste injection is allowed only in strict conformity with state and federal regulations. Waste water injection through the annulus of these exploratory wells into presently unexempted aquifers containing an undetermined TDS concentration does not appear to be in conformance with these regulations. Thank you for your consideration of these comments. Very truly yours, Randall M. Weiner Executive Director cc: w/attach. Harold Scott, EPA, Seattle wo/attach. William McGee, ADEC, Fairbanks George Wilson, ADEC, Juneau Bill Christian, ARCO, Anchorage Dan Robison, EPA, Anchorage Roy Roberts, UNOCAL, Anchorage John McDonough, Dept. of Law, Fairbanks Steve Porter, Dept. of Law, Anchorage TRUSTEES FOR ALASKA'S COMMENTS ON ARCO ALASKA INC.'$ APPLICATION FOR A SOLID WASTE DISPOSAL PERMIT FOR PT. McINTYRE #3 AND #4 - 8836-BA024 DECEMBER 7, 1988 The following comments are keyed to the format submitted by the applicant and to that prescribed by 18 AAC 60. 1. Attachment I - Cover letter A. ARCO's states in Appendix A, that incinerator solids will be buried in the reserve pit. This contradicts ARCO's statement in the cover letter that no dcmestic waste will be buried in the pit. B. It is our understanding that pads such as those at Point McIntyre, are required to be removed at the end of their useful lives. If ADEC allows the interment of waste below such a pad, does this not mean that this waste may have to be removed at some point in time? This area may be below sea level when the pad is removed. Waste burial at this site should not occur. C. ARCO's statement that there are no residents within 2 miles does not appear to be true since the ARCO STP resident work force resides within two miles of this project at the end of the West Dock causeway. D. ARCO's statement that there are no below grade fresh water sources is speculation. The existence of below grade fresh water sources has not been disproven, and in fact the Ugnu formation has been used.as a fresh water source by both the ARCO Kuparuk River Unit and the Conoco Milne Point Unit. In any event, there is no aquifer exemption in effect for the Prudhoe Bay Unit, Eastern Operating Area, or for units north of this area. Until such time as an aquifer exemption is applied for and granted, the aquifers beneath the Prudhoe Bay field and other areas cited must be protect- ed as sources of drinking water. 2. Attachment 2 - ADEC Permit application A. Statements in Attachment 7 indicate that the cuttings could be covered by as little as 3-feet of soil, rather than the 8 feet implied by ARCO. This conflict requires resolution prior to the issuance of a pern~it. 3. Attachment 3 - Location Plan A. The location plan, figure 3-1, does not identify and locate the following items among others: (1). Pipelines in the vicinity (2). The ARCO Seawater Treatment plant (3). The SAPC/ARCO 69ky transformer installation at the head of the West Dock causeway The location plan should be revised to incorporate these required details. B. The location plan in general lacks detail and fails to identify the major topographical, geological, hydrological, biologi- cal, and archeological features as required by 18 AAC 60.210. (b)(3) (A). The location plan should be revised to incor- porate these required details. 4. Attachment 4 - Site Plan A. Some of the drawings submitted by ARCO have no scale. 18 AAC 60.210.(b)(4) (A) requires that these ~rawings be to scale. These drawing must be revised by the applicant to reflect the proper scale. B. The detail shown on the drawings for attachment 4 are vague and do not reflect the level of detail required by the regulations. For instance, trenches and Contair~ment stru6tures are not shown. C. ARCO has failed to address the flow of surface water off the site. ARCO has stated that the surface and ground water flow patterns are indicated on figure 4-3 but they are not. ADEC must require that ARCO correct this omission. D. Methods, techniques, or devices to collect and dispose of leachate are not addressed by ARCO in Attachment 4. E. ARCO has stated that stockpile areas are designated on figure 4-3 but they are not. ADEC must require that ARCO correct this omission. 5. Attachment 5 - Development Narrative A. ARCO does not address how fluid accumulations will be monitored and how the accumulation of excess fluids will be prevent- ed. During the proposed operations time frame all these fluids will immediately freeze when directed into the open pit. ADEC must ~require ARCO to develoF a program to prevent the entry of f'luids into the pit, as it is quite obvious that once there, these frozen fluids will be buried. B. ARCO does not address methods to ~educe the volume of wastes as required by the regulations. This application should be revised to address this requirement. C. ARCO's entire operational plan is founded on the premise that continuous permafrost exists below the Dad, and that the interred waste will freeze and remain perpetually frozen. Both of these assumptions are questionable and will be examined in more detail 'in the comments on Attachments 6 and 7. D. ARCO has not included the engineering design standards required by 18 AAC 60.210. (b) ~5) (D). The application should be revised to include these standards. E. ARCO's description is replete with "may be" and "possibly". It is obvious that what is built and operated could differ substan- tially from the description in the application. ADEC should require ARCO to submit a detailed and realistic development narrative prior to approving ARCO's application. Fo The certification of the containment structure design and construction by an engineer registered in Alaska appears to be missing. There is an engineer's stamp after Attachment 12 that may relate to this certification, but there is no certification of plans as required by Note 1 of Attachment 2. It appears that the applica- tion needs further review and certification by the applicant. 6. Attachment 6 - Physical Environmental Conditions A. ARCO has failed to consider, has failed to discuss, or has drawn incorrect conclusions concerning several physical processes and conditions which can affect this site. (1). The site is located in an area subject to thermal shore- line erosion. Shoreline regression rates in this area range from 1 to 3' meters per year (Ref. 5, 6, 10). Waste interred at this . site will eventually be exposed, probably in the next 50-100 years if the present rates of erosion remain constant. Waste disposal by the freezeback method at this site is therefore inappropriate · and should not be permitted. (2). The site is located in an area subject to storm surges from the Beau,o_t Sea Minor storm surges will approach this area from the northeast and some small degree of protection may be afforded by the West Dock causeway. Major storm surges will 'ap- . . proach this area from the west-northwest in Which case the West Dock causeway will probably greatly increase the severity of a storm surge by focusing its effect in the embayment between Stump Island and the West Dock causeway (Ref. 7, 8, 9). It appears highly probable that the Pt. McIntyre area will be inundated by stor~: surges on a regular basis. The existence of the West Dock causeway not on!y does not provide any protection from major storm surges, but appears to be a focusing mechanism which will exacerbate the severity of the surge by magnifying the depth and severity of the inundation. Waste disposal in such an area is 5 most inappropriate and should be prohibited. (3). A rise in sea level will occur over the next few decades. The extent.of the rise in temperate latitudes is estimated at anywhere from 1 to 20 feet (Ref. 12, 13). This rise is predicted to be Greater in the arctic regions. This rise will have a direct effect on the Pt. McIntyre pad. Waste disposal at such a site is inappropriate. (4). A sharp rise in the temperature of the permafrost is underway and has been for a number of years (Ref. 14, XS). This is due to an increase in the temperature of the Earth's atmosphere which has been underway for a number of years. Until such time as the extent of this temperature rise is predictable, waste disposal by the freezeback method is an unproven disposal practice and should be prohibited. 7. Attachment 7 - Geotechnical Information A. The geotechnical data presented by ARCO in Attachment 7 has some basic defects: (1). The data is for inland sites, not for sites near the Beaufort Sea coast which will be subject to a number of processes which ARCO has not considered, but which are described briefly in the comments on Attachment 6. (2). ARCO has assumed that the atmospheric temperature will remain constant, although it is known to be increasing dramatically (Ref.. 12, 13). (3). Plate 1 presents data from ARCO PiPeline State Number 1, which is 20 miles inland from Pt. McIntyre. The moisture contents and soils conditions are not applicable to Pt McIntyre which is within 600 feet of salt water and is above sea level only by virtue of the pad on which it sits. The level of the interred wastes in the pit at Pt. McIntyre will be approximately ten feet below sea level. The heat transfer regime in the Pt McIntyre area may have to take into account extensive thawed areas, saline in- trusions, and hydraulic conductivities radically different from those of inland sites above sea level. (4). The data in Plate 3 does not appear to have any applica- bility to the Pt. McIntyre site. It is not referred to in the text, confuses the issues, and should be removed from the application. (5). The data presented in Plate 8 is not accompanied by any as-built drawing identifying the physical locations of the thermis- tors which it references. Without some such reference document, the data is useless, and simply serves to confuse the issue. (6). ARCO has neglected to account for the effect of salt water which will be percolating into the pad and the underlying soils from frequent storm surge events in this area (Ref.7, 8, 9) 8. Leachate Generation Evaluation A. ARCO's leachate evaluation simply says there will be no leachate because everything will be frozen forever. This is com- pletely inadequate. The application should be returned to ARCO to be revised to evaluate the probability of leachate generation as required by 18 AAC 60.210.(b)(8). Leachate generation potential should be evaluated for these circumstances at a minimum: (1). inundation of the area by storm surges resulting in saturation of the area with salt water. The effect of this event on the pad, the underlying soils, and the interred wastes should be evaluated. (2). Eventual re,ova! of the pad as required by the original fill permits. Eventual inundation of the area by salt water will occur. The waste will eventually be in & submarine environment. (3). Continued thermal erosion of the Beaufort Sea coast resulting in the Beaufort eventually covering this site. (4). Groundwater flow beneath the pad during the summer and fall months. (5). Several thousand barrels of fluids may be interred in this pit in the form of ice. In the event that thawed areas exist beneath the Dad~ saline water or ground water enters the area, or some other mechanism eventually thaws' this fluid, a large potential for leachate release will be present in the pit. 9. Attachment 9 - Fluid Management Plan and Certification A. ARCO's fluid management plan assumes that the below grade soils are completely frozen and will remain completely frozen. This does not appear to be a valid conclusion as discussed in the com- ments on attachments 6 and 7. 10. Attachment 10 - Monitoring Plan A. ARCO's visual monitoring plan is inadequate in that it does not designate a specific individual or position to make observation and file reports. The sentence that states "Variations requiring remedial action will be reported to ADEC at a frequency specified in the permit" is nonsensical. The application should be revised to concisely define the requirements for remedial action. B. There is no plan included to establish any baseline water quality data against which samples can be compared. Without such baseline data-, the sample results will be of marginal value. ADEC should require the establishment of baseline data. This 4ara could even be obtained from winter borehole testing if cores are taken. C. ARCO's monitoring procedures do not include provisions for the notification of ADEC if sample results exceed a preset guide- line. This requirement should be a stipulation of the permit. D. Samples should be collected at least twice a year rather than the once per year proposed by ARCO. A number of physical processes appear likely to negatively affect the likelihood of success of the freezeback method of waste containment at this particular site. These processes have already been described. If only one sample is taken, then it should be taken in late August or early September, after groundwater flow has been active for three months. E. ADEC should require that ARCO submit such forms as visual monitoring reports, field data sheets, sample logs, instrument calibration sheets, etc. for review prior to approval of this application. F. ARCO plans to monitor only in the 1st, 3rd, and 5th years. This is inadequate for this particular site which will be subject t'o a wide variety of events and conditions. DEC should specify an annual monitoring program at a minimum. G. ARCO does not describe with what frequency monitoring records will be duplicated and forwarded to ADEC nor does ARCO detail the archiving procedure or location. ADEC must specify these details and must ensure that the archived records will be accessible to the Public on demand. H. The description of the thermistor temperature monitoring program is inadequate. An engineering drawing is required as per Note 4. Details regarding thermistor locations, in both the verti- cal' and horizontal planes should be provided. The use of tWO thermistors in a pit 93 feet long and 93 feet wide is inadequate · to present a real picture of the thermal regime. Thermistor strings beneath the pit, on each side of the pit, on top of the pit, and at selected locations within the waste interred in the pit will be required to provide an accurate picture of this thermal regime. I. The monitoring plan as presented does not comply with the requirements of 18 AAC 60.210(b) (10) to provide detailed engineering drawings, material specification, and design calculations. The application cannot be processed until it is complete. J. The down Gradient monitoring locations shown on figure 10-1 are much too renote from the pits. ADEC should require addi- tional monitoring points at this pad because of the existence of 2 pits. l0¸ 11. Attachment 11 - Closure Plan A. Closure of this facility wifh the waste remaining in place is not appropriate at this site. The interred waste will eventually be exposed through a number of processes, some of which are detailed in the comments on Attachments 6 and 7 and the attached references. Many of the processes that will effect this site are also treated in some detail in Trustees for Alaska's comments of the North Slope Borough's Oxbow Landfill solid waste permit application. To the extent applicable, Trustees' comments on the NSB Oxbow proposal are incorporated by reference. · Trustees for Alaska is not opposed to exploratory drilling at this site. However, we are opposed to the implementation of long term waste dfsposal at this site, and to the implementation of the freezeback ~ethod of waste disposal at this site. We recommend that the drilling waste Generated at this site be transported to an appropriate inland disposal site. 12. Attach~.ent 12 - Landowner Notification A. ARCO has answered at least one question incorrectly on the Department of Natural Resources portion of the Coastal Project Questionnaire. 13. Attachment 13 - Coastal Project Questionnaire A. Department of Natural Resources Approvals ARCO has checked no on the second question of this ~section. This is incorrect, since the elevation of the bottom of the reserve pit will be at approximately 10 feet below sea level. This is a lower elevation than sea level of the Beaufort Sea approximately 600 feet away. B. Federal Approvals ARCO apparently has not applied for an NPDES permit for this facility ARCO's verbal description of the Pt. McIntyre operations plan in Appendix A states that 4000 ~allons of prey water will be discharged each day. Unless this water ~s hauled to a sewage treatment plant with an NPDE$ permit in effect, then an NPDES permit must be obtained. . C. ADEC Approvals ARCO has not answered question number 7. Appendix A plainly states that 4000 gallons per day of grey water will be discharged daily. 14. Appendix A - Plan of Operation A. ARCO has maintained throughout the application that fluids will be removed from the pit on an ongoing basis and hauled away. The window during which this operation will occur is March 15 to April 30. During this time period, any fluids discharged to the pit will immediately freeze. How does ARCO propose to prevent the accumulation of large amounts of frozen fluids in the pit? The descriptive material says that daily water usage for drilling is' estimated at 50,000 gallons How much of this is going to end up in the pit? How does ARCO propose to remove this fluid before it freezes? What steps is ARCO taking to separate the liquids from the muds and cuttings before the mixture enters the pit, collect the liquids, and dispose of them in a rational manner? Based on the material provided, the described procedure does not appear to provide a practical means to separate and collect the liquids in question. It appears that several thousand barrels of frozen liquids will also be interred if the plan proposed by ARCO is approved. ADEC must ascertain in detail how waste fluids will be handled on this project, how they will be prevented from entering the pit, and exactly how they will be disposed of. 15. ApPendix B - Waste Water Disposal Notification A. ~ow does ARCO propose to control injection occurring below the surface casing shoe? Does ARCO plan to set a packer below the injection point in the 9 5/$ annulus or is injection occurring through the 13 3/8 annulus? The mechanism by which water is in- jected into the formation cannot be derived from the material provide~. B. Injection of liquids at 4000-4100 feet would result in injection of those liquids into aquifers which are not presently exempted by an aquifer exemption issued by AOGCC or EPA. Such injection cannot be legally permitted regardless of the fact that this is annular injection of exempted wastes through a well which does not fall under the UIC program. TRUSTEES FOR ALASKA'S COMMENTS ON ARCO ALASF3. INC. 'S APPLICATION FOR A SOLID WASTE DISPOSAL PERMIT FOR POINT McINTYRE #5 - 8836-BA026 DECEMBER 7, 1988 The following comments are keyed to the format submitted by . the applicant and to that prescribed by 18 AAC 60. 1. Attachment 1 - Cover letter A. ARCO stated that 15,000 cubic feet of drilling waste will be produced. This figure conflicts with ARCO's statement in Attachment 2, Part I-C.G.,which states that 18,500 cubic feet of "drilled material" plus up to 11,500 cubic feet of drilling mud would be placed in the pit. This discrepancy raises some concern about the accuracy of ARCO's statement in the cover letter that "no other drilling or domestic waste will be disposed, of in this pit", as does ARCO's statement in ApPendix A that incinerator solids will be buried in the reserve pit. B. It is our understanding that pads such as those at the West Dock staging area are required tO be removed at the end of their useful lives. If ADEC allows, the interment of waste below such a pad, does this not mean that this waste may have to be removed at some point 'in time? This area may be below sea level when the pad is removed. In any event, the interment of waste below a staging area, which may again some day be an active staging and traffic area, hardly seems to be an example of responsible waste management. C. ARCO apparently intends to fill in the triangular area in the southwest corner of the staging area. Maps and aerial photos of the area indicate that this is currently a wetland (Ref. 1, 2, 3). It appears that ARCO will require a fill permit from the Army Corp of Engineers for this activity and &pparently is applying for this permit. The application was not include, d as a part of this permit package. ARCO's specified reasons for this fill in paragraph 5 of the cover letter are illogical. We are very concerned with what "fill material" ARCO intends to dispose of in this area. There is no apparent reason for filling in an area over 2000 feet from the project area. A~EC and ACOE must determine why such an activity is required at a point remote from the project area and exact1y what "fill material" is going to be disposed of in this area. D. ARCO's statement that there are no residents within 2 miles does not appear to be true, since the ARCO STP resident work force resides within two miles of this project at the end of the West Dock causeway. E. ARCO's statement that there are no below grade fresh water sources is speculation. The existence of below grade fresh water sources has not been disproven, and in fact the Ugnu formation has been used as a fresh water source by both the ARCO Kuparuk River Unit and the Conoco Milne Point Unit. In any event, there is no aquifer exemption in effect for the Prudhoe Bay Unit, Eastern Operating Area, or for units north of this area. Until such time as an aquifer exemption is.applied for and granted, the aquifers beneath the Prudhoe Bay field and other areas cited must be protected as sources of drinking water. 2. Attachment 2 - ADEC Permit application A. As previously stated in 1.B, above, there is a disparity , between the 15,000 figure used in the cover letter and the sum of 30,000 yards in Attach.2 - Part I.C.G. Further conflict is evident if the statements made in Attachment 7, Section D, are considered. The statements in Attachment 7 indicate that the cuttings could be covered by as little as 3 feet of soil, rather than the 8 feet implied by ARCO. This conflict requires resolution prior to the issuance of a permit. ADEC must ascertain what ARCO's real intentions are at this site, how much waste will be buried, and how deep. The figures presented in this application must be revised to refiect facts before processing of this application can proceed. 3. At'tachment 3 m Location Plan A. The lOcation plan, figure 3-1, does not identify and locate the following items, among others: (1). Pipelines in the vicinity (2)° The ARCO .Seawater Treatment plant (3). The SAPC/ARCO 69ky transformer installation at the head of the'West Dock causeway The location plan should be revised to incorporate these required details. B. The location plan in general lacks detail and fails to identify the major topographical, geological, hydrological, biological, and archeological features as required by 18 AAC 60.210.(b) (3) (A). The location plan should be revised to incorporate these required details. 4. Attachment 4 - Site Plan A. The drawings submitted by ARCO are marked "no scale". 18 AAC 60.210. (b) (4) (A) requires that these 4rawings be to scale. These drawing must be revised by the applicant to reflect the proper scale. B. The detail shown on the drawings for attachment 4 are vague and do not reflect the level of detail required by the regulations. For instance, trenches, and containment structures are not shown. C. ARCO has failed to address the flow of surface water Off the site with the exception of two arrows on one drawing. This area apparently will drain to a saline embayment immediately to the northwest of the ARCO site. ARCO has indicated in other portions of its application that the nearest surface water is 1000 feet away. This is incorrect. The embayment is less than 200 feet away and will apparently receive the surface drainage from this site according to the ARCO drawings (Ref. 2, 4). This poses serious questions regarding the quality of the surface drainage, and the effect on this saline embayment, which provides high quality habitat for numerous shore birds (Ref. 4). ADEC must ensure that the permittee takes the necessary steps to protect this area. D. Methods~ techniques, or devices to collect and dispose of leachate are not addressed by ARCO in Attachment 4. 5. Attachment 5 - Development Narrative A. ARCO does not address how fluid accumulations will be monitored and how the accumulation of excess fluids will be prevented. During the proposed operations time frame al/ these fluids will immediately freeze when directed into the open pit. ADEC must require ARCO to develop a program to prevent the entry of fluids into the pit, as it is quite obvious that once there, these frozen fluids will be buried. B. ARCO does not address methods to reduce the volume of wastes as required by the regulations. This application should be revised to address this requirement. C. ARCO's entire operational plan is founded on the premise that continuous permafrost exists below the pad, and that the interred waste will freeze and remain perpetually frozen. Both of these assumptions are questionable and will be examined in more detail in the comments on Attachments 6 and 7. D. Water pollution will occur if the wastes below the pad do not freeze and leachate migrates from the pit to the saline embayment to the northwest. This definitely appears to be a possibility. The portion of the pad where ARCO intends to drill was laid over the southeastern portion of a saline embayment'. The depth of this embayment is not known, but it may have been deep enough not to freeze in the winter. If so, this area will have a thaw bulb beneath it. ADEC should require whatever tests are · necessary to ascertain the condition of the subsurface soils in this area o E. ARCO has not included the engineering design standards required by 18 AAC 60.210.(b) (5) (D). The application should be revised to inClUde these standards. F. ARcO's description is replete with "maybe" and "possibly." It is obvious that what is actually built and operated could differ substantially from the description in the application. ADEC should · require ARCO to submit a detailed and realistic development narrative prior to approving ARCO's application. G. The certification of the containment structure design and construction by an engineer registered in Alaska appears to be missing. There is an engineer's stamp after Attachment 9 that may relate to this certification, but there is no certification of plans as required by Note I of Attachment 2. It appears that the application needs further review and certification by the applicant. 6o Attachment 6 - Physical Environmental Conditions Ao ARCO states that surface water drains east and west off the gravel in Attachment 6, yet in figure 4-3 the drainage lines are drawn depicting drainage to the northwest toward the embayment. ARCO further contradicts itself in the fourth paragraph of Attachment 6, stating, "The drill site location is on an elevated gravel pad with good drainage both east and northeast." It is obvious that ARCO has not bothered to determine exactly where drainage from this site will gO. This discrepancy must be resolved and the information required by 18 AAC 60.210(b) (6) provided before this application process can proceed. Several references which are attached to these comments illustrate quite clearly that the embayment that ARCO claims is 1000 feet to the northwest is in actuality less than 200 feet to the northwest (Ref. 1, 2, 3, 4). Figure 4-3, supplied by ARCO as a portion of its application, also depicts.this adjoining embayment, although ARCO has not labeled it as such. It appears that a portion of the pad where drilling is to occur is actually laid over the southeast portion of this e~bayment. ADEC must require ARCO to provide correct information and to resolve discrepancies and errors in the material provided to date before this permit may be further processed. B. ARCO has failed to consider, has failed to discuss, or has drawn incorrect conclusions concerning several physical processes and conditions which can affect this site. (1). The site is located in an area subject to thermal shoreline erosion. Shoreline regression rates in this area range from 1 to 3 meters per year (Ref. 5, 6, 10). The West Dock causeway affords a small amount of protection from this process at the present time, yet it is still progressing. When the West Dock is eventually removed, this process will accelerate. Waste interred at this site will eventuall2 be exposed, probably in the next 50- 100 years, if the present rates of erosion remain constant. Waste disposal by the freezeback method at this site is therefore inappropriate and should not be permitted. (2). The site is located in an area subject to storm surges from the Beaufort Sea. ARCO has concluded, incorrectly, that the West Dock causeway will protect the site from storm surges. Minor Storm surges will approach this area from the northeast, in which case the West Dock causeway will have no effect other than to cause some.wave refraction, which may exacerbate the situation at the foot of the causeway. Major storm surges will approach this area from the west-northwest in which case the West Dock causeway will probabl~ greatly increase the severity of a storm surge by focusing its effect in-the-embayment between Stump Island and the West Dock causeway (Ref. 7, 8, 9). It appears highly probable that the area at the foot of the west Dock causeway will be inundated by storm surges on a regular basis. The existence of the West Dock causeway not only does not provide any protection from storm surges, but appears to be a focusing mechanism which will exacerbate the severity of the surge by magnifying the depth and severity of the inundation. Waste disposal in such an area is most inappropriate and should be prohibited. (3). The embayment immediately adjacent to the proposed location has been transformed from a lake to a saline embayment within the past 30 years through mechanical and thermal erosional processes. A Comparison of the USGS Beechy Point Ouadrangle (Ref. 3), with the Geobotanical Maps produced for the West Dock EIS in 1979 (Ref. 4), reflect this change. This is indicative of the ongoing shoreline processes prevalent along the Beaufort Sea coast between Point Barrow, Alaska and the Mackenzie River delta in Canada (Ref. 5, 6). The barrier island presently protecting this embayment will erode away over the next few years, exposing the staging pad and the Pt. McIntyre site to the continuous seasonal thermal and mechanical erosional effects of the Beaufort Sea. Alternately, a single large storm surge could accomplish this erosion in a matter of hours (Ref.7, 8, 9). At the present time this area is subject to sporadic erosional events and the Pt. McIntyre site will be subject to this erosion also (Ref. 6, pg. 64). Waste disposal in this area is most inappropriate and should be prohibited. Direct thermal and mechanical erosion of the Pt. McIntyre pad by the Beaufort Sea could be occurring in less than ten years. . (4). ARCO states that "Drill site stability is essential for oil field activities and is a prime consideration in selecting thermaliy stable areas°" ARCO also maintains that exploration wells are exempt from soil borings and states that the "uniformity of the alluvial'permafrost whiCh exists throughout this area is well understood.'' ARCO has provided no site specific data that supports its indirectly stated assumptions regarding the permafrost in this area. Areas immediately adjacent to embayments, beaches, barrier islands and other shoreline structures along the Beaufort Sea coast are likely to be underlain by poorly bonded or unbonded soils, which may be subject to seasonal intrusion by saline waters (Ref. 11). It would be irresponsible t° commence drilling operations in this area without information regarding the soil properties beneath the · pad. Waste disposal in such an area is unthinkable. (5). A rise in sea level will occur over the next few decades. The extent of the rise in temperate latitudes is estimated at anywhere from 1 to 20 feet (Ref. 12, 13). This rise is predicted to be greater in the arctic regions. This rise will have a direct effect on the Pt. McIntyre pad, the northwest ~)ortion of which will be directly exposed to the Beaufort Sea within perhaps as few ms 10 years, waste disposal at such a site is inappropriate. (6). A sharp rise in the' temperature of the permafrost is · underway and has been for a number of years (Ref. 14, 15). This is due to an increase in the temperature of the Earth's atmosphere which has been underway for a number of years. Until such time as the extent of this temperature rise is predictable, waste disposal by the freezeback method is an' unproven .disposal practice and should be prohibited. 7. Attachment 7 -Geotechnical Information A. The soil conditions at this site do not appear to be accurately reflected by ARCO's descriptive material in Attachment 7. It appears that the portion of the staging area upon which the Pt McIntyre site will be built is a pad partially laid in a temporarily drained embaymento The area will probably be underlain by lake sediments, which will be overlain by beach sands. ARCO's statements that the sediments will be well bonded by ice are 10 questionable (Ref. 6). B. The geotechnical data presented by ARCO in Attachment 7 have some basic defects: (1). The data is for inland sites, not for sites near the Beaufort Sea coast which will be subject to a number of processes which ARCO has not considered, but which are described briefly in the comments on Attachment 6. (2). ARCO has assumed that the atmospheric temperature will remain constant, although it is known to.be increasing dramaticallF. (Ref. 12, 13). (3). ARCO has neglected to consider heat transfer to the embayment to the northwest of the site. This embayment will eventually become an active portion of'the Beaufort Sea. Combined with a rising sea level, this will produce a heat sink to the northwest of this site. Heat transfer by conduction and eventually by saline current circulation (conduction/cOnvection) appears likely to develop over the next few years. (4). Plate ! presents data from ARCO Pipeline State Number 1, which is 20 miles inland from Pt. McIntyre. The moisture contents and soils conditions are not applicable to Pt McIntyre which is within 200 feet of salt water and is above sea level only by virtue of the pad on which it sits. The level of the interred wastes in the pit at Pt. McIntyre will be approximately ten feet below sea level. The heat transfer regime in the Pt McIntyre area may have to take into account extensive thawed areas, saline intrusions, 'and hydraulic conductivities radically different from 11 those of inland sites above sea level. (5). The data in Plate 3 does not appear to have any applicability to the Pt. McIntyre site. It is not referred to in the text, confuses the issues, and should be removed from the application. (6). The data presented in Plate 4 indicates that there may be a process occurring at the edge of the staging area pad which would lead to a thaw wedge developing beneath the northwest toe of the pad, which is submerged beneath the embayment. Such a thaw wedge may of course already exist, but .if not, this process would appear to be building one. Such a wedge could eventually reach the · buried wastes and provide a transmission path for wastes and leachate to reach the environment. (7). The data presented in Plate 8 is not accompanied by any as-built drawing identifying the physical locations of the thermistors which it references. Without some such reference document, the data is useless, 'and simply serves to confuse the issue. (8). ARCO has neglected to account for the effect of salt water which will be percolating into the pad and the underlying soils from frequent storm surge events in this area (Ref. 7, 8, 9). 8. Leachate Generation Evaluation A. ARC0'$ leachate evaluation simply says there will be no leachate because everything will be frozen forever. This is completely inadequate. The application should be returned to ARCO to be revised to evaluate the probability of leachate generation as required by 18 AAC 60.210.(b) (8). Leachate generation potential should be evaluated for these circumstances, at a minimum: (1). Inundation of the area by storm surges, resulting in saturation of the area with salt water. The effect of this event on the pad, the underlying soils, and the interred wastes should be evaluated. (2). Erosion of the barrier island protecting the embayment from the Beaufort Sea. The subsequent exposure of the staging area pad to the Beaufort Sea should be evaluated to ascertain the effect on the pad and the wastes below it. (3)'. Development of a thaw wedge beneath the lip of the 9ad submerged beneath the embayr, ent. Such a thaw wedge may eventually reach the waste. (4). Eventual removal of the staging area pad as required by the original fill permits. This will result in inundation of the area by salt water. The waste will eventually be in a submarine environment. (5). Continued thermal erosion of the Beaufort Sea coast resulting 'in the Beaufort eventually covering this site. (6). Groundwater flow beneath the pad during the summer and fall months. It is known that the groundwater flow to the south of this area has been dammed by the roads and pads in this area (Ref. 6). This flow is now apparently being forced to flow beneath the staging area pad to reach sea level. The ponding which ARCO claims as a reason to fill in the triangular portion of wetland in the southwestern part of the staging pad appears to be indicative of the hydraulic head at the south end of the pad. (7). several' thousand barrels of fluids may be interred in this pit in the form of ice. In the event that thawed areas exist beneath the pad, saline water or ground water enters the area, or some other mechanism eventually thaws this fluid, a !arge potential for leachate ~elease will be present in the pit. 9. Attachment 9 - Fluid Management Plan and Certification A. ARCO's fluid management plan assumes that the below grade soils are completely frozen and will remain completely frozen. This does no% appear to be a valid conclusion as discussed in the comments on Attachments 6 and 7. 10. Attachment 10 - Monitoring Plan A. ARCO's visual mcnitoring plan is inadequate in that it does not designate a specific individual or position to make observation and file reports. The sentence that states "Variations requiring remedial action will be reported to ADEC at a frequency specified in the permit" is nonsensical. The application should be revised to concisely define the requirements for remedial action. B. There is no plan included to establish any baseline water quality data against which sar. ples can be compared. Without' such baseline data, the sample.results will be of marginal value. ADEc should require the establishment of baseline data. This data could 14 even be obtained from winter borehole testing if cores are taken. C. ARCO's monitoring procedures do not include provisions for · the notification of ADEC if sar. ple results exceed a preset guideline. This requirement should be a stipulation of the permit. D. Samples should be collected at least twice a year rather than the once per year proposed by ARCO. A number of physical processes appear likely to negatively affect the likelihood of success of the freezeback method of waste containment at this particular site. These processes have already been described. If only one sample is taken, then it should be taken in late August or early September, after groundwater flow has been active for three months. E. ADEC should require ARCO to submit such forms as visual monitoring reports, field data s?,eets, sa~.p!e logs, instru~.ent calibration sheets, etc. for review prior to approval of this aPPlication. F. ARCO plans to monitor' only in the 1st, 3rd, and 5th years. This is inadequate for this particular site, since it will be subject to a wide variety of events and conditions. DEC should specify an annual monitoring program at a minimum. G. ARCO does not describe with what frequency monitoring records will be duplicated and forwarded to ADEC, nor does ARCO detail the archiving procedure or location. ADEC must specify these details and must ensure that the archived records will be accessible to the public on demand. H. The description of the thermistor temperature monitoring 15 program is inadequate. An engineering drawing is required as per Note 4. Details regarding thermistor locations, in both the vertical and horizontal planes should be provided. The use of three thermistors in a pit 150 feet long and 75 feet wide is inadequate to present a real picture of the thermal regime. Thermistor strings beneath the pit, on each side of the pit, on top of the pit, and at selected locations within the waste interred in the pit will be required to provide an accurate picture of this thermal regime. I. The monitoring plan as presented does not comply with the requirements of I8 AAC 60.210(b) (10) to provide detailed engineering drawings, material specification, and design calculations. The application cannot be processed until it is complete. 11. Attachr~ent 11 - Closure Plan A. Closure of this facility with the waste remaining in place is not appropriate at this site. The interred waste will eventually be exposed through a number of processes, some of which are detailed . . in the comments on Attachments 6 and 7 and 'the attached references. Many of the processes that will effect this site are also treated in some detail in Trustees for Alaska's comments on the North Slope Borough's Oxbow Landfill solid waste permit application. To the extent applicable, Trustees' comments on the NSB Oxbow proposal are incorporated by reference. Trustees for Alaska is not opposed to exploratory drilling at this site. However, we are opposed to the implementation of long term waste disposal at this site, and to the implementation of the 16 freezeback method of waste disposal at this site. We recommend that the drilling waste generated at this site be transported to an appropriate inland disposal site. 12. Attachment 12- Landowner Notification A. ARCO has answered at least one question incorrectly on the Department of Natural Resources portion of the Coastal Project Questionnaire. Refer to Attachment 13. 13. Attachment 13 - Coastal Project'Questionnaire A. Department of Natural Resources Approvals ARCO has checked no on the second question of this section. This is incorrect, since the elevation of the bottom of the reserve pit will be at approximately 10 feet below sea level. This is a lower elevation than the embayment immediately adjacent to the site on the northwest which is directly connected to 'the Beaufort Sea. B. Federal Approvals ARCO has apparently applied for a fill permit to fill. the triangular shaped area of wetland approximately 1/2 mile to the south of the Pt McIntyre site. No logical reason for filling this area has been presented. ARCO apparently has not applied for an NPDES permit for this facility. ARCO's verbal description of the Pt. McIntyre operations plan in Appendix.A states that 4000 gallons of grey water will be discharged each day. Unless this water is hauled to a sewage treatment plant with an NPDES per,.it in effect, then an NPDES permit must be obtained. C. ADEC Approvals ARCO has answered question number 6 with a no. This appears to be incorrect, as ARCO has applied for a fill permit in conjunction with this project. ARCO has answered question number 7 with a no. This appears to be incorrect, as the verbal description of the operations plan in Appendix A plainly states that 4000 gallons ~er day of grey water will be discharged daily. ARCO has answered question 8 with a no. This appears to be incorrect, as the facility is currently unpermitted. 14. Appendix A - Plan of Operation A. ARCO has maintained throughout the application that fluids will be removed from the pit on. an ongoing basis and hauled away. The window during which this operation will occur is March 15 to April ~0. During this time period, any fluids discharged to the pit will immediately freeze. How does ARCO propose to prevent the accumulation of large amounts of frozen fluids in the pit? The descriptive material says that total water usage is estimated at 59,500 barrels. How much of this is going to end up in the pit? How does ARCO propose to remove this fluid before it freezes? What steps is ARCO takingr to separate the liquids from the muds and cuttings before the mixture enters the pit, collect the liquids, and dispose of them in a rational manner? Based on the material provided, the described procedure does not appear to provide a practical means to separate and collect the liquids in question. It appears that several thousand barrels of frozen liquids will also be interred if the plan proposed by ARCO is approved. ADEC must ascertain in detail how waste fluids will be handled on this project, how they will be prevented from entering the pit, and exactly how they will be disposed of. 15. Appendix B - Waste Water Disposal Nofification A. How does ARCO propose to control injection occurring below the surface casing shoe? Does ARCO plan to set a packer below the injection point in the 9 5/8 annulus or is injection occurring through the 13 3'/8 annulus? The mechanism by which water is injected into the formation cannot be derived from the material provided. B. Injection of liquids at 4000-4100 feet would result in injection of those liquids into aquifers which are not presently exempte~ by an aquifer exemption issued by AOGCC or EPA. Such injection cannot be legally permitted, regardless of the fact that this is annular injection of exempted wastes through a well which does not fall under the UIC program. 19 REFERENCES 1. Endicott Project Development Area, Aerial Photo Mosaic, 1986, Air Photo Tech, Anchorage, Alaska. 2. Prudhoe Bay Waterflood Monitoring Program, U.S. Army Corp of Engineers, Anchorage, Alaska, 1981, Geobotanical Master Map. 3. Beechey Point B-3 Quadrangle, US Department of the Interior, US Geological Survey, 1955, Photorevised, 1975. 4. Prudhoe Bay Waterflood Environmental Impact Statement, U.S. Army Corp of Engineers, Anchorage, Alaska, 1981, Volume 2, figures L-i, L-2, L-3, L-40, .and L-41. 5. Lewellen, R.I., 1970, Permafrost .erosion along the Beaufort Sea coast, Geography and Geology Department, University of Denver. 6. Rawlinson, S.E., 1983, Guidebook to Permafrost and Related Features, Prudhoe Bay, Alaska, Alaska Division of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska. 7. Reimnitz, E., and Maurer, D.K., Effects of Storm Surges on the Beaufort Sea Coast, Northern Alaska, Arctic, December, 1979. 8. Wise, J.L., Comiskey, A.L., Becker, R., 1981, Storm Surge Climatology and Forecasting in Alaska, Arctic Environmental Information and Data Center, University of Alaska, Anchorage, Alaska. 9. ~ansen, R.M., Joy, J.W., 'and McCartney, F.W., 1979, Hindcast Survey of Extreme Surge, Wave and Current Conditions Near Prudhoe Bay, Alaska, Exxon Production Research Co., Houston, Texas. 10. Barnes, P., Reimnitz, E., Smith, G., and Melchior, J., 1977, Bathymetric and Shoreline Changes Northwestern Prudhoe Bay, Alaska, U.S.G.S., Open-File Report 77-161. 11. Harper, J.R., Owens, E.H., and Wiseman, W.J.,Jr., 1983, Arctic Beach Processes and the Thaw of Ice-bonded Sediments in the Littoral Zone, Permafrost Fourth International Conference, Fairbanks, Alaska. 12. Sbabecoff, Philip, New York Times, 'Earth Warming Likely to Cause Heavy Damage, appearing in Anchorage Daily News, Oct. 20, 1988. 13. Wolkomir, R., The Greenhouse Revolution, Oceans, April, 1988. 14. Lachenbruch, A.H., and Marshall, B.V., 1986, Changing Climate: Geother=al Evidence from Permafrost in the Alaskan Arctic, Science, November 7, 1986. 15. Osterkamp, T.E., 1983, Response of Alaskan Permafrost to Climate, Proceedings, Permafrost Fourth International Conference, Fairbanks, Alaska. 16. Walker, H.J., 1983, Erosion In A Permafrost-Dominated Delta, Proceedings, Permafrost Fourth International Conference, Fairbanks, Alaska. 17. Walker, H.J., 1978, The Nature of the Seawater-Freshwater Interface During Breakup in the Colville River Delta, Alaska, Permafrost Third International Conference. 18. ~wang, C.T., and Smith, M.W., 1978, Thermal Disturbance Due to Channel Shifting, Mackenzie Delta, N.W.T., Canada, Permafrost Third International Conference. 2O TRUSTEES FOR ALASKA'S COMMENTS ON ARCO ALA$~ INC.~$ APPLICATION FOR A SOLID WASTE DISPOSAL PERMIT FOR WEST STORKERSEN #1 8836-BA025 DECEMBER 7, 1988 The following comments are keyed to the format submitted by the applicant and to that prescribed by 18 ;[AC 60. 1. Attachment I - Cover letter A. ARCO states that an aerial photograph of this area has been submitted. No such photograph has been included as a part of this application package. Aerial photographs of this particular site are critical as it is located in an area that is changing rapidly due to several different erosion processes. The application package should be revised to incorporate this aerial photograph. B. ARCO states that the West Storkerson site is in the North Prudhoe Bay area. It appears that this exploratory well will actually be drilled in the G~dyr Bay Unit and will not be subject to any field rules established for the Prudhoe Bay or Kuparuk River Units. C. ARCO states in Appendix A, that incinerator solids will be buried in the reserve pit. This contradicts ARCO's statement in the cover letter that no domestic waste will be buried in the pit. D. ARCO's statement that.there are no below grade fresh water sources is speculation. The existence of below grade fresh water sources has not been disproven, and in fact the Ugnu formation has- been used as a fresh water source by both the ARCO Kuparuk River Unit and the Conoco Milne Point Unit. In any event, there is no aquifer exemption in effect for the Prudhoe Bay or Gwydyr Bay Units. Until such time as an aquifer exemption is applied for and granted, the aqUifers beneath these units must be protected a.s sources of drinking water. 2. Attachment 2 - ADEC Permit application A. ARCO has indicated that this application is for an unpermitted existing facility. This appears to be incorrect. The facility is to be constructed on a currently non-existent ice pad in March of 1989. 3. Attachment 3'- LOcation Plan A. The location plan, figure 3-1, does not identify and locate the following items among others required by 18 AAC 60.210(b)(3): (1). Major topographical features such as the numerous lakes in the int~ediate vicinity, low lying tundra, and elevations in the immediate area. The character and geography of this area is changing rapidly in response to a number of physical processes which will be further discussed in sections 6 and 7. A simple comparison of Figures 3-1, 6-1, and the Beechey Point B-4 Quadrangle (Ref. 19) indicates the extent of some of the changes 4. Attachment 4 - Site Plan A. The detail shown on the drawings for Attachment 4 are vague and do not reflect the level of detail required by the regulations. ~{owever, by referring to Exhibit C of Appendix A ~uch of the necessary detail can be deduced. B. ARCO is assuming that there will be no leachate and thus is not making provisions for leachate collection. This may be an invalid conclusion at this particular si.re. The site appears to be particularly susceptible to saline intrusions. It also appears that the permafrost beneath this site may be discontinuous and may be thawing. 5. Attachment 5 - Development Narrative A. ARCO does not address how fluid accur.~ulatlcns will be monitored and how ~he accumulation of excess fluids will be prevent- ed. During the proposed operations time frame all these fluids will immediately freeze when directed into the open pit. ADEC must require ARCO to develop a program to prevent the entry of fluids into the pit, as it is quite obvious that once there, these frozen fluids will be buried. B. ARCO does not address methods to reduce the volume of wastes as required by the regulations. This application should be revised to address this requirement. C. ARCO's entire operational plan is founded on the premise that continuous permafrost exists below the pad, and that the impacting this area. The island in the Kuparuk River delta, located 1 mile north of the proposed West Storkersen 1 site, has been · dramatically altered over the past 13 years. It now occupies less than half the area it occupied in 1975 at the date of the last photorevision of the Beechey Point B-4 Quadrangle (Ref. 19). (2). Major hydrological features such as the surface drainage patterns, creeks, and streams, in the immediate wicinit~. The site appears to be surrounded around 300 compass degrees by flowing streams and interconnected surface water bodies. It ts probable that this area will become another island in the Kuparuk ~iver delta within 10 to 20 ]~ears. (3). Major geological features such as eroding coastlines and areas that are slumping due to the' thawing of sub surface permafrost. (4}. Major biological features which are not shown at all. (5). Major archeological features. The site location plan should be revised to incorporate these required details. This site location plan for this particular project should receive added attention due to the location of the West Storkersen #1 in an area that is very obviously unsuited for waste disposal. B. The location plan in general lacks detail and fails to identify the major topographical, geological, hydrological, biologi- cal, and arche01ogical features as required b]~ 18 AAC 60.210. (b)(3)(A). The location plan should be revised to incor- porate these required details. interred waste will freeze and remain perpetually frozen. Both of these assumptions are questionable and will be examined in more detail in the comments'on Attachments 6 and 7. D. ARCO has not included the engineering design standards required by 18 AAC 60.210.(b) (5)(D). The application should be revised to include these standards. E. ARCO's description is replete with "may be" and "possibly". It is Obvious that what is built and operated could differ substan- tially from the description in the application. ADEC should require ARCO to submit a detailed and realistic development narrative prior to approving ARCO's application. F. The certification of the containment structure design and construction by 'an engineer registered in Alaska appears to be missing. There is an engineer's stamp after Attachment 9 that may relate to this certification, but there is no certification of plans as required by Note 1 of Attachment 2. It appears that the applica- tion needs further review and certification by the'applicant. 6. Attachment 6 - Physical Environmental Conditions Ao ARCO has failed to consider, has failed to discuss, or has drawn incorrect conclusions concerning several physical processes and conditions which can affect this site. (1). The site is located in an area subject to thermal shore- line erosion. Shoreline regression rates in this area range from 1 to 3 meters per year (Ref. 5, 6, 10). The low lying bench to the west of the West Storkersen site can be expected to rapidly disappear as thermal erosion, river bank erosion, and slumping progress. The waste interred at this site will probably be within 200 feet of the active channel of the Kuparuk River in less than twenty years. Thermal and mechanical erosion will then proceed at a rapid rate on the fairly steep bank below the site. The waste will eventually be exposed, probably within in the next 50 years if the present rates of erosion remain constant and none of the on- going processes are accelerated. However, it appears that many of these processes will accelerate due to ongoing global climatic changes. Waste disposal by the freezeback method at this site is most inappropriate and should not be permitted under any conditions. (2). The site is located in an area subject to storm surges from the Beaufort Sea. Minor storm surges will approach this area from the northeast and probably will not have much effect on this site. Major storm surges will approach this area from the northwest. Protection formerly afforded this area by the large island in the Kuparuk River delta has been compromised by disappearance of over half of the island since 1975 (Ref. 19). Storm surges will have an increasingly dramatic effect on this site due to the eventual disappearance of the bench to the west of the site. (3). A rise in sea level w±ll occur over the next few decades. The extent of the rise in temperate latitudes is estimated at anywhere from 1 to 20 feet (Ref. 12, 13). This rise is predicted to be greater in the arctic regions. This rise will have a direct' effect on the West Storkersen Site. This process alone will cause the Beaufort Sea to approach to within less than 200 feet of this site by the year 2050. Waste disposal at such a site is .inappropriate and must he prohibited. (4). A sharp rise in the temperature of the permafrost is underway and has been for a number of years (Ref. 14, 15). This is due to an increase in the temperature of the Earth's atmosphere which has been underway for a number of years. Until such time as the extent of this temperature rise is predictable, waste disposal by the freezeback method is an unproven disposal practice and should be prohibited. .. (5). The West Storkersen site is located within a few hundred feet of the Kuparuk River which is a najor north slope river. Relevant studies indicate that the Kuparuk River' delta, the Kuparuk River upstrear: from the delta for a distance in excess of 10 ~'les, and the area on either s!~e of the Kuparuk River delta for perhaps 2 to 3 miles, will be subject to the process of saline intrusion (Ref. 17). Salt water will invade the areas beneath Kuparuk River ice, ~he sediments beneath the river, and the sediments on either side of the river when the flow of fresh water in the river slows dramatically in the winter. This intrusion will displace fresh water in areas adjacent to permafrost and will cause a slow continuous thawing action due to the lower freezing point of the saline waters and the circulating currents. (6). Bank erosion occurs rapidly in the del. tas of braided rivers on the north slope. The bank erosion appears to be primarily concentrated on the right bank of these northward flowing streams, and the West Storkersen site is on the right bank (Ref. 16). (7). The combination of thermal and mechanical erosion processes leads to channel shifting by major north slope streams. This channel shifting is frequently in an easterly direction and occurs at a predictable velocity. The Kuparuk River delta appears to be influenced by this phenomena (Ref. 18). (8). Slumping of large areas of land occurs as the permafrost · in the soils melts and the soils compact. This process is most evident in river deltas on the north slope (Ref. 16). The Kuparuk River delta appears to be a particularly illustrative example of this process. The character and geography of this area are changing with astonishing rapidity as reference to maps and aerial photographs of the area illustrate. Comparison of the Beechey Point B-4 Quadrangle (Ref. 19) and the map provided by Arco in Figure 6-I of the application reveal that the 27 foot elevation point in section 15, which was the high point in this section in 1955, is now less than 20 feet in elevation. Another example is the disappearance of over half the island 1 mile north of the West Storkersen site. Numerous examples of this type of disturbance within a few miles of the Beaufort Sea coast are easily discernible along the entire coast from Point Barrow to the Mackenzie River delta. 7. Attachment 7 - Geotechnical Information Ao The geOtechnical data presented by ARCO in Attachment 7 has some basic defects: (1). The data is for inland sites, not for sites near the Beaufort Sea coast which will be subject to a number of processe~ which ARCO has not considered, but which are described briefly in the cor~ents on Attachment 6. (2). ARCO has assumed that the atmospheric temperature will remain constant, although it is known to be increasing dramatically (Ref. 12, 13). (3). Plate 1 presents data from ARCO Pipeline State Number l, which is 20 miles inland from West Storkersen. The moisture 'conten~s and soil conditions may not be applicable to the West Storkersen which is within 1500 feet of salt water and is a subject to a variety of processes that the Pipeline State site is not. The level of the interred'wastes in the pit at West Storkersen will be within 3 or 4 feet of sea level, and may will be in an area of discontinuous permafrost or a thawed area subject to saline intrusion. The heat transfer regime in the West Storkersen area may have to take into account extensive thawed areas, saline in- trusions, and hydraulic conductivities radically different from those of inland sites above sea level. (4). The data in Plate 3 does not appear to have any applica- bility to the West Storkersen site. It is not referred to in the text, confuses the issues, and should be removed from the application. (5). The data presented in Plate 8 is not accompanied by any as-built drawing identifying the physical locations of the thermis- 'tors which it references. There is also no data concerning initial baseline conditions in the reserve pit, final conditions in the reserve pit at closeout, initial baseline conditions at the thermistor sites, or final conditions at the thermistor sites . Without reference drawings and baseline data and reference data the information presented is Plate 8 are simply numbers out of the text of some report and are of no value. (6). ARCO has neglected to consider the effect of salt water which will be percolating into the soils adjacent to and above~ the pit from frequent storm surge events in this area (Ref.7, 8, 9) (7). ARCO has neglected to consider the effects of saline or fresh waters which may be invading the area from the Beaufort Sea or the Kuparuk River. 8. Leachate Generation Evaluation A. ARCO's leachate evaluation simply says there will be no leachate because everything will be frozen forever. This is com- pletely inadequate. The application should be returned to ARCO to be revised to evaluate the probability of leachate generation as required by 18 AAC 60.210.(b) (8)o Leachate generation potential should be evaluated for these circumstances at a minimum: (1). Inundation of the area by storm surges resulting in saturation of the area with salt water. The effect of this event the soils adjacent to, above, and beneath the pit should be evaluated. (2). The eventual inundation of the area by salt water due to the processes of thermal erosion, riverbank erosion, ocean level rise, saline intrusion, and general area subsidence among others. This waste will eventually be in a submarine environment, probably within 50-100 years and possibly less. (3). Several thousand barrels of fluids may be interred in this pit in the form of ice. In the event that thawed areas exist beneath the pad, saline water or ground water enters the area, or some other mechanism eventually thaws this fluid, or if this fluid simply never freezes, a large Dotential for leachate release will be present in the pit. 9o Attachment 9 - Fluid Management Plan and Certification A. ARCO's fluid management plan assumes that the below grade soils are completely frozen and will remain completely frozen. This does not appear to be a valid conclusion as discussed in the com- ments on attachments 6 and 7. 10. Attachment 10 - Monitoring Plan A. ARCO's visual monitoring plan is inadequate in that it does not designate a specific individual or position to make observation and file reports. The sentence that states "Variations requirin~ remedial action will be reported to ADEC at a frequency specified in the pernit" is nonsensical° The application should be revised to concisely define the requirements for remedial action. B. There is no 'plan included to establish any baseline water quality data against which samples can be compared. Without such baseline data, the sample results will be of marginal value. ADEC should requir~ the establishment of baseline data. This data could even be obtained from winter borehole testing if cores are taken. C. ARCO's monitoring procedures do not include provisions for the notification of ADEC if sample results exceed a preset guide- line. This requirement should be a stipulation of the permit. D. Samples should be collected at least twice a year rather than the once per year proposed by ARCO. A number of physical processes appear likely to negatively affect the likelihood of success' of the freezeback method of waste containment at this particular site. These processes have already been described. If only one' sample is taken, then it should be taken in late August or early September, after groundwater flow has been active for three months. E. ADEC should require that ARCO submit such forms as visual monitoring reports, field data sheets, sample logs, instrument calibration sheets, etc. for review prior to approval of this application. F. ARCO plans to monitor only in the 1st, 3rd, and 5th years. This is inadequate for this particular site which will be subject to a wide variety of events and conditions. DEC should specify an annual monitoring program at a minimum. G. ARCO does not describe with what frequency monitoring records will be duplicated and forwarded to ADEC nor does ARCO detail the archiving procedure or location. ADEC must specify these details and must ensure that the archived records will be accessible to the public on demand. ~. The description of the thermistor temperature monitoring program is inadequate. An engineering drawing is required as per Note 4. Details regarding thermistor locations, in both the verti- ca~ and horizontal planes should be provided. The use of three thermistors in a pit 200 feet long and 50 feet wide is inadequate to present a real picture of the thermal regime. Thermistor strings beneath the pit, on each side of the pit, on top of the pit, and at selected locations within the waste interred in the pit will be required to provide an accurate picture of this thermal regime. I. The monitoring plan as presented does not comply with the requirements of 1'8 AAC 60.210(b) (10) to provide detailed engineering~ drawings, material specification, and design calculations. The application cannot be processed until it is complete. J. The monitoring locations shown on Exhibit E of appendix A are incorrectly located. If the drainage arrows are correct, then the sampling point on the north side of the pad will never see any waste plume. The sampling location at the northwest corner of the pad is approximately 400 feet from the edge of the pit and any leakage detected at this point would be diluted by several orders of magnitude. ADEC should require additional monitoring points between 50 and 100 feet west of the pit. These sampling locations' should be established in the summer of 1989 after the ice pad has melted. ll. Attachment 11 - Closure Plan A. Closure of this facility with the waste remaining in place is not appropriate at this site. The interred waste will eventually · be exposed through a number of processes, some of which are detailed in the comments on Attachments 6 and 7 and the attached references. Many of the processes that will effect this site are also treated in some detail in Trustees for Alaska's comments of the Korth Slope Borough's Oxbow Landfill solid waste permit application. To the extent applicable, Trustees' comments on the NSB Oxbow proposal are incorporated by reference. Trustees for Alaska is not opposed to exploratory drilling at this si.te. However, we are opposed to the implementation of waste disposal of any description at this site, and to the implementation of the freezeback method of waste disposal at this site. We recommend that the drilling waste generated at th~s site be transported to an appropriate inland disposal site. i2. Attachment 12 - Landowner Notification A. ARCO has answered at least one question incorrectly on the Department of Natural Resources portion of the Coastal Project Questionnaire. 13. Attachment 13 - Coastal Project Questionnaire A. Department of Natural Resources Approvals ARCO has checked no on the second question of this section. This may be incorrect, since the elevation of the bottom of the reserve pit will be at approximately 4 feet above sea level. At this elevation, the pit bottom is below the level of many of the lakes in the area, and it will be below the flood level of the Kuparuk River in the delta during breakup. B. Federal Approvals ARCO apparently has not applied for an NPDES permit for this facility. ARCO's verbal description of the West Storkersen · operations plan in Appendix A states that 4000 gallons of grey water will be discharged each day. Unless this water is hauled to a sewage treatment plant with an NPDES permit in effect, then an NPDES permit must be obtained. C. ADEC Approvals ARCO has answered question number 7 with a no. Appendix A plainly states that 4000'gallons per day of grey water will be discharged daily. ARCO has answered question number 8 with a no. We are unaware of any permits issued for West Storkersen. 14. APpendix A - Plan of Operation A. ARCO has maintained throughout the application that fluids will be removed from the pit on an ongoing basis and hauled away. The window during which this operation will occur is March 15 to April 30. During this time period, any fluids discharged to the pit will immediately freeze. How does ARCO propose to prevent the accumulation of large, amounts of frozen fluids in the pit? The descriptive material says that daily water usage for drilling is estimated at 50,000 gallons How much of this is going to end uD 15 in the pit? How does ARco propose to remove this fluid before it freezes? What steps is ARCO taking to separate the liquids from the muds and cuttings before the mixture enters the pit, collect the liquids, and dispose of them in a rational manner? Based on the material provided, the described procedure does not appear to provide a practical means to separate and collect the liquids in question. It appears that several thousand barrels of frozen liquids will also be interred if the plan proposed by ARCO · is approved. ADEC must ascertain in detail how waste fluids will be handled on this project, how they will be prevented from entering the pit., and exactly how they will be disposed of. 15. Appendix B - Waste Water Disposal Notification A. How does ARCO propose to control injection occurring below the surface casing shoe? Does ARCO plan to set a packer below the injection point in the 9 5/8 annulus or is injection occurring through the 13 3/8 annulus? The mechanism by which, water is in- jected into the formation cannot be 4erived from the material provided. B. Injection of liquids at 4000-4100 feet would result in injection of those liquids into aquifers which are not presently exempted by an aquifer exemption issued by AOGCC or EPA. Such injection cannot be legally permitted regardless of the fact that this is annular injection of exempted wastes through a well which does not fall under the UIC program. REFERENCES 1. Endicott Project Development Area, Aerial Photo Mosaic, 1986, Air Photo Tech, Anchorage, Alaska. 2. Prudhoe Bay Waterflood Monitoring'Program, U.S. Army Corp of Engineers, Anchorage, Alaska, 1981, Geobotanical Master Map. 3. Beechey Point B-3 Quadrangle, US Department of the Interior, US Geological Survey, 1955, Photorevised, 1975. 4. Prudhoe Bay Waterflood Environmental Impact Statement, U.S. Army Corp of Engineers, Anchorage, Alaska, 1981, Volume 2, figures L-l, L-2, L-3, L-40, and L-41. 5. Lewellen, R.I., 1970, Permafrost erosion along the Beaufort Sea coast, Geography and Geology Department, University of Denver. 6. Rawlinson, S.E., 1983, Guidebook to Permafrost and Related Features, Prudhoe Bay, Alaska, Alaska Division of Geological and Geophysical Surveys, Department of Natural Resources, State of Alaska. 7. Reimnitz, E.., and Maurer, D.K., Effects of Storm Surges on the Beaufort Sea Coast, Northern Alaska, Arctic, December, 1979. 8. Wise, J.L., Comiskey, A.L., Becket, R., 1981, Storm Surge Climatology and Forecasting in Alaska, Arctic Environmental Informa- tion and Data Center, University of A!aska, Anchorage, Alaska. 9. Hansen, R.M., Joy, J.W., and McCartney, F.W., 1979, Hindcast Survey of Extreme Surge, Wave'and Current Conditions Near Prudhoe Bay, Alaska, Exxon Production Research Co., Houston, Texas. 10. Barnes, P., Reimnitz, E., Smith, G., and Melchior, J., 1977, Bathymetric and Shoreline Changes Northwestern Prudhoe Bay, Alaska, U.S.G.S., Open-File Report 77-161. 11. Harper, J.R., Owens, E.H., and Wiseman, W.J.,Jr., 1983, Arctic Beach Processes and the Thaw of Ice-bonded Sediments in the Littoral Zone, Permafrost Fourth InternationalConference, Fairbanks, Alaska. 12. Shabecoff, Philip, New York Times, Earth Warming Likely to Cause Heavy Damage, appearing in Anchorage Daily News, Oct. 20, 1988. 13. Wolkomir, Ro, The Greenhouse Revolution, Oceans, April, 1988. 14. Lachenbruch, A.H., and Marshall, B.¥., 1986, Changing Climate: Geothermal Evidence from Permafrost in the Alaskan Arctic, Science, November 7, 1986. 15. Osterkamp, T.E., 1983, Response of Alaskan Permafrost to Climate, Proceedings, Permafrost Fourth International Conference, Fairbanks, Alaska. 16o Walker, H.J., 1983, Erosion In A Permafrost-Dominated Delta, Proceedings, Permafrost Fourth International Conference, Fairbanks, Alaska. 17. Walker, H.J., 1978, The Nature of the Seawater-Freshwater Interface' During Breakup in the Colville River Delta, Alaska, ~ermafrost Third International Conference. 18. Hwang, C.T., and Smith, M.W., 1978, Thermal Disturbance Due to Channel Shifting, Mackenzie Delta, N.W.T., Canada, Permafrost Third International Conference. 19. Beechey Point B-4 Quadrangle, US Department of the Interior, us Geological Survey, 1955, Photorevised 1975. 17 ARCO Alaska, Inc. Post Office 5,.,,, ~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1989 Chat Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Request for Exception to the Provisions of 20 AAC 25.055 Pt. McIntyre #4 Dear Commissioner Chatterton: ARCO Alaska Inc. ("ARCO") hereby applies for an exception to the provisions of 20 AAC 25.055 for the drilling of the Pt. McIntyre #4 Well (the "Well"),for which the propoSed bottomhole location is: (1) Surface Location: 1489' FSL, 681' FEL, Section 16, Township 12N, Range 14E, Umiat Meridian (2) Intersection with Top of Productive Interval: 172' FSL, 6' FWL, Section 11, Township 12 N, Range 14E, Umiat Meridian (3) Total.Depth: 500' FSL, 500' FWL, Section 11, Township 12N, Range 14E, Umiat Meridian. The owners and operators of all governmental quarter sections directly and diagonally offsetting the proposed location of the Well are ARCO Alaska, Inc., Exxon Corporation, and Standard Alaska Production Company. The plat required by the regulation is attached as Exhibit 1. The verification required by the regulation is attached as Exhibit 2. Copies of the notifications to the owners and operators, as well as the required information with respect to mailing are attached in the package designated as Exhibit 3. If you have any questions or require any additional information, please contact the undersigned. Sincerely, AR~X~Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieloCompany STUblP (COND) 3-31-77 ~t. ' S.T.P. RECEIVED JAH 2 ~ t.q~'.q 11-30-95 -2 USS 6905 ARCO-EXXON ALK 06O ,1-31-77 WEST DOCK ]-75 _ (GONO) ]NO) ADL ,14624 I°B STATE ADL 28297 ~ · · ~ I lleqeq ~,,q VERIFICATION OF APPLICATION FOR SPACING EXCEPTION PT. McINTYRE #4 WELL '~ Jeff B. Kewin, Regional Drilling Engineer in the ARCO Alaska, Inc. Drilling Department, does hereby verify the following: 1. I am acquainted with the facts associated with the drilling of the Pt. McIntyre #4 Well. 2. I have reviewed the application submitted for the exception to 20 AAC 25.055 and all facts therein are true. · ~ 3. I have reviewed the plat attached as Exhibit B and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this /~ day of January, 1989. STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) Je~k~e~ ~ SUBSCRIBED AND SWORN TO before me this day of January, 1989. 008/AMT RECEIVED JAN ! 8 Alasl~ Dil & Gas Cons. Commission '-~,~ ~chomge 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 ) AFFIDAVIT OF JON W. WOOD Request of ARCO Alaska, Inc. for) an Exception to the Provisions ) of 20 AAC 25.055 ) ) STATE OF ALASKA THIRD JUDICIAL DISTRICT Jon W. Wood, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jon W. Wood, I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am an Area Landman for the well operator, ARCO Alaska, Inc. 3. Pursuant to 20 AAC 25. 055 (b) , ARCO Alaska, Inc. ("ARCO"), the well operator, prepared a Notice of Request for an Exception to the Provision of 20 AAC 25. 055. A copy of this notice is attached hereto as Exhibit A. 4. On January 17, 1989, pursuant to 20 AAC 25.055(b) ARCO sent a copy of said notice by registered mail to the last known address of each owner and operator of governmental quarter sections directly and diagonally offsetting the quarter section of the proposed location of the oil well. Attached hereto as Exhibit B is an Affidavit of Mailing of Notice. Subscribed and sworn to this 17th day of January, 1989. JO~ J ~OOD~ STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) The foregqing instrument was acknowledged before me this day of /~~~....:. , 1989, by Jon W. Wood. Notar~ ublic~ state of Alaska My Commission Expires: ARCO Amska, Inc. !~%,~ EXHIBIT JerryL Gees Vice Pre$~,' '. January 17, 1989 Standard Alaska Production Company Attn: Mike H. Brownhill, Vice President P. O. Box 196612 Anchorage, AK 99519-6612 Exxon Corporation Attn: G. T. Theriot, Manager Alaska Interest P. O. Box 2180 Houston, TX 77252-2180 Re: Notice of Request for Exception to the Provisions of 20 AAC 25.055 Pt. McIntyre No. 4 Well Gentlemen: Pursuant to the requirements of 20 AAC 25.055(b), ARCO Alaska, Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an excep- tion to the spacing requirements of 20 AAC 25.055(a) (3). ARCO's request, if approved will permit the intersection of the wellbore of the captioned well with the top of the Kuparuk formation within 500 feet of the south line and within 500 feet of the west line of the governmental section in which the well will be bottomed. Specifically,. the intersection point applied for will be as follows: 172 feet from the south line and 6 feet from the west line of Section 11, Township 12 North, Range 14 East, Umiat Meridian. A copy of the request is attached. Very truly yours, Dees JLD: JWW: 190 Attachment RECEIVED JAH 1 8 Alasl Oil & Gas Cons. Commission '~ ~nchorage EXHIBIT B TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF MAILING OF NOTICE Request of ARCO Alaska, Inc. for) an Exception to the Provisions ) of 20 AAC 25.055 ) ) STATE OF ALASKA THIRD JUDICIAL DISTRICT Linda Sellner, being first duly sworn, upon her oath, de- poses and says: I am a citizen of the United States of America, over the age of 19 years, and employed as a secretary for ARCO Alaska, Inc. That on the 17th day of January, 1989, I sent true and correct copies of Jerry L. Dees' January 17, 1989 Notice of Request for Exception to the Provisions of 20 AAC 25.055 via United States Registered Mail, to: Mike H. Brownhill Standard Alaska Production Co. 900 E. Benson Boulevard P. O. Box 196612 Anchorage, AK 99519-6612 G. T. Theriot Exxon Company, U.S.A. 800 Bell Street P. O. Box 2180 Houston,' TX 77252-2180 DATED at Anchorage, Alaska, this 17th day of January, 1989. ~inda L. Sellner SUBSCRIBED AND SWORN TO before me this /~day of ~ , 1989. Notary Public, State of Alaska My Commission Expires: . /,/-.%/.~- February 22, 1989 Telecopy~ (907)276-7542 Mr. J. B. K~in Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re~ Pt. M¢Intyre State 4 ARCO Alaska, Inc. Permit No. 89-13 Sur. Loc. 1468'FSL, 666'FEL, Sec. 16, T12N, R14E, UM. Btm_hole Loc. 500'FSL, 500'FWL, Sec. 11, T12N, R14E, UM. Dear Mr. Kewin~ Enclosed is the approved application for permit to drill the above referenced well. The pe~it 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. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment in.stallation so that the Commission may witness testing before drtllzng below the shoe of the conductor pipe. Chairman of / Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION dif Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' STATE OF ALASKA ~-' ~--',-*"- ALASKA OiL AND GAS CONSERVATION COrv~MlSSlON PERMIT TO DRILL I:011[ilJ[lliiil 20 AAC 25.005 I la. Type of work Drill [] Redrill ©1 lb. Type of well. Exploratory [] Stratigraphic Test E3 Development Oil Re-Entry [] DeepenE]I Service [] Developement Gas [] Single Zone E.] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool feet ARCO A1 a.~ka I nc. DF =, 35' 3. Address 6. Property Designation Wi 1 dcat P.0. Box 100360, Anchorage, AK 99510 ADL 365548 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see20 AAC 25.025) 1468' FSL, 666' FEL, Sec. 16, T12N, R14E, UM N/A Statewide At top of productive interval 8. Well nu .mber Number 325' FSL, 238' FWL, Sec. 11, T12N, R14E, UM Pt. Mclntyre Stal;e 4 U-630610 At total depth 9. Approximate spud date Amount 500' FSL, 500' FWL, Sec. 11, T12N, R14E, UM March 10, 1989 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line Pt. Mci ntyre #3 500' ~ TD feet 50' at surface feet 2560 12744'MD/9542'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.O35 Kickoff depth 500 feet Maximum hole angle 49.~° Maximum surface 2841 psig At total depth (TVD) 5740 psig 18. Casing program Setting Depth (DF) size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26" 20" 80' 35' 35' 115' 115' 125 sx AS III 'i/-1/Z' 15-5/~d" 68# L-80 BTC 5148' 34' 34' 5182' 4000' 3600 sx AS Ill, 500 Class ( i2-'i//+;- 9-b/u" ~/¢ L-b~U I:;IC 11380' 33' 33' 11413' 8292' 630 sx G 8-i/2:: 7"" 29# L-80 I~IL, lfo~b' -I-IU~' f156' lZ//-~q.' ~5/~2' :300 SX G lg. 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 Surface RECEIVED Intermediate Production ~: ~i:. ~, 1 .f Liner Perforation depth: measured ,Alaska 0il & Gas Cons, C0miTIJssJ0~, true vertical ' '~ ~ch0rage 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ DiverterSketch ~ Drilling program ~ Drilling fluid program [] Time vs depth plot [] Refraction analysis ~Seabed report [] 20AAC 25.050 requirements 21.1 hereby c~¢['~fy-'~hat the foreg4Ncjg~ue and correct to the best of my knowledge Signed { /.¢ ~/'.,¢~,,.4./¢'"O,,~ ~£-.¢'''''''/' 4 Title Regional Drilling Engineer Date; Commission Use Only ,,-- / / PD3/068fWJP)/::~~)/F) (','~'%~ ' ' Permit N_umC'e~ z l APl number I Approval date ' I See cover letter 50 4::~.~. 2_.. ~'/ o for other requirements I - ?¢ I 02/2,./8g I ' Oon~iti~n~ of ~pprov~l 8~mple.~ required ];~Ye8 [] No Mud Icg required. ~Yes [] No Hydrogen sulfide measures ~('Yes_ [] No'" I~irectional survey required ~""~.~.e.s'- [] No Required working~pr.e~sure/f)dr ~-~ .,~¢M;_[] 3~; ~ 5M; [] 10M; [] 15M Other: / /..~/ / _ /// / /¢ // // // j/ /~~ ~ byorderof ,/ /f_... Approved by ~_J/~ ~ ~,,_~"//'/~ Commissioner the commission DateT,~..y~'¢/' ..... Subr'ni triplicate Form 10-401 Rev. 5 ,/ SUMMARY WELL PLAN Pt. McInt~vre State #4 1. With 20' conductor already set, spud and drill 17-1/2" hole to 500'. 2. Kick off well at 500', building angle at 2-1/2°/100' to an angle of 49.5° at 2477'MD (2241'TVD). 3. Lock drilling assembly and drill 17-1/2" hole at 49.5° to 5182'MD (4000'TVD). 4. Set 13-3/8" casing at 5182'MD (4000'TVD). Test casing, drill out, and conduct leak-off test. 5. Drill 12-1/4" hole at 49.5° to 9942'MD (7096'TVD). 6. At 9942'MD, start dropping angle toward vertical; at a rate of 2°/100'. 7. Drill while dropping angle to 11413'MD (8292'TVD). This is the top of the target interval and the wellbore angle at this point should be 20°. 8. Set 9-5/8" casing at 11413'MD (8292'TVD). Test casing, drill out, and conduct leak-off test. 9. With locked drilling assembly, drill and core through the target interval to TD (12744'MD/9542'TVD) while maintaining a 20° wellbore angle. 10. Set 7" liner from the 9-5/8" casing shoe to TD. Clean out liner and test 1 ap. 11. Run 4-1/2" tubing and packer for production test. 12. Perforate and test target interval. Store all produced fluids in properly-bermed stock tanks on location and, upon completion of testing activities, inject fluids back into reservoir. 13. After testing, set plug in tubing tail, safety valve high in tubing, and xmas tree at surface and leave well in condition to produce without additional rig work. RECEIVED Alaska .Oil .& 6as Cons. Commissior~ Po~nt Storkerson 31 20 T. 12N T. IIN 32 Topo Features Taken From Beechey Point (B-3),Alaska CERTIFICATE POINT MclNTYRE STATE NO. 4 LAT. : 70°23'27.32'' LONG.: 148°:34, 52.48" X = 674,390 Y: 5394,600 I hereby certify that lam properly registered and licensedto practice land surveying in the State of Alaska andthat this plat represents a location survey made byme or under my direct supervision and that .all details are correct. /-2..7- ~? DATE SURVEYOR I~UDHO~ Alaska.Oil .& Gas Cons. Commission. NO.,,T,,E :~~e$ Are Alaska State ~ane Zone 4 AS-BUILT WELL LOCATION POINT MclNTYRE STATE NO. 4 LOCATED IN S.E. It/4 PROTRACTED SEC.16iT. 12 N.~ R.14 E. UMIAT MERIDIAN AK. FOR ARCO ALASKA Inc. SURVEYED BY BESSE, EPPS, & POTTS ANI('Hf~RA~F Al A~KA 349-6451 · 3127G6 Hl27~9 EASTERN IERAOA ~OL ~OOI EGG IS. Et'AL 9-30-79 3-2?-04 :~urface Local 4LK-2307-A 2-28-86 AIlED-EXXON J&K-230~ NKX)-EXXON .4~LK '--2510 3 ,/ H-PAD 3-27-84 ADC 2a204 4Ot 2a2,77 3S 31 (COHO) ,N)L ~2~0 //" &K-Z315 3-27--~4 <3: L,~ C-PAD // CC- 1 t 7-31 \ TEXAS EA~IT:RN I -,il -~O N)L. 312a09 Ct.lEV- / BUlKLIN PI.IlL ET,N. 7-31-90 7-31-62 ¥-0182 AI)L 34,3103 Bottomhole Location STUMP s5. \. aOL 2aZJ7 A~::;O - E'XXOI4 N.K- 2.111 4RC3Q-EXXON ALK-Z]I4 3-27--~4 St.t~ Pt. Mc!ntyre #4 Surface Location /1468' FSL,$66' FEL, Sec. 16, T12N, R14E, UM Top of Productive Interval ~325' FSL,238'FTaT_,Sec. 11, T12N, R14E, UM Bottomhole Location. (at TD) 500' FSL, 500' FWL, Sec. 11, T12N, R14E, UM ADL 34,]107 ). 11-30-95 AR(~--EXXON N.K.-~O 3-31-77 WEST DOCK P8 SIA1[ ~1 ~S 6~ AR<X)-EXX(314 ~ 34~27 7-..11 -~0 I 1-30-~5 ARCO -EXXON .q.K-.~t · 3-31-77 BA ~ 34~2~ I sT./2 ALK-2312 3-27 -84 ALK-2$I7 DS-18 5-; IS. N.K-a~4 S.-.4-H AOL 54~2~ JJ~O-EXXO~ ALK~ 3-31-77 y' ARCO-EXXOel ALK-~, 3-27-04 ADC .14~Hi EAST 0oc~ ,,~ N.K-2HIg LPC ~-2~-a4 ~-AL)L 28321 £AST STATE %"'" 3-Z?-84 Y-Ola~ SOHIO J NIAKUK UN I T H-&!-77 NIAKUK IS. 5-27--.a4 N)L _"~_~_%~0 1-31-9O ADL 312~27 3-27-~4 aDL ~35 SAPC .I-27-O4 REFRACTION ANALYSIS PT, MclNTYRE STATE #4 ARCO, Alaska Inc. requests an exception to the requirements of 20AAC25.033(e)(1). The reason for this request is based on the drilling history of the immediate area. Please reference the attached map, The two nearest offset wells are the Pt. Mclntyre State #1 and State #3. At their bottomhole locations, the wells are 0.7 miles and 1.1 miles, respectively, away from the planned well. Although there is slight abnormal pressure below the top of the Cretaceous, these two wells along with the Pt. Mclntyre State #2 required only a maximum mud weight of 10.7ppg to drill to the top of the Jurassic. Correlation of test data from nearby wells indicates maximum bottomhole pressures for the proposed well to be near .51 psi/ft (9.8ppg). The proposed surface casing setting depth is below the base of potable water strata and the permafrost. It is also above any hydrocarbon zones. Reference log is the Pt. Mclntyre State #1 Dual Induction Laterolog, 9/15/77. PT. MclNTYRE STATE #4 DRILLING FLUID PROGRAM Spud to 13-3/8" 13-3/8" shoe to Sudace Casina 9-5/8" Casina -- _ 9-5/8" shoe toTD Density 8.7-9.2 9.0-9.8 9.8-10.5 F'V 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 5 0 - 1 0 0 3 5 - 4 0 3 5 - 4 5 Initial Gel 5-15 2-4 3-5 10 Min. Gel 15-30 4-8 5-12 APl Filtrate 2 0 1 0- 2 0 6 pH 8-9 10-11 11-12 % Solids _+ 6 4 - 7 9- 1 2 Drillina Fluid System' ° Triple tandem shale shaker ° Degasser ° 2 Desanders o 2 Desilter/Mud Cleaners ° 2 Centrifuges ° Mud Agitators ° 2 Trip tanks ° Mud tank/trip tank level indicators ° Fluid flow indicator Drilling fluid practices will be in accordance with the appropriate regulations stated in 20AAC25.033. Maximum anticipated surface pressure is calculated using 11.0 ppg mud with the well half evacuated with gas of gradient 0.11 psi/ft. This yields a maximum surface pressure of 2841 psi with the well at TD. At this pressure, the formation at the 9-5/8" casing shoe should not break down. During well testing, produced fluids will be stored in properly-bermed stock tanks on location. Upon completion of testing, produced fluids will be injected back into the reservoir. MUD SYSTEM POOL 5 II I SAND TRAP 12 BBLS PIT I PIT 2 DEGASSER PIT DESANDER PIT 105 BBLS 99 BBLS i PIT 3 PIT 4 MUD CLEANER PIT PILL PIT 100 BBLS 108 BBLS PIT 5 PIT 6 VOLUME PIT SUCTION PIT 391 BBLS 280 BBLS BRANDT TRIPLE SHALE SHAKERS SWACO DEGASSER, 1000 GPM PIONEER DESANDER (2 EACH, 1000 GPM) PIONEER DESILTER/MUD CLEANER (2 EACH, 800 GPM) PIONEER CENTRIFUGE (2 EACH, 100 GPM) JG 6/14/88 SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I III RISER 20" ~ 2000 PSI DIVERTER IFLOWLINE 10" BALL VALVE CONDUCTOR 10" BALL VALVE NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINES I I I I WELL I I" I ~ RIG MODULES ~ I I NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 13-5/8" 5000 PSI BOP STACK DIAGRAM ! ' I PREYEUTER ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS :5000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TII'IE AND 12:00 PSI REMAINING PRESSURE. PIPE RAI'I~ BLI ND R.4rlS DRILLING SPOOL PI PE RArlS DRLG SPOOL SPOOL ALL BOP EQUIPMENT 5000 PSI RATED 11. 13;-5/8" BOP STACK TEST 1. FILL BOP STACK AND I'tkNIFOLD WITH A NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING ,JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PiPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. :5. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 2:50 PSI LOW PRESSURE TEST FOR A I'IlNII'IUI'IOF $ r'IlNUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO 3;000 PSI AND HOLD FOR A MI NI MUM OF $ I'IlNUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3; MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAI'I OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3; MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAI'IS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOI"I :SET OF PIPE RAMS AND HOLD FOR AT LEAST $ MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PI PE RAMS. BACK OFF RUNNING ,JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST $1'11NUTES. 13;.BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. 1 4.TEST STANDPIPE VALVES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 18. PERFORI"I COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8- 26-85 ARCO"ALASKA. Ino, Point HeIntyre Stets #4 Revised Proposal Pt, Hclntyre, North Slope, Aleeke 1000 2000 RKB ELEVATION~ 42' KOP TVD=500 TI'ID=500 DEP=O s lO BUILD 2.5 OEO !$ PER I00 Fl' 2O 25 30 4o 45 EOC TVD'=2241 THD=2477 DEP=801 3000 4OOO 5OOO 60O0 MAX[HUH ANGLE 49 DEG 26 M[N 13 318" CSG PT TVD=4000 THD=5182 DEP=2856 7OOO BOO0 9OOO BEGIN ANGLE DROP TVD=7096 THD=9942 DEP=6471 TARGET ANGLE 20 DEG DROP 2 DEO PER 100 F~ 9 5/8' CSO PT / END ANGLE DROP TVD=8292 TMD=lI413 DEP=7300 4.8 44 40 36 32 28 24 20 TD / 7" CSG PT TVD=9542 THD=12744 DEP=7755 10000 1000 2000 i i i t i 3000 4000 5000 6000 7000 VERTICAL SECT[ON I 8000 HORIZONTAL PROJECTION SCALE 1 IN. '-- 1000 FEET ARCO ALASKA, Ina. Point Holntyre State #4 Revised Proposal Pt. He[ntyre. North Slope. Alaska Z --4 '1' I C~ '-4 'r 5000 4000' _ 3000 _ 2000 _ 1000 _ O 1000 _ WEST-EAST 000 0 1000 2000 3000 I I I I SURFACE N 56 DEO 13 HI N E 7755' ( TO TD ) SURFACE LOCATION, 1468' FSL. 666' FEL SEC. 16. T12N. R14E 4000 5000 6000 7000 I I I I TD LOCAT[ONt $00' FSL. 500' FWL SEC. II. T12N. R14E ~50 5O 5O 100 150 200 I ! 200 150 100 50 0 I, I I I ~00 I ! 1 50 1 O0 50 100 O0 150 i /'""1 400 5500 3400 3300 20O 3200 J "1 ! 'i i '! " ' 50 0 50 1 O0 1 50 200 150 100 5O 5O 100 150 ARCO Alaska, Inc. February 13, 1989 Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attention: Mr. Mike Minder Dear Mr. Minder: Per your discussion with Tom Maunder on February 10, en- closed are the required copies of the Pt. McIntyre #4 revised permit to drill. The permit application was revised due to receipt of the surface location survey and reducing the ultimate depth proposed. The directional drawings have been revised accordingly and the application text and attachments have been changed to reflect the corrected information. The entire package has been resubmitted per your suggestion to avoid any possible confusion. We ask that you please return the application previously submitted. It is also requested that all information concerning this project be held confidential in accordance with the Commissions' procedures. Should you require any further information, please contact me at 263-4970 or Tom Maunder at 263-4971. Yours truly, ~. B .~ Ke~fin ~ egional Drilling Engineer JBK/TEM/ih Ltr01 2/13/89 cc: T. E. Maunder Pt. McIntyre #4 File RECEIVED A/aska Oil & Gas Cons. Commisslor~' ..... ~ ~chorage ---- STATE OF ALASKA ALASKA ~..- AND GAS CONSERVATION CC.,~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill ~1 ~b. Type of well. Exploratory t~' Stratigraphic Test Re-Entry ~ Deepen[]1 Service [] Developement Gas [] Single Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. F/d and Pool ARCO A1 aska, I nc. DF = 35' feet /~Wi 1 dcat 3. Address 6. Property Designation P.O. Box 100360, Anchorage, AK 99510 ADL 365548 / 4. Location of well at surface 7. Unit or property Name ~ 11. Type Bond lsee20AAC25.025~ 1489' FSL, 681, FEL, Sec. 16, T12N, R14E, UM N/A/ Statewide At top of product~e interval 8. Well nu .mber / Number 172' FSL, 6' F~I~, Sec. 11, T12N, R14E, UM Pt. Nl~_lnt'_vr~.c,~.n~_~_ ~ 8088-26-27 At total depth~ 9. Approximat~ s/F6d date Amount / 500' FSL, 500' FWL, S~¢. 11, T12N, R14E, UM March 1~ ,,1'989 $500~000 12. Distance to nearest N~3. Distance to nearest well 14. Number/¢~ acres in property 15. Proposed depth(MO and TW~ propertyline ~ Pt. Mclntyre #3/ / 681 feet 7,5' al; ~urf~.~ feet 2~c--~ 16. To be completed for deviated we'lt~, · 17. A/~cil:~ted pressure ,se~ ~o A~c'~.0s5 Kickoff depth 500 feet Maxir~m hole angle 48 0 Maxij;~'um sul~ce 2841 ,-psig- At totalded~h (TVD) 5740 ps,g 18. Casing program ' ~ \ / Settin~6epth ,ur size Specificatioi~ // Top 'X~Bottom /Quantity of cement Hole Casing Weight Grade Couplin~Length /~M_D. TVD I~ TVD / (includestagedata) 26" 20" o,~, ~ ..... .,.. . ~'~.., 17-1/91" I~,-~,/R~ ~R~ I -R~l RT~' -~c;, m~no, ;,nn ~,"nn .- ~-c , ~ ~ cnn ~-c ............ ........%7;; 12- " 9-5/8" 47# I-RO RT¢, I ' '~r~ k 1~, I 1 '~RCi~ , 19. To be completed for Redrill, Re-entry, and n OD ns. Present well condition summary ~/ ~ ~ Total depth: measured (/ / !b~t ~Plugs (measui~e,~ true vertical "/ fee't, \ -- Effective depth: measured ,// feet'~ J un~(measu red) . true vertical /~~. / \ feet ~ Casing --..--'"'"~ngt~--~ Size Cemented k Measured depth True Vertical depth Structural .~ k / Conductor / k k / Surface / '~ ~._~ ~ D I nt~rme~iante .R E C E IV E PerfL~Ta~i°n d~th: rr;?cal J~j],S[(~3, C0,mmissi°n %N/rue vert'cal ! ..... X .... ' ~ "" '" 20. Attachments ng program Drilling fluid C 25.050 requirements 21' I hereby c~tify//that the fOre~/~ng i~;x'ue and c°rrect tO the best Of my knOwledge Signed /~,~,~ /~~' Title Regional Drilling Engineer Date //X'- ~' ~' / / ~" ~ Commission Use Only Permit Nt/"nber I API number I Approval date Ieee co~er letter ~'¢_/,~' 50--O~_. ~'- ,,~//¢/,2.- for othe~requirements Conditions of approval Samples required ,,~3rYes [] No Mud Icg required ,,~Yes [] Hydrogen sulfide measures ,~Yes [] No Directional survey required ,~K;YO's' [] No Required working pressure for BOPE ?.2M; [] 3M; ~ 5M; [] 10M; [] 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate SUMMARY WELL PLAN PT. MclNTYRE STATE #4 1. With 20" conductor already set, spud and drill 17-1/2" hole to 500'. ~-- ' 2. Kick off well at 500', building angle at 2-1/2°/100' to an angle of 48°, 2'MD (2205'TVD).~., 3. Lock drilling assembly and drill 17-1/2" hole at 48° to 5108'MD (40~0'~'VD). _ 4. Set 13-3/8" casin'q at 5108 MD (4000'TVD). Test casing, drill ~,, and conduct leak-off 5. Drill 12-1/4" hole at'x~8o to 9987'MD (7261'TVD). 6. At 9987'MD, start dropp'i~ angle tow, ard vertical at a~ate of 2°/100'. 7. Drill while dropping _angle',~o 11,389MD (8412'TVD~. This is the top of the target interval and the w~ilbore .angle at this~point should be 20°/ 8. Set 9-5/8 casing at 11,38'9,'MD (8412'TV/D). Test casing, drill out, and conduct leak-off test.. ..... ~ ~ , 9. With locked drilling assembly, drill~and c~re through the target interval to TD (13,124 MD, 10,042'TVD) while maintaining a 20~w~llbore angle. 10. Set 7" liner from the 9-5/8" casing ~ TD. Clean out liner and test lap. 11. Run 4-1/2" tubing and packer fo/r/producfioxn test. 12, Perforate and test target interyal. Store all ~oduced fluids in properly-bermed stock tanks on location and, upon compl.~, on of. testing act~(~es, inject fluids back into reservoir. 13.aAnfc~elre taevSetinwgeiI ~netcPlUg in t~bing tail, safety valve~igh in tubing., and xmas tree at surface REFRACTION ANALYSIS PT. MclNTYRE STATE #4 ARCO, Alaska Inc. requests an exception to the requirements of 20AAC25.033(e)(1).//~ The reason for this request is based on the drilling history of the immediate~rea. Please reference the attached ma The two nearest offset wells the Pt. Mclntyre State #1 and State #~ ~ At their bottomhole locations, the wells are 0.7 and 1.1 miles, respectively, awaY/from the planned well. Although there is slight abnormal I: ssure below the top of the these two wells along with the Pt. Mclntyre State #2 ;d only a maximum mud w ~ht of 10.7ppg to drill to the top of the Jurassic. Correlation of data from nearby wel maximum bottomhole pressures for the proposed well to be .51 psi/ft (9.8 The proposed surface casing setting de permafrost. It is also above any h~ Dual Induction Laterolog, 9/15/77. is below th zones. base of potable water strata and the ;ference log is the Pt. Mclntyre State #1 ~OL 3127~8 7-31-93 L~ SM=C 5-27-84 T- .~OL 2~278 N)L 2~2al / H-PAD 3-27-84 A0L 28284 I-5! -90 NiL 5127~ 1EXAS ~N I-]l-~O AOL]I2~O~ ~IDL 51~I001 ECG IS. ?-5l ]IEXAS EASTERN 1-3! -90 AOL 312a0~ 7-Jl-g2 .41)L~I0~ jBottomhole Location Pt. MclntYre #4 Surface Location 1489' FSL, 681' FEL, Sec. 16, T12N, R14E, UM Top of Productive Interval 172' FSL, 6' FWL, Sec. 11, T12N, R14E, UM Bottomhole Location. (at TD) 500' FSL, 500' FWL, Sec. 11, T12N, R14E, UM .41)L~107 R&B 9-5~-75 :~urface Location1 STUMP IS. CJI.OIL VAUGHN PE'mOL ALK-230?-A 2 ,. I I · 40L 2~277 7-31-~0 F-PAD 3-27--~4 CC- 1 I ADL .EXXON K-PAD -N~:30-EXXON ALK-2$14 3-27-B4 P.B.~ ST.Jl 9-~-75 (mNO) I sri2 ALK-2{I2 , 3-27 -84 N.K-2517 ~ os-18t 5-: M.K-Z315 3-27-84 · M:)L 28504 ARCO -lDO(ON 3-51-77 AOL 3~26 ,NK:X)-EXX~ ,M.K-B63 9 -4 -~ BEACH l$. J4.K-a64 0-.4-98 ARCO-EXXON 4LK~ 3-31-77 ,~N.K-2319 ,LPC ~-:2'7 ~ -~-ADL 28]21 .4d~O-EXXOel 3-27-a4 ADL 34~51 EAST DOCK EAST BAY STATE ,NK~O-EXXOIM %% 5-z1-84 Y-Old · Sq~C SOHIO NIAKUK UN I T 5-,31-77 ~OL 346Z5 9-4-96 NIAKUK IS. ,~-27--a4 ADL 4RCO-L-XXON N.K-2321 3-27-84 DS~-L4 -31-90 2827 SAPC 3-27-84 ADL .}4~35 ,3-27---~4 : .. ~ c, , !.. 51 .--'.~ ,-'..., , ..,., ~ . <,. ,.. · f;::..'" .. ...,...o...o, ..~.. ~..~,.,, ,., ,.. ,,, i.~-:~.....,. ...,, o.,,.-:.:.~' · /' ' :~'; ~':'" S :" I~ ~/'-. ' ":: ", .,./' , '. .. conoco Ill SOulh l' ',-- ,:' _..,~-" ' · '.." ' .... ...~' Hi~lt~ ¥ · ugh n ~,~. \ :~/ Niakuk 3 ' ~.,, p~Oposed well location Pl. ". MUD SYSTEM POOL 5 SAND TRAP 12 BBLS PIT I PIT 2 DEGASSER PIT DESANDER PIT 105 BBLS 99 BBLS _ PIT 3 PIT 4 MUD CLEANER PIT PILL PIT 100 BBLS 108 BBLS I I I I PIT 5 PIT 6 VOLUME PIT SUCTION PIT 391 BBLS 280 BBLS BRANDT TRIPLE SHALE SHAKERS SWACO DEGA$SER, 1000 GPM PIONEER DESANDER (2 EACH, 1000 GPM) PIONEER DESILTER/MUD CLEANER (2 EACH, 800 GPM) PIONEER CENTRIFUGE (2 EACH, 100 GPM) JG 6/14/88 SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE 2000 PSI DIVERTER RISER I FLOWLINE 10" BALL VALVE I I CONDUCTOR 10" BALL VALVE NOTE' ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINES I I I I nl~ I WELL 0 ~11 I I" I I ' RIG MODULES I I NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 PT. MclNTYRE STATE #4 DRILLING FLUID PROGRAM Spud to 13-3/8" 13-3/8" shoe to ,Surface Casina 9-5/8" Casing 9-5/8" shoe toTD Density PV Viscosity Initial Gel 10 Min. Gel 8.7-9.2 9.0-9.8 15-30 5- 1 5 '$~-40 8-12 100 35-40 5- 5 2-4/~ 15- 0 9.8-10.5 9-13 8-12 35 45 - 3-5 5-12 //10-20 6 APl Filtrate 20 10-11 pH % Solids +_6 4 - 7 9- 1 2 11-12 Drilling Fluid System: ° Triple tandem shale s \ o Degasser / ~ o 2 Desanders \ ° 2 Desilter/Mud Cl~ n ;rs ~ ° 2 Centrifuges / ~ ° Mud Agitators / ~ o 2 Trip tanks / ~ o Mud tank/trip/tank level indicators ~ ° Fluid flow ~icator ~, Drilling fluid practi)bes will be in accordance with~the appropriate regulations stated in 20AAC25.033. / _~ Maximum anticipaled surface pressure is calculated us~g 11.0 ppg mud with the well half evacuated with ga~ of gradient 0.11 psi/ft. This yields a m'~ximum surface pressure of 2841 psi with the well at TI~. At this pressure, the formation at the ~-5/8" casing shoe should not break down. ~. ~ During well testing, produced fluids will be stored in properly-bermed stock tanks on location. Upon completion of testing, produced fluids will be injected back into the reservoir. 1,3-5/8" 000 PSI BOP STACK DIAGRAM I I IANNULAR PRFyFNTER1 PI pF RAMS BLIND RAMS DRILLING SPOOL PI PE RAMS DRLG SPOOL CSG SPOOL 13-3/8" HEAD ALI. BOP EQUIPMENT 5000 PSI RATED ACCUMULATOR CAPAI~ITY TI~T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS :5000 PSI WITH 1500 PS1 DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IAI)C: REPORT. THE ACCEPTABLE LOWER LIMIT I$ 45 SECONDS CLOSING TIME AND 12:00 PS1 REMAINING PRESSURE. , , e Be 10. 11. 12:. 13. 14. 15. 16. 17. 18. 13-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING ,JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. FUNCTIONALLY TEST CHOKES. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 2:50 PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TEST AT THE HIGH PRESSURE. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR A MINIMUM OF $ MINUTES. BLEED PRESSURE TO ZERO. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3 MINUTES. BLEED PRESSURE TO ZERO. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO SO00 PSI AND HOLD FOR AT LEAST $1'11NUTES. BLEED PRESSURE TO ZERO. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO SO00 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST $ MINUTES. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH SO00 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PI PE RAHS. BACK OFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST $1'11NUTES. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8- 26-85 HORIZONTAL PROJECTION SCALE 1 IN. ~- 1000 FEET ARCO ALASKA, l~c. Point Mclntyre Stets #4 Proposed Pt. Hclntyre. North Slope. Aleeke 5000 4000 _ 3000 . z 1000 _ 1 000 _ WEST-EAST 0 1000 2000 3000 4000 5000 6000 ~..,~. SEC. 1 1, T.~,.,I~A~. R 14E %-,.. N 56, DEG 25 TARGET TVD-S412 TI*lb- 11389 DEP=T 163 NORTH 3963 EAST 5g~? GET LOCATION' FSL, 6' FWL !1, T12N. RI4E SURFACE 7000 I SURFACE LOCATION, 148g' FSL. 681' FEL SEC. 16, T12N. R14E ARCO ALASKA, I~e, Po~n~ Moln~yre S~e~e #4 Proposed P~. Mclntyre. North Slope, Aleeka 1000 2000 3000 4000 5000 6000 7000 8000 9O00 10000 11000 I RKB ELEVAT[O#, 42' KOP TVD-500 TMD-500 DEP-O $ lO I $ 2.5 OEO 20 I00 Fl' 30 40 4s EOC TMD-2422 13 3/8' PT TVD-4000 TMD-5108 DEP-2757 MAXI NGLE 48 DEG 3 MIN BEGIN ANGLE DROP TVD=7261 TMD-9987 DEP-6386 4~ 44 40 36 DROP 2 OEO PER lOO FT 32 28 24 TARGET / 9 5/8" CSO PT TVD-8412 TMD=II389 DEP=7163 (END OF DROP) TARGET ANGLE 20 DEG TO / 7" CSG PT TVD-10042 TMD-13124 DEP-?756 I I I I I I I I 1 000 2000 :~000 4000 5000 6000 7000 9000 200 _ 150 _ 100 50 - O ~ 50 _ 100 _ 150 200 200 150 1 O0 50 0 50 1 O0 1 50 200 I I i i i I I i J 0oo 10o IOO '0o ~oo / '~! 300 "' 1200 "' 1100 / 000 / "'900 800 ;00 400 I I I 3600i _ 200 150 I00 5O oo I ~0o ~o0 oo O0 3300 50 I I ! I I I I I 200 ~ 50 100 50 0 50 100 ! 50 200 _ 150 _ 2OO ,/ ARC ' ~ /,,~os~ffice Box 100360 f A~orage, Alaska 99510-0360 ~lephor;e 907 276 1215 October 20, 1988 Mr. W. D. McGee Regional Environmental Supervisor Northern Regional Office Alaska Department of Environmental Conservation 1001 Noble Su'eet, Suite 350 Fairbanks, AK 99701 Re: RES ENO F Permit Application for Disposal of Solid Dfillin~,g~Waste at Pt. Mclntyre Exploratory Drill Sites #3 an0[~4 ) Dear Mr. McGee: SR ENG SR ENG ENG ASST I GEOL ASST/ '~E-'~ ASSTI , ARCO Alaska Inc. hereby makes application for a solid waste disposal permit at the proposed exploratory drill site Pt. McIntyre #4, to be located on an existing gravel pad near Well #3. An aerial photograph has been submitted which shows the area of proposed activity. The Pt. McIntyre drill site will contain only one new below-grade drilling waste reserve pit, to contain the cuttings from drilling new Well #4 and reentering/deepening Well #3, as indicated in Attachment 4, Figure 4-3. Only drilling wastes from this exploratory activity will be disposed of at this location. It is estimated that up to 15,000 cubic feet of drilling waste may be generated durtn~ this operation, but no other drilling or domestic waste will be disposed of in this pit. This application provides for burial of the drilling waste at a depth of at least eight feet below tundra level, as stipulated by ADEC. This depth is submitted for approval only because this is an exploratory well and its permitting is time-critical. ARCO still maintains that freezeback (i.e., crystallization) of the solid waste will occur and be maintained at a depth of four feet or less below tundra. ARCO only agrees to incur the additional cost of constructing this pit with eight feet of freeboard in order to gather additional data to support the geotechnical calculations that show four feet of freeboard is adequate. Therefore, this permit application is not intended to, nor should it be construed to, waive ARCO's position that it is unnecessary to bury the waste eight feet below tundra to achieve freezeback. This site was selected in an attempt to minimize any possible adverse land surface impact and still serve the objectives of searching for and evaluating new. hydrocarbon ,~,~ 12~ ~.~,--(7"~ ~ [[ E D accumulations. By locating the well on an existing gravel pad, the drilling waste can be covered over with native soils for permanent freezeback and further buffed under a gravel pad if production development is warranted. OCT 2 7 . Total personnel at the proposed location at any given time during drilling operations is not Oil & ~as Cons. C0nm}i:..si,:~xpected to exceed 50 employees and contractors. There are no residents within two miles of the proposed location and no below-grade fresh · water sources exist because of permafrost. · o JPG/88-029 ARCO Alaska. Inc. I. a Subsidiary of AtlantlcRIchlteldCompany CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8)' '- ' ($) (3) Admin 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~.~.~ ..~. -/~-M~ (14 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. Company .. ~ ~,~) Is the permit fee attached .......................................... Lease & Well No. ~D/-.~&c~G~ YES NO 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... ~.~ Is the lease number appropriate ..................................... ~p~ Does the well have a unique name and number ......................... ~.~C~ Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. . ..... 0 thru' 31) rev: 01/30/89 011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. ~c~ ~ , Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented~ Additional requirements ............................................. INITIAL OEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information. COIqP*ANY N:AIMIE : ARCO *ALASKA~, ]:NC,. : PT. RC]:NTYR~ .'STATE : ti ~AT : SLOPE : : 5 Zg-Z191Z : 73,293 I c LIdED .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: **** REEL HEADER *~*f SERVICE NA~E : EDIT DATE : 89/04/23 ORIGIN : FLIC REEL NAME : T3193 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA INCos ~ILDCAT, PT. #CINTYRE STATE ~4, 50-019-21912 ~*** TAPE HEADER SERVICE NAME : EDIT DATE : 89/04/23 TAPE NAME : 73293 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA INC., WILDCAT, PT. MCINTYRE STATE ~4, 50-029-21912 '~V ICE : FLZC VERSION : 00!1A02 DATE : 89/04/23 MAX REC SIZE : I096 FILE TYPE : L'O LAST FILE COMPANY NAHE: ARCO ALASKA, INC. NELL: PT. MCINTYRE STATE FIELD: ~ILDCAT' BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBER: 50-029-21912-00 LOCATION: 1468' FSL & 666' FEL SECTION: 16 TOWNSHIP: RANGE:: 14E PERMANENT DATUM: MSL ELEVATION: O. .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: Z LOG MEASURED FROM RKB 42. ELEVATIONS DATE LOGGED: RUN NUMBER: TD ORILLER: TD LOGGER: CASING 1: ABOVE PERMANENT DATUM DF: 42. GL: 7. OS-APR-89 ONE 11355. 11024. 9 5/8m ~ DRILLER DEPTH OF 5Z00 AND LOGGER DEPTH OF 5201 BIT SIZE 1: 12 1/4" T¥,PE FLUID,' I#,:-:H~E,~: OENSITY: 9.6 VISCOSITY PH: 8.9 MUD RESISTIVITY: MUD CAKE RESISTIVITY: 2.54 a 70. 1.91 a 70. t, RO ED: 1 37 . LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUOHOE BAY WARNER CAMPAIGN/COOPER TOOL NUMBERS: DIS EC 1131 SGC JC 310 SLC MA I55 NLM:BC '1016 DIC DA 417 SLS HA 1500' IEM BO 1347 SLM DA 1552 FIELD REMARKS: SEVEN 3" STANDOFFS AND 2' HOLE FINDER USED. SP SHIFT AT 9804eo DATE JOB STARTED:: lO-APR-89 JOB REFERENCE NO': 73275 LDP/ANA: R. SINES RUN NUMBER: TWO TD DRILLER: 12845 TO LOGGER: 128Z6 CASING CASING 13 3/8" ~ DRILLER OEP'TH OF 5200e AND LOGGER DEPTH OF 5201' 9 5/8n ~ DRILLER DEPTH OF 11348e AND LOGGER DEPTH OF 11348~ BIT SIZE 1: 12 1/4 .IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: BIT SIZE 2: 8 1/2 TYPE FLUID IN HOLE: LSND POLYMER OENSITY: 10 LB/G VISCOSITY: &2.O S PH: 8.6 FLUID LOSS: 6.2 C3 MUD RESISTIVITY: 1.92 a 68 FILTRATE RESISTIVITY: 1.71 i 68 MUD CAKE RESISTIVITY: 1.6 a 68 TIME CIRCULATION ENDED: 13:45 16-APR TIME LOGGER ON BOTTOM: 01:30 1T-APR MAXIMUM TEMP RECORDED: 174 LOGGING DISTRICT: PRUDHOE BAY LOGGING ENGINEER: SARBER WIT NE S S: C AMPA ~GN/COOP ER TOOL NUMBERS: AMM-AA-8TO TCC-B-281 DZC 271 O~$~,276 TC~ 107 STR 130 NDH 5~1 FIELD REWlARKS: FOUR I 1/2" STANDOFFS USEO ON DITE. SIX ! 1/2" STANOOFFS USEO ON SDT. KALMAN ~ILTER OPTION USED ON NGT. MATRIX DENSITY = 2,65 G/C3. FLUID OENSITY= 1o0 G/C3. DATE JOB STARTED: II-APR-89 JOB REFERENCE NO: 73293 LDP/ANA: J. KOHRING THIS DATA HAS NOT BEEN DEPTH .SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED IIITH THiS FILE (EDIT.O01): <SEE FILE EDIT.O02 FOR 2"' SAMPLED EPT/MLL DATA) DUAL INDUCTION LOG C.OIL - RUN1) FIRST TO LAST READING:' 11016' TO 5201' BOREHOLE COMPENSATED LOG (oBHC - RU'N1) FIRST TO LAST READING: 1008'1" TO 5201' CASING GAMMA RAY LOG (.CHL - RUN1) FIRST TO, LAST READING: 5219' TO O' .IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 24-APR'lO89 18:07 DEPTH CHECK CORRELATION PASS C.COR - RUN2) FIRST TO LAST READING: 10256' TO 9964' PHASOR DUAL INDUCTION LOG (.DTE - RUNZ) FIRST TO LAST READING: 12818' TO 11348' ARRAY SONIC LOG C.SDT - RUN2) FIRST TO LAST READING: 12785e TO 113a8' NGT GAMMA RAY (oNGT RUNZ) FIRST TO LAST READING: 1ZT49' TO 10624' LITHO DENSITY COMPENSATED LOG C.LDT- RUNZ) FIRST TO LAST READING: 128Z2' TD 11348' COMPENSATED NEUTRON LOG ¢oCNL - RUN2) FtR'ST 1~T94:":' TO 11348" PAGE: TUNI , VALU DEFI CN ARCO ALASKA. INC. COMPANY NAME FN WILDCAT FIELD NAME WN PT. MCINTYRE STATE ~,¢. WELL NAME APIN 50-029-2191Z API SERIAL NUMBER FL 1468' FSL~ & 666' FEL FTELD LOCATION SECT 16 SECTION T OWN 12N TO~N'SH~ P RANG .I~E RANGE COUN NORTH SLOPE COUNTY STAT ALASKA STATE OR PROVINCE NAT1 USA NATION ENGI G. SARBER ENGINEER~S NAME M~TN ~. CAMPAI,GN~ G. COOPER ~ITNESS"S NAME SON .5&8~,3Z SERVICE OROER NUMBER PDAT MSL PERMANENT DATU~ EPD FT L~P DRILLING FLOOR LOG MEASUREO FROM APO FT EKB EOF PT · Z. 5 EG:L FT T. TDD FT ZZB~5. TABLE TYPE : CURV DEFI DEPT SFLU DEPTH CHANNEL NAME SFL UNAVERAGED TAPE VERTFICATION LISTTNG [CHLUNBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: ILM iLO SP GR TENS DT TT1 TTZ TT3 TT4 GR SP TENS GR TENS SFLU ILlq ILO IL-MEDIUM RESISTIVITY IL-DEEP RESISTIVITY SPONTANEOUS POTENTIAL GAMMA RAY TENSION DELTA:T TRAN:S~T TIME ! TRANSIT TIME 2: TRANSi~T TIME 3 TRANS'XT TIME d~ GAMMA :RaY NTIAL TE GAMMA "'RAY TENSION SFL UNAVERAGED I L-MEDIUM *R E SIST I V IT Y I R:E$I5~ H IFRE CIDP CIMP IIRD IIXD IIRH SGR TENS MTEM MRES HTEN DT DTL DTLN OTLF DTCO DTSM COHC COH$ COST TT1 TTZ TT3 TT~ LTT! LTTZ LTT3 LTT~ SGR TENS HT EN SGR N'EO~:UM PHASOR RESISTIVITY INDUCTION CALIBRATED FREQUENCY I.NDUCT~ON OEEP PHASOR CONOUCTIVITY INDUCTION MEDIUM PHASOR CONDUCTIVITY INTER~:EDIATE INDUCTION REAL DEEP CONDUCTIVITY INTERIqEDIATE INDUCTION QUADRATURE DEEP CONDUCTIVITY INTERMEDIATE 'INDUCTION REAL ~qEDIUM CONDUCTIVITY SPECTROSCOPY GAMMA-RAY TENSION MUO TEMPERATURE MUD RESIST!VITY HEAD TENSION 'DELIA-T DELT.A T LONG SPACING DELT::A-T LONG SPACING NEAR DELTA-:T LONG SPACING FAR DELTA'T CO'MPRESSIONAL DELTA-T SHEAR MEASUREMENT COHERENCE'VALUE AT COR:PRESSIONAC PEAK COHERENCE VALUE: AT SHEAR PEAK COHERENCE VALUE AT STONELEY'~':P'EAK TRANSIT TIME ! TRANSIT TT~E Z TRANSIT TI~E 3 TRANSIT TIME A LONG SPACING TRANSIT TIME MODE ~ LONG SPACING TRANSIT TIME MODE 2 LONG SPACING TRANSIT TIME MODE 3 LONG SPACING~TRANSIT TIME MODE 4 SPECTROSCOPY GAM'MA-R AY TENSION HEAD TENSION SPECTROSCOPY GARMA-RAY .IS TAPE VERIFICATION LISTING ;CHLUR~ERGER ALASKA COMPUTING CENTER Z4-APR-1989 18:07 PAGE: DEFI ....................... CGR COMPUTED GAM~A . S~UM THOR THORZUM POTA POTASSIUM URAN URANIUM WZNG WINDOW I (.150 - .5 MEV) WZNG WINDOW 2 (.5 - 1.1 MEV) W3NG WINOOW 3 (1.1 - 1.6 REV) W~NG WINDOW · C1.6 - Z MEV) WSNG WINDOW 5 (Z - 3 MEV) CS CABLE SPEED HTEN HEAD ~TEN:S~ OPH~ DENSITY POROSITY RHOB BULK DENS,T1 DRHQ DELTA RHO PEF PHOTO-ELECTRiC FACTOR QLS QUALITY CONTROL OF LONG SPACING FOR LOT QSS QUALITY: CONTROL ~ SHORT SPACING FOR LOT LL LITH SS1 SS2 LSHV SSHV S1RH LSRH LURH CALI GR TENS MTEM MRE S HTEN ENPH ENRA CFEC CNEC RCEF RCEN NPH! TNPH TN:RA RTNR NPOR RCNT RCFT CNTC CFTC GR NVR FVR LONG ~/LO:WER #INOO:W COUNT RATE LITH:OLOG WINDOW COUNT RATE SHORT SPACING I WINDOW COUNT RATE SHORT SPACING 2 WINDOW COUNT: RATE LONG SPACING 'HIGH VOLTAGE OUTPUT SHORT SPACING HIGH VOLTAGE LOOP OUTPUT SHORT SPACING I DENSITY LONG SPACING~'RHOB CUNCORRECTED) LONG UPPER RHOB CALIPER GAMMA RaY TENSION HUD TEHPERATURE HUD 'RESISTIVITY HEAD TENSION EPITHER~AL NEUTRON POROSITY CALIBRATED EPITHERMAL NEUTRON RATIO CORRECTED FAR EPZTHERNAL COUNTS CDRRECTEO NEAR EPITHERHAL COUNTS RAW CORRECTED EPITHERHAL FAR COUNTS RAW CORRECTED'EPITHERMAL 'NEAR COUNTS NEUTRON POROSITY THERMAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO RAW THERMAL NEUTRON RATIO NEUTRON POROSI'T¥ OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAWI~A RAY NEAR VOLTAGE REFERENCE FAR VOLTAGE REFERENCE TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTINg CENTER 24-APR-1989 18;07 PAGE: 7 DEFI GR GA#MA RAY SA SMALL ARM CALI CALIPER TENS TE~ION MTEM MUD' TEMPERATURE MRES MUO RESISTIVITY HTEN HEAD TENSION IOPH INDUCTION DEEP PHASOR RESISTIVITY IMPH INOU~ION MEOTUM PHASOR RESISTIVITY SP SPONTANEOUS POTENTIAL SGR SP OSCOPY GAMMA-RAY HTEN HE IDN SET TYPE - 64EB TYPE ,REPR CODE VALUE ! 66 0 Z 66 0 3 73 6 66 5 66 6 T3 7' 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 1~ 65 FT 15 66 68 16 66 0 66 .0 .~m .m,,.-- ~.m --~ ,,.,m. -- ** SET TYPE - CHAN ~ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOO NUmB SAMP ELEM CODE CHEX) DEPT FT ~48432 O0 000 O0 0 :[ :1 :!. & 68 0000000000 SFLU DIL OHMM 54863Z 07 Z20 01 0 ! 1 1 4 68 0000000000 ILM OIL OHMM 548432 07 tZO 44 0 1 1 1 4 68 0000000000 ILO DIL OHMM 54843Z 07 120 46 0 1 I 1 4 68 0000000000 SP DIL NV 548432 07 OlO O1 0 ! 1 I 4 68 0000000000 GR DiL GAPI 548432 07 310 O1 0 1 I 1 4 68 0000000000 ,IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18~07 PAGE: NAME SERV UNIT SERVICE API AP/ API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE CHEX) TENS D/L LB 548432 07 DT BHC US/F 548432 07 TT1 BHC US 548432 07 TTZ BHC US 548432 07 TT3 BHC US 548432 07 TT4 BHC US 548432 07 GR BHC GAPI 54843Z 07 SP BHC MV 548432 07 TENS BHC LB 548432 OT 635 21 0 I I I 4 68 520 80 0 1 I I · 68 522 83 0 I I I 4 68 522 83 0 I I I 4 68 522 83 0 I I I 4 68 522 83 0 I I I 4 68 310 01 0 I 1 I 4 68 010 01 0 I I I 4 68 635 21 0 I I I 4 68 O t ! 1~. 4 0 I I I 4 0 I 1 1 4 0 1 1 1 4 0 1 1 1 4 O I I I 4 0 I I I 4 GR ........ 6~'~ ~'t ~:~:~ O~ .... 13t0 Ot TENS CHL LB 548432' 07 635 21 SFLU DTE OHMM 548432 07 220 01 ILM DTE OHMN 548432 07 120 44 ILO DTE OHMM 548432 07 120 46 SP DTE MY 548432 07 010 01 IDPH DTE OH:MM 5~8432' 07 1;!0 46 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 '68 68 00OOO00000 68 0OOOOOOOO0 68 0000000000 68 0000000000 68 0000000000 68 0000000000 DTE, CIMP DTE ' MMHO 548432 IIRD DTE MMHO 548~32 ~IXD OTE MMHO 548432 , IIR~ DTE M~HO 548432 SGR DTE GAPI 548432 MTEM OTE DEGF 5~8~32 MRES DTE OHM~ 548432 HTEN DTE ' LB 5~8~32 DT SOT US/F 548~32 DTL SDT US/F 5~8~32 OTLN SOT US/~ 548432 DTLF SOT US/F 5~8~32 DTCO SOT US/F 5~8432 DTSM SDT US/F 548432 COHC SOT COHS SDT COST SOT TT! SDT U5 TT2 5DT U5 TT3~ SDT , US TT4 SOT US LTT1 SOT US LTTZ SDT US LTT3 5DT US LTT4 SDT US 548432 548432 548432 54843Z 5,48432 548432 54843Z 54843Z 548432 54843Z 54843Z SGR SOT GAPI 548432 TENS SOT LB 548432 HTEN SOT LB 548432 SGR NGT GAPI 548432 CGR NGT GAPI 548432 THOR NGT PPM 548432 07 07 07 07 07 07 07 07 0'7 07 07 07 07 O7 O0 O0 O0 O0 O0 O7 O7 O7 O7 O7 07 O7 O7 O7 07 07 O7 O7 O7 I 46 0 I I I 4 68 110 44 0 I I I 4 68 O00 0.0 0 I I I 4 68 000 O0 0 I I I 4 68 000 0 0 0 1 1 1 4 68 310 O1 0 1 1 1 4 68 635 21 0 1 1 1 4 68 000 O0 0 1 1 1 4 68 000 O0 0 I 1 1 ~ 68 000 O0 0 1 I 1 4 68 520 80 0 I I I 4 68 520 80 0 1 I 1 4 68 520 80 0 1 I I 4 68 520 80 0 1 I I 4 68 000 O0 0 I I 1 4 68 0.00 O0 0 I I I 4 68 000 O0 0 I I I 4 68 000 O0 0 I 1 1 4 68 000 O0 0 1 1 1 4 68 522 83 0 I I 1 4 68 522 83 0 I 1 1 4 68 522 83 0 I 1 1 4 68 522 83 0 I I I 4 68 522 83 0 1 1 1 4 68 522 83 0 1 1 I 4 68 522 83 0 1 1 1 4 6 8 522 83 0 1 1 1 4 68 31'0 01 0 1 1 1 4 68 635 21 0 1 1 1 4 68 000 O0 0 I I I 4 68 310 O1 0 1 I 1 4 68 310 01 0 1 1 1 4 68 790 50 0 1 I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000'000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 .IS TAPE VERIFICATION LISTING ;CHLUMBER6ER ALASKA COMPUTING CENTER Z4-APR-1989 18:07 PAGE: NAME SERV UNIT SERVICE API ID ORDER ~ LOG POTA NGT PU 548432 URAN NGT PPM 548432 WING NGT CPS 548432 W2NG NGT CPS 548432 W3NG NGT CPS 548432 W4NG NGT CPS 548432 WSNG NGT CPS 548432 TENS NGT LB 548432 CS NGT F/HR 548432 DPH! LDT PU 548432 RHDB LDT G/C3 548432 DRHO LOT G/C3 548432 PEF LDT 548432 QLS LOT 548432 QSS LDT 548432' LL L~ LITH LOT $$1 LOT SSI LOT LSHV LDT SSHV LDT SIRH LDT LSRH LDT LURH LDT CALI LDT GR LOT TENS LOT MTEM: LOT MRE$ LOT HTEN LOT ENPH CNL ENRA CML CFEC CNL CNEC CNL RCEF CML RCEN CNL NPMI CNL TNPH CNL TNRA CML RTNR CNL NPOR CNL RCNT CNL RCFT CNL CNTC' CNL CFTCCNL GR CNL N~R EPT FVR EPT CPS 54 32 CPS 548432 .CPS 548432 CPS 548432 V 548432 V 548432 G/C3 548432 G/C3 548432 G/C3 548432 IN 548432 GAP! 548432 LB 548432 DEGF 548432 OHNM 548432 LB 548432 PU 5'48432 548432 CPS 548432 CPS 548432 CPS 548432 CPS 548432 PU 548432 PU 548632 548432 54843Z PU 548432 CPS 548432 CPS 548432 CPS 54843Z CPS 548432 GAP! 548432 V 54843Z V 54843Z AP! API API FILE NUMB NUMB SIZE REPR TYPE CLASS MOD NUMB SAMP ELEM CODE 07 719 50 0 1 07 792 50 0 1 07 310 01 0 1 07 31'0 01 0 1 07 310 01 0 1 07 310 01 0 1 07 310 01 0 1 07 635 21 0 1 07 636 21 0 1 07 000 ....O0 O 1 07 000 O0 0 1 15 350 02 0 1 15 356 01 0 1 15 358 01 0 1 15 354 01 0 1 15 354 01 0 I 15 354 01 0 1 15 354 01 0 1 15 354 02 0 1 15 354 O2 0 1 15 354 O0 0 1 15 354 O0 0 1 15 350 02 0 1 15 350 02 0 1 15 350 02 0 15 280 01 0 1 15 310 01 0 1 15 635 21 0 1 15 000 O0 0 1 15 000 O0 0 1 15 000 O0 0 1 15 890 0'0 0 1 15 620 01 0 1 15 420 01 0 1 15 420 O1 0 1 15 420 01 0 1 15 420 01 0 1 15 890 O0 0 1 15 890 0'0 0 1 15 420 01 0 1 15 420 01 0 1 15 890' O0 0 1 15 420 0I 0 1 15 420 01 0 15 420 01 0 1 15 420 01 0 1 15 310 01 0 09 132 OI 0 1 09 132 11 0 I 1 1 4 68 1 I 4 68 1 1 4 68 1 1 4 68 I 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 ! 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 I I 4 68 1 1 4 68 1 1 4 68 1 1 4 68 I I 4 68 1 1 4 68 1 1 4 68 1 I 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 I 1 4 68 1 1 4 68 1 1 4 68 I I 4 68 1 1 4 68 1 1 4 68 1 1 4 68 I 1 4 68 1 1 4 68 1 I 4 68 1 1 4 68 1 1 6 68 1 1 4 6 8 1 1 4 68 1 1 4 68 1 1 4 68 1 1 4 68 1 1 6 68 PROCESS CHEX) 000000~000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OOOOOOOO0,O 0'O00000O~0:0 0000000000 0000000000 0000000000 0000000000 0000000000 O0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 '0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000, 0000000000 0'000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 .IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE= 10 NAME SERV UNIT SERV ID ORDE GR EPT GAPI 5484 SA EPT IN 5484 CALI EPT IN 5484 TENS EPT LB 5484 PqTEM EPT DEGF 5484 PERES EPT QHMPE 5484 HTEN EPT LB 5484 ICE API AP! API API FILE NUNB NUMB SIZE REPR PROCESS R i LOG TYPE CLASS MOO NUNB SAHP ELEPE CODE CHEX) 32 09 310 01 0 I I I 4 68 0000000000 32 09 Z80 01 0 I I I 4 68 0000000000 3Z 09 280 01 0 I I I 4 68 0000000000 3Z 09 635 21 0 I I I 4 68 0000000000 32 09 000 O0 0 I I I 4 68 0000000000 3Z 09 000 O0 0 I I I 4 68 0000000000 3Z 09 000 ~00 0 I 1 ! 4 68 0000000000 IDPH COR DHRM 548432 07 120 46 0 I I I 4 68 0000000000 XMPH COR OHHM 54843Z 07 120 44 0 I I I 4 68 0000000000 SP ~ .... #¥ .... 5~8~,3-2 OT 0]:0'~':' 01 0 t t I ~ 68 O~O00~OO SGR COR GAPZ 548432 07 310 01 0 I I I 4 68 0000000000 TENS CDR LB 548432 O7 635 21 0 I I I 4 68 0000000000 HTEN CaR LB 54843Z OT 000 O0 0 I I I · 68 0000000000 DEPT. 1Z900.000 SP.DIL -999.250 TT1. BN:C -999. ZSO GR.BHC -999oZ50 TENS.CHL -999. 250 S P.'DTE -13. 000 C IDP. OTE 745.000 IIRMoDTE TO8.000 NRES.DTE 0.622 D.TLN. $0 T 1'03. TOO COHC.SDT 0.000 TT2.SDT 440.000 LTTZ.SDT 961,.200 TENS.SOT Z514.000 THOR' NGT 0 o 0.00 HZNG.NGT 145 o 2.38 T ENS~ NGT 2514. 000 R HOB*~ LDT -999. Z 50 Q$$.LDT -999. ZSO LITHoLDT -999.2'50 SSHV.LDT -999.250 CALI.LDT -999.250 MAES.LOT -999oZ50 CFEC.CNL -999.250 NPHZ. CNL -999., Z 50 NPOR. CHL -999.2 50 CFTC.CNL -999. Z50 GR.EPT -999.Z50 MT EM. EPT -999.250 IM. PH.COR -999.Z50 HT EN. COR -999 . Z 5'0 SFLU.DIL -999.250: IL#.DIL -999.250 ILO.OIL -GR.DZL .- 999. ZSO TENS.OIL -999.250 DToBHC TTZ,-BHC -999'250 TT3o BHC -999. Z50 TT4.gHC SP.BHC -999.250 TENS.BHC -999.Z50 GRoCHL SFLU. DTE 1.237 ILM.DTE 1.Z78 ILO.DTE IDPH.DTE 1.342 IMPH.DTE 1.271 IFRE.OTE CIMP.DTE 7'86.000 IIRD.DTE 57'4.000 IIXD.OTE SGR.DTE 0.000 TENS.DTE 2514.000 PETEM.DTE HTEN.DTE 3'.914 DT.SOT 102.400 DTL.SDT DTLF.SDT 104.700 DTCOoSDT 0.000 DTSM.SDT COHS.SDT 0.000 COST.SOT 0.000 TT1.SDT TT3.SDT 849.200 TT4. SOT 648°800 LTT1.SDT LTT3. SOT 1378. 000 LTT4. SOT 1169 °-200 SGR. SOT HTEN.SDT 3.914 SGR.NGT 0.000 CGR.NGT POTA.NGT O.O. O0 URAN.NGT 0.000 WING.NGT W3NG.NGT 55.952 W4NG. NGT 11.905 W5NG.NGT CS.NGT 9T3.500 HTEN. NGT 3.914 DPHI.LDT DRHO.LDT -999'Z50 PEF.LDT -999.Z50 QLS.LDT LS.LOT -999.250 LU.-LOT -999°250 LLoLDT SS1.LDT -999'Z50 SS2oLDT -999°250 LSHV.LDT SIRH.LDT -999.Z50 LSRH.LDT -999.250 LURH.LDT GR.LOT -999. ZSO TENS.LDT -999.250 PETEM.LDT HTEN.LDT -999.250 ENPH.CNL -999.250 ENRA.CNL CNEC.CNL -999.250 RCEF.CNL -999. Z50 RCENoCNL TNPHoCNL -999.Z50 TNRA.CNL -999.250 RTNR.CNL RCNT.CNL -999. Z50 RCFT.CNL -999.250 CNTC.CNL GR.CNL -999.250 NVR.EPT -999.250 FVR.EPT SA.EPT -999.250 CALI.EPT -999.250 TENS.EPT MRES.EPT -999.Z50 HTEN.EPT -999.250 IDPHoCOR SPoCOR -999. Z50 SGR.COR -999.250 TENS.COR -999 .ZSO -999.250 -999.250 -999.250 1.314 gO.O00 134.875 165.875 IOZoZO0 0.000 640.800 1168.000 0.000 0.000 3Z0.238 10.714 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COHPUTING CENTER 24-APR-1989 18:07 PAGE: 11 DEPT. 12800.000 SFLU.DZL SP.D/L -999.250 GR.DZL TTI.BHC -999.250 TT2,BHC GR.BHC -999.250 SP.BHC TEN$.CHL -999.250 SFLUoDTE SP.DTE -12.641 IDPH.DTE CIDP.DTE 804.500 CINP.DTE XIRMoDTE 752o000 5GR.DTE MRES.DTE O.6ZZ HTEN.DTE DTLNoSDT 104.000 DTLF.SDT CONC.SDT 0.000 COHS.SDT TT2. SOT 446. OOO TT3. SOT T EN5. SDT 5604.000' HTEN' SOT THOR. NGT 9.906 POTA.NGT #ZNG.NGT 145.238 g3NG.NGT TENS.NGT 5604.00~1 CS. NGT RHOB.LDT 2.305 DRHO.LDT QSS. LOT* O. 077 L $. LOT CALZ, )T 9.0T0 GR.LDT FIRES.LDT 0-593 HTEN.LDT CFECoCNL 392.926 CNEC.CNL NPHI.CN;L 3'4.300 TNPH.CNL NPOR.CNL 35.160 RCNT.CNL C FTC. CNL 566.199 GR. C NL GR. EPT 128.250 SA-EPT MTEM.EPT 173.250 MRESoEPT I NPH. COR -999.250 SP. COR HTEN.COR -999.250 DEPT. 12700.000 SFLU.O.IL SP.DIL -999.250 GR.DIL TT1. BHC -999- 250 TT2. BHC GR. BHC -999. Z 50 SP. BHC TENS.CHL -9'99.250 SFLU.DTE $:P. DTE 18.500 IDPH.DTE CT. DPoDTE 380,.000 CIMP.DTE I IRN. DTE 357.750 SGR. DTE NRES. DTE 0.624 HTEN. DTE DTLN.SDT 96.500 DTLF.SDT COHC. SOT 0.979 COHS.SDT TTZ.SOT 434.000 TT3oSDT LTTZoSOT 928.400 LTT3.SDT TENS.SOT 5480.000 HTEN.SDT THOR.NGT 10.647 POTA.NGT gZNG.N'GT 152.053 g3N'G.NG:T TEN$.NGT 5480.000 CS.NGT RHOB.LDT 2.40'9 DRHO.LDT QSS.LOT 0.051 LS.LDT L TTH. LOT 69.250 S S1. LOT 5SHV.LDT 1221.000 SIRH.LDT CALT.LDT 9. 805 GRLLDT -999.250 ILN. D/L -999.250 TENS.OIL -999. 250 TT3.BNC -999. 250 TENS.BHC 1.438 ZLIq. DTE 1.242 ZMPH.DTE 837.000 I~RD.DTE 101.~24 TENS.DTE 1369.000 DT. SOT 105.000 DTCO. SOT 0.000 COST.SOT 851.Z00 TTA. SOT 369° 000 SGR. NGT Z. 342 URAN.NGT 55.952 g4NG, NGT 999. 500 HTEN.NGT O. 179 PEF. LDT 45 ~T 114~'5'63''' TENS.LOT 1579.000 ENPH.CNL 2144.465 RCEF.CNL 35.759 TNRA.CNL 1850. 881 RCFT. CNL 11~. 563 NVR.EPT 0.283 CALI.EPT 0,.602 HTEN. EPT -999.250 SGR.COR -999.250 ILM. OIL -999.250 TENS.OIL -999.250 TT3.BNC -999.250 TENS. BHC 2.873 ZLH.DTE 2~629 IMPH.DTE 381.500 IIRO.DTE 10~-6.07 TENS.DTE 1353.000 DT. SDT 96.900 DTCO. SDT 0.320 COST.SOT 817. Z00 TT4.SDT 1312.000 LTT4.SDT 1353.000 SGR.NGT Z.827 URAN.NGT 63.818 W4NG.NGT 1014.500 HTEN.NGT 0.110 PEF.LDT 334o250 LU.LDT 244.625 SSI.LOT 2o072 LSRH.LDT 94. 313 TENS.LOT -999.250 ILO.OIL -999.250 -999.250 OT.8HC -999.250 -999.250 TT4.BHC -999.250 -999.250 GR.CHL -999.250 1o199 ILD.DTE 1.181 1.19~ IFRE.DTE 20.000 611.000 IIXD.DTE 137.250 5604.000 HTEN.'DTE 165.875 101.400 OTL.SDT 101.300 0.000 DTSM.SOT 0.000 0o000 TT1.SDT 642.000 .1168~80,0 101.124 101.124 CGR.NGT 75.558 3.&17 ~ING.NGT 320.238 11.905 MSNG.NGT 10.714 1369o000 DPHI.LDT Z0.931 5.188 ~LS.LDT -0.054 4 239.125 6628'000 MTEN.LDT 174.875 37.122 ENRA.CNL 5.458 369.665 RCEN.CNL 20480341 3.060 RTNR.CNL 3.193 551.029 CNTC.CNL 1747.365 3.721 FVR.EPT 0.684 8.609 TENS.EPT 6932.000 1895.000 IDPH.COR -999.250 -999.250 TENS.CDR -999.250 -999.250 ILO.OIL -999.250 -999.250 DToBHC -999.250 -999.250 TT4.BHC -999.250 -999.25:0 GR.CHL -999.250 2.596 ILD.DTE Z.615 2.619 ZFRE.DTE ZO.O00 316.250 IIXD.DTE 5.6.625 5480.000 MTE~.DTE 167.250 97.900 DTL.SOT 96.800 97.000 DTS~.SDT 167.000 0.250 TTI.$DT 62~.800 620.800 LTTI.$DT 1121.600 1119.200 SGR.SDT 104.607 104.607 'CGR.NGT 86.135 Z.469 WING.NGT 332.963 8.879 W5NG.NGT 11.654 1353.000 DPHI.LDT 1~.617 4.945 QLS.LDT -0.069 326.500 LL.LDT 171.000 330.750 LSHV.LDT 1167o000 2.297 LURHoLDT ZoZ87 6852.000 MTEM.LDT 17'6.000 ,IS TAPE VERIFICATION LISTING iCHLUNBERGER ALASKA COMPUTING CENTER MRESoLD~T 0.585 HTEN.LOT CFEC.CNL 538.549 CNEC.CNL NPHI.CNL 38.044 TNPH.CNL NPORoCNL 37.170 RCNT.CNL CFTCoCNL 614.610 GR.CNL GR'EPT 107. 313 SA.EPT MTEM.EPT 174.150 MRES.EPT IMPHoCOR -999.150 SP.COR HTEN.COR -999.250 DEPT. 11600.000 SFLU.DIL SP.DIL -999.150 GR.DIL TTloBHC -999.150 TT2.BHC TENSoCHL -999.150 SFLU.DTE SP.OTE 10500 IOPH.DTE CIDPoOTE 471.500 CIMP'DTE IIRMoDTE 4Z3.500 SGR.DTE MRES.DTE 0.630 HTEN-DTE OTLH. SDT 98. OOO DTLF' SDT LTT 94~. 800 LTT3, TENS.SOT 5572.000 HTEN. SOT THOR.NGT 11.208 POTA.NGT WZNG. NGT 157.190 N3NG.NGT TENS. NGT 5572. 000 CS. NGT RHOB.LDT 2.407 DRHO.LOT USS.0 LOT 0. 041 LS. LOT L ITH. LDT 74.188 S 51. LOT $SHVoLDT 1121.000 SiRH.LOT CALI.LDT 10.000 GR.LDT MRES.LDT 0.594 HTEN.LOT C FEC. CNL 522. & 81 CN EC. CNL NPHI.CNL 38.970 TNPH.CNL NPQR.CNL 40. 637 RCNT.CNL CFTC.CNL 553. 807 GRoCNL GR. ePT 97.938 SA.EPT MTEM. EPT 173.625 MRES.EPT I~PH'COR -999. 250 SP.COR HTEN. COR -999- 2 50 DEPT. 12500.000 SFLU.DIL SP. OIL -999.150 GR.,IL TT1 oBHC -999. 250 TT2. BHC GR.BHC -999.250 SP.BHC TENS.CHL -999.150 SFLU-DTE SPoDTE -9. 150 IDPH.DTE CIDPoDTE 163.125 CIMP'DTE IIRMoOTE 155.000 SGR'DTE MRES. DTE 0.634 flTEN.DTE DTLN.SDT 80.600 DTLF.SDT COHC.SDT 0.913 COHS.SDT TTZ. SOT 349.600 TT3.SDT LTTZ.SDT 75'9.600 LTT3oSOT 24-APR-1989 18:07 1674..000 ENPH.CNL 2619.054 RCEF.CNL 38.514 TNRA.CNL 21150313 RCFT.CNL 94.313 NYR.EPT 1.811 CALI.EPT 0.591 HTENoEPT -999.150 SGR.COR -999.150 ILIq. DIL -999.Z~0 TENS.OIL -9990150 TT3.BHC - 999'~~'2~50 T'E~~ ~BNC 2'658 ~LH.DTE 20119 I#PH. DTE 45'9.000 I/RD. DTE 10.5"096 TENS.DTE 1~21.000 DT. SOT '98.300 1. SOT 1339.600 14 21. 000 SGR. NGT 2., 871 URAN.NGT 60. 276 W4NG.NGT 1014.500 HTEN.NGT 0.118 PEFoLOT 3400 500 LU*LDT 147. 500 SS2.LDT 20051 LSRH. LDT 107-625 TENS.LOT 1549.000 ENPH. CNL 2 530. 976 RCEF*CNL 39. 771 TNRA. CN'L 19180668 RCFT.CNL 1070625 NVR.EPT 10855 CALI.EPT 0.599 HTEN. EPT -9990250 SGR.COR -999.150 ILM.DIL -9:990250 TENSoDIL -999-150 TT3.BHC -999.150 TENS'BHC 6'"445 iLM.DTE 6.125 IMPH.OTE 161.500 IIRD. OTE 85.789 TENS.DTE 1325.000 DT.SDT 81.. 200 OTTO. SDT 0.787 COST.SOT 6660000 TT4.SDT 10780800 LTT4.SOT 30.883 545.843 3.315 601.745 3.717 9.625 1783.000 -999.250 -999.250 -999.250 -999.250 Z.182 2.176 387. 150 5571.000 97.500 1000000 11390200 105.096 2.151 9. 185 14210000 4.090 321.750 339.250 20289 6668.000 30.446 479.111 3.391 560.598 3.709 ~10.203 1915.000 -999.250 -999.250 -999.250 -999.250 -999.250 6.078 6.188 145.115 5372.000 79.700 78.000 0.957 508.800 914.400 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FV R. EPT TENS.EPT IDPHoCOR TENS.COR ILO.OIL DT.BHC TT4.BHC GRg CHL ' ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT SGR 0 $DT CGR.NGT WING.NG'T WSNG.NGT DPHI'.LDT ~LSoLOT LL.LOT LSHV.LDT LURH o LDT NTEM.LDT ENRA.CNL RCEN.CNL RTNRoCNL CNTC.CNL FVR.EPT TEN S. EP'T IDPH.COR TENS.COR ILD.DIL DT.BHC TT4. B HC GR.CHL ILD.DTE IFRE.DTE IIXDoOTE MTE~.DTE DTL. SDT DTSM.SOT TT1. SDT LTT1. SDT SGR. SDT PAGE: 1Z 4.882 2531.363 3.563 2057.261 0.678 6784.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999~250 10109 ZO.O00 76.615 166.000 97.000 167.000 .... 615,~Z~0 1,~39,600 105-096 89.000 313.766 12.055 14.713 -0.028 179.125 1167.000 Z.Z93 175.500 4.8~4 2308.854 3.617 187Z.007 0.673 7018.000 -999.250 -999.250 -999.250 -999.150 -999.250 -.999.250 6.008 ZO.O00 18.047 165.125 79.500 137.000 505.600 919.600 85.789 .TS TAPE VER.[FTCAT:[ON L:[ST]:NG ;CHLUHBERGER ALASKA COMPUTING CENTER TENS.SDT 5J72o000 HTEN.SDT THOR.NGT 9.579 POTA.NGT NZNG.NGT 120.977 ~3NG.NGT TENS. NGT 537200 O0 CS. NGT RHOB.LDT Z.550 DRHO.LDT QS$oLDT O.OZZ LS.LDT L[TH.LDT 56.500 SS1.LOT SSHV.LDT 1ZZZ.O00 SIRH.LDT CALI.LDT 8.906 GR.LDT MRESoLDT 0.596 HTEN.LDT CFEC.CN'L 1226.740 CNEC.CNL NPHToCNL 21.498 TNPH.CNL NPOR.CNL 21.752 RCNT.CNL CFTC-~C#L ! :~ ~t,2~ ............... GR ~'CNL GR. EPT 79.438 SA; E PT MTENo EPT 172. 625 IqR ES. EPT Z HPH. COR -999. Z 50 SP. COR HTEN.COR -999.250 DEPT. 1240:0.000 SFLU.DZL OR -9~, ~0 SP- BHC TENSoCHL -999.250 SFLUoDTE SP.DTE -64. 500 ZDPH'DTE CZDP.DTE 345.750 CZNP.DTE I IRN. DT E 270.5,00 SGR. DTE HRES. DTE 0.635 HTEN.DTE DTLN. SDT ST. 500 DTLF.SDT COHC.SDT 0.978 COHS.SDT TTZ.$DT 369-600 TT3.SDT LTTZ.,SDT 807.Z00 LTT3oSDT TENS.SDT 5352. 000 HT:EN:. SOT T H'DR. NGT 4.722 POT'A. NGT ldZNG.NGT 60-990 g3NG,.NGT TENS. NGT 53 52. 000 CS. NGT RHOB.LDT 2.334 DRHO'LDT QSS.LDT 0.023 LS.LDT L ITH. LOT 92.125 S $1. LOT $SHV.LDT 1221.000 SIRH'LDT CAL, i. LDT 8.39,1 GR. LOT NRES.LDT O. 599 HTEN.LDT CFEC.CNL 849.102 CNEC.CNL NPHZ.CNL Z4.ZIZ TNPH.CNL NPOR.CNL 24.184 RCNT.CNL CFTC.CNL 1541.254 GR.CNL GR. EPT 38-063 SA.EPT NTEM.EPT 1'71.250 MRES.EPT I MPH.CUR -999° 250 SP.COR HTENoCOR -999.250 DEPT. 1Z300.000 SFLU.D[L SP. DZL -999.250 GR.DZL TTI.BHC -999.250 TTZ.BHC GRoBHC -999.250 SP.BHC 24-APR-1989 18:07 1325.000 SGR.NGT 1.633 URAN.NGT 49. 945 W4NG.NGT 1000.000 HTEN.NGT 0.011 PEF.LDT 227.125 LU.LDT Z01.125 SS2.LDT 2.494 LSRH. LDT 86.125 TENS.LDT 1404. 000 ENPH.CNL 3675.773 RCEF.CNL 21.947 TNRA.CNL 3500. 782 RCFToCNL 1.685 CALZ.EPT 0.604 HTEN.EPT -999.250 SGR.COR PAGE: 13 85.789 CGR.NGT 63.034 3.041 WlNG.NGT Z66.371 7.214 g5NG.NGT 11.654 1325.000 DPHZ.LDT 6.040 3.113 QLS.LDT -0.016 221.125 LL.LDT 116.500 273.250 LSHV.LDT 1168.000 Z.539 LURH.LOT Z.537 6440.000 NTENoLDT 174.625 14.825 ENRA.CNL 2.996 1208.897 RCEN.CNL 3486.853 2.206 RTNR.CNL 2.418 3~705 FVR~EPT 0.668 8.820 TENS.EPT 6752.000 1696.000 ZDPH.COR -999.250 -999o250 TENS.CON -999.250 -999,,, 25~ ZLN.DZL -999. Z!i0 ZLD.OZL -999' ZSO TENS~.BHC 7.395 [LM.DTE 2'891 [~PH. DTE 287.750 ZZRD.DTE 41. 836 TENS.DTE 1323. 000 DT. SOT 88.800 DTCO. SDT 0.888 COST.SDT 708.000 TT4.SDT 1156. 800 LTT4.SOT 1323.000 SGR.NGT O. 740 URAN. NGT 16.686 144NG.NGT 1014. 500 HTEN. NGT 0.005 PEF.LDT 323.250 LU. L DT 211.00'0 _ S_SZ.L DT Z" 3~07 L SRH. L DT 35.313 TENS:o, LDT 1278- 000 ENPH. CNL 32170003 RCEF.CNL 24.814 TNRA.CNL 3853.300 RCFT. CNL 35,313 NVR-EPT 1.751 CAL[-EPT O. 607 HTEN. E PT -999.25'0 SGR.COR -999.250 [LN.DIL -999.250 TENS.DZL -999.250 TT3.BHC -999.250 TENS. BHC -999:~ZS0 -999.250 GR.CHL -999.250 3.453 ILD.DTE Z.924 3.475 ZFRE.DTE ZO.O00 286.250 ZZXD.DTE 52.031 5352.000 NTEN. DTE 164.750 89.700 DTL.SDT 84.000 83.000 DTSN.SDT 1430000 00887 TTloSDT 538'400 548.400 LTT1.SDT 990.800 972.800 SGR.SDT 41.836 410836 CGR.NGT 30.045 1.576 glNG.NGT 139.241 4-603 W5NG.NGT 3.452 1323.000 DPH[.LOT 19.123 2.463 QLS.LDT 0.015 298.750 LL.LDT 174.000 Z98.750 LSHV.LDT 1168.000 2.328 LURH. LDT Z.342 6148.000 NTE~.LDT 173.000 21.513 ENRA.CNL 3.789 867.944 RCEN.CNL 3151.059 2.345 RTNR.CNL Z.470 1534.314 CNTC.CNL 3620.512 3.703 F'VR.EPT 0.672 8.570 TENS.EPT 6492.000 1590.000 IDPH.COR -999.250 -999.250 TENS.COR -999.250 -999.250 ILD.DIL -999.250 -999.250 DT. BHC -999.250 -999.250 TT4.SHC -999.250 -999.250 GR.CHL -999.250 .l.S TAPE YERIPICATION LISTING ;£HLUMBERGER ALASKA COMPUTING CENT~_R TENS.CML -999. 250 SFLU. gTE SP.DTE -84.750 IDPH.DTE CIDP.DTE 20.406 CIMP.DTE IIRM.DTE 32.751 SGR.DTE MRES.DTE 0.650 HTEN.OTE DTLN. SDT 81.1 O0 DTLF. SOT ~OHC.SDT 0.887 COHS.SDT TT2. SOT 370. 400 TT3. SOT LTTZ.$DT 814.400 LTT3.SDT lENS.SOT 5360.000 HTEN.SDT 1 HUR. NGT 3o 721 POTA.NGT WZNG.NGT 49.327 W3NG.NGT TENS.NGT 5360. 000 CS.NGT RHOtSoLDT 2.354 DRMO.LOT QSS. LOT O. 025 LS. LOT LITH. LOT 74. 500 $ S1. LOT SSHV.LDT 12Z2.000 S1RH.LDT CAL:[.LDT 8.539 OR.LOT MRES.LDT 0.614 HTEN.LDT CFEC.CNL 798.737 CNEC.CNL NPH.[.CNL 28.671 TNPH.CNL NPOR.CNL 29.471 RCNT.CNL CFTC.CNL IZ21. 134 GR. CNL GR.EPT 3Zo469 SA.EPT MTEM. EPT Z 69.Z 50 MR ES.EPT IMPH.COR -999.Z 50 SP.COR HTEN.COR -999.250 DEPT. 12200.000 SFLU.OIL SP.DIL -999. 250 GR.DIL TT1. BHC -999.250 TT2.8HC GR.BHC -999.250 SP.BHC TENS.CML -999.250 SFLU.DTE SP.OTE -6.8.750 IDPH.DTE CIDP.DTE 49.9.38 CIMP.DTE IIRM. gTE 56. 844 SGR. gTE MRES.DTE 0.657 HTEN.OTE DTLN. SOT 87.700 DTLF.SDT COHC. SOT O. 890 COHS.SOT TlZ. SOT 380.400 TT3. SOT L'TTZ.SDT 868.000 LTT3.SOT TENS.SOT 5360.000 HTEN.SDT THORoNGT 5°484 POTA.NGT WZNG. NGT 59. 091 W3NG.NGT TENS.NGT 5360. 000 CS. NGT RHOB.LDT 2,,438 DRHO.LOT QSS.LDT 0.009 LS.LDT LITH.LOT 55. 031 S51.LOT SSHV.LDT 1221. 000 SIRH.LDT CALI.LDT 8- 680 GR.LOT MRIES..LDT 0.624 HTEN.~LDT CFEC.CNL 849.457 CNEC.CNL NPHI.CNL 30.178 TNPH.CNL NPOR.CNL 31.261 RCNT.CNL CFTC.CNL 1093.4 13 GR.CNL 24-APR-1989 18:07 31.031 ILM.DTE 48.969 IMPH.DTE 31.578 IIRD.OTE 33.726 TENS.gTE 1328.000 DT. SDT 80.500 DTCO.SDT 0.792 COST.SOT 712.800 TT4.SDT 1168.800 LTT4.SDT 1328.000 SGR.NGT 0.860 URAN.NGT 17.937 W4NG.NGT 1025o000 MTEN.NGT 0.004 PEF.LDT 308.500 LU.LOT 208.750 SS2.LDT Z.334 LSRH.LDT 33.406 TENS.LOT 1303.000 ENPH.CNL 3115.578 RCEF.CNL 28.919. TNRA.CNL 3292.981 RCFT.CNL 33.406 NVR.EPT 1.651 CALI.EPT 0.623 HTEN.EPT -999.250 SGR.COR -999.250 ILM.OIL -999.250 TENS.DIL -999.250 TT3.BHC -999.250 TENS.BHC 19.453 ILM.DTE 20.016 IMPH.DTE 58.594 IIRD.DTE 44.052 TENS.gTE 1359.000 OT.SDT 89.400 gTCO.SOT 0.730 COST.SOT 728.000 TT4.SDT 1199.200 L'TT4. SDT 1359..000 SGR.NGT 0.?63 URAN.NGT 22.727 W4NG.NGT 1030.000 HTEN.NGT -0.011 PEF.LDT Z59.750 LU.LDT 194.625 SSZ.LDT 2.494 LSRH.LDT 43.156 TENS.LOT 1266.000 ENPH.CNL 3312.912 RCEF-CNL 29.591 TNRA.CNL 2919.668 RCFT.CNL 43.156 NVR.EPT 28.984 31.656 21.469 5360.000 82.300 86.000 0.932 541.200 985.200 33.726 0.756 5.045 1328.000 3.125 291.000 293.750 2.350 6168.000 22.418 798.556 Z.654 1169.634 3.T03 8.609 1570.000 -999.250 -999.250 -999.250 -999.250 16.688 17.047 45.594 5360°000 87.300 91.000 0.963 550.800 1035.000 44.052 1.428 3.977 1359.000 4.156 247.750 274.750 2.449 6104.000 22.303 898.056 2.766 1033.701 3.703 ILD.DTE IFRE.DTE IIXD.OTE MTEM.DTE DTL.SDT DTSM.SDT TTZ.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURM.LDT MTEM.LOT ENRR.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILD.OIL DT.BHC TT4.BHC GR.CHL ILD.OTE IFRE.DTE IIXD.DTE MTEM. OTE DTL.SDT DTSMoSDT TT1.SDT LTT1.SDT SGR.SDT CG~.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSH¥.LDT LURM.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVRoEPT PAGE: 44.438 ZO.O00 6.301 163.125 80.100 143.000 538.000 987.600 33.726 28.071 108.744 3.924 17.912 -0.011 163.000 1168.000 Z.357 1 ?0.8 ?5 3.904 2907.782 2.887 3200.408 0.669 6368.000 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 19.375 ZO.O00 4.238 161.000 89.800 154.000 549.600 1033.600 44.052 33.36~ 147.I59 4.545 12.837 -0.004 135.750 1168.000 2.461 168.3'75 3.900 3140.241 Z.888 2920.913 0.6?0 14 .IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER GR.EPT 46.125 SA.EPT MTEM.EPT 166.750 MRES.EPT IMPH.COR -999.Z50 SP.COR HTEN.COR -999.250 DEPT. 12100.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1. ~HC -999.250 TT2. BHC GR.BHC -999.250 SP.BHC TENS.CML -999.Z50 SFLU.OTE SP. DTE -75. 750 IDPH. DTE CIDP.DTE 45.094 CIMP.OTE IIRM.gTE 53. 531 SGR. DTE MRES.DTE 0.663 HTEN.OTE DTLN.SBT 87.200 OTLF.SOT COHC.SDT 0.918 COHS.SDT TT2.SDT 409.200 TT3.SBT LTT2.SDT 843.200 LTT3.SDT TENS.SOT 5408.000 HTEN.SDT THOR.NGT 10.380 POTA.NGT W2NG.NGT 90.493 W3NG.NGT TENS.NGT 5408.000 CS.NGT RHOB.LDT 2-482 DRHO.LDT QSS.LD'T 0.0 31 LS.LDT LITH.LDT 40. 375 S S1. LOT SSHV.LDT 1221.000 SIRH.LDT CALI.LDT 9.352 GR.LDT MRES.LDT 0.635 HTEN.LOT CFEC.CNL 5,69.488 CNEC.CNL NPMI.CNL 40.809 TNPH.CNL NPOR.CNL 40.964 RCNT.CNL CFTC.CNL 6Z7.910 GR.CNL GR.EPT 64.000 SA.EPT MTEM.EPT 164.875 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.CBR -999.250 OEPT. 12000.000 SFLU.DIL SP.DIL -999.250 GR.OIL TT1.BHC -999.250 TT2.BHC GR.~HC -999.250 SP.BHC TENS.CML -999.250 SFLU.DTE SP.DTE -42.000 IDPM.DTE CIDP.DTE 624.500 CIMP.DTE IIRM.OTE 553.000 SGR.DTE MRES'DTE 0.674 HTEN.DTE DTLN.SDT 104.800 OTLF.SOT COHC.SDT 0.935 COHS.SDT TTZ. SBT 533. ZOO T T3. SOT LTTZ.SUT 108Z.000, LTT3.SDT TENS.SOT 5272.000 HTEN.SOT THOR.NGT 11.076 POTA.NGT WZNG.NGT 175.258 W3NGoNGT IENS.NGT 5ZTZ.O00 CS.NGT RHOB.LDT 2.319 DRHO.LOT 24-APR-1989 18:07 1.821 CALI.EPT 0.634 HTEN.EPT -999.250 SGR.COR -999.250 ILM.DIL -999.250 TENS.OIL -999.250 TT3.BHC -999.250 TENS.BMC 1~.156 ILM.DTE 22.172 IMPM.DTE 53.375 IIRD.DTE 64.854 TENS.DTE 1384.000 OT.SDT 93. 100 DTCO. SOT 0.859 COST.SOT 749.600 TT4.SDT 1210.800 LTT4.SDT 1384.000 SGR.NGT 1.059 URAN.NGT 29.210 W4NG.NGT 1032.000 HTEN.NGT O.O1Z PEF.LDT 247.Z50 LU.LOT ZO6.ZSO SS2.LOT 2.420 LSRH.LDT 65.250 TENS.LOT 1351.000 ENPH.CNL 2757.165 RCEF.CNL 39.385 TNRAoCNL 2108.321 RCFT.CNL 65.250 NVR.EPT 1.785 CALI.EPT 0.644 HTEN. EPT -999.250 SGR.COR -999.250 ILM. OIL -999.250 TENS.DIL -999.250 TT3.BHC -999.250 TENS.BHC 2.158 ILM.DTE 1.600 IMPH.DTE 604.5'00 IIRD.OTE 119.176 TENS.DTE 1355.000 BT. SOT 106.600 DTCO.SDT 0.283 COST.SOT 945.Z00 TT4.SOT 1458.800 LTT4.SOT 1355.000 SGR.NGT 2.595 URAN.NGT 59.565 W4NG.NGT 1024.000 HTEN.NGT 0.060 PEF.LDT 8.695 1697.000 -999.250 -999.250 -999.250 -999.250 -999.250 17.719 18.719 41.781 5408.000 94.000 92.000 0.910 586.000 1019.200 64.854 1.046 6.813 1384.000 7.391 241.750 281 .rJOO 2.469 6188.000 30.660 570.169 3.438 594.973 3.707 9.766 1633.000 -999. 250 -999.250 -999.250 '-999.,250 -999.250 1.654 1.653 481.250 5272.000 106.000 107.000 0.250 73 8..4.00 1286.800 119.176 4.686 11.455 1355.000 4..086 TENS.EPT IDPH.CDR TENS.COR ILD.OIL DT.BHC TT4.BHC GR.CHL ILO .OTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.SDT OTSM.SDT TT1.SDT LTT1.SDT SGR.SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNRoCNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO .OIL OT. BHC TT4..BHC GR.CHL ILO.DTE IFRE. DTE IIXD.DTE MTEM.DTE gTL.SDT DTSM.SDT TTI. SDT :L T T 1. S D T SGR.SDT CGR.NGT WING.NGT W ENG. NGT DPHI.LOT QLS.LDT PAGE: 6580.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z1.266 ZO.O00 6.520 159.250 90.500 164.000 588.800 1021.600 6~.85~ 57.031 Z17.06B 8.591 10.164 -0.037 126.313 1169.000 Z.477 166.250 4.84I 2724.007 3.646 20B9.130 0.667 6440.000 -999.250 -999.Z50 -999.250 -999o250 -999.250 -999.250 1.561 20.000 89.813 157.750 103.600 1,41.000 755.200 1278.800 119.176 84.113 376.861 11.455 Z0.074 -0.006 I5 .IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER QSS.LDT 0.043 LS.LDT L ITH. LOT 78. 188 SS1.LOT S SHV.LDT 1221. 000 SIRH. LOT CALI.LDT 11.719 GR.LDT MRE$.LDT 0.649 HTEN.LDT CFEC.CNL 346.8?7 CNEC.CNL NPHI.CNL 49.226 TNPH.CNL NPORoCNL 45. 524 RCNToCNL CFTC.CNL 426.655 GR.CNL GR.EPT 114.313 SA.EPT MTEM.EPT 163.125 MRES.EPT IMPH.CUR -999.2 50 SP.COR HTEN.COR -999.250 DEPT. 11900.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1. BHC -999. 250 TT2. BHC GR. BHC -999. 250 SP. BHC TENS.CHL -999.250 SFLU.DTE 5PoDTE -52.250 IDPH.DTE CIOP.DTE 339.250 CTMP.DTE IIR:MoDTE 320.250 SGR.DTE MRES.DTE 0.688 HTEN.DTE DTLN.SDT 106.300 DTLF.SOT COHC. SDT 0.799 COHS.SDT TTZ. 5DT 447. ZOO TT3. SDT LTTZ.SDT 1000.800 LTT3.SDT TENS.SOT 5464.000 HTEN.$OT THOR.NGT 18.214 POTA.NGT WZNG.NGT 279.816 W3NG.NGT TENS. NGT 5464.000 CS.NGT RHOB.LDT Z.ZO9 DRHO.LDT QSS.LDT 0.087 LS.LDT LITH.LDT 77.6 88 SSI.LOT 5SHV.LDT 1ZZO.O00 S1RH.LDT CALI.LDT 10.820 GR.LOT MRES.LDT 0.664 HTEN.LOT CFEC.CNL 4,q.Z. 730 CNEC.CNL NPHI.CNL 37.938 TNPH.CNL NPOR.CNL 43.169 RCNT.CNL CFTC.CNL 561.328 GR.CNL GR. EPT 122.8?5 SA. EPT MTEM.EPT 160.1 25 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN-COR -999.250 DEPT. 11800.000 SFLU.DIL SP.OIL -999.250 GR,.OIL TTI.BHC -999. 250 TT2.BHC GR.BHC -999.250 SP.BHC TENS.:CHL -999.250 SFLU.OTE SP.DTE -47. 500 IDPH.DTE CIDP.DTE 3BSoOOO CIMP.DTE IIRM. OTE 342. 500 SGR. OTE MRES.DTE 0.689 HTEN.DTE 24-APR-1989 18:07 359.250 LU.LDT 233.000 SS2.LDT 2.119 LSRH.LDT 115.063 TENS.LDT 1400.000 ENPH.CNL 2062.606 RCEF.CNL 44.946 TNRA.CNL 1657.983 RCFT.CNL 115.063 NVR.EPT 2.129 CALI.EPT 0.657 HTEN.EPT -999.250 SGR.COR -999.250 ILM.DIL -999.250 TENS.OIL -999.250 TT3.BHC -999.250 TENS.BHC 4.410 ILM.DTE 2.945 IMPH.OTE 325.750 IIRO.OTE 195.313 TENS.OTE 1458.000 DT.SDT 103.600 OTCO.SDT 0.250 COST.SOT 862.000 TT4.SDT 1355.200 LTT4oSDT 1458.000 SGR.NGT 3.818 URAN.NGT 84.862 WaNG.NGT 1013.000 HTEN.NGT 0.068 PEF.LOT 437.250 LU.LDT Z42.625 SS2.LDT 1.989 LSRH.LDT 178.000 TENS.LOT 1695.000 ENPH.CNL 2659.596 RCEF.CNL 41. 704 TNRA.CNL ,2008.400 RCFT.CNL 178'000 NVR.EPT 2.063 CALI.EPT 0.670 HTEN.EPT -999.250 SGR.COR 334.000 323.000 2.258 6164.000 41.603 366.194 4.035 385.734 3.707 11.797 1675.000 -999.250 -999.250 -999.250 -999.250 -999.250 Z.906 3.066 288.750 5464.000 105.800 98.000 0.569 658.400 1171.Z00 195.313 8.571 22.362 1458.000 5.559 422.750 324.750 2. t41 6544.000 42.590 450.198 3.395 570.169 3.711 10.977 1774.000 -999.250 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 TT3.BHC -999.250 -999.250 TENS,.BHC -999.250 2.119 ILM.DTE 2.713 2.576 IMPH.DTE 2.688 371.750 IIRD.DTE 320.250 103.402 TENS.DTE 5408.000 1443.000 DT.SDT 84.300 LL.LDT LSHV.LDT LURH.LOT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL OT.BHC TT4.BHC GR.CHL ILD.DTE I~RE.DTE IIXD.DTE MTEM.OTE OTL.SDT DTSM.SDT TT1.SDT LTT1.SOT SGR.SOT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLSoLDT LL.LDT LSHV.LDT LURH.LDT MTEM.LD'T ENRA.CNL RCEN .CNL RTNR. CNL CNTC .CNL FVR.EPT TENS.~PT IDPH.COR TENS.CDR ILD.DIL D'T. BHC TT4.BHC GR.CHL ILD.DTE IFRE.OTE IIXD.DTE MTEM.DTE DTL. SDT PAGE: 192.250 1167.000 Z.273 164.500 5.946 2018.942 4.Z00 1605.934 0.667 6568.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.951 ZO.O00 57.813 154.875 196.600 118.000 658.800 1162.800 195.313 131.176 633.601 13.761 Z6.722 -0.076 225.875 1166.000 2.135 161.750 6.007 2459.863 3.5Z5 198Z.761 0.670 6648.000 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 Z.62! ZO.O00 61.469 154.250 84.200 16 .IS TAPE VERIFICATION LISTING ~CHLUMAERGER ALASKA COMPUTING CENTER DTEN.SDT 81.000 DTLF.SOT COHC.SDT 0.944 COHS.SDT TTZ. SOT 389. 600 TT3. SOT LTTZ. SOT $Z8.400 LTT3.SOT YENS. SOT 5408. 000 HT EN. SOT THDR.NGT 10. 732 POTA. NGT WZNG.NGT 140.982 W3NG.NGT TENS. NGT 5408. 000 CS.NGT RHOB.LDT Z.361 ORHO.LOT QSS.LDT 0.040 LS.LDT LITH.LDT 80. 813 SS1.LDT SSHV.LDT 12ZO.O00 SIRH.LDT CALI.LOT 9.609 GR. LOT MRES.LOT 0.668 HTEN.LDT CFEC.CNL 6Z8.264 CNEC.CNL NPHI.CNL 31.403 TNPH.CNL NPOR.CNL 32 oZ01 RCNT.CNL CFTC.CNL 879.621 GR.CNL GR.EPT 97.250 SA.EPT MTEM.EPT 158.625 MRES.EPT IMPH.COR -999. ZSO SP.COR HTEN.COR -999. 250 DEPT. 11700.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1. BHC -999. Z 50 TT2.BHC GR.BHC -999. Z50 SP. BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -67.500 IDPH.DTE CIDP.DTE 179.125 CIMP.DTE IIRM. DTE 175. DOD SGR. DTE MRES.DTE 0.694 HTEN.DTE DTLN. SOT 8Z. 100 OTLF. SOT COHC.SDT 0.79Z COHS.SDT TT2.SD'T 377. 600 T'T3. SOT LTTZ.SDT 804.000 LTT3.SOT TENS.SOT 5228.000 HTEN.SOT THUR.NGT 8.844 POTA.NGT WZNG'NGT 167. 595 W3NG. NGT TENS.NGT 52Z8. 000 CS.NGT RHOB.LDT g.400 ORHO.LOT qSS.LOT O. 03Z LS.LOT LITH.LDT 87. 000 SS1.LDT SSHV.LDT 1219.000 SIRH.LDT CALI.LDT 10.016 GR.LOT MRES.LOT 0.6'76 HTEN.LOT CFEC.CNL 923. 516 CNEC,CNL NPHI.CNL Z1.589 TNPH.CNL NPOR.CNL Z2.760 RCNT.CNL CFIC.CNL 1307. 833 GRoCNL GR.EPT 90.438 SA.EPT MTEM.EPT 157.000 MRESoEPT IMPH.COR -999. 250 SP. COR HTEN.COR -999. ZSO 24-APR-1989 18:07 BO. 500 DTCO.SDT 0.54Z COST.SOT 698.400 TT4.SDT 1181.600 LTT4.SDT 1443. 000 SGR.NGT 2.044 URAN.NGT 47.374 W4NG.NGT 1037.000 HTEN.NGT O. 040 PEF.LDT 325.250 LU.LDT Z23.750 SS2.LDT Z.Z17 LSRH.LDT 106.688 TENS.LOT 14Z5.000 ENPH.CNL 284Z.030 RCEF.CNL 30. 825 TNRA.CNL Z478.596 RCFT.CNL 106,.688 NVR.EPT 1.685 CALI.EPT O. 674 HTEN.EPT -999.250 SGR.COR -999.250 ILM.DIL -999.Z50 TENS.DIL -99'9.Z50 TT3.BHC -999.Z50 TENS.BHC 6.316 ILM.DTE 5.578 IMPH.OTE 162.625 IIRD.DTE 95.632 TENS.gTE 1364.000 OToSDT 82.500 DTCO.SOT 0.366 COST.SOT 689.600 TT4. SDT 1106.800 LTT4.SDT 1364.000 SGR.NGT 2.251 URAN.NGT 41.203 W4NG. NGT 104B.000 HTEN.NGT 0.037 PEF.LOT 305.250 LU.LOT 220.250 SS2.LDT Z. 264 LSRH.LDT 95. 000 TENS.LOT 1397.000 ENPH.CNL 3149-653 RCEF.CNL 25.077 TNRA.CNL 3573.130 RCFT.CNL 95.000 NVR.EPT 1.821 CALI.EPT 0.681 HTEN. EPT -999. Z50 SGR.COR 86.000 0.250 527.Z00 1011.Z00 103.402 3.926 10.845 1443.000 3.922 307.500 308.750 2.320 6160.000 27.517 654.929 Z.924 80Z.553 3.715 9.828 1729.000 -999.Z50 -999.Z50 -999.250 -999.Z50 -999.250 5.371 6.145 160.250 5228.000 82.900 78.000 0.250 542.800 945.600 95.632 3.426 6.125 1364.000 3.219 288.750 305.000 2.36! 6104.000 17.737 918.144 2.303 125 5.713 3.71 '? 10.242 1723.000 -999.Z50 OTSM.SDT TT1.SDT LTT1.SDT SGR, SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENR~.CNL RCENoCNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL D'T.BHC TT4.BHC GR.CHL ILO.gTE IFRE.DTE IIXO.OTE MTEM.OTE OTL.SDT DTSM.SDT TTI.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NG'T WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT [DPH.COR TENS.COR PAGE: 173.000 532.000 1006.000 103.402 74.022 346.461 1Z.557 17.502 -O.OZO 111.500 1166.000 2.3Z4 160.1Z5 4.524 2766.715 3.100 2458.587 0.'667 651Zo000 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 5.406 ZO.O00 ZZ.39I 153.125 84.200 158.000 548.800 936.800 95.632 69.999 Z93.430 7.795 15.164 -0.013 161.000 1166.000 2.361 158.250 3.411 3263.901 2.298 3187.804 0.672 6488.000 -999.250 -999.250 1'2' .IS TAPk VERIPIC&TION LISTING ;CHLUMBERGER ALASK~ COMPUTING CENTER DEPT. 11600.000 SFLU.OIL SP. DIL -999.250 GRoDIL T]lo BHC -999. Z 50 TTZ. BHC GR.BHC -999.250 SP.SHC TENS.CHL -999.250 SFLU.DTE SP.UTE -71.750 IDPHoDTE CIOPoDTE 395.250 CIMP.DTE IIRMoDTE 359.500 SGR.OTE MRESoDTE 0.699 HTEN.DTE DTLNo SOT 88. 100 OTLF. SDT COHC.SDT 0.958 COHS. SOT TTZ. SOT 411. ZOO TT3.SDT LTTZoSDT 886.000 LTT3.SOT TENS.SDT 5104.000 HTEN.SDT THOR.NGT 9.599 POTA.NGT WZNG.NGT 149. 527 W3NG.NGT TENS. NGT 5104.000 CSoNGT RHOB.LDT 2.485 DRHOoLDT QSS.LDT 0.043 LS.LOT LITH.LDT 69.813 SS1.LDT SSHV.LDT 1219-000 S1RH.LOT CALI.LDT 13.602 GR.LDT MRES.LDT 0.685 HTEN.LOT CFEC.CNL 749. 699 CNEC.CNL NPHI.CNL 28. 171 TNPH.CNL NPOR.CNL 27.728 RCNT.CNL CFTC.CNL 903.3 39 GR. CNL GR. EPT 94. 375 SA. EPT MTEM.EPT 155.375 MRES.EPT IMPH.COR -999.250 SP.COR HTENoCUR -999.250 DEPT. 11500.000 SFLU.DIL SP.DIL -999.250 GR.DIt TTlo BHC -9 99.250 TT2. BHC GR.~HC -999. 250 SP. BHC TENSoCHL -999.250 SFLU.DTE SP.DTE -10,,250 IDPHoDTE CIDP.UT~ 4132.750 CIMPoDTE I IRM. DTE 400. Z 50 SGR. DTE MRESoDTE 0.702 HTEN.DTE DTLN.SOT 93.800 DTLF. SgT COHC.SO! 0.986 COHS.SOT TTZ. SOT 436.400 T 73. SOT LTTZ.SDT 928. 800 LTT3.SDT TENS.SOT 5092.000 HTEN.SDT THOR.NG'T 9.569 POTA.NGT WZNG.NGT 161.162 W3NG.NGT TENS.NGT 5092. 000 CS. NGT RHOB.LDT 2.432 ORHO.LOT QSS.LDT O.OZ3 LS.LOT LITH.LDT '70. 063 SS1.LOT SSHV.LDT .1218. 000 SIRH.LgT CALI. LOT 13. 672 GR.LOT 24-APR-1989 18:07 -999.250 ILM.DIL -999.250 TENS.DIL -999.250 TT3.BHC -999.250 TENS.BHC Z.666 ILM.DTE 2.529 IMPH.OTE 386.000 IIRD.DTE 101.831 TENS.DTE 1317.000 OT.SDT 88.500 DTCO.SDT 0. Z50 COST.SOT 774.800 TT4.SDT 1238.000 LTT4.SDT 1317.000 SGR.NGT Z.383 URAN.NGT 56.147 W4NG.NGT 1046.000 HTEN.NGT 0.055 PEF.LDT ZTi. O00 LU.LDT 220°375 SSZ.LDT 2.301 LSRH.LDT 89.188 TENS.LOT 1392.000 ENPH.CNL 3098.789 RCEF.CNL 28.262 TNRA.CNL 2670.358 RCFT.CNL 89.188 NVR.EPT 1.855 CALI.EPT 0.687 HTEN.EPT -999.Z50 SGR.COR -999o250 ILM.DIL -999.250 TENS.OIL -999.250 TT3.BHC -999. Z50 TENS.BHC 2.~I8 ILM.DTE 2.309 IMPH.DTE ~31.250 IIRD.DTE 1106.38t *TENS.DTE 1328.000 OT.SOT 93.00:0 DTCO.SDT O. ZSO ,COST.SOT 812.400 TT4.SOT 1309.600 LTT4.SDT 1328.000 SGR.NGT Z.883 URRN.NGT 59.ZZ6 W4NG.NGT 1052.000 HTEN.NGT 0.041 PEF.LDT 288.000 LU.LOT 219.250 SSZ.LDT 2.287 LSRH.LDT 101.563 'TENS.LDT -999.250 -999.250 -999.250 -999.250 2.580 2.588 324.250 5104.000 90.000 88.000 0.947 593.600 1058.800 101.831 3.584 10.638 1317.000 3.268 259.750 295.750 2.430 587Z.000 23.03Z 762.472 2.874 866.651 3.719 13.938 1673.000 -999.250 -999.250 -999.250 -999.250 -999.250 2.31.3 2.318 35,3.500 5092.000 95.600 95.000 0.969 624.800 1123.600 106.38I 3.147 10.251 1328.000 3.387 273.500 305.250 2.391 578~.000 ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.DTE IFRE.DTE IIXD. DTE MTEM.DTE OTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT OPHI.LDT QLS.LDT LL.LOT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.COR ILO.OIL DT.BHC TT4.3HC GR.CHL ILO.OTE IFRS.DTE IIXD.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGRoSDT CGR.NGT WING.NG'T WSNG.NGT OPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT PAGE' · -999.250 -999.250 -999.250 -999.250 Z.533 ZO.O00 61.719 151.750 90.600 171.000 596.000 1061.600 101.831 75.016 333.333 11.820 10.006 -0o017 141.250 1155.000 2.430 156.375 4.133 25~9.676 Z.901 2519.465 0.6'71 6372.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z.297 ZO.O00 67.313 150.750 95.200 16'6.000 630.000 11Z0.400 106.381 82.832 3Z2.893 9.112 13.200 -0.012 151.375 1164.000 Z.396 154.875 18 .IS 'TAPE VERIFICATION LISTING ~CHLUM~ERGER ALASKA COMPUTING CENTER MRE5.LDT 0.692 HTEN.LDT CFEC.CNL 70Z.653 CNEC.CNL NPHi. CNL 31. 899 TNPH.CNL NPOR.CNL 32.083 RCNT.CNL CPTC.CNL 801.823 GR. CNL GR. EPT 104.438 SA. EPT MTEM.EPT 153.875 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 11400. 000 SFLU. OIL SP.DIL -999.250 OR.OIL TT1. BHC -999. 250 TT2. BHC GR.BHC -999.250 SP.BHC TENS.CML -999.250 SFLU.DTE SP.DTE -63.500 IDPH.DTE CIDP.DTE 383.750 CIMP.DTE I IRM. UT e 353. 000 SGR.DTE MRES. gTE O. 704 HT EN. gTE DTLN.SDT 93.000 OTLF.SOT CL1HC. SOT 0.9~5 COHS.SDT TT2.SDT 430.000 TT3.SOT LTTZ. SOT 9ZZ. BO0 LTT3. SOT TENS.SOT 5048.000 HTEN.SOT THOR.NGT 9.756 POTA.NGT WZNG.NGT 154.023 W3NG.NGT TENS. NOT 5048.000 CS. NGT RHO~.LUT 2.457 DRHO.LOT QSS.LDT 0.018 LS.LOT LITH.LDT ?0.1 Z5 SS1.LDT $SHV.LDT 1217.000 S1RH.LOT CALI.LDT 12.641 GR.LDT MRES.LDT 0.695 HTEN.LOT CPEC.CNL 691.768 CNEC.CNL NPHI.CNL ,31.~15 TNPH.CNL NPOR.CNL 33.504 RCNT.CNL CFTC.CNL 822. 594 GR.CNL GR. EPT 89. 688 SA. EPT MTEM.EPT 152.625 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN.COg -999. 250 DEPT. 11300.000 SFLU.DIL SP.OIL -999.250 OR.OIL TTI.~HC -999.250 TTZ.BHC GR.BHC -999.250 SP.BHC TENS.CML -999.250 SFLU.DTE SP.DTE -138.000 IDPH.DTE CIDP.DTE 76.375 CIMP.OTE IIRM.DTE -260.750 SGR.DTE MRES.DTE 0.710 HTEN.D'TE DTLN.SDT 93.200 DTLF.SOT COHC.SDT 0.833 COHS.SOT TTZ.SDT 2'17.600 TT3oSOT LTTZ.SDT 956.000 LTT3.SOT 24-APR-lO89 15:07 1311.000 ENPH.CNL 3020.120 RCEF.CNL 30.'772 TNRA.CNL 2392.204 RCFT.CNL 101.563 NVR.EPT 1.718 CALI.EPT 0.694 HTEN.EPT -999.250 SGR.COR -999.250 ILM.DIL -999.250 TENS.DIL -999.250 TT3.BHC -999.250 TENS.BHC 2.650 ILM.DTE 2.604 IMPH.OTE 384°000 IIRD.DTE 98.971 TENS.DTE 1354.000 DT.SDT 93.100 OTCO.SDT O. ZSO COST.SOT 809. ZOO TT4.SDT 1302.800 LTT~.SDT 1354.000 SGR.NGT Z.713 URAN.NGT 58.521 W4NG.NGT 1051.000 HTEN. NGT 0.032 PEP.LOT 273.250 LU.LOT 214. 875 SS2.LDT 2.336 LSRH.LDT 87.063 TENS.LOT 1307.000 ENPH.CNL 3000.028 RCEF.CNL 31.805 TNRA.CNL 2455.962 RCFT.CNL 87.063 NVRoEPT 1.618 CALI.EPT 0.698 HTEN. EPT -999.250 SGR.COR -999.250 ILM.DIL -999.250 TENS.OIL -999.250 TT3.BHC -999.250 TENS.BHC 9696.000 ILM.DTE 13.0?B IMPH.OTE -263.750 IIRD.DTE 50.589 TENS.DTE 1426.000 OT.SDT 94.600 gTCO. SOT 0.304 COST.SOT 556.400 TT4.SDT 1357.200 LTT4oSDT 24.474 720.877 3.124 762.079 3.723 14.055 1659.000 -999.250 -999.250 -999.250 -999.250 -999.250 2.631 2.602 317.750 5048.000 95.700 92.000 0.965 620.000 1111.600 98.971 2.421 6.322 1354.000 3.408 262.500 299.500 2.424 5680.000 25.017 742. 846 3.065 770.410 3.723 12.813 1656. 000 -999.250 -999.250 -999.250 -999.250 -999.250 1950.000 1950.000 69.188 5160.000 83.100 96.000 0.950 442.800 1157.200 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL OT.BHC TT4.~HC GR.CHL ILD.DTE IFRE.OTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TTI.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT W5NG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.gTE IFRE.OTE IIXD.OTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT PAGE: 4.298 2885.488 3.395 2369.094 0.680 6264.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.611 20.000 61.125 150.000 95.500 166.000 621.200 1113.600 98.971 80.855 Z95.977 11.494 11.682 -0.022 142.125 1164.000 2.4Z4 153.375 4.337 2911.112 3.179 2453.874 0.678 6t68.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12.906 ZO.O00 0.000 149.125 56.300 173.000 442.800 1158.400 50.589 I9 ,IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER lENS.SOT 5160.000 HTEN.SDT THOR.NGT 4. 210 POTA. NGT WZNG. NGT 69.026 W3NG.NGT 1 ENS.NGT 5160.000 CS. NGT RHOB.LOT 1. 844 ORHO. LOT QSS.LOT -0.105 LS.LDT L ITH.LDT 14.773 S S1.LOT ~ SHV.LDT 1219. 000 SIRH.LOT CALI.LOT 8.828 GR.LOT MRES.LOT 0.700 HTEN.LDT CPEC.CNL 377.1Z3 CNEC.CNL NPHI.CNL 52. 576 TNPM.CNL NPORoCNL 48. 175 RCNT. CNL CFTC.CNL 353. 950 GR.CNL GR.EPT 46. 625 SA. EPT MTEM.EPT 151.375 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 11200.000 SFLU.DIL SP.DIL -999.250 GR.OIL TT!.BHC -999. 250 TT2.BHC GR. BHC -999. 250 SP. BHC TENS.CML -999.250 SFLU.DTE SP.DTE -156.750 IDPH.DTE CIDP.DTE 76.313 CIMP.DTE ! IRM. DTE -Z80. 000 SGR.DTE MRES.OTE 0.718 HTEN.OTE BTLN.SDT 62.200 OTLF.SOT CDHC.SDT 0.850 COHS.SDT TTZ. SDT 269. 200 TT3. SDT LTTZ.SDT 594.000 LTT3.SOT TENS.SOT 5108.000 HTEN.SOT THDR.NGT 6.528 POTA.NGT WZNG.NGT 97.862 W3NG.NGT TENS. NGT 5108. 000 CS.NGT RHOB.LOT -999. Z50 ORHO.LOT QSS.LDT -999. 250 LS.LOT L ITH.LDT -999. 250 SS1.LDT SSHV.LDT -999.250 SIRH.LOT CALI.LOT -999. 250 GR. LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.Z50 RCNT.CNL CFTC.CNL -999. 250 GR. CNL GR. tPT -999.2 50 SA. EPT MTEM. EPT -999 · 250 MR ES. EPT IMPH.COR -999. ZSO SP.COR HTEN.COR -999.250 DEPT. 11100.000 SFLU.DIL SP.OIL -999.Z50 GR.DIL TT1.BHC -999.Z50 TTZ.BHC GR.BMC -999.250 SP.BHC 24-APR-1989 18:07 1426.000 SGR.NGT 1.084 URAN.NGT 24.942 W4NG.NGT 15BZ.O00 HTEN.NGT -1.006 PEF.LDT 138.250 LU.LDT 50.000 SSZ.LOT 4.891 LSRH.LDT 47.344 TENS.LOT 1Z55.000 ENPH.CNL 2327.615 RCEF.CNL 47.206 TNRA.CNL 1374.312 RCFT.CNL 47.34~ NVR.EPT 1.685 CALI.EPT 0.705 HTEN.EPT -999.Z50 SGR.COR -999.250 ILM.DIL -999.250 TENS.DIL -999.250 TT3.BHC -999.250 TENS.BHC 9596.000 ILM.DTE 13.094 IMPH. DTE -277.000 IIRO.DTE 56.Z71 TENS.DTE 1413.000 DT.SDT 69.800 DTCO. SDT 0.280 COST.SOT 521.600 TT4.SDT 844.800 LTT4.SDT 1¢13.000 SGR.NGT 1.374 URAN.NGT 27.961 W4NG.NGT 1578.000 HTEN.NGT -999.Z50 PEF.LOT -99:9.Z50 LU.LDT -999. Z50 SS2.LDT -999. Z50 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999. Z50 CALI.EPT -999.Z50 HTEN.EPT -999.250 SGR.COR 50.589 2.281 4.060 1426.000 32.125 139.500 B0.313 2.850 5552.000 45.440 369.082 4.038 331.590 3.73Z 8.641 1517.000 -999.250 -999.250 -999.250 -999.250 -999.250 1950.000 1950.000 69.500 5108.000 55.500 97.000 0.250 382.000 73Z.000 56.271 1.225 0.822 1413.000 -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 CGR.NGT WING .NGT W5NG. NGT DPHI.LDT QLS .LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT ENRA .CNL RCEN.CNL RTNR.CNL CNTC .CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT&.BHC GR .CHL ILO.OTE IFRE.OTE IIXO. DTE MTEM.OTE DTL. SOT DTSM.SDT TT1.SDT LTT1. SOT SGR. SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT ENRA.CNL RCEN.CNL R TNR. CNL CNTC .CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR PAGE: ZO 33.518 171.694 4.060 48.824 0.109 68.563 1165.000 Z.906 151.750 6.172 22~6.485 3.941 13&0.586 0.676 58~8.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12.742 ZO.O00 0.000 147.750 64.700 148.000 3gZ.O00 707.600 56.2'?1 47.107 175.164 6.57'9 -999.,250 -999.250 -999.~50 -999-250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 ILM.DIL -999.,Z50 ILO.OIL -999.250 -999.250 TENS.OIL -999.250 DT.BHC -999.250 -999.250 TT3oBHC -999.Z50 TT4.BHC -999.Z5U -999.250 TENS.BHC --999.250 GR.CHL -999.250 .IS TAPE YERIPICATION ~LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER TENS.CHL -999.250 SFLU.DTE SP. gTE -169. 000 IDPH.DTE IDP. DTE 78.1 25 CIMP. DTE IIRM. DTE -Z$1. 500 SGR. DTE MRES.DTE 0.722 HTEN.DTE DTLN. SOT 65. 900 gTLF. SOT COHC. SOT O. 971 COHS. SOT TTZ. SDT 270. 400 TT3. SOT LTTZ.SDT 623.600 LTT3.SDT TENS.SOT 5044.000 HTEN.SDT THOR.NGT 3. 995 POTA. NGT W2NG.NGT 75.531 'W3NG. NGT TENSoNGT 5044. 000 CS.NGT RHOB. LDT -999. Z 50 DRHO. LOT QSS.LDT -999. 250 ES. LOT ITH. LDT -999. 250 S SI.LOT 5HV·LDT -999. 250 51RH.LOT CAL1.LDT -999. 250 GR. LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPH~..CNL -999.250 TNPH.CNL NPOR.CNL -999.Z50 RCNT.CNL CFTC.CNL -999.2 50 GR. CNL GR. EPT -999. 250 SA. EPT MTEM.~PT -999.250 MRES.EPT IMPH.COR -999. Z 50 SP. COR HTEN.COR -999.250 DEPT. 11000.000 SFLU.DIL SP..DIL -19. 969 GR. DIL TT1.BHC 639· 500 TT2. BHC GR.BHC 80. 625 SP.BHC TENS.CML -999.Z50 SFLU.DTE SP.OTE -148.250 IDPH.DTE CIDP.DTE 57.063 CIMP.DTE I IRM. D'!E -350.3 75 SGR. DTE MRESoDTE 0.728 HTEN.DTE DTLN·SDT 56.400 DTLF.SDT COHC.5DT 0.950 COHS.SOT TTZ. SDT 263.600 TT3. SOT LTTZ.SDT 596.400 LTT3.SDT TENS.SOT ~948.000 HTEN.SOT THOR.NGT 6.393 POTA.NGT W2NG.NGT 84.201 W3NG.NGT T ENS.NGT ~948. 000 CS. NGT RHOG.LDT -999.250 ORHO.LDT QSS. LOT -999. 350 tS. LOT LITH. LOT -999. Z50 SS1. LOT SSHV.LDT -999.350 S1RH.LDT C ALI:,. LOT -999.2 50 GR.LOT MRES.LD'T -999.250 HTEN.LOT CFEC.CNL -999.Z50 CNEC.CNL NPHI.CNL -999.Z50 TNPH.CNL NPOR.CNL -999.250 RCNT·CNL CFTC.CNL -999,. Z50 GR.CNL Z4-APR-1989 18:07 9696.000 ILM.DTE 13.789 IMPH.DTE -291.500 IIRD.DTE 53.417 TENS.DTE 1 ~1 Z. 000 DT. SOT )71.100 DTCO.SDT O.3ZB COST.SOT 533.600 TT4.SOT 1318.400 LTT4.SDT 141Z.000 SGR.NGT 1.385 URAN.NGT 31.250 W4NG.NGT 1570. 000 HTEN.NGT -999. 350 PEF.LOT -999.2.50 LU.LOT -999.250 SS2.LDT -999.350 [.SRH.LDT -999.350 TENS.LOT -999.350 ENPH.CNL -999.250 RCEF.CNL -999.350 TNRA.CNL -999· Z50 ~CFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.350 HTEN.EPT -999. 250 SGR.COR 2.401 ILM.DIL 80.625 TENS'DIL &58.250 TT3.BHC -lg. 969 TENS.BHC 9696.000 ILM. DTE 17. 516 IMPH. DTE -350. 875 IIRD.DTE 53.446 TENS.DTE 1385.000 DT.SOT 66.000 DTCO.SOT O. 313 COST. SOT 520.800 TT4. SOT 823.600 LTT4,SDT 1385.000 SGR.NGT 1.162 UR~,N.NGT 20.~33 W4NG.NGT 1577.000 HTEN.NGT -999.350 PEF.LDT --999. 250 LU.LOT -999.250 SS2.LDT -999.350 LSRH.LOT -999.Z50 TENS.LDT -999.2.50 ENPHoCNL -999.2.50 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999. 250 NVR.EPT 1950. 1950. 70. 5044. 62. 93. O. 409. 683. 53. Z. 2. 1413. -999. -999. -999. -999. -999. -999. -999. -999° -999. --999. -999. --999. --999. . 7404. 637. 7,404. 1950. 1950. 4948. 93. O. 383. 708. 1. Z. 1385. -999. -999. -999. -999. -999. -999. -999. --999. -999. -999. 000 000 813 000 700 000 955 600 ZOO 417 131 604 000 350 25O 250 25O 25O 25O 250 250 25O 25O 2-5O 25O 25O 563 000 500 000 000 000 656 000 400 000 ,633 ZOO 000 446 235 604 000 2-5O 25O 250 2-50 25O 25O 2.5O 350 250 2.50 ILO. DTE IFRE.DTE IIXD.OTE MTEM.DTE O'TL. S DT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR. NGT W[NG.NGT WGNG.NGT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA .CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.CDR TENS.CDR ILD.O, IL BT .BHC TT.~.. 8HC GR.CHL ILO .DTE IFRE.OTE IIXD.DTE MTEM.DTE DTL.$DT DTSM.SDT T11. SDT L T T 1. S D T SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR. EPT PAGE: 13.563 ZO.O00 0.000 147.000 62.700 157.000 406.800 741.Z00 53.417 37.468 182.292 1.736 -999.250 -999.250 -999.350 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z.527 91.188 454.250 -9~9.250 17.063 20.000 0.000 55.900 153.000 380.000 710.800 5Z.446 43.207 157.986 7.813 -999.Z50 -999.2.90 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.350 -'999.250 -999.250 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER GR.EPT -999.250 SA.EPT MTEM. EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 10900. 000 SFLU. OIL SP.OIL -20.250 GR.DIL fTI.BHC 669.000 TT2.BHC GR.BHC 85.500 SP.BHC lENS.CML -999. 250 SFLU. OTE SP. DTE -146. 500 IDPH. DTE CIDP.DTE 76.188 CIMP.DTE IIRM.DTE -312.250 SGR.DTE MRES.OTE 0.732 HTEN.DTE DTLN.SDT 56.700 OTLF.SDT COHC. SOT 0.917 COHS.SOT TT2. SOT 266. 800 TT3. SOT LTT2.SDT 592.000 LTT3.SOT TENS.SOT 5068.000 HTEN.SOT THOR. NGT 4. 738 POTA.NGT W2NG.NGT 85.938 W3NGoNGT TENS.NGT 5068' 000 CS.NGT RHO~S.LDT -999.250 ORHO.LDT Q$S. LOT -999.2 50 ES. LOT LITH.LDT -999. 250 SS1. LOT SSHV.LDT -999.250 SIRH.LOT CALI.LDT -999. 250 GR.LOT MRESoLDT -999.250 HTEN.LOT CFEC.CNL -999. 250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. Z50 GR.CNL GR. EPT -999. Z5O SA. EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.2 50 SP.COR HTEN.CUR -999.2 50 DEPT. 10800.000 SFLU.DIL SP.DIL 8.523 GR.DIL lTl. §HC 568. 000 TT2. BHC GR.BHC 66.813 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -149.250 IDPH.DTE CIDP.DTE 68.063 CIMP.DTE IRM. UTE -240. 000 SGR. DTE MRES.DTE 0.739 HTEN.DTE DTLN.SDT :63.400 OTLF.SOT COHC. SDT 0.736 COHS.SDT TTZ. SOT 269oZ00 T*T3. SOT LTTZ.SOT 598.000 LTT3.SDT TENS.SOT 5028.000 HTEN. SO'T THOR. NGT 5.630 POTA.NGT WZNG.NGT 86.505 W3NG.NGT ENS.NGT 5028. 000 CS. NGT RflOB.LDT -999. 250 ORHO.LDT 24-APR-1989 18:07 -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 1.751 ILM.DIL 85.500 TENS.DIL 477.000 TT3.BHC -20.250 TENS.BHC 9696.000 ILM.DTE 13.125 IMPH.DTE -312.Z50 IIRD.DTE 55.478 TENS.DTE 1474.000 DT.SDT 57.100 DTCO.SDT 0.328 COST.SDT 498.~00 TT4.SDT 884.400 LTT4. SDT 1474.000 SGR.NGT 1.448 URAN.NGT 24.306 W4NG'NGT 1580.000 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LOT -999.250 LSRH.LOT -999.250 TENS.LDT -999. Z50 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.Z50 RCFT.CNL -999. 250 NVR. EPT -999. 250 CALI. EPT -999.250 HTEN.EPT -999. Z50 SGR.COR 3.862 ILM. DIL 66.813 TENS.OIL 434.750 TT3.BHC 8.523 TENS.BHC 9696.000 ILM.DTE 14.680 IMPH.DTE -240.125 IIRD.DTE 5Z.148 TENS.DTE 1489.000 DT.SOT 68.900 DTCO. SDT 0.250 COST.SOT 489.600 TT4.SDT 8Z6.$00 LTT¢.SDT 1489.000 SGR.NGT 1.442 URAN.NGT 29.412 W4NG.NGT 1575.000 HTEN.NGT -999.250 PEF.LDT -999.250 -999.Z50 -999.Z50 1.937 7308.000 670.000 7308.000 1950.000 1950.000 69.875 5068.000 55.700 97.000 0.250 406.800 714.000 55.478 1.889 4.340 1474.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 3.493 721 2. 000 566.000 7212.000 1950.000 1950.000 6'3.500 5028.000 4'7. 900 103.000 0.706 380.400 711 .,600 52.148 0.995 1.730 1489.000 -999.250 TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT4.~HC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.OTE DTL.SDT DTSM.SOT TTt. SOT LTTI.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSMV.LDT LURH.LOT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FYR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.DTE IFRE.DTE IIXD.DTE MTEM.OTE OTL.SDT DTSM.SDT TT1.SDT LTTI.$DT SGR.SDT CGR.NGT WlNG.NGT WSNG.NGT OPHI.LDT QLS.LDT PAGE: -999.250 -999.250 -999.250 1.896 95.500 478.000 -999.250 1Z.789 20.000 0.000 1~5.1Z5 61.600 164.000 380.000 715.200 55.478 41.342 168.403 5.Z08 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25'0 -999.250 -999.250 -999.250 -999.250 3.329 78.125 438.000 -999.250 14.250 20.000 0.000 54.600 150.125 378.400 712.000 52.148 44.702 164.360 6.055 -999.250 -999.250 .IS 'TAPE VERIFICATION LISTING ;CHLUMBERGER AL~SK~ COMPUTING CENTER QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SS1.LDT SSHV.LOT -999.250 S1RH.LOT CALI.LDT -999.250 GR.LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.Z50 RCNT.CNL CFTC.CNL -999.Z50 GR.CNL GR.EPT -999.Z50 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 [)EPT. 10700.000 SFLU.DIL SP.DIL 23.750 GR.DIL TT1.BHC 678.000 TT2.BHC GR.BHC 82.938 SP.BHC TEN~.CHL -999.250 SFLU.DTE SP.OTE -167.500 IDPH.DTE CIDP.DTE 76.313 CIMP.DTE IIRM'DTE -309.500 SGR.DTE MRES.OTE 0.744 HTEN.DTE DTLN.SDT 57.200 DTLF.SDT COHC.SDT 0.917 COHS.SOT TTZ.$DT 265.200 TT3.SOT L'TTZ.SDT 592.800 LTT3.SOT TENS.SOT 4900.000 HTEN.SOT THOR.NGT 6.276 POTA.NGT WZNG.NGT 87.931 W3NG.NGT TENS.NGT 4900.000 CS.NGT RHOB.LDT -999.25U DRHO.LOT QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SS1.LOT SSHV.LDT -999.250 S1RH.LOT CALI.LDT -999.250 GR.LDT MRES.LDT -999.250 HTEN.L~T CPEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.Z50 TNPH.CNL NPgR.CNL -999.Z50 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SAoEPT MTEM.EPT -999.250 MRES.EPT IMPHoCOR -999.250 SP.COR H'TEN.COR -:999.250 DEPTo 10600.000 SFLU.DIL SP.UIL 35'719 GR.OIL TT1.SHC 686.000 TT2.BHC GRoBHC 85.438 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.OTE -999.250 IDPH.D'TE CIDP.O'TE -999.250 CIMPoDTE IIRM.DTE -999.250 SGRoD'TE MRES.DTE -999.250 HTEN.DTE 24-~PR-1989 1B:07 -999. 250 LU.LOT -99 9. 250 -999.250 SS2.LOT -999.250 -999.250 LSRH.LOT --999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL --999.250 -999.250 TNRA.CNL -999.250 -999.250 RC,~T.CNL -999.250 -999. Z50 NVR.EPT -999. 250 -999.250 CALI.EPT -999.Z50 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 1.991 ILM.DIL Z.155 82.938 TENS.OIL 7164.000 484.000 TT3.BHC 678.500 23.750 TENS.BHC 7164.000 9696.000 ILM.OTE 1950.000 13.102 IMPH.DTE 1950.000 -313.500 IIRD.DTE 70.063 55.699 TENS.OTE 4900.000 1438.000 DT.SDT 49.400 57.500 OTCO. SDT 101.000 0.259 COST.SOT 0.509 518.000 TT4.SDT 379.200 821.600 LTT4.SDT 706.800 1438.000 SGR.NGT 55.699 1.469 URAN.NGT 1.079 28..~48 W4NG.NGT 5.172 1613.000 HTEN.NGT 1438.000 -999.250 PEF.LOT -999.250 -999. Z 50 LU.EDT -999. 250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.Z50 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.2:50 -999.250 HTEN.EPT -999.250 -999. 250 SGR.COR -999.250 2.069 ILM.OIL 2.287 83.438 TENS.DIL 7020.000 ,~88.250 TT3.BHC 688.500 35.719 TENS.BHC 70Z0.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIR[).OTE -999.250 -999.250 TENS.DTE -999.250 -999.2 50 OT. SOT -999. 250 LL.LDT LSHV .LOT LURH.LOT MTEM.LDT ENRA.CNL RCEN.CNL RTNR .CNL CNTC.CNL FVR. EPT TENS.EPT IOPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.OTE IFRE.OTE IIXO.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT L SHV. LD'T LURH. LDT MTE~.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPM.COR TENS.COR ILO.DIL DT. BHC TT,~.BHC GR.CHL ILO.DTE IFRE.DTE IIXD.OTE MTEM.OTE OTL.SDT PAGE: 23 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 --999.250 -999.250 -999.250 2.111 97.625 485.000 -999.250 12.703 ZO.O00 0.000 143.125 ~9.600 166.000 405.Z00 708.400 55.699 47.627 166.379 5.1'72 -999.~50 -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 2.254 97.188 488.750 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING ;CHLUM,~ERGER ALASKA COMPUTING CENTER DTLN.SDT -999.Z50 OTLF.SDT COHC.SDT -999.250 COHS.SOT TT2. SOT -999.250 TT]. SOT LTTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SOT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOB.LDT -999.Z50 DRHO.LDT QSS.LDT -999.Z 50 LS.LDT LITH. LOT -999. 250 $ S!.LOT SSHV.LDT -999.250 S]RH.LOT CALI.LOT -999. Z 50 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SA.EPT MTEM. EPT -999.250 MRES.EPT IMPH.CUR -999. 250 SP.COR HTEN'COR -999. 250 DEPT. 10500.000 SFLU.DIL SP.DIL 25.516 GR.DIL TT1.BHC 691 . 500 TT2.BHC GR.BHC 87.000 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IRM.DTE -999. 250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN. GDT -999.2 50 OTLF. SOT COHC.SDT -999.250 COHS.SDT TTZ.SDT -999. 250 TT3. SOT LTTZ.SOT -999.250 LTT3.SDT TENS.GDT -999.250 HTEN.SDT 'THOR.NGT -999.250 POTAoNGT WZNG.NGT -999.250 W3NG.NGT ENS.NGT -999. 250 CS.NGT RHOB.LDT -999.Z50 ORHO.LOT QS S. LDT -999. 250 LS. LOT ITH.LDT -999. 250 SSI.LOT SSHV.LDT -999.250 S1RH.LOT CALI.LDT -999. 250 GR. LOT MRES.LD'T -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SA. EPT MTEM.~PT -999.250 MRES.EPT MPH.COR -999.Z50 SP.COR HTEN.COR -999. 250 24-APR-1989 18:07 -999.250 OTCO.SOT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W~NG.NGT -999.Z50 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LOT -999.250 SS2.LOT -999.250 LSRH.LOT -999.250 TENS.LDT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 1.920 ILM.DIL 87.000 TENS.OIL 492.Z50 TT3.BHC 25.516 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999o250 IIRO.OTE -999.250 TENS.DTE -999.250 OT.SDT -999.250 DTCO.SDT -999.Z50 COST.SOT -999.250 TT4.SOT -999.250 LTT~.SOT -999. Z50 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LOT -999.250 LU.LDT -999.250 SSZ.LDT -999.250 LSRH.LDT -999. 250 TENS.LOT -999.250 ENPHoCNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR -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 -999.2S0 -999.250 2.170 7008.000 690.000 7008.000 -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 DTSM. SOT TT1 .SOT L'TT1. SOT SGR.SDT CGR.NGT WtNG.NGT W5NG.NGT DPHI.LDT QLS.LDT LL .LOT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.SHC TT4.BHC GR.CHL ILD.OTE IFRE.DTE IIXD.OTE MTEM.OTE D T L. S D T DTSM. SOT TT1.SDT LTT 1. SOT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EP'T IDPH.COR TENS.COR PAGE: -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. Z. 98. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 24 250 Z50 250 25O 250 250 250 250 25O 25O 25O 250 25O 25O 250 250 250 25O 25O 250 25O 117 750 000 25O 25O 25O 25O 25O 250 250 25O 25O 25O 250 25O 25O 25O 25O 25O 250 250 25O 25O 25O 25O 25O 250 250 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER /~LASKA COMPUTING CENTER DEPT. 10400.000 SFLU.DIL SP.DIL 4.754 GR.OIL TTI.BHC 662.500 TTZ.BHC GR.BHC 83.563 SP.BHC TENS.CHL -999.250 SFEU.DTE SP. DTE -999.250 IDPH.DTE ClOP. UTE -999.250 CIMP.DTE IIRM.DTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.$D[ -999.250 OTLF.SDT COHC.SDT -999.250 COHS.SOT TTZoSDT -999.250 TT3.SDT LTTZ.SDT -999.250 LTT3.SOT TENS.GDT -999.250 HTEN.SOT YHOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOB.LOT -999.250 DRHO.LDT QSS.LDT -999.250 ES.LOT LITH.LDT -999.250 SSI.LOT SSHVoLOT -999.250 S1RH.LOT CALl. LOT -999.2 50 GR.LDT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 10300.000 SFLU.OIL SP.OIL -4.758 GR. OIL TT1. §HC 691. 000 TT2. BHC GR.~HC 87.063 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.OTE -999.250 CIMP.DTE IIRM. DTE -999o2 50 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLNoSDT '-999.250 OTLF.SOT COHC.SDT -999.250 COHS.SOT TTZ.SOT -999.250 TT3. SOT LTTZ SOT -9'99.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NG'T -999. Z 50 CS. NGT RHOB.LDT -999. 250 DRHO. LOT QSS.LDT -999.2 50 LS.LOT L ITH.LDT -999. 250 S S1. LOT SSHV.LDT -999.250 S1RH.LOT CALI.LDT -999.250 GR. LOT 24-APR-1989 18:07 2.299 ILM.DIL 83.563 TENS.DIL 483.000 TT3.BHC 4.754 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRO.OTE -999.250 TENS.DTE -999.250 DT.SDT -999.250 DTCO.SDT -999.250 COST.SOT -999.250 TT4.SOT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LOT -999.250 SS2.LOT -999.250 LSRH.LOT -999. 250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 2.595 6764.000 660.000 6764.000 -999.250 -999.250 -999.250 -999.250 -ggg.z50 -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 3.194 ILM.OIL 3.524 87.063 TENS'OIL 6664.000 499.500 TT3.BHC 688.000 -4.T58 TENS.BHC 6664.000 -999.250 ILM. DTE '-999.250 -999. 250 IMPH. DTE -99'9. 250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 OT. SOT -999.250 -999.250 DTCO.SOT -999.250 -999.250 COST.SOT '-999. 250 -999.250 TT4.SDT -999.250 -999.250 LTT4. SDT -999.250 -999.250 SGR. NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W&NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LOT -999.250 -999.250 SS2.LOT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 ILO.OIL OT.,~HC TT4.5HC GR.CHL ILO.DTE IFRE.DTE IIXD.OTE MTEM. DTE DTL.SOT DTSM.SDT TT1.SDT LTT1 .SOT SGR.SOT CGR.NGT W1NG.NGT WENG. NGT DPHI .LOT QLS.LDT EL.LOT LSHV .LOT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS. EPT IOPH.COR TENS.COR ILO .OIL DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXO.DTE MTEM.OTE DTL. SDT DTSM. SOT TT1. SOT LTT1.SDT SGR.SDT CGR.NGT WING. NG'T WENG.NGT DPHI .LOT QLS.LDT EL.LOT LSHVoLDT LURH. LDT MTEM.LOT PAGt: 25 Z.607 95.313 462.000 -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 3.471 96.313 490.250 -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 r--999.250 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999. 250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPDR.CNL -999.250 RCNT.CNL CFTC.CNL -9 99. 250 GR.CNL GR. EPT -999. 250 SA. EPT MTEMoEPT -999.250 MRES.EPT I MPH.CQR 1950. 000 SP.COR HTEN.COR 1457.000 DEPT. 10ZO0.O00 SFLU. OIL SP.DIL -18.297 GR.DIL TT1.BHC 668. 500 TTZ.BHC GR. BHC 73. Z 50 SP.BHC TENS.CHL -999.Z50 SFLU.DTE SP.OTE -999.250 IDPH.DTE CIDP.DTE -999.250 C[MP.DTE I IRM. gTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SOT COHC.SOT -999.250 COHS.SDT TTZ. SOT -999.250 TT3' SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT l ENS.NGT -999. Z 50 CS. NOT RHOB.LDT -999. 250 ORHO.LOT USS. LOT -999. 250 LS.LOT LITH. LOT -999. Z 50 S S1.LDT SSHV.LD'T -999.250 SIRH.Lt'JT CALl.LOT -999. 250 GR.LOT MRES.LDT -999. 250 HTEN.LDT CPEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.2 50 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR 1950. 000 SP.COR HTEN.COR 1297.000 DEPT. 10100.000 SFLU.DIL SP.DIL -5.50B GR.DIL TT1 .BHC 671 . OOO TTZ .BHC GR.BHC 71.500 SP.BHC TENS. CHL -999.2 50 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -9'99.250 CIMP.DTE IIRM. DTE -999. 250 SGR. DTE MRES.DT~ -999.250 HTEN.DTE DTLN.SDT -99'9.250 DTLF. St'JT COHC.SDT -999.Z50 CE)MS.SOT TTZ. SOT -999.250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT 24'-APR-1959 1~:07 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -~99.250 -999.250 HTEN.EPT -999.250 -222.875 SGR.COR 66.233 2.672 ILM.DIL 73.250 TENS.OIL 481.000 TT3.BHC -18.Z97 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999.250 TENS.OTE -999.250 gT.SOT -999.250 gTCO.SOT -999. Z50 COST.SOT -999.250 TT4.SOT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LOT -999.250 LU.LOT -999.Z50 SS2.LDT -999.250 LSRH.LOT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 'TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -232.500 SGR.COR 1.95Z ILM.DIL 71.500 TENS.DIL 479.000 TT3.BHC -5.508 TENS.BHC -999.250 ILM.OTE -999.Z50 IMPH.DTE -999.250 IIRD.OTE -999.250 TENS.gTE -999.250 DT.SDT -999.250 gTCO.SOT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4,.SDT 3.023 6612.000 672.000 6612. 000 -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 60.603 2.365 64. 84. OOO 668.000 6484.000 -999.250 -999.250 --999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL O'T.BHC TT4.BHC GR.CHL ILO.gTE IFRE.DTE IIXD.OTE MTEM.OTE OTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.CDR TENS.CDR ILO.OIL DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXg'DTE MTEM. DTE DTL.SDT DTSM.SDT TT1.SDT LTTI.SDT SGR.SDT PAGE: 26 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 15.719 Z.992 95.563 483.000 -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 15.609 ¢572.000 2.449 96.188 ~80.250 -999.250 -999.250 -999.250 -~9~.250 999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS 'TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER lENS.SOT -999.250 HTEN.SDT THOR. NGT -999. 250 POTA. NGT WZN~.NGT -999.250 W3 NG.NGT ENS. NGT -999.250 CS. NGT RHQ~.LDT -999.Z50 ORHO.LDT USS. LOT -999. 250 LS. LOT ITH. LOT -999. Z 50 SS1.LDT SSHV.LDT -999. 250 SIRH. LOT CALI.LOT -999. Z50 GR.LDT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL FTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT ZMPH.COR 1950. 000 SP.COR HTEN.COR 1467.000 DEPT. 10000.000 SFLU.DIL SP.OZL 3.998 GR.DIL TT1.SHC 646.500 TTZ.BHC GR.BHC 67.313 SP.BHC TENS. CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.OTE CIDP.OTE -999.250 CIMP.DTE IIRM. gTE -999. 250 SGR. gTE MRES.DTE -999.250 HTEN.DTE DTLN.SOT -999.250 DTLF.SOT COHC.SDT -999. 250 COHS.SOT TTZ. SDT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SOT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999. Z 50 CS. NGT RHUB..LDT -999.250 ORHO.LOT QSS.LDT -999. 250 LS.LOT L ITH. LOT -999.250 SSI.LOT SSHV.LDT -999.250 SZRH.LgT [ALI.LDT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -9!~9.Z50 TNPH.CNL NPOR,.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR. EP'T -999.2 50 SA. EPT MTEM. EPT -999. 250 MRES. EPT IMPH.COR 1950. O00 SP.COR HTEN.COR 1357.000 DEPt'. 9900.000 SFLU.OIL SP.UIL -31.016 GR.OIL TT1.BHC 6~2.000 TT2.BHC GR.BHC 68.563 SP.~HC 24-APR-1989 18:07 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999.250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LOT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN. EPT -999.250 -235.750 SGR.COR 51.231 3.162 ILM.DIL 3.581 67.313 TENS.OIL 6340.000 a66.250 TT3.BHC 640.000 3.998 TENS.BHC 6340.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.OTE -999.250 -999. 250 DT. SOT -999.250 -999.250 gTCO.SOT -999.250 -999.Z50 COST.SOT -999.250 -999.250 TT4.SOT -999.230 - 999. 250 LTT4.S OT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999. Z50 W4NG.NGT -999.250 -999. 250 HTEN.NGT -999.250 -999.250 PEF.LOT -999.230 -999.. 250 LU.LOT -999. 250 -999.250 SS2.LDT -999.250 -999. 250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.Z50 ~CEF.CNL -999.Z50 -999.250 TNRA.CNL -999.250 -999. 250 RCFT.CNL -999°250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -Z40.O00 SGR.COR 48.417 3.787 ILM.OIL 68.563 TENS,OIL 462.750 TT3.BHC -31.016 TENS.BHC 4.565 6208.000 640.500 6208.000 CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.gTE IFRE.OTE IIXO.DTE MTEM.DTE DTL.SDT DTSM.SDT TTI.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG. NGT WSNG.NGT OPHI.LDT QLS.LDT LL.LD'T LSHV.LDT LURH.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTCoCNL FVR.EPT TENS.EPT IDPHoCOR TENS.CDR ILO.OIL DT.BHC TT~.~HC GR.CHL PAGE: Z7 -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 13.453 ¢81Z.000 3.547 90.438 461.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.230 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -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 14.078 ~600.000 4.573 90.000 463.500 -999.250 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ~LASK& COMPUTING CENTER TENS.CHL -999.250 SFLU.DTE SP. DTE -999.250 IDPH.DTE CIDP.OTE -999.250 CIMP.DTE IIRM.DTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF.SOT LOHC.SDT -999.250 COHS.SOT TTZ.SDT -999.250 TT3.SOT LTTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SDT THUR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOS.LDT -999.250 DRHO.LDT ~5S.LDT -999.250 LS.LDT L ITH.LD'T -999. 250 SSi.LOT SSHV.LOT -999.250 SIRH.LDT CAL!.LDT -999.250 GR.LDT MRES.LOT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHZ.CNL -999.250 TNPH.CNL NPOR.CNL -999'250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EPT MTEM. EPT -999.250 MRES.EPT IMPH.COR -999.250 5PoC~R HTEN.CUR -999.250 DEPT. 9800.000 SFLU.DIL SP.DIL -13.000 GR.D[L 'TT1.BHC 674.000 TTZ.BMC GR.BHC 61.344 SP.BHC TENS.CHL -999.250 SFLUoDTE 5P.DTE -999.250 IDPH.DTE CIOP.DTE -999.250 CIMP.DTE ! IRM.DTE -999.250 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT CUHCoSDf -999.250 COHS.SOT 'TTZ.SUT -999.250 TT3.SDT LTTZ.SDT -999.250 LTT3.SDT TENS.SDT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT 1ENS.NGT -999.250 CS.NGT RHOB.LDT -999.250 ORHO.LOT QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SSI.LOT 5SHV.LDT -999.250 S1RH.LOT CALI. LDT -9 99. 250 GR.LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 'TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL 24-~PR-1989 1~:07 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 9T. SOT -999. 250 -999.250 OTCO.SDT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LOT -999.250 -999. 250 LU.LDT -999. 250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LOT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999o250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999. 250 SGR.COR -999.250 1.036 ILM. OIL 61.344 TENS.OIL · 95.500 TT3.BHC -13.000 TENS.BHC -999.250 ILM.OTE -999.250. IMPH.DTE -999.250 IIRO.DTE -999.250 TENS.DTE -999.250 DT.SDT -999.250 DTCO.SDT -999.250 COST.SDT -999.250 TT4.SOT -999.250 LTT4"SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W~NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SSZ.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT 1.902 6452.000 67~.000 6452.000 -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 ILO.DTE IFRE.OTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM. LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EP'T TENS.EPT IDPH.COR TENS.COR ILD.DIL DToBHC 'TT~.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.OTE MTEM.DTE OTL.SDT DTSM. SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LOT LSHV.LDT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT PAGE: -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 1.960 105.938 500.250 -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 28 TAPE VERIFICATION LISTING S~H/UMBERGER ALASKA COMPUTING CENTER GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EOT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 9700.000 SFLU.DIL SP.DIL -93.063 GR.DIL TT1.8HE 681 · 500 TT2. BHC 5R.BHC 33.375 SP.BHC T ENS.CHL -9'99. Z50 SFLU. gTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM. DTE -999. 250 SGE. DTE MRES.DTE -999.250 HTEN.DTE DTLN. SOT -999. 250 DTLF. SOT COHC.SDT -999.250 COHS.SOT TT2. SOT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3. SOT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NG'T -9:99. 250 CS. NGT RHOB.LDT -999.250 DRHO.LOT QSS.LOT -999.250 LS.LDT L ITH.LDT -999. 250 SS1. LOT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999. Z 50 GR. LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.2.50 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CML -999.2 50 GR.CNL GR. EPT -999. 250 SA. EPT MTEM.EPT -999.250 MRES.EPT I MPH.COR -999.2 50 SP.CgR HTEN. COR -999. Z 50 DEPT. 9600.000 SFLU.DIL SP.DIL -53.281 GR.D[L TT1. BHC 626. 000 TT2.BHC GR. §HC 55.688 SP. BHC 'lENS.CML -999.250 SFLU.DTE 5P.DTE -999.Z50 IDPH.OTE CIOP.OTE -999.250 CIMP.DTE I IRM. OTE -999. Z 50 SGR. DTE MRES.DTE -999°250 HTEN.DTE DTLN. SDT -999. 250 OTLF. SOT COHC. SOT -999.250 {;OHS.SOT TTZ. SOT -999.250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SDT -999.250 HTEN.SDT THOR. NGT ' -999.2 50 POTA.NGT WZNG.NGT -999.250 'W3NG.NGT TENS:NGT -999. 250 CS. NGT RHOB.LDT -999.250 DRHO.LDT 24-~PR-1989 18:07 -999.250 -999.250 -999.Z50 3.795 33.375 481.500 -93.063 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.~50 -999.250 -999.250 -999.~50 5.002 55.688 452.Z50 -53. ZB1 -999.250 -999.250 -999.250 -999.250 -999,Z50 -999-250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CALI.EPT HTEN. EPT SGR.COR ILM.DIL TENS.OIL TT3.BHC TENS.BHC ILM.DTE IMPH.DTE IIRD.DTE TENS.DTE DT.SOT OTCO.SOT COST.SOT TT4.SDT LTT4.SDT SGR.NGT URAN.NGT W~NG.NGT HTEN.NGT PEF.LDT LU.LOT SS2.LOT LSRH.LDT TENS.LOT ENPH.CNL RCEF.CNL TNRA.CNL RCFT.CNL NYR.EPT CALI.EPT HTEN.EPT SGR.COR ILM.DIL TENS.OIL TT3.BHC TENS.BHC ILM.OTE IMPH.OTE IIRD.DTE TENS.DTE OT.SOT OTCO.SOT COST.SOT TT4.SDT LTT4.SDT SGR.NGT URAN.NGT W4NG.NGT HTEN.NGT PEF.LOT -999.250 -999.250 -999.250 1.752 6104.000 684.000 6104.000 -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.~50 -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. 335 6072.000 629.000 6072.000 -999.250 -999.250 -999.250 -99 9. ZSO -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.'250 -999. 250 -999.250 TENS.EPT IDPH.COR TENS.CgR ILO.OIL DT.BHC TT¢.3HC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTTI.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL D'T.~HC TT~¢. BHC GR.CHL IlO .DTE IFRE.DTE IIXO. gTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING. NGT WSNG.NGT OPHI.LDT QLS.LDT -999.250 -999.250 -999.250 1.530 101.500 484.000 -999.250 -999.Z50 -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 2.932 89.188 452.750 -999.250 -999.250 -999.250 -999.250 -999.250 -999o250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 29 .IS TAPE YERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 24-A, PR-1999 18:07 QSS.LDT -999.250 LS.LOT -999. 250 LU.LDT LITH.LDT -999.250 SS1.LDT -999.250 SS2.LOT SSHV.LDT -999.250 S1RH.LOT -999.250 LSRH.LDT CALI.LDT -999.250 GR.LDT -999.250 TENS.LOT MRES.LDT -999.250 HTEN.LDT -999.250 ENPM.CNL CFEC.CNL -999.250 CNEC.CNL -999.250 RCEP.CNL NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL NPOR.CNL -999,250 RCNT.CNL -999.Z50 RC.~T.CNL CPTC.CNL -999.250 GR.CNL -999.250 NVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT IMPH.COR -999.250 SP.COR -999.250 SGR.COR HTEN.COR -999.2:50 DEPT. 9500.000 SFLU.DZL SP.DIL -17.766 GR.DIL TT1. BHC 652. 500 TT2.BHC GR.BHC 60.000 SP.BHC TENS.CML -999.250 SFLU.DTE SP. DTE -999.250 IDPH.DTE CIOP.DTE -999.250 CIMP.DTE IIRM.OTE -999.250 SGR.DTE MRES. DTE -999. 250 HTEN. DTE OTLN.SDT -999.250 OTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ. SOT -999.250 TT3. SOT LTIZ.SOT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SOT THOR.NGT -999. 250 POTA. NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999. Z 50 CS. NGT RHOB.LDT -999. 250 ~RHO.LOT QSS.LDT -999.. 250 LS.LDT L ITH. LDT -999. 250 S S1 oLOT SSHV.LDT -999.250 SiRH.LOT C ALI.LOT -999. 250 GR. LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NP[JR.CNL -999.250 RCNT.CNL C FTC.CNL -999.250 GR. CNL GR.t:PT -999,250 SA.EPT MTEM. EPT -999.2 50 MR ES. EPT IMPH.CUR -999. 250 SP. COR HTEN.COR -999.250 DEPT. 9400.000 SFLU.DIL SP.OIL -30.500 GR.DIL TT1. BHC 668. 000 TTZ. BHC GR.BHC 61,, 375 SPoBHC TENS.CML -999.250 SFLU.DTE' SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM. DTE -999. Z 50 SGR. DTE MRES.DTE -999.250 HTEN.DTE 2.823 ILM.DIL 60.000 TENS.OIL 469.000 TT3.BHC -17.766 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999. 250 TENS.OTE -999. 250 DT. SOT -999.250 DTCO. SOT -999.250 COST.SOT -999.250 TT4.SDT -999. 250 LTT4. SOT -999.250 SGR.NGT -999.250 URAN. NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LDT -999. 250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI .EPT -999.250 HTEN.EPT -999,250 SGR.COR -999.250 --999.250 -999.250 --999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.369 5804.000 655.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -ggg.250 -ggg.250 -999.250 -999.250 -999.250 -999.250 -999.250 --999.250 --99 9. 250 --999.250 -999.250 -999.250 -999. 250 -999.250 4.087 ILM.DIL 4.536 61.375 TENS.OIL 6020.000 459.500 TT3.BHC 66.5.000 -30.500 TENS.BHC 6020.000 -999. 250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE ,-999.250 -999.250 TENS.DTE -999.250 - 999.2.50 [}T. SOT -999.250 LL.LDT LSHV.LDT LURH.LDT NTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.CDR TENS.COR ILO.OIL DT.BHC TT4. BHC GR.CHL ILD.DTE IFRE.OTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1 .SOT LTT1.SDT SGR.SDT C GR. NGT WING.NGT WSNG.NGT DPHI .LOT r2LS .LOT LL.LOT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR. EP'T TENS.EPT IDPH.COR TENS .COR ILO.OIL DT. BHC TT4.BHC GR.CHL ILDoOTE IFRE.DTE IIXO.DTE MTEM.OTE DTL.SDT PAGE: 30 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.259 92.938 ~70.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.290 -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 4.735 91.188 465.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER DTLN.SDT COHC.SOT TTZoSDT LTTZoSDT lENS.SOT THURoNGT WZNG.NGT TENS.NGT RHUB.LOT ~SS.LDT LITH.LDT SSH¥.LDT CALI.LDT HRES.LDT CFEC.CNL NPHIoCNL NPUR.CNL CFTC .CNL GR.EPT MTEM. EPT ~MPH.COR MTENoCOR DEPT. SP.OIL TT 1. B MC GR.BHC TENS.CHL SP. DT E CIgP.DTE IIRM.OTE MRES.DTE DTLN.SDT COHC.SDT TT2.SDT L TTZ. SOT TENS.SOT THDR.NGT W2NG.NGT TENS.NGT RHDB.LDT Q $ S. L D T LITH.LDT SSHV.LDT C AL I. LDT MRES.LDT CFEC.CNL NPH~.CNL NPOR.CNL C FTC. CNL GR.EPT MTEM.EPT IMPH.COR HTEN.CgR -999.250 DTLF.SDT -999.250 CDHS.SDT -999. Z50 TT3. SOT -999.250 LTTD.SOT -999.250 HTEN.SDT -999.250 POTA.NGT -999.250 W3NG.NGT -999.250 CS.NGT -999.250 DRHO.LDT -999.250 LS.LOT -999.250 SS1.LDT -999.250 S1RH.LDT -999.250 GR.LDT -999.250 HTEN.LDT -999.250 CNEC.CNL -999.250 TNPH.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 SA.EPT -999.250 MRES.EPT -999.250 SP.COR -999.250 9300.000 SFLU.DIL -74.563 GR.DIL 684.000 TTZ.BHC 39.000 SP.BHC -999.250 SFLU.DTE -999.250 IDPH.DTE -999.250 CIMP.DTE -999.250 SGR.DTE -999.250 HTEN.DTE -999.250 DTLF.SDT -999.2 50 COHS. SOT -999.250 TT3.SOT -999.250 LTT3.SOT -999.250 HTEN.SDT -999.250 PO'TA.NGT -999.250 W3NG.NGT -999.250 CS.NGT -999.Z50 DRHO.LDT -999.250 LS.LDT -999.250 SSI.LOT -999.250 SIRH.LOT -999.250 GR.LBT -999.250 HTEN.LOT -999. 250 CNEC.CNL -9'99.250 TNPH.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 SA.EPT '-999.250 MRES.EPT -999.250 SP.COR -999.250 24-*PR-1989 18:07 -999.250 DTCO.SOT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LDT -999.250 LSRH.LDT -999.Z50 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.Z50 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 4.Z73 ILM.DIL 39.000 TENS.OIL 4~3.500 TT3.BHC -74.563 TENS.BHC -999.250 ILM.OTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999.250 'TENS.DTE -999.250 BT.SOT -999.250 OTCO.SDT -999.250 COST. SOT -999.250 TT4.SDT -999.250 LTT4.SOT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LUoLOT -999. 250 SS2.LDT -999.250 LSRH.LDT -999. 250 'TENS'LDT -999.Z50 ENPH. CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EP'T -999.250 HTEN.EPT -999.250 SGR.COR -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 1.685 5744.000 686.000 5'744. 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.2S0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. Z50 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2S0 -999.250 DTSM.SDT TTloSDT LTTt. SDT SGR.SDT CGR.NGT WING.NGT WENG.NGT OPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILD.DIL DT.BHC 'TT4.BHC GR.CHL ILD.DTE IFRE.OTE IIXO.DTE MTEM.OTE DTL.SDT DTS~.SDT TTJ.SDT LTT1.SOT SGR.SDT CGR.NGT W1NG.NGT WENG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL ~VR.EPT TENS. EPT IDPH.COR TENS.CDR PAGE' -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 1.438 101.563 4B5.000 -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 31 .IS TAPE YERIFICATIDN LISTING ;CHLUM5ERGER ~LASK~ COMPUTING CENTER DEPT. 9200.000 SFLU.DIL SP.DIL -47.1Z5 GR.DIL TT1. I:iHC 677. go0 TT2. BHC GR.BHC 64°688 SP.BHC T ENS.CHL -999.250 SFLU. DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. DTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN.OTE DTLN. SOT -999.250 OTLF.SDT COHC.SDT -999.250 COHS.SOT TTZ.SDT -999. Z 50 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS. SDT -999.250 MT EN. SDT THOR.NGT -999. Z50 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NOT -999.250 CS. NGT RHOB.LDT -999.2 50 DR HO. LOT QSS.LOT -999. 250 LS.LDT LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999. 250 SIRH.LDT CALI.LDT -999.250 GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999. 250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR. EPT -999. 250 SA. EPT MTEM.EPT -999.250 MRES.EPT IMPH.CDR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 9100.000 SFLU.DIL SP.DIL -73.313 GR.DIL TT1.BHC 654. 500 TT2.BHC GR.OHC 45.344 SP.BHC TENS.CHL -999.250 SPLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. OTE -999.2 50 SGR o DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF. SDT COHC.SDT -999.250 COHS.SOT TTZ. SOT -999. ZSO TT3. SOT LTTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SDT THOR.NOT -999.250 POTA.NGT WZNG.NGT -999.Z50 W3NG.NGT TENS.NOT -999. Z 50 CS. NOT RHOB.LDT -999.250 DRHO.LDT QSS.LOT -999. Z 50 LS.LDT L ITH.LDT -999. 250 SS1.LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999.250 GR.EDT 24-APR-1989 18:07 2.559 ILM.DIL 64.688 TENS.OIL 489.000 TT3.BHC -47.125 TENS.BMC -999.250 ILM. OTE -999.250 IMPH.OTE -999.250 IIRD.DTE -999.250 TENS.OTE -999.250 DT.SDT -999.250 DTCO.SDT -999. 250 COST.SOT -999. Z50 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LOT -999.250 LU.LDT -999.250 SSZ.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 5NPH.CNL --999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN. EPT -999.250 SGR.COR 4.703 ILM.DIL 45.344 TENS.OIL 456.250 TT3.BHC -73.313 'TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999.250 TENS.DTE -999.250 DT.SOT -999.250 DTCO. SDT -999.250 COST.SDT -999.250 TT4. SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 UR~N.NGT -999.250 W4NGoNGT -999.250 HTEN.NGT -999.250 PEF.LD'T -999.250 LU.LDT -999.250 SSZ.LOT -999.250 LSRH.LOT -999.250 TENS.LOT 2.022 5692.000 674.000 5692.000 -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 2.680 5644.000 655.000 5644.000 -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 IlO.OIL DT.~HC TT~. BHC GR.CHL ILD.OTE IFRE.DTE IIXO.DTE MTEM.DTE DTL.SDT DTSM. SOT TT1.SDT LTll. SDT SGR. SOT CGR.NGT WING.NGT WSNG.NGT DPHI .LDT QL S. LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL R'TNR .CNL CNTC.CNL FVR.EPT TENSoEPT IOPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILD.DTE IPRE.DTE IIXD.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SOT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT PAGE: 32 1.87B 94.375 490.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.ZS0 -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 '-999o250 -999.250 -999.250 2.326 87.000 456.750 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 TAPE VERIFICATION LISTING iCHLUMBERGER ALASK~ COMPUTING CENTER MR ES.LOT -999. Z 50 HT EN. LOT CFEC.CNL -999.Z50 CNEC.CNL NPHI.CNL -999. Z 50 TNPH.CNL NPOR.CNL -999.2 50 RCNT.CNL CFTC.CNL -999. Z 50 GR.CNL GR. EPT -999. 250 SA. EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 9000. 000 SPLU. OIL SP.DIL -57.Z81 GR.DIL TT1. BHC 577. 500 TT2. BHC GR.BHC 44.938 SP.BHC TENS.CHL -999.Z50 5FLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. UTE -999. 250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS. SOT TTZ. SOT -999-250 TT3.SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SOT THOR.NGT -999.250 POTA.NGT WZN[~. NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOB.LDT -999.250 DRHO.LOT QSS.LDT -999. 250 LS.LDT LITH.LOT -999.250 S51.LDT SSHV.LDT -999.250 S1RH.LOT CALI.LDT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -9'99.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999. 250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.CUR -999. Z 50 SP. CDR HTEN.COR -999.250 DEPT. 8900.000 SFLU.DIL 5P.DIL -51.031 GR.OIL 'TTI.3HC 689.000 TTZ.BHC GR.SHC ~3.375 SP.~HC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.OTE CIDP.D'TE -999,250 CIMP.DTE IIRM. DTE -9 99 o2 50 SGR. OTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF.SOT COHC.SOT -999.250 COHS.SDT TTZ.SDT -999.250 TT3.SOT LTTZ.SD'! -999.Z50 LTT3.SOT 24-~PR-1989 18:07 -999. 250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA,CNL -999.250 -999.Z50 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN. EPT -999.250 -999.250 SGR.CrJR --999.250 10.592 ILM.DIL 3.919 44.938 TENS.OIL 5504.000 423.000 TT3.BHC 580.500 -57.Z81 TENS.BHC 5504.000 -999. 250 ILM.OTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 DT. SOT -999. 250 -999.250 DTCO.SDT -999.250 -999.250 COST.SOT -999.250 -999. 250 TT4.SDT -999.250 -999.250 LTT~.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999. 250 -999.Z50 SS2.LOT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 'TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT --999.250 -999.250 CALI.EPT -999.250 -9'99.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 3.550 ILM.DIL 1.896 43.375 TENS.OIL 5512.000 477.500 TT3.BHC 684.000 -51.031 TENS.BHC 5512.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999. Z50 TENS.OTE -999.250 -999.Z50 DT.SDT -999.250 -999.250 OTCOoSDT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4.SDT -999.250 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EP'T TENS.EPT IOPH.COR TENSoCOR ILO.OIL DT.BHC TT6.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WENG.NGT DPHi.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.CDR ILO.OIL DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.OTE IIXO.DTE MTEM.DTE DTL.SDT OTSM.SDT TT1.SDT LTT1.SDT SGR.SDT PAGE: 33 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 3.734 82.1~8 425.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9V9.250 -999.250 -999.Z50 -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 1.658 100.438 ~80.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -:999.250 -999.250 -999.250 -999.250 ,iS TAPE VERIFICATION LISTING ;LHLUMBERGER ALASKA COMPUTING CENTER TENS.SUT -999. 250 HTEN. SOT THOR. NGT -999. 250 POTA. NtT WZNG. NGT -999.250 W3 NG. NGT IENS.NGT -999. 250 CS.NGT RHOB.LDT -999. 250 ORHO.LOT qSS.LDT -999. 250 LS.LOT LITH.LDT -999.Z50 SSI.LOT $ SHV.LDT -999. ZSO S1RH. LOT CALI.LOT -999. Z 50 GR.LOT MRES.LDT -999. Z 50 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999. ZSO TNPH.ENL NPOR.CNL -999. 250 RCNT. CNL CFTC.ENL -999.250 GR.CNL GR. EPT -999.2 50 SA.EPT MTEM.EPT -999.250 ~RES.EPT IMPH.COR -999. 250 HTEN.COR -999.250 DEPT. 8800.000 SFLU.DIL SP.DIL -48. 781 GR.DIL TT1.BHC 666.500 TT2.BHC GR.BHC 44.250 SP.BHC TENS.CML -999.2 50 SFLU.BTE 5P. DTE .-999. 250 IDPH.DTE CIOP.DTE -999.250 CIMP.DTE I IRM. DTE -999.250 SGR. DTE MRES. DTE -999.2 50 HTEN.DTE DTLN.SDT -999.250 OTLF.SOT COHC.SDT -999.250 COHS.SOT TTZ. SOT -999. 250 TT3. SOT LTTZ.SDT -999.25'0 L'TT3.SDT TENS.SOT -999.250 HTEN.SOT 'THOR.NGT -999.250 POTA.NGT WZNG.NGT -999. 250 W3NG.NGT '! ENS.NG'T -999. Z 50 CS' NGT RHO,~.LOT -999. 250 DRHO.LDT QSS.LOT -999. 250 LS.LOT LITH. LOT -999.250 S S1.LOT SSHV.LOT -999.2 50 SIRH.LDT {;ALI.LOT -999. Z50 GR.LDT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999. Z 50 TNPH.CNL NPOR.CNL -999.Z50 R'CNT.CNL CFTC.CNL -999.250 GR.CNL GR. I:PT -999.2 50 SA. EPT MTEMoEPT -999.250 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN. CDR -999.2 50 :DEPT. 8700.000 ~SFLU.DIL SP.OIL -Z5.500 GR.DIL TI1.BHC 724.000 TTZ.BHC GR.BHC 75.500 SP.§HC 24-APR-1989 lB:07 -999.250 SGR.NGT -999.250 URAN. NGT -999.250 W4NG.NGT -999.250 HTEN. NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LDT -999.250 LSRH.LOT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999. 250 TNRA.CNL -999.250 RCFT.CNL -999. Z50 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 3.227 ILM.DIL 44.250 TENS.OIL 476. 750 TT3.BHC -48.781 TENS.BHC -999.250 ILM.DTE -999. 250 IMPH.DTE -999.250 IIRD.DTE -999.Z50 TENS.DTE -999.250 DT.SDT -999.250 DTCO. SOT -999.250 COST.SOT -999. Z50 TT4.SDT -999. Z50 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999. 250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999. 250 LU.LDT - 999.. 250 SS2.LOT -999. Z50 LSRH.LOT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999. 250 'TNRA. CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999. Z50 CALI.EPT -999.250 HTEN. EPT -999.250 SGR.COR 3.544 ILM.DIL 75.500 TENS.OIL 527.000 TT3.BHC -25.500 TENS.§HC -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 Z.326 5364.000 667.000 5364.000 -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.~50 -999.250 -999.250 -999.250 -999. ~750 -'999.250 3.,635 5368.000 730.000 5368.000 CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL R'TNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL OT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.SDT DTSM.SDT TTI.SDT LTT1.SDT SGR. SDT CGR.NGT W[NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTCoCNL FVR.EPT TEN$.EPT IDPH.COR TENS.COR ILD.DIL DT.BHC TT:~.BHC GR.CHL PASE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.104 98.938 480.000 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'9'9.250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.818 96.875 5Z0.500 -999.Z50 34 .IS TAPE VERIPICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER TENS.CHL -999.250 SFLU.DTE SP. gTE -999. 250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. DTE -999. Z50 SGR. gTE MRES. DTE -999. 250 HTEN. gTE DTLN. SDT -999.2 50 DTLF.SOT COHC.SDT -999.Z50 COHS.SDT TT2. SDT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SDT -999.250 HTEN.SOT THOR. NGT -999. Z 50 POTA. NGT WZNG.NGT -999. 250 W3NG. Nr~T TENS.NGT -999.250 CS.NGT RHOB.LDT -999.Z50 ORHO.LDT qSS.LDT -999. 250 LS.LDT LITH.LDT -999.2.50 SSI.LDT SSHV.LDT -999.250 SIRH.LOT CALl. LOT -999. 250 GR.LOT MRES.LDT -999. 250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPH[.CNL -999.250 TNPH.CNL NPOR.CNL -999'250 RCNT-CNL CFTC.CNL -999. Z50 GR.CNL GR. EPT -999. 250 .SA. EPT MTEM.EPT -999.250 MRES.EPT I MPH.COR -999. 250 SP. COR HTEN.COR -999.250 DEPT. 8600.000 SFLU.DIL SP.DIL -B3.313 GR.DIL TT1. OMC 673. 500 TT2.BHC GR.BHC 49.969 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM.DTE -999.250 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SOT COHC. SDT -999.250 COHS.SOT TTZ. SDT -999.Z50 TT3.SDT LTTZ.SDT -999.Z50 LTT3.SDT TENS.SDT -999.250 HTEN.SgT THOR,.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999. 250 CS. NGT RHOB.LD'T -999.250 gRHO.LOT QS$.LOT -999. Z50 LS.LOT LITH.LDT -999. 250 SSI.LOT SSHV.LDT -999.250 S1RH.LOT CALi. LDT -999. Z50 GR.LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999o250 CNEC.CNL NPHI.CNL -999. 250 TNPH.CNL NPOR. CNL -999.250 RCNT.CNL CFTC.CNL -999.Z 50 GR.CNL 24-aPR-1989 18:07 -999.250 ILM.DTE -999. -999. 250 IMPH.DTE -999. -999.250 IIRD.DTE -999. -999.250 TENS.gTE -999. -999. 250 DT. SDT -999. -999.250 gTCO.SOT -999. -999.250 COST.SOT -999. -999.250 TT4.SDT -999. -999.Z50 LTT4.SDT -999. -999. 250 SGR.NGT -999. -999.250 URAN.NGT -999. -999.250 W4NG. NGT -999. -999.Z50 HTEN.NGT -999. -999.250 PEF.LOT -999. -999.250 LU.LOT -999. -999.250 SS2.LDT -999. -999.250 LSRH.LDT -999. -999.250 TENS.LOT -999. -999.250 ENPH.CNL -999. -999.250 RCEF.CNL -999. -999.250 TNRA.CNL -999. -999.250 RCFT.CNL -999. -999.250 NVR.EPT -999. -999.250 CALI.EPT -999. -999.250 HTEN.EPT -999. -999.250 SGR.COR -999. 3.'?04 ILM.DIL 49. 969 TENS. OIL ~76.750 TT3.BHC -83..313 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.OTE -999.250 IIRD.DTE -999.250 TENS.gTE -999.250 DT. SOT -999.250 gTCO. SOT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999. 250 LU.LDT -999.250 SS2.LOT -999. 250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999. 250 RCEF.CNL -999.Z50 TNRA.CNL -999. 250 RCFT.CNL -999.250 NVR.EPT . 5328. 680. 5328. -999. -999. -999. -999. -999. -999- -999. -999. -999. -999. -999. -999. -999 o -999. -999. -999. --999. -999. -999. -999. -999. -999. -999. 25O 250 250 25O 25O 25O 25O 250 250 250 250 25O 75O 25O 25O 25O 25O 25O 75O 250 250 25O 25O 25O 25O 25O 242 000 50O 000 25O 25O 250 250 250 250 250 25O 25O 250 25O 25O 250 250 25O 250 25O 250 250 250 250 ILD.DTE IFRE. DTE IIXO.OTE MTEM.OTE OTL.SDT DTSM. SOT TT1..SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL .LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL R C EN. C NL RTNR.~NL CNTC.CNL FVR.EPT TENS.EPT IgPH.COR TENS.COR ILO.git DT.BHC TT4.BHC GR.CHL ILO.gTE IFRE.OTE IIXO.OTE MTEM.OTE DTL.SDT DTSM. SOT TT1.SDT LTT1.SDT SGR.SDT CGR. NGT W1NG.NGT WSNG.NGT DPHI.LDT QL S. LDT LL.L~T LSHV .LOT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR .CNL CNTC.CNL FVR. EPT PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2.50 -999. Z50 -999.250 -999.2:50 -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 Z.O01 100.000 484.000 -999.250 -999.250 -999.250 -999.25'0 -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 -999.2S0 -999.250 -999.Z~0 -999.250 35 -IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 TENS.SPT MTEM.EPT -999.250 ~RES.EPT -999.250 HTEN.EPT -999.250 IDPH.COR IMPH.COR -999.250 SP.COR -999.250 SGR.COR -999.250 TENS COR HTEN.COR -999.250 DEPT. 8500.000 SFLU.DIL SP.DIL -81.438 GR.DIL TT1.BHC 675.000 TT2.BHC GR.BHC ~1o906 SP.BHC IENS.CNL -999.250 SFLU.DTE SP.OTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.DTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN'DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ.SDT -999.250 TT3.SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHO~.LDT -999.250 DRHO.LDT QSS.LOT -999. 250 LS.LDT LITH.LDT -999. 250 $ S1. LOT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999.250 GR.LDT MR E S. LDT -999 . Z 50 HT EN. LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 8400.000 SFLU.DIL SP.DII -19.281 GR.DIL [T1.BHC 669.500 TT2.BMC GR.BHC 60.813 SPoBHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM. UTE -999. Z 50 SGR.gTE MRES.DTE -999.250 HTEN.D'TE DTLN.SDT -999.250 OTLF.SDT COHC.SDT -999.250 COHS.SOT TTZ.SDT -999.250 TT3.SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOB.LDT -999.250 DRHO.LOT 3.688 ILM.DIL 1.556 41.906 TENS.OIL 5268.000 ¢88.000 TT3.BHC 683.000 -81.~38 TENS.BHC 5268.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999.2.50 DT.SDT -999. 250 -999.250 OTCO.SOT --999.250 -999.250 COST.SOT -999.250 -999.250 TT~. SOT -999.250 -999.2.50 LTT~. SDT -999. 250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT --999.250 -9'99.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -99'9.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999. 250 RCEF.CNL -'999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CN'L -999.250 -999. 250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 2.861 ILM.DIL 2-467 60.813 TENS.OIL 5488.000 ~64.2'50 TT3.BMC 667.500 -19.281 TENS.BHC 5488.000 -999.250 ILM. D'TE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -99'9.250 -999.250 'TENS.DTE -999.250 -999.250 OT. SOT -999. 250 -999.250 DTCO. SDT -999.250 -999.250 COST.SOT -999.250 -999.250 TT&.SDT -999.250 -999.250 LTT4.$DT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NST -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.DTE IFRE.OTE IIXD.DTE MTEM.DTE DTL.SOT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WENG.NGT DPHI.LDT QLS.LDT LLoLDT LSHV.LDT LURH.LDT ~TE~.LDT ENRA.CNL RCEN.CNL RTNRoCNL CNTC.CNL FVR.EPT TENS.EP'T IDPH.COR TENS.COR ILO.OIL D'T.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXO.DTE MTEM.DTE OTL.SDT' DTSM. SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WENG.NGT DPHI.LDT QL$oLDT PAGE: 36 -999.250 -999.250 -999.250 1.356 101.438 491.500 -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 Z.339 82.500 457.500 -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 .iS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 QSE.LDT -999.250 LS.LDT -999.250 LU.LDT -999.250 LITH.LDT -999.250 SSI.LOT -999.250 SS2.LOT -999.250 SSHV.LDT -999.250 SIRH.LDT -999.250 LSRH.LOT -999.250 CALI.LDT -999.250 OR.LOT -999.250 TENS.LDT -999.250 MRES.LDT -999.250 HTEN.LOT -999.250 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999. Z50 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999.250 SGR.COR -999 250 HTEN.COR -999.250 OEPT. 8300.000 SFLU.DIL 2.286 ILM.DIL 1.871 SP.DIL -47.813 GR.DIL 44.313 TENS.DIL 5324.000 TTI.BHC 771.500 TT2.BHC 547.000 TT3.BHC 772.000 GR.BHC 44.313 SP.BHC -47.813 TENS.BHC 5324.000 TENS.CHL -999.250 SFLU.DTE -999.250 ILM.OTE -999.250 5P.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 CIDPoDTE -999.250 CIMP.DTE -999.250 IIRO.DTE -999.250 __IIRM+DT'E -qqQ,9=~'n SC~"DTE ~99.25G TENS.gTE -999.250 MRES.D~E -~~ HTEN.DTE -999.250 DT.SDT -999.250 DTLN.SDT -999.250 OTLF.SOT -999.250 gTCO.SOT -999.250 COHC.SDT -999.250 COHS.SDT -999.250 COST.SOT -999.250 TTZ.SDT -999.250 TT3.SDT -999.Z50 TT4.SDT -999.250 LTTZ.SDT -999.250 LTT3. SOT -999.250 LTT4oSDT -999.250 TENS.SOT -999.250 H~EN.SOT -999.250 5GR.NGT -999.250 TH~R.NGT -999.250 POTA.NGT -999.250 URAN. NGT -999.250 WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.250 TENS.NOT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 RHOB.LDT -999.250 DRHO.LOT -999.250 PEF.LDT -999°250 QSS.LDT -999.250 LS.LOT -999.250 LU.LDT -999.250 LITH.LDT -999.250 SS1.LOT -999.250 SS2.LOT -'999.250 5SHV.LDT -999.250 SiRHoLDT -999.250 LSRH.LDT -999.250 C.~LI.LDT -999.250 GR.LOT -999.250 TENS.LOT -999..250 MRES.LDT -999.250 HTEN.LOT -999.250 ENPH.CNL -999.250 CFE~.SNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999..250 NPHI.CNL -999.250 TNPH.CNL -999'250 TNR~.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.Z50 CALIoEPT -999.250 MTEMoEPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999.250 SGR COR -999 250 HTEN.COR -999.250 ' ' DEP~'. 8200.000 SFLU.DIL 2.696 ILM.DIL 3.216 SP.DIL 5.230 GR.DIL 62.469 TENS.OIL 5280.000 TT1.BHC 705.000 TTZ.BHC '483.500 TT3.BHC 704.000 :GR.BHC 6Z.469 SP.BHC 5.230 TENS.BHC 5280.000 TENS.CHL -999.250 SFLU.D'TE -999.250 ILM.DTE -999.250 SP.DTE -999.250 IDPH.DTE -999.250 IMPHoDTE -999.250 EIDP.DIE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DTE -999.250 SGR.OTE -999.25,0 TENS.gTE -999.250 MRES'DTE -999.250 HTEN.DTE -999.~50 OT.SDT -999.250 LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL ~VR.EPT TENS.EPT IOPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.gTE IFRE.DTE IIXO.OTE MTEM.DTE OTL.SDT DTS~.SOT TTlo SOT LTT[.SDT SG~. SDT CGR.NGT WING.NGT WENE.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT TENS.COR ILO. OIL DT. TT4.BHC GR.CHL ILD.DTE IFRE.OTE IIXD.DTE MTEM.OTE DTL.SDT PAGE: -9V9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.683 125.125 545.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -999..Z50 -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 -9~9.250 3.370 95.625 492.250 -999.250 -999.250 -999.250 -999.250 -999.250 37 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASK:~ COMPUTING CENTER DTLN.SDT -999.250 DTLF.SOT COHC. SOT -999. 250 CUHS. SOT TTZ. SOT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SOT TENS. SOT -999. Z 50 HTEN. SOT THOR.NGT -999.Z50 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999. 250 CS. NGT RHUB.LDT -999.250 DRHU.LDT DSS.LOT -999.250 LS.LOT LITH.LDT -999. 250 SS1.LOT SSHV. LDT -999.2 50 S1RH.LDT CALI.LDT -999.Z50 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHJ~. CNL -999. Z 50 TNPH.CNL NPDR.CNL -9 99.2 50 RCNY.CNL CFTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SA.EPT MTEM. EPT -999.2 50 MR ES. EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 8100.000 SFLU.DIL SP. OIL 0.487 GR.DIL TTI.BHC 7 26. 500 TT2.BHC GR.BHC 52.094 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.OTE -999.250 IDPHoDTE CIDP.DTE -999.250 CIMP.DTE IIRM.OTE -999. Z50 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN. SDT -999.250 DTLF.SOT COHC.SDT -999.250 COHSoSOT TTZ. SOT -999. 250 TT3. SOT L'TTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT W2NG'NGT -999.250 W3NG.NGT TENS.NGT -999. 250 CSoNGT RHO§.LDT -999.250 gRHO.LOT DSS.LOT -999. 250 LS.LOT LITH.LOT -999. 250 SS1.LOT SSHV.LDT -999.250 S1RH.LOT CALL.LOT -999.250 GR. LOT MRESoLDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHf..CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. Z50 GR.CNL GR.EPT -999.250 SA.EPT MTEM. EPT -999.250 MRESoEPT IMPH.COR -999. 250 SP.COR HTEN.CUR -999.250 24-APR-lOB9 18:07 -999. 250 OTCO.SDT -999.250 -999.250 COST.SOT -99).250 -999. 250 TT4.SOT -999.250 -999.250 LTT4.SDT -999.2.50 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999. 250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SSZ.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.EDT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999. 250 SGR.COR -999.250 2.674 ILM.DIL Z.832 52. 094 TENS.DIL 5360.000 511.000 TT3.BHC 725.500 0.487 TENS.BHC 5360.000 -999.250 ILM.OTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IlRD.DTE -999.2.50 -999.250 TENS.DTE -999.2.50 -999.2.50 DT. SOT -999. 250 -999.250 DTCO.SOT -999.250 -999.250 COST. SDT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4. SOT -999.250 -999. 250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.2.50 W4NG.NGT -999.250 -999.Z50 HTEN.NGT -999.2.50 -999.250 PEF.LOT -999.250 -999. 250 LU' LOT -999.250 -999.250 SS2.LOT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999. ZEO SGR.COR --999.250 DTSM.SDT TT1.SDT LTT1.SDT SGR. SOT CGR.NGT W1NG .NGT WSNG.NGT DPH[.LDT QLS.LDT LL.LDT LSHV.LOT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILD.DIL OT.BHC TT~.BHC GR.CHL ILO.DTE IFRE.OTE IIXD.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT EL.LOT LSHV.LDT LURH.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR PAGE: -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 -9~9.250 -999.250 -999.250 -999.250 -999.250 2.8:10 110.563 51~.000 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -999.250 -999.250 -999.250 -999.250 -999.250 ,-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2~0 -999.250 --999.250 38 TAPE VERIPICATION LISTING S£HLUMBERGER ALASKA COMPUTING CENTER DEPT. 8000.000 SFLU.DIL SP.DIL -0.7¢5 GR.DIL TI1.8NC 651. 000 TTZ.BHC GR.BHC $4.125 SP.BHC TENS.CHL -999.250 SFLU.DTE SP. DTE -999. 250 IDPH. DTE CIDP.DTE -999.250 CIMP.DTE IIRM. OTE -999. 250 SGR.gTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ. SOT -999. ZSO TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SDT -999.250 HTEN.SDT THOR.NGT -999.2 50 POTA.NGT WZNG.NGT -999.250 W3NG.NGT T ENS.NGT -999. 250 CS. NGT RHOt$.LDT -999.250 ORHO.LOT QSS.LDT -999.Z 50 LS.LDT LITH.LOT -999.250 SS1.LDT SSHV.LDT -999. 250 Sl RM.LOT CALI.LDT -999.2 50 GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC..CNL -999.250 CNEC.CNL NPHI.CNL -999. 250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR. EPT -999. 250 SA. EPT MTEM. EPT -999.250 MRES.EPT IMPH.COR -999.2 50 SP.COR HTEN. CUR -999.2 50 DEPT. 7900. OOO SFLU. DIE SP.OIL -1.675 GR.DIL TT1. BHC 754. 500 T'T2. BHC GR.BHC 70.500 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.DTE -999o Z 50 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF. SOT COHC.SOT -999.250 CDHS.SOT TTZ. 5DT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SOT TENS.SDT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT '-999. Z 50 CS. NGT RHOB.LOT -999.250 ORHO.LDT ~SS.LDT -999.2 50 LS..LOT LITH.LDT -999. 250 SS1.LDT SSHV.LOT -999. ZSO S! RH. LDT CALI.LDT -999. 250 GR. LD'T Z4-~PR-1989 18:07 2.896 ILM.OIL 3.205 64.125 TENS.DIL 5024.000 ~88.750 TT3.BHC 670.000 -0.745 TENS.BMC 5024.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRO.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 DT. SOT -999. 250 -999.250 OTCO.SDT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4.SDT -999.250 -999.Z50 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999. Z50 LO.LOT -999. 250 -999.250 SSZ.LOT -999.250 -999.250 LSRH. LDT -999.250 -999o250 TENS.LDT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 2.558 ILM.DIL 70.500 TENS.OIL 541.500 TT3oBHC -1.675 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999-250 TENS.DTE - 999. 250 OT. SOT -999.250 OTCO. SDT -999. Z50 COST.SOT -999.Z50 TT4.SOT -999.250 LTT4.SOT -999.250 SGR.NGT -999.250 UR~N.NGT -999.250 W4NG. NG'T -999.250 H'TEN.NGT -999.250 PEF.EOT -999.Z50 LU.LOT -999.250 SS2.LOT -999.250 LSRH.LDT -999.250 TENS.EDT 3.368 4912.000 754.000 4912.000 -999.250 -999.250 -99 9. 250 -999.250 -999.250 -999.250 -99 9. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 -999. 250 -999.250 ILD.DIL OT.BHC TT4.BHC GR.CHL ILO.DTE IFRE.DTE IIXO.DTE MTEM.DTE OTL.SDT DTSM.SDT TT1.SD'T LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LOT QLS. EDT EL.LOT ESPY.LOT LURH.LOT M'TE M. LOT ENRA. CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL OT.BHC TT4.BHC GR.CHL ILO.DTE ImRE.DTE IIXD.OTE MTEM.OTE OTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT EL.EDT LSHV.LDT LURH.LDT MTEM.LDT PAGE: 2.989 90.250 508.000 -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 -9'99.250 -999.250 3.606 109.500 539.000 -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 39 LIS TAPE VERIFICATION LISTING SCHLUMBERGER aLaSKA COMPUTING CENTER TENS.SUT -999. 250 HTEN. SOT THOR. NOT -999.250 POTA. NGT WZNG. NGT -999.2 50 W3 NG. NOT ! ENS. NOT -999. 250 CS. NOT RHOB.LUT -999.250 ORHO.LDT qSS.LDT -999. 250 LS. LOT L [TH. LOT -999. Z 50 S S1. LDT SSHV.LOT -999. 250 S1RH.LDT CALI.LDT -999.250 GR. LOT MRES.LDT -999. 250 MTEN.LDT CFEC.CNL -999. Z 50 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999. 250 RCNT.CNL CFTC.CNL -999. 250 SR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999. 250 MR ES. EPT IMPH. COR -999.250 SP. COR HTEN.COR -999.250 DEPT. 7600.000 SFLU.OIL SP.DIL -32.750 GR.DIL TT1.BI-IC 780. 000 T'T2. BHC GR.BHC 53.3~4 SP.BHC TENS.CML -999.2 50 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999. 250 CIMP.DTE I IRM. OTE -9 99. 250 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF.SOT COHC.SDT -999,,250 COHS.SDT TTZ. SOT -9 99. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SgT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT T ENS.NGT -999. Z 50 CS.NGT RHO8.LDT -999.250 ORHO.LDT QSS.LDT -999. 250 LS.LOT LITH. LOT -999. 250 S S1 .LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999. 250 GR.LOT MRES.LDT -999. 250 HTEN.LOT CPEC.CNL -999.250 CNEC.CNL NPHI.CNL -999. ZSO TNPH.CN:L NPOR.CNL -999. 250 RCNT.CNL CFTC.CNL -999. 250 gR.CNL GR. ~PT -99'9.2 50 S~,. EPT MTEM.EPT -999-;~50 MRES.EPT IMPH.CUR -999. 250 SP.COR HTEN.CUR -999.250 DEPT. 7500.000 SFLU.DIL SP.DIL -4.754 GR.DIL TTi. BHC 634.000 TTZ.BHC GRoBHC 59.156 SP.BHC 24- ~PR-1989 18:07 -999. Z50 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999. 250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999. 250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NYR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 MTEN.EPT -999.250 -999.250 SGR.COR -999.250 3.27B ILM.DIL 2.321 53.344 TENS. DIL 4720.000 540.000 TT3.BHC 7B3.500 -32.750 TENS.BHC 4720.000 -999. 250 ILM.DTE -999. 250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. Z50 OT.SDT '-999.250 -999.250 OTCO.SOT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LT'T4.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999.250 LUoLDT -999.250 -999.250 SSZ.LDT -999.250 -999.250 LSRH.LOT -999.250 -999.250 'TENS.LOT '-999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 ,-999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 3.350 ILM.DIL 2.579 59.156 TENS.DIL 4744.000 407.000 TT3.BHC 632.000 -4.75~ TENS.BHC 4744.000 CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.OTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SOT SGR.SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSMV.LDT LURH.LOT MTEM.LDT ENR~oCNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.~PT IDPH.COR TENS.COR ILD.DIL DT.BHC TT4.BHC GR.CHL -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 2.209 lZl.500 540.000 -999.250 -999-250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -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 Z.326 66.1BB -999.250 .IS TAPE VERIPICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER TENS.CHL -999.250 SFLU.OTE SP.DTE -999.250 IDPHoDTE £IDP.DTE -999.250 CIMP.DTE IRM.OTE -999. 250 SGR. DTE MRES.DTE -999.250 HTEN.OTE DTLN. SDT -9 99.2 50 DTLF. SOT COHC.SOT -999.250 COHS.SDT TT2. SOT -999. Z 50 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT ENS. SOT -999. Z 50 HT EN. SOT THUR. NGT -999. Z 50 POTA. NGT W2NG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT HOB. LOT -9 99.2 50 DR HO.LOT QSS.LOT -999. 250 LS. LOT LITH. LOT -999. 250 S SI.LOT SSHV.LDT -999.250 SIRH.LDT ALI.LOT -999. 250 GR. LOT MRES.LDT -999.2 50 HTEN.LOT CFEC.CNL -999. 250 CNEC.CNL NPHI.CNL -999.250 TNPH.CN:L NPOR.CNL -999'250 RCNT'CNL FTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EP[ -999.250 MRES.EPT MPH.COR -999.2 50 SP. COR HTEN.COR -999.250 DEPT. '7'400.000 SFLU.DIL SP.DIL --23.750 GR.DIL TT1. BHC 781. 000 TT2.8HC GR.BHC 52.094 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. DTE -999. Z 50 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999°250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ. SOT -999° 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TEN~.~DT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.N:GT -999.250 W3NG.NGT TENS. NGT -999. Z 50 CS. NGT RHOB.LDT -999.250 DRHO.LDT QSP.LOT -999o Z 50 LS.LOT LITH.LDT -999. 250 SS1.LOT SSHV.LDT -999.250 SIRH.LDT CALI. LOT -999.250 GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -9'99o Z 50 GE.CNL 24-APR-IgB9 18:07 -999.250 ILM.DTE -999. 250 IMPH.DTE -999.250 IIRD.DTE -999.250 TENS.DTE -999.250 DT.SDT -999. 250 DTCO.SDT -999.250 COST.SOT -399.250 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LOT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL - 999' 250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR -999.250 -999.250 -999.250 -999.250 -999.250 -999.25D -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 3.046 ILM. DIL 2.237 52.094 TENS.OIL 4704.000 543.000 TT3.BHC 780.500 -23. ?50 TENS. BHC 4704.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.D'TE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 OT. SOT -999. 250 -999.250 DTCO.SDT --999.250 -999.250 COST.SOT -999.250 -99'9. 250 TT4. SOT -999..250 -999.250 LTT4.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -99'9.250 W~NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999. 250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.,250 RCFT.CNL -999.250 -999. 250 NVR.EPT -999.250 ILD.DTE IFRE.OTE IIXD.OTE MTEM.OTE 9TL.SDT DTSM. SOT TT1.SDT LTT1. SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI .LDT QLS.LDT LL .LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA .CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENSoCOR ILO.OIL DT.BHC 'TT~.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEMoDTE DTL.SDT DTSM.SDT TT1.SOT LTTI.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT PAGE: -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 Z.077 124.250 544.000 -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 .IS TAPE YtRIFIC.~TION LISTING SCHLUMBtRGER aLASKA COMPUTING CENTER GR.EPT -999.250 SA.EDT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.CDR HTEN.COR -999.250 DEPT. 7300.000 SFLU.OIL SP.DIL -14.500 GR.DIL lTl. BHC 760.000 TT2.BHC GR.BNC 58.250 SP.BHC T ENS.CHL -999. Z 50 SFLU. gTE SP. DTE -999.250 IDPH. DTE CIDP.DTE -999.250 CIMP.DTE ! IRM.DTE -999.2 50 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SOT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ.SDT -999· Z50 TT3. SOT LTTZ.SDT -ggg.zEO LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR. NGT -999.250 POTA. NGT W2NG.NGT -999.Z50 W3NG.NGT TENS.NGT -999. 250 CSoNGT RHO§.LDT -999.250 ORHO.LDT USS. LOT -999. 250 LS.LOT LITH.LDT -999. 250 SS1.LOT SSHV.LDT -999. 250 SIRH.LDT CALI. LOT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. Z 50 GR. CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH. COR -999.2 50 SP.COR HTEN.COR -999. Z 50 DEPT. 7200.000 SFLU.DIL SP.DIL -28.750 GR.DIL TT1.BHC 768.500 TT2.BHC GR.SHC 58.~06 SP.BHC 1ENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. DTE -999.Z 50 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT 'TTZ.SDT -999.250 TT3.SOT LTTZ.SOT -999.250 LTT3.SDT TENS.SDT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOB.LDT -999.250 ORHO.LDT 2Z~- ~PR-1989 lB:07 -ggg.zEo CALI.EPT -999.250 -999.250 HTEN. EPT -999.250 -999. ZSO SGR. COR -999. 250 6.195 ILM.DIL 58.250 TENS.OIL 530.500 TT3.BHC -14.500 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999. Z50 IIRD.DTE -999. Z50 TENS.DTE -999.250 DT.SDT -999.250 OTCO.SDT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999. Z50 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SSZ.LOT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 6.865 4548.000 764.000 4548.000 -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 -999.230 -999.250 -999.250 -999.250 -999.250 -999. 250 2-515 ILM.DIL 2-568 58'406 TENS.DIL 4472.000 5:35.000 TT3-BHC 767.000 -28.750 TENS.BHC 4472.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 OT. SDT -999.250 -999. Z50 DTCO. SOT -999.250 -999. Z50 COST.SOT -999.Z50 -999. 250 TT4'SDT -999.250 -999. 250 LTT4. SOT -999.250 -999.250 SGR.NGT -999-250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 TENS.EPT IOPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.OTE IFRE.OTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TTI.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL DT.BHC TT~. BHC GR.CHL ILO.OTE I FRE. DT E IIXO.DTE MTEM.DTE DTL.SDT DTSMoSDT TTI.SDT LTT1.SOT SGR.SDT CGR.NGT WING.NGT WENG.NGT OPHI.LDT QLS.LDT PAGE: -999.250 -999.250 -999.250 9.012 108.000 527.000 -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 -999.2S0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.446 115.625 535.000 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999-25:0 -999.250 -999.250 -999.250 ~3 .IS TAPE VERIFICATION LISTING iCMLUMBERGER ALASKR COMPUTING CENTER qSS.LOT -999.2 50 LS. LOT LIIM.LDT -999.250 SSI. LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999.250 GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR . CNL -999 . Z 50 RCNT . CNL CFTC. CNL -999. Z 50 GR.CNL GR. EPT -999. ZSO SA. EPT M'TEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP. CDR HTEN.COR -999.250 DEPT. 7100.000 SFLU.DIL SP.DIL -33. 500 GR. DIL TT1. BHC 786. 000 TT2.8HC GR.BHC 70.063 SP.BHC TENS.CHL -999.250 SFLU. gTE SP. gTE -999. 250 IDPH. OTE CIDP.DTE -999.250 CIMP.DTE IIRM.OTE -999.250 SGR.DTE MRES. UTE -999.2 50 HTEN. gTE DTLN.SDT -999.250 DTLF.SOT COHC.SDT -999.250 COHS.SgT TTZ. SOT -999. 250 TT3. SDT LTTZ.SDT -999.Z50 LTT3.SDT TENS.SOT -999.250 HT'EN. SOT THOR.NOT -999.250 POTA.NGT WZNG.NG'[ -999.250 W3NG.NGT TENS.NGT -999.250 CS. NOT RHOB.LDT -999.250 DRHD.LDT CISS.LDT -999.250 LS. LOT LITH.LDT -999.250 SS1. LOT SSHV.LDT -999.250 SIRH.LOT CALI.LOT -999. Z 50 GR. LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.Z~0 RCNT.CNL CFTC.CNL -999.250 ' GR.CNL GR. ~PT -999.2 50 SA. EPT M'TEM. EPT -999.250 MR'ES.EPT [MPH.CfJR -999. 250 SP.COR HTEN. COR -999.250 DEPT,. 7000.000 SFLU.DIL SP. UIL -64.7 50 GR. DIL TT1. BHC 774. 500 TTZ. BHC GRoBHC ,¢9.031 SP.BHC TENS.CML -999.250 SFLU.DTE SP. DT,~ -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM. gTE ,-999. Z 50 SGR. gTE MRES.DTE -999.250 HTEN.DTE 24-~PR-1989 18:07 -999. 250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999. 250 TENS.LDT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999. 250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999. Z50 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 3.213 ILM.DIL 3.327 70.063 TENS.OIL &34~.000 56!. 000 TT3. BHC 792. 500 -33.500 TENS.BHC -999.250 ILM-OTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.OTE -999.250 - 999. 250 DT.SOT -999. 250 -999.250 gTCO. SOT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4. GDT -999.250 -999.250 SGR.NGT -999.250 -999.250 UR~N.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -99=9.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LOT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999. 250 NVR. EPT -999. 250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 3. Z67 I'LM.DIL 1,924 49,031 'TENS.DIL 4540.000 535.000 TT3.BHC 776.000 -64.750 TENS.BHC ~540o000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.gTE -999.2.50 -999.250 DT. SOT -999. 250 LL.LDT LSHVoLDT LURH.LDT MTEM.LDT ENRA.CNL RCEN .CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILD.DIL DT.BHC TT4.9HC GR.CHL IL O. OTE IFRE.DTE IIXO.OTE ~TE~.OT~ DTL.SDT DTSM.SDT TT1.SDT LTT1. SOT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS .LOT LL .LOT LSHV.LDT LURH.LDT MTEM.LDT ENR~,.CNL RCEN.CNL RTNR.CNL CNTC..CNL FVR.EPT TENS.EPT IOPH.COR TENS.CO~ ILO.OIL DT.BHC TT~.SHC GR.CHL ILD.OTE IFRE.OTE IIXD.OTE MTEM.~TE DTL.SOT PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.682 108.250 566.500 -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 1.685 120.375 538.000 -999.250 -.999.250 -999.250 -999.250 -999.250 -999.250 ,IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER DTLN. SDT -999. Z 50 DTLF. SOT CDHC.SDT -999.Z50 COHS.SOT TTZ.SDT -999.250 TT3 . SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THUR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NGT -999.2 50 CS.NGT RHOB.LDT -999. 750 DR HO.LOT QSS.LOT -999. ZSO LS.LDT LITH.LOT -999.250 SS1.LOT SSHV.LDT -999. Z 50 S1 RH.LOT CALI.LOT -999.Z 50 GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999. Z50 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR. EPT -999. 250 SA. EPT MTEM. EPT -999.250 MRES.EPT !MPH.COR -999. 250 SP.COR HTEN.COR -999. 250 DEPT. 6900.000 SFLU.DIL SP.UIL -32.250 GR.DIL TT1. BHC 766.000 TT2. BHC GR.BHC 61.688 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.DTE -999. 250 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF.SDT COHC.SDT -999.250 COHSoSOT TT 2. SOT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SOT THUR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -9 99. 250 CS.NGT RHOS.LOT -999.Z50 DRHO.LOT QSS.LOT -999. 250 LS.LOT LITH.LD'T -999. 250 SSI.LDT SSHV.LDT -999.250 StRH.LOT CALI.LD'T -999. Z50 GR.LDT MRES.LDT -999.250 HTEN.L~T CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. Z 50 GR. CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH. COR -999.2 50 SP.COR HTEN.CUR -999. Z50 24-APR-1989 18:07 -999.250 DTCO.SOT - 999. 250 CO ST. SOT -999.250 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LOT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 TENS.LDT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR -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 2.944 ILM.DIL 2.959 61.688 TENS.OIL 4228.000 522.500 TT3. Bric 767.000 -32.Z50 TENS.BHC 4228.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999..250 -9'99.250 TENS.DTE -999.2.50 -999. 250 DT. SOT -999. 250 -999.250 DTCO.SDT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4.SOT ' -999.250 -999. 250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999.250 LU.LOT --99'9.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999. 250 'TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR. EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999. 250 SGR.COR -999.250 DTSM. SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LOT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT~.~HC GR.CHL ILO.DTE IFRE.OTE IIXO.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNRoCNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR PAGE: -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 Z.705 107.1Z5 5ZZ.O00 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25:0 -999-250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999. 250 45 · IS TAPk VERIFICATION LISTING ;CHLUMBERGER ALASK~ COMPUTING CENTER DEPT. 6800.000 SFLU.DIL SP.DIL -6;'.250 GR.DIL TT1.8HC 766. 000 TT2. BHC GR. BMC 4Z. 875 SP. BHC TENS.CML -999.250 SFLU.DTE SP.OTE -999-250 IDPH.OTE CIDP.DTE -999.250 CIMP.DTE I IRM. gTE -999.250 SGR. gTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SOT TTZ. SOT -999. Z 50 TT3. SOT LTTZ.SDT -999.250 LTTD.SOT TENS.SDT -999.250 HTEN.SDT THUR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT T ENS.NGT -999. 250 CS. NGT RHOB.LDT -999.250 DRHO.LOT QSS.LDT -999.Z50 LS. LOT LIIH.LOT -999. 250 SS!.LDT SSHV.LOT -'999,. 2~0 S1RH.LDT CALl. LDT -999.2 50 GRo tOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999. 250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.Z50 GR.CNL GR. EPT -999. 250 SA. EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.2 50 SP.COR HTEN.CUR -999.250 24-APR-1989 18:07 3.497 ILM.DIL 2.146 42.875 TENS.OIL 4164.000 532. 500 TT3.BHC 766.000 -62.250 TENS.BHC 4164.000 -999.250 ILM.DTE -999.250 -999.Z50 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.OTE -999.250 -999. 250 DT. SOT -999.2 50 -999.250 gTCO.SOT -999.250 -999.250 COST.SOT --999.250 -999.750 TT4.SBT -999.250 -999.250 LTT4.SOT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LOT -999.250 -999. 250 LU.LDT -999.250 -999.Z50 SSZ.LDT -999.250 -999.250 LSRH.LDT -999.250 -999. Z50 TENS.LOT -999.250 -999. 250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 --999.Z50 HTEN.EPT --999.250 -999.250 SGR.COR -999.250 DEPT. 6700.000 SFLU.DIL 2.,~85 ILM.DIL 3.111 SP.DIL -5.000 GR. DIL 70.125 TENS.OIL 4100.000 TTI.BHC 797.000 TT2.BHC 581.500 TT3.BHC 798.5'00 GR.~HC '10.125 SP.BHC -5.000 TENS.BHC 4100.000 TENS.CML -999.250 SFLU.DTE -999.250 ILM. DTE --999.250 SP.DTE -999.250 IOPH.DTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE --999.250 IIRM.DTE -999.250 SGR.DTE -999.250 TENS.gTE --999.250 MRES.DTE -999.250 HTEN.DTE -999.250 DT.SDT -999.250 DTLN.SD'T -999.250 DTLF.SDT -999.250 gTCO.SOT -999.250 COHC.SDT -999.250 COHS.SDT -999. Z50 COST.SOT -999.250 TTZ.SDT -999.250 TT3.SOT -999.250 TT4.SOT -999.250 LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4.SOT -999.250 TENS.SOT -999.250 HTEN.SDT -999.250 SGR.NGT -999.250 THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 WZNG.NGT -999.250 W3NG.NGT -999. 250 W4NG.NGT -999.250 TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 RHOB.LDT -999.250 DRHO.LOT -999.250 PEF.LDT -999.250 [JS$.LDT -999. Z 50 LS.LOT -999. ZGO LU.LDT -999. 250 LITH.LOT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 SSHV.LDT -999o250 S1RH.LDT -999.250 LSRH.LOT -999.250 CALI.LDT -999.250 GR.LDT -999.250 TENS.LOT -999.250 ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.gTE ImRE.DTE IIXD.DTE MTEM.OTE OTL.SDT DTEM.SDT TT1.SDT LTT1.SDT SG~.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LOT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL OT.BHC TT4.BHC GR.CHL ILD.OTE IFRE.OTE IIXD.DTE M'TEM.OTE OTL.SDT DTSM.SDT TT1.SDT LTT[.SDT SG~.SDT CGR.NGT WING.NGT WENG.NGT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT PAGE: 46 1.996 116.875 554.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.~50 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 117.500 583.000 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.~50 -999.250 -999.250 -999.~50 -999.250 -999.250 -99'9.~50 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 .I5 TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER MRES.LOT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.2.50 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SAoEPT MTEM.EPT -999.250 MRES.EPT I MPH. COR -999.250 SP .COR HTEN.COR -999.250 DEPT. 6600.000 SFLU.DIL SP.DIL -21.250 GR.DIL TT1.8HC 831. 500 TTZ. BHC GR. BHC 72.313 SP.BHC TENS.CML -999.250 SFLU. DTE SP.DTE -999. 250 IDPH. DTE CIDP.DTE -999.250 CIMP.DTE I IRM. OTC -999.2 50 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.Z50 DTL.F. SOT COHC. SDT -999.250 COHS.$DT TTZ. SOT -999'250 TT3* SOT LTTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENSoNGT -999. Z50 CS. NGT RHOB.LDT -999.250 ORHO.LOT QSS.LDT -999.250 LS.LOT LITH.LOT -999.Z50 SS1.LOT 55HV.LDT -999.250 SiRH.LOT CALI.LDT -999. 250 GR. LOT MRES.LOT -999.250 HTEN.LDT CFEC.CNL -999.Z50 CNEC.CNL NPHIoCNL -999. ZSO TNPH.CNL NPDR.CNL -999.250 RCNT.CNL CFT~.CNL -999.250 GE.CNL GR. EPT -999.2 50 SA. EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 6500.000 SFLU.DIL SP.DIL -40.000 GR.DIL TTI.BHC 735. 000 TTZ. BHC GR. BHC 64. 500 SP.BHC TENS-CH~L -999.250 SFLU.DTE 5P.DTE -999°250 IDPH.D'TE CIDP.DTE -999.250 CIMP.DTE IIRM. DTE -999. Z 50 5GR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999°250 DTLF.SOT COHC.SDT -999.250 COHS.SOT TTZ. SDT -999. 250 TT3. SOT LTTZ.SDT -999.Z50 LTT3.SDT 24-~PR-1989 18:07 -999.Z50 ENPH.CNL -999.250 -999.Z50 RCEF.CNL -999.250 -999.Z50 TNRA. CNL -999.250 -999.Z50 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.Z50 SGR.COR -999.250 Z.364 ILM.DIL 72.313 TENS.OIL 593.000 TT3. BHC -21.Z50 TENS.OMC -999.Z50 ILM.DTE -999.250 IMPH.DTE -999.Z50 IIRO.OTE -999. Z50 TENS.DTE -999.Z50 DT. SDT -999.Z50 DTCO.SDT -999.Z50 COST.SDT -999.250 TT4oSDT -999.250 LTT~.SDT -999.Z50 SGR.NGT -999.Z50 URAN.NGT -999.Z50 W4NG. NGT -999.Z50 HTEN.NGT -999.Z50 PEF.LOT -999.250 LU.LDT -999.250 SS2.LOT -999.250 LSRH.LDT -999.250 TENS.LOT -999.Z50 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.Z50 NVR.EPT -999. Z50 CALI.EPT -999.Z50 HTEN. EPT -999.250 SGR.COR 3.120 401¢.000 828.000 4014.000 -999.Z50 -999.250 --999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.Z50 -999.Z50 - 999. Z50 -999.250 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 -999.,250 3.611 ILM.DIL 3.288 64.500 'TENS.DIL 3'934.000 5Z7.000 TT3.BHC 731.000 -,40.000 TENS.BHC 3934.000 -999. Z50 ILM.DTE -999.250 -999.250 IMPH.OTE -999.250 -999.250 IIRD.DTE ' -999.250 -999.250 TENS.DTE -999.250 -999. Z50 DT.SDT -999.250 -999.250 DTCO.SDT -999.250 -999. Z50 COST.SOT -999.250 -999.Z50 TT4.SDT -999.250 -999. Z50 LTT~.SDT -999.250 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILD.DIL DT.BHC TT4.BHC GR.CHL ILO.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT D'TSM.SDT TT1.SDT LTTI. SDT SGR.SDT CGR .NGT WING.NGT W5NG.NGT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TEN$.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILD.OTE IFRE.DTE IIXO.DTE MTEM.DTE DTL.SDT DTSM.SDT 'TT1.SOT LTT1.SDT SGR.SDT PAGE: -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~.430 134.125 588.500 -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.Z50 2.955 112.3'75 526.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~7 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG. NGT -999.250 W3NG.NGT TENSoNGT -999.250 CS.NGT RHOB.LDT -999.250 ORHO.LOT USS.LOT -999.Z50 LS.LOT LITH.LDT -999.250 SSI.LOT 55HV.LDT -999.250 $1RH.LDT CALI.LDT -999.250 GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 6400.000 SFLU.DIL SP-OIL -23.000 GR.OIL TT1.BHC 775.000 TTZ.BHC GR.BHC 72-500 SP.BHC TENS.CML -999.250 SFLU-DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.OTE IIRM.OTE -999-250 SGR.OTE MRES.OTE -999.250 HTEN.OTE DTLN.50T -999.250 OTLF.SOT COHC.SDT -999.250 COHS.SDT TTZ.SDT -999-250 TT3-SDT LTTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZN~.NGT -999-250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHUB.LDT -999.250 DRHO.~LOT QSS.LDT -999.250 LS.LDT LITM.LDT -999.250 SS1.LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999.250 GRoLDT MRESoLOT -999.250 HTE'N.LOT CPEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPUR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.~PT -999o250 MRES.EPT IMPH.COR -999o250 SP.COR HTEN.COR -999.250 DEPT. 6300.000 SFLU.DIL SP.OIL -Z6.750 GR.DIL TT1.BHC 865.000 TTZ.BHC GR.BMC 61.Z19 SP.BHC 24-APR-t989 18:07 -999. 250 SGR. NGT -999.250 -999.250 URAN.NGT -999.250 -999. 250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEP.LOT -999.250 -999. 250 LU. LDT -999. 250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LOT -999.250 -999. 250 TENS.LOT -999.250 -999. Z50 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999. ZSO CALI.EPT -999. ZSO -999.250 HTEN.EPT -999.250 -999.250 5GR.COR -999.250 Z.959 ILM.DIL 72.500 TENS.OIL 558'500 TT3.BMC -23.000 TENS.OMC -999.250 ILM.DTE -999.250 IMPH. DTE -999.250 IIRD.DTE -999.250 TENS.DTE -999.250 DT.SDT -999.250 OTCO.SOT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4.$DT -999.250 SGR.NGT -999.250 URRN.NGT -999. Z50 W4NG.NGT -999.250 MTEN.NGT -999.250 PEP.LOT -999.250 LU.LDT -999.250 SS2.LDT -999.250 LSRH.LOT -999.250 TENS.LOT -999.Z50 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRAoCNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGRoCOR 2.646 ILM.DIL 61.219 TENS.DIL 609.500 TT3.BHC -Z6.750 TENS.BHC 3.807 4044.000 778.000 4044.000 -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 2.850 3874.000 863.500 3874.000 CGR .NGT W1NG.NGT WSNG.NGT DPHI .LOT QLS .LOT LL.LOT L SHY. LOT LUR?I.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL PVR.EPT TEN$.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT¢.8HC GR.CHL ILO.OTE IFRE .DTE IIXO.DTE MTEM.DTE DTL.SOT DTSM'SDT TT1.SDT LTTI. SOT SGR. SDT CGR.NGT WING. NGT WSNG.NGT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FV~.EPT TENS.EPT I DP H. 'CO R TENS .COR ILO.OIL DT.BHC TT4.BHC GR.CHL PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -999.250 -999.250 4.152 565.000 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.106 1Z8 -8'15 598.000 -999.250 48 .IS TAPE YERIPIC~IIDN LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER Z~-APR-1989 18:07 TENS.CHL -999.250 SFLU.DTE -999.250 ILM.DTE -999.250 SP.DT~ -999.Z50 IDPH.DTE -999.Z50 IMPH.DTE -999.Z50 CIDP.DTE -999.Z50 CIMP.DTE -999.250 II~D.OTE -999.250 IIRM.DTE -999.Z50 SGR.OTE -999.250 TENS.DTE -999.250 MRES.DTE -999.Z50 HTEN.DTE -999.250 DT.SDT -999.250 DTLN.SDT -999.250 DTLF.SOT -999. Z50 OTCO.SOT -999.250 COHC.SDT -999.Z50 COHS.SDT -999.250 COST. SOT -999.250 TTZ.SDT -999.Z50 TT3.SDT -999.250 TT4.SOT -999.250 LTTZ.SOT -999.250 LTT3.SOT -999.Z50 LTT4.SDT -999.250 TENS.SOT -999.Z50 HTEN.SDT -999.250 SGR.NGT -999.250 THOR.NGT -999.Z50 POTA.NGT -999.250 URAN.NGT -999.250 WZNG.NGT -999.250 W3NG.NGT -999.Z50 ~4NG.NGT -999.250 TEN$.NGT -999.250 CS.NGT -999. ZSO HTEN.NGT -999.250 RHOB.LDT -999.Z50 DRHO.LOT -999. ZSO PEF.LDT -999.250 qSS.LDT -999. g50 LS.LOT -999. ZSO LU.LDT -999. 250 LITH.LDT -999.Z50 SS1.LDT -999.Z50 SS2.LDT -999.250 SSHV.LDT -999.250 SIRH.LDT -999.Z50 LSRH.LOT -999.250 CALI.LDT -999.Z50 GR.LDT -999.Z50 TENS.LDT -999.250 MRES.LDT -999.Z50 HTEN.LOT -999.Z50 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -9,99,,Z50 TNPH-CNL -999.250 TNR&?C#L -999,250 NPOR.CNL -999'2'50 R'CNT. CNL -999. ZSO RCFT.CNL -999.250 [;FTC.CNL -999.250 GR.CNL -999.250 NVR. EPT -999.250 GR.EPT -999.250 SA.EPT -999.Z50 CALI.EPT -999.250 MTE~.~PT -999.250 MRES.EPT -999.Z50 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999 250 SGR COR -999.250 HTEN.CUR -999. 250 DEPT. 6200.000 SFLU.DIL 3.99Z ILM. DIL 3.740 SP.DIL -¢5.000 GE.OIL 55.344 TENS.OIL 3760.000 TTZ.BHC 7Z6,000 TT2.BHC 539.500 TT3.BHC 725,.500 [~R.BHC 56.344 SP.BHC -45.000 TENS.BHC 3760.000 TENS.CHL -999.Z50 SFLU.DTE -999.Z50 ILM.DTE -999.250 SP.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.Z50 IIRD.DTE -99'9. ZEO ZIRM.D'T5 -999.Z50 SGR.DTE -999.250 TENS.DTE -999.250 MRES.DTE -999.25[} HTEN.DTE -999.250 DT.SDT -999.250 DTLN.SDT -999.250 DTLF. SOT -999.250 DTCO.SDT -999.250 COHC.SDT -999°250 COHS.SDT -999.Z50 COST.SDT -999.,Z50 TTZ.SDT -999.250 TT3.SOT -999.250 TT4.SDT -999.250 LTTZ.SDT -999.Z50 LTT3.SOT -999*-250 LTT4-SDT -999-,250 TENS.SOT -999.250 HTEN.SOT -999,.250 SGR.NGT -999.250 THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 NZNG.NGT -999.Z50 W3NG.NGT -999.250 W4NG.NGT -999.250 TENS,NGT -999.Z50 CS,NGT -999.250 HTEN.NGT -999.250 RHOB.LDT -999.Z50 DRHOoLDT -999.Z50 PEF.LOT -999.250 QSS.LDT -999.Z50 LS.LOT - 999' 250 LU.LDT -999. Z50 LITH.LDT -999.250 SSI.,LDT -999.250 SS2.LDT -999.250 SSHV,.L'DT -999.250 S1RH.LDT -999.Z50 LSRH.LDT -999.250 CALI.LDT -999.2',50 GE.LOT -999.250 TENS.LOT -999.250 HRES.LDT -999.Z50 HTEN.LDT -999.250 ~NPH.CNL -999.250 CFEC,CNL -999,Z50 CNEC,CNL -399,250 RCEF,CNL -999,250 NPHI,CNL -999,250 TNPH,CNL -999,250 TNRA.CNL -999,250 NPOR,CNL -999,250 RCNT,CNL -999,Z50 RCFT,CNL -999,250 CFTC,CNL -999,Z50 GR,CNL -999, :ZSO NVR,EPT -999.Z50 ILD. DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SOT DTSM.SDT TT1 .SOT LTT!. SOT SGR.SDT CGR,NGT WING,NGT W5NG,NGT DPHI .LOT QLS.LDT LL .LOT LSHV.LDT LURH.LDT NTEM.LDT ENRA .CNL RCEN.CNL RTNR .CNL CNTC.CNL FVR.EPT TENS.~PT IDPH,COR TENS.COR ILO,OIL DT,SHC TT4,BHC GR,CHL ILO ,DTE IFRE,DTE IIXD,OTE M'TEM.DTE DTL. SOT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING. NGT WENG. NGT DPHI.LDT QLS.LDT LL. LOT LSHV.LDT LURH.LDT M'T E M. L D T ENR~.CNL RCEN,CNL RTNR ,CNL CNTC ,CNL FVR, EPT PAEE: -999.Z50 -999.250 -999.Z50 -999.Z50 -999.Z50 -999.250 -999.Z50 -999.Z50 -999.Z50 -999.Z50 -999.250 -999.Z50 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.401 105.750 538.500 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 --999.250 '-999.250 -999.250 -999.Z50 -999.250 -999.250 49 .IS TAPE VERIFICATION LISTING ;CttLUMBt-RSER ALASKA COMPUTING CENTER GR.EPT -999.Z50 S~.EPT MTEM.EPT -999.Z50 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.CgR -999.Z50 DEPT. 6100.000 SFLU.DIL SP.DIL -87.000 GR.DIL TT1.BHC 844.000 TT2.BHC GR.BHC 43.938 SP.BHC TENS.CHL -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.OTE -999.250 CIMP.DTE IIRM.DTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SOT COHC.SDT -999.250 COHS.SDT TTZ.SDT -999.250 TT3.SDT LTT2.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOS.LDT -999.250 DRHO.LOT QSS.LDT -999.250 LS.LOT LITH.LDT -999.250 SSloLDT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999.250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 S~.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.CUR -999.250 DEPT. 6000.000 SFLU.DIL SP.DIL -35.000 GR.DIL TT1.BHC 862.000 TT2.BHC GR.~HC 74.250 SP.BHC TENS.CHL -999.250 SFLU.D'TE SP. DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM.D! ~ -999. Z 50 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF.SOT COHC.SDT -999.250 COHS.SOT TTZ.5DT -999.250 TT3.50T LTTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHOB.LDT -999.250 ORHO.LDT Z¢-APR-1989 18:07 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -399.250 SGR.COR -999.250 3.368 ILM.DIL 1.&63 43.938 TENS.OIL 3790.000 582.000 TT3.BHC 846.500 -87.000 TENS.BHC 3790.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.OTE -999.250 -999.250 DT.SOT -999.250 , -999.250 DTCO.SDT -999.250 -999. Z50 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4. SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999' Z'50 HTEN.NGT -999.250 -999.250 PEF.LDT --999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LOT -999.250 -999.250 LSRH.LDT -999.250 -999. 250 TENS.LOT -999.250 -999. ZSO ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVRoEPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 2.109 ILM.DIL 2.66& 74.250 TENS.OIL 3770.000 604.0~00 TT3.BHC 862.500 -35.000 'TENS.BHC 3770.000 -999.250 ILM. OTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.OTE -999.250 -999.250 TENS.DTE -999.250 -999.250 OT.SDT -999.250 -999.250 O~TCO.SDT -999.250 -999.Z50 COST.SOT -999.250 -999.250 TT4oSDT -999.250 -999.250 LTT4.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.,250 -999.250 HTEN.NGT -=999.250 -999.250 PEF.LDT -999.250 TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT4.SHC GR.CHL ILD.OTE IFRE.DTE IIXD.DTE MTEM.OTE OTL.SDT OTSM.SDT TTI.SD'T LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LOT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL DT.SHC TT4.BHC GR.CHL ILO.gTE IFRE.OTE IIXD.DTE MTEM.OTE DTL.SDT DTSM.SDT TTI.SDT LTT1.SDT SGR.SDT CGR.NGT W1N~.NGT WSNG.NGT DPHI.LDT QLS.LDT PAGE: -999.250 -999.250 -999.250 1.416 133.625 582.000 -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 Z.gOO 129.125 606.500 -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 5O -IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 QSG.LDT -999.250 tS.LOT -999.250 LU.LDT -999.250 kITH.LOT -999.250 SSI.LDT -999.250 SSZ.LDT -999.250 SSHV.LDT -999.250 S1RH.LOT -999.250 LSRH.LDT -999.250 CALI.LOT -999.250 GR.LDT -999.250 TENS.LOT -999.250 MRES.LDT -999.250 HTEN.LDT -999.Z50 ENPH.CNL -999.250 CFEC.CNL -999.250 CN~C.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CPTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999 250 SGR.COR -999 250 HTEN.COR -999.250 ' DEPT. 5900.000 SFLU.DIL SP.DIL -55.500 GR.OIL TTI.BHC 794.500 TT2.BHC GR.6HC 55.844 SP.BHC TENS.CML -999.250 SFLU.DTE 5P.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. OTE -99'9.250 SGR.DTE MAES.gTE '-999.250 HTEN.DTE OTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ.SD~ -999.250 TT3.SDT LTTZ.SDT -999.Z50 LTT3oSOT TENS.GDT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NOT -999.250 CS.NGT RHUB.LDT -999.250 DRHO.LOT QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SS1.LDT 55HV.LDT -999.250 S1RH.LDT CALI.LOT -999.250 OR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.2 50 TNPH.CNL NPUR.CNL -999.250 RCNT.CNL C'FTCoCNL -999.250 GR.CNL GR.Epr -999.250 SA.EPT MTEM.!EPT -999.250 MRESoEPT IMPH.COR -999o250 SP.C~R HTEN. COR -999.2~0 4.132 ILM.DIL 55.844 TENS.DIL 564.500 TT3.BMC -55.500 TENS.BHC -999.250 ILM.OTE -999.250 IMPH.DTE -'999.250 IIRD.DTE -999.250 TENS.gTE -999.250 DT.SDT -999.250 DTCO. SDT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4. SOT -999.250 SGR.NGT -999.250 URAN.NGT -999.Z50 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LOT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 3.495 3664.000 796.000 3664.000 -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 LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL OT.BHC TT~.SMC GR.CHL ILO.gTE IFRE.OTE IIXD.DTE MTEMoDTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WGNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TE~S.COR DEP%. 5800.000 5FLU.DIL 4.471 ILM'OIL 2.46~ ILO.OIL SP.OIL -93.500 OR.OIL 37.625 TENS.DIL 3620.000 DT.OHC TT1.BHC 859.500 TTZ.BHC 584.500 TT3.BHC 858.000 TT~.BHC GR.BHC 37.625 SP.BHC -93.500 TENS.BHC 3620.000 GR.CHL TENS.CHL -999.250 SFLU.OTE -999.250 ILM.DTE -999.250 ILD.DTE SP.OTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 IFRE.DTE CIDP.OTE -999.250 CIMP.O'TE -999.250 [IRD.DTE -999.250 IIXO.DTE IIRM.DTE -999.250 SGR.DTE -99'9.250 TENS.gTE -999.250 MTEM.DTE MRES.DTE -999.250 HTEN.DTE -999.250 DT.SDT -999.250 DTL.SDT PAGE: -9~9.250 -999.Z50 -999.Z50 -999.250 -9~9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.183 119.000 563.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -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 -9~9.250 1.857 130.375 582.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 51 .iS I APE VERIFICATION LISTING ;CHLUMUERGER ALASKa COMPUTING CENTER 24-~PR-1989 18:0'7 DTLN.SDT -999.250 DTLF.SDT -999.250 DTCO.SDT -999.250 COHC.SDT -999.Z50 CDHS.SDT -999.Z50 COST.SOT -999.250 TTZ.SDT -999.250 TT3.SDT -'999.7_50 TT4.SDT -999.250 LTTZ.SDT -999.250 LTT3.SDT -999.Z50 LTT4.SDT -999.Z50 TENS.SOT -999.Z50 HTEN.SDT -999.Z50 SGR.NGT -999.250 IHOR.NGT -999.250 POTA.NGT -999.Z50 URAN.NGT -999.250 WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.250 TENS.NGT -999.250 CS.NGT -999.Z50 HTEN.NGT -999.250 RHOB.LDT -999.Z50 ORHO.LDT -999.Z50 PEF.LDT -999.Z50 QSS.LDT -999. 250 LS.LDT -999. 250 LU.LDT -999. 250 LITH.LDT -999.250 SS1.LDT -999.Z50 SSZ.LDT -999.250 SSHV.LDT -999.250 SIRH.LDT -999. Z50 LSRH.LDT -999.Z50 CALI.LDT -999.Z50 GR.LDT -999.Z50 TENS.LDT -999.Z50 MRES.LDT -999.250 HTEN.LOT -999.Z50 ENPH.CNL -999.Z50 CFEC.CNL -999.250 CNECoCNL -999.Z50 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.Z50 TNRA.CNL -999.Z$0 NPOR.CNL -999.Z50 RCNT.CNL -999.250 RCFT.CNL -999.Z50 CFTCoCNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.Z50 HTEN.EPT -999.Z50 ZMPH.COR -999.Z50 SP.COR -999.250 SGR COR -999.Z50 HTEN.CO:R -999. 250 ' DEPT. 5700°000 SFLU.DIL 4.622 ILM.DIL Z.Z47 SP.UIL -90.750 GR.DIL 44.031 TENS.DIL TTI.BHC 841.000 TTZ.BHC 577.000 TT3.BHC 841.000 GR.BHC ~4.031 SPoBHC -90.750 TENS.BHC 3464.000 TENS.CHL -999.250 SFLU.OTE -999.Z50 ILM.DTE -999.250 SP.DTE -999.Z50 IDPH.DTE -999. ZEO IMPH.DTE -999.Z50 CIUP.DTE -999.Z50 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 M,RES. DTE -999.250 HTEN.DTE -999.250 DT.SDT -999.Z50 DTLN. SDT -999.250 OTLF.SDT -999. ZEO DTCD.SDT -999.Z50 COHC.SDT -999.Z50 COHS.SDT -999.Z50 COST.SOT -999.250 TTZ.SDT -999.Z50 TT).SDT ' 999.250 TT4.SDT -999. ZEO LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4. SOT -999.250 TENS.SDT -999.Z50 HTENoSDT -999. ZEO SGR.NGT -999.Z50 'THOR.NGT -999.Z50 POTA.NGT -999.250 URAN.NGT -999.250 W2NG.NGT -999.2,50 W3NG.NGT -999.250 W4NG.NGT -999.250 TE'NS.NGT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 RHO~.LDT -999.250 DRHO.LOT -999.Z50 PEF.LOT -999.Z50 QSS'LDT -999.250 LS. LOT -999. Z 50 LU.LOT -999.250 LITH.LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 SSHV.LDT -999.250 SI, RH.LOT -999.250 LSRH.LDT -999.250 CA:LI.LDT -999.250 GR.LDT -999. Z50 TENS.LOT -999.250 MRES.LDT -999.Z50 HTEN.LOT -999. 250 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHIoCNL -999.250 TNPH.CNL -999.Z50 TNRA.CNL -999.250 NPOR.CNL -999.Z50 RCNT.CNL -999. 250 RCFT.CNL -999.Z50 CFTC.CNL -999.Z50 GR. CN:L -999.Z50 N'VR. EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT --999.250 MTEMoEP[ -999.250 MRES.EPT -999.Z50 HT'EN.EPT -999.250 IMPH.COR -999.250 SP.COR -999.Z50 SGR.COR -999 250 HTEN. COR -999. 250 DTS M. SOT TT1 .SDT LTTI.SDT SGR. SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH. LOT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS .COR ILD.DIL OT.BHC TT4.SHC GR.CHL ILD.DTE IFRE.OTE IIXD.DT~ MTEM.DTE DTL.SDT DTSM.SDT TT1. SDT LTT1.SDT SGR.SDT CGR o NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL .LDT L SHV. LDT LURH.LDT MTEM. LDT ENR~. CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR. EPT TENS. EP*T IOPH.COR TENS.COR PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 1.707 13Z.6Z5 57'7.500 -999.Z50 -999.Z50 -999.250 -999.250 '-999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.Z50 -999'250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.Z50 -999.250 '-999.250 5Z TAPE VERIPICATION LISTING ~CHLUMBERGER ALASKA CO)lPUTING CENTER 24-APR-1989 18:07 53 DEPT. 5600.000 SFLU.DIL 4.Z64 SP.DIL -92. 000 GR.OIL 38. 781 TT1. BHC 856. 000 TTZ.BHC 588. 000 GR. BHC 38.78! SP. BHC -92. 000 TENS.CHL -999.250 SFLU.DTE -999.250 SP. DTE -999.250 IDPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999. 250 IIRM. OTE -999. 250 SGR. DTE - 999. 250 MRES.DTE -999.250 HTEN.DTE -999.250 DTLN.SDT -999.250 DTLF.SDT -999.250 CDHC.SDT -999.250 COHS.SOT -999.250 TT2. SOT -999. 250 TT3. SOT -999. 250 LTT2.SDT -999.250 LTT3.SDT -999.250 TENS.SOT -999.250 HTEN.SDT -999.250 IHUR.NGT -999.250 POTA.NGT -999.250 W2NG.NGT -999.250 W3NG.NGT -999.250 TENS.NGT -999.250 CS. NGT -999. 250 RHOB.LDT -999.250 ORHO.LDT -999.250 QSS.LOT -999. Z 50 tS. LOT -999. 250 LITH.LDT -999. 250 5S!.LDT -999.250 SSHV.LOT -999' 25'0 SIRH. LOT -999. 250 CALI.LDT -999.250 GR.LDT -999. 250 MRES.LDT -999.250 HTEN.LDT -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999. Z50 GR. EPT -999. 250 SA. EPT - 999. 250 MTEM.EPT -999.250 MRES.EPT -999.250 IMPH.COR -999.250 .SP.COR -999 250 HTEN. CUR -999. Z 50 DEPT. 5500.000 SFLU.DIL 4.159 SP. OIL -111. 500 GR.DIL 46. 344 TT1.8HC 839. 500 TT2. BHC 575. SO0 GR.BH~ 46.344 SP.BHC - !11. 500 TENS.CHL -999.250 SFLU.DTE -999.250 SP.DTE -999.250 IDPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRM. DTE -999. Z 50 SGR. D'TE -999. 250 MRES.DTE -999-250 HTEN.DTE -999.250 DTLN.SDT '-999.250 DTLF.SDT -999.250 CUHC. SDT -999.250 COHS.SOT -999. 250 TTZ.SDT -999.2 50 TT3. SOT -999. 250 LTTZ.SDT -999.250 LTT3.SOT -999.250 TENS.SDT -999.250 HTEN.SDT -999.250 THOR.NGT '-999.250 POTA.NGT -999.Z50 W2NG.NGT -999.Z50 W3NG.NGT -999.250 1 ENS.NG'T -999. Z 50 CS. NGT - 999. 250 RHOB.LDT -999.250 DRHO.LDT -999.250 ~SS. LOT -999.2 50 LS.LOT - 999. Z50 LITH.LDT -999.250 SS1. LOT -999. Z50 5SHV.LDT -999.250 S1RHoLOT -999.250 CALI. LDT -999. 250 GR. LOT -999. 250 ILM.DIL TENS.DIL TT3.BHC TENS.BHC ILM.DTE INPH.DTE IIRD.DTE TENS.DTE DT.SDT DTCO.SDT COST .SDT TT4.SDT LTT4.SOT SGR.NGT URAN.NGT W4NG.NGT HTEN.NGT PEF.LDT LU.LDT SSZ.LOT LSRH.LOT TENS .LOT ENPH.CNL RCEF.CNL TNRA.CNL RCFT.CNL NVR.EPT CALI.EPT HTEN. EPT SGR.COR ILM. DIL TENS.OIL TT3.BHC TENS.BHC ILM.DTE IMPH.DTE IIRD.DTE TENS.DTE DT. SDT OTCO. SDT COST.SDT TT4.SDT LTT~.SDT SGR.NGT URAN.NGT W~NG.NGT HTEN. NGT PEF.LDT LU.LDT SSZ. LOT LSRH.LDT TENS.LDT Z.011 3460.000 867.500 3460.000 -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 3.074 3430.000 83 6. 000 3430.000 -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 -99'9.250 -999.250 -999.250 ILO.OIL DT.BHC TTq,. BHC GR .CHL ILO.DTE ImRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1. SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI .LDT qt S. LDT LL.LDT LSHV.LDT LURH.LDT NTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL ~VR,EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL DT.BHC TT~.BHC GR.CHL ILD'DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TTloSDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI .LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT 1.477 136.000 591.000 -999.250 -999.Z50 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 --999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 124.250 5'75.500 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.2.50 -999.250 -999.250 -999°250 -999.Z50 -999oZ50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 .IS TAPE YERIFICATION LISTING iCHLUM~ERGkR ALASKA, COMPUTING CENTER MRES.LDT -999.Z50 HTEN.LgT CFEC.CNL -999. Z50 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC. CNL -999. Z50 GR.CNL GR. EPT -999. 250 SA. EPT MTEM.EPT -999.250 MRES.EPT I MPH.COR -999.250 SP.COR HTEN.CQR -999.250 DEPT. 5400.000 SFLU.DIL SP.OIL -63.250 GR.DIL TTI. BHC 846. 500 TTZ. OMC GR.BHC 53.438 SP.BHC TENS.CHL -999.250 SFLU.DTE 5P.DTE -999.Z50 IDPH.DTE CLOP. DTE -999. 250 CIMP. DTE IIRM.DTE -999.2 50 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SOT -999. 250 COHS.SDT TTZ . SOT -999 '250 TT3 . SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999. 250 CS. NGT RHgB.LDT -999.250 ORHO.LOT QSS.LDT -999. 250 tS.LOT L ITH. LDT -999. Z 50 S S1.LOT SSHV. LOT -999. 250 S1 RH. LOT CALI.LOT -999. 250 GR. LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CPTC.CNL -999. 250 GR.CNL GR. EPT -999.2 50 SA.EPT MTEMoEPT -999.Z50 MRES.EPT IMPH. CDR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 5300,000 SFLU.DIL SP.DIL -6Z.000 GR.DIL TT1.BHC 846.000 TT2.BHC GR.BHC 56.594 SP.BHC TENS.CML -999.250 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.OTE -999.250 CIMP.DTE IIRM.DTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SOT COHC.SDT -999.250 COHS.SDT TTZ.SDT -999.250 TT3.SOT LTTZ.SDT -999.250 LTT3oSOT 24-APR-1989 18:07 -999. 250 ENPH.CNL -999.250 -999.250 RCEP.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999. 250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 3.819 ILM. DIL 53.438 TENS.OIL 582.000 TT3.BHC -63.250 TENS.BHC -999.250 ILM.DTE -999.250 IMPH. DTE -999.250 IIRO.DTE -999.250 TENS.DTE -999.250 OT.SOT -999.250 OTCO.SDT -999.Z50 COST.SOT -999. 250 TT4'$OT -999.250 LTT4. SOT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LOT -999.250 LSRH.LDT -999. 250 TENS.LOT -999.250 ENPH.CNL -999. 250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR 4.547 ILM.DIL 56.594 'TENS.DIL 578.500 TT3.BHC -6Z.000 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRD.OTE -999.Z50 TENS.DTE -999.250 DT.SOT -999.250 DTCO.SOT -999.250 COST.SOT -999.Z50 TT4.SDT -999.250 LTT4.SDT 3.279 3410.000 848.000 3410.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -;999.250 -99 9.250 -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. Z 50 -999.250 3.723 3310.000 $ 46.500 3310.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.CDR TENS.CDR ILD.DIL OT.BHC TT4.BHC GR.CML ILD.DTE IFRE.OTE IIXD.OTE MTEM.DTE OTL.SDT DTSM.SOT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNS.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.COR ILO.OIL D'T.SHC TT4.BHC GR.CHL ILO.DTE IFRE.OTE IIXO.DTE MTEM.DTE OTL.SDT DTSM.SOT TT1 .SDT LTT1. SOT SGR. SOT PAGE: 54 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 2.835 128.125 589.000 -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 -9~9.250 -999.250 -999.250 3.0'19 128.500 5~Z.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -IS TAPE VERIFICRTION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER 24-APR-lO89 18:07 TENS.SOT -999.250 HTEN.SDT -999.250 SGR.NGT -999.250 THOR.NGT -999.250 POT~.NGT -999.250 URAN.NGT -999.250 WZNG.NGT -999.250 W3NG.NGT -999.Z50 W4NG.NGT -999.250 TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 RHOB.LDT -999.250 DRHO.LOT -999.250 PEF.LDT -999.250 QSS.LDT -999.250 LS.LOT -999.250 LU.LOT -999.250 LITH. LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 5SHV.LDT -999.250 S1RH.LDT -999.250 LSRH.LDT -999.250 CALI.LDT -999.250 GR.LDT -999.250 TENS.LOT -999.250 MRES.LDT -999.250 HTEN.LOT -999.250 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 'TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CFTC-CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999.250 SGR COR -999 250 HTEN.CQR -999.250 ' ' CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FYR.EPT TENS.EPT IOPH.COR TENS.COR DEP'[. 5Z00.000 SFLU.DIL 0.129 ILM.DIL 2000.000 ILO.OIL SP.DZL 0-632 GR.DIL 36°406 TENS.DIL 3410.000 DT.BHC TTI.BHC 708'0'00 TTZ.BHC 500.~00 TT3.BHC 700.000 TT4.BHC GR.BHC 36.406 SP.BHC 0.63Z TENS.BHC 3~10.000 GR.CHL TENS.CHL 3364.000 SFLU.DTE -999.250 ILM.DTE -9'99.250 ILD.DTE SP.OTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 IFRE.DTE CIDP.DTE -999.250 CIMP.OTE -999.250 IIRD.DTE -999.250 IIXD.OTE IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MTEM.DTE MRE$.DTE -999.250 HTEN.DTE -999.250 DT.SOT -999.250 DTL. SDT DTLN.SDT -999.250 DTLF.SOT -999.250 OTCO.SDT -999.250 DTSM.SDT COHC.SDT -999.250 COHS.SDT -999.250 COST. SOT -999.250 TTI.$DT TTZ.SDT -999.250 TT3.SDT -999.250 TT4.SDT -999.250 LTTI.SDT LTTZ.SDT -999.250 LTT3.SDT -999.Z50 LTT4.SDT -999.250 SGR.SDT TENS.SOT -999.250 HTEN.SDT -999.250 SGR.NGT -999.250 CGR.NGT THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 WING.NGT WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.250 WSNG.NGT [ENS.NGT -999.250 CSoNGT -999.250 HTEN.NGT -999.250 DPHI.LDT RHOB.LDT -999.250 DRHD.LDT -999.250 PEF.LDT -999.250 QL.S.LDT QSS.LDT -999.250 LS.LDT -999.250 LU.LDT -999.250 LL.LOT LITH,.LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 LSHV.LDT SSHV.LDT -999.250 SIRH.LOT -999.250 LSRH.LDT -999.250 LURH.LDT CALI.LDT -999.250 GR.LOT -999.250 TENS.LOT -999.250 MTEMoLDT MRES.LDT -999.250 HTEN.LOT -999.250 ENPH.CNL -999.250 ENRA.CNL CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 RCEN.CNL NPHI.CNL -999.250 TNPH.CNL -999.250 TNRAoCNL -999o250 RTNR.CNL NPUR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 FVR.EPT GRoEPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 TENS.EPT MTEMoEPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IDPH.COR IMPH.COR -999.Z50 SP.COR -999.250 SGR.COR -999.250 TENS COR HTEN.COR -999.2.50 - 0.148 ILM.DIL 47.625 TENS.DIL ~2Z.O00 TT3.BMC -7.578 TENS.BHC 2000.000 3320.000 ¢81.000 3320.000 OEP[. 5.100.000 SFLU.DIL SP.DIL -7.578 GR.DIL TTloBHC 481.000 TTZ.BHC GR.BHC 47.625 SP.BHC ILD.DIL DT.SHC TT4.SHC GR.CHL -999.250 -999.250 -999.250 -999.Z50 -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 ZO00.O00 97.438 500.250 37.344 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999o250 -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 2000.000 ~3.500 352.750 50.813 55 .IS TAPE VERIPIC,~TION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 24-.~PR-1989 1,3:07 TEN~.CHL 3410.000 SFLU.DTE -999.250 ILM.DTE -999.250 SP.DT5 -999.250 IDPHoOTE -999.250 INPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DT5 -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MRES.DTE -999.250 HTEN.DTE -999.250 DT.SDT -999.250 DTLN.SDT -999.250 DTLF.SOT -999.250 DTCO.SDT -999.250 COHC.SDT -999.Z50 COHS.SDT -999.250 COST.SOT -999.250 TT2oSDT -999.250 TT3.SDT -999.250 TT4.SDT -999.250 LTTZ.SOT -999.250 LTT3.SDT -999.250 LTT4.SDT -999.250 TENS.SOT -999.250 HTEN.SOT -999.250 SGR.NGT -999.250 THOR.NGT -999.250 POTA.NGT -999.250 URRN.NGT -999.250 WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.250 TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 RHOB.LDT -999.250 ORHO.I. DT -999.250 PEF.LOT -999.250 QSS.LOT -999. 250 LS.LDT -999.250 LO.LOT -999.250 LITH.LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 SSHV.LDT -999.250 SIRH.LDT -999.250 LSRH.LOT -999.250 CALI.LDT -999.250 GR.LOT -999. Z50 TENS.LOT -999.2S0 MRES.LDT -999.250 HTEN.LDT -999.250 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHZ.ENL -999.250 TNPH-CNL -999oZ50 TNRA'CNL -999.250 NPOR.CNL -999'250 RC:NT~CNL -999'Z50 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM. EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999.250 SGR COR -999 250 HTEN.COR -999.250 DEPT. 5000.000 SFLU.DIL SP.OIL -7.012 GR.OIL TTI.§HC 448. 000 TT2.BHC GRo BHC 44o 625 SP.BHC TENS.CHL 3290.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.OT5 -999.250 CIMP.DTE IIRM.OTE -999. 250 SGR.DTE HRES.DTE -999.250 HTEN.OTE DTLN. SOT -999. 250 DTLF. SOT CUHC.SDT -999°250 COHS.SDT 'TTZ. SOT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.2-'50 HTEN.SDT THOR.NGT -999°250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NGT -999. 250 CS. NGT RHOB. LOT -999. Z 50 OR HO.LOT QSS.LDT -999. 250 LS.LOT LITH.LDT -999. 250 SS1.LOT SSHV. LDT -999.250 S1 RH. LOT CALI.LDT -999. 250 GR. LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -99'9.250 RCNT.CNL CFTC.CNL -999. Z 50 GR.CNL 0.150 ILM.DIL ZO00.O00 44.625 TENS.OIL 3240.000 333.000 TT3.BHC 448.250 -7.012 TENS.BHC 3240.000 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999. 250 TENS.DTE -999.250 -999. 250 DTo SOT -999.250 -999. 250 DTCO. SOT -999..250 -999. Z50 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4.SDT -999.,250 -999.250 SGR.NGT -999.250 -999.250 URAN.NST -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LOT -999.250 -999.250 LSRHoLDT -999.250 -999. Z50 TENS.LDT -999. 250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.2:50 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 ILD. OTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SOT DTSM. SDT TT1.SDT LTT1.SDT SGR.SOT CGR.NGT WING.NGT WENG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LUEH.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.DIL OT.BHC TT4. BHC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE HTEM.OTE OTL.SOT DTSM.SDT TT1.SDT LTTI.SDT SGR.SDT CGR.NGT WING. NGT W 5 NG. NGT DPHI.LDT q L S. L D'T LL.LDT LSHV.LDT LURH.LOT MTE-M. L BT ENR~.CNL RCEN.CNL RTNR-CNL CNTC.CNL FVR. EPT PAGE'. -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 2090.000 57.500 332.750 44.219 -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 -999.2,50 -999.250 56 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 TENS.EPT MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IDPH.CGR IMPH.CDR -999.250 SP.COR -999.250 SGR.CDR -999.250 T;NS CDR HTEN.COR -999.250 - ' DEPT. 4900.000 SFLU.OIL -999.250 ILM.DIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.OIL -999.250 TT1.BHC -999.250 TT2.BHC -999.250 TT3.BHC -999.250 GR.BHC -999.250 SP.BHC -999.250 TENS.BHC -999.250 TENS.CHL 3204.000 SFLU. DTE -999.250 ILM.DTE -999.250 SP.DTE -999.250 IDPH.OTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MRES.DTE -999.250 HTEN.DTE -999.250 DT.SOT -999.250 DTLN.SDT -999.250 DTLF.SDT -999.250 DTCO.SDT -999.250 COHC.SDT -999.250 COHS.SDT -999.250 COST.SOT -999.250 TTZ.SDT -999.Z50 TT3.SDT -999.250 TT4.SDT -999.250 LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4. SOT -999.250 TENS.SOT -999.250 HTEN.SDT -999.250 SGR.NGT -999.250 THOR.NGT -999.250 POTa.NGT -999.250 URAN.NGT -999.250 W2NG.NGT -999.250 N3NG.NGT -999.250 W4NG.NGT -999'250 TENS.NGT -999'250 CS.NGT -999.250 HTEN.NGT -999.250 RHO§.LDT -999.250 ORHO.LDT -999.250 PEF.LOT -999.250 qSS.LDT -999.250 LS.LOT -999.250 LU.LDT -999.250 LITH.LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 SSHV.LDT -999.250 S1RH.LDT -999.250 LSRH.LDT -999.250 CALI.LDT -999.250 GR.LDT -999.250 TENS.LOT -999.250 MRES.LDT -999.250 HTEN.LOT -999.250 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 HTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.CDR -999.250 SP.COR -999. Z50 SGR.COR -999 250 HTEN.COR -999.250 ' ILO.OIL DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.OTE MTEM.DTE OTL.SDT DTSM.SOT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WZNG.NGT WSNG.NGT DPHI.LDT QL S. LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENSoEPT IDPH.COR TENS.CDR DEPT. 4800.000 SFL'U.D[L -999.250 ILM.DIL -999.250 ILO.OIL SP.DIL -999.Z50 GR.DIL -999.Z50 TENS.OIL -999.Z50 DT.BHC TT1.SHC -999.250 TTZ.BHC -999.Z50 TT3.BHC -999.250 TT4.BHC GR.BHC -999.250 SP.BHC -999.250 TENS.BHC -999.250 GR.CHL TENS.CNL 3224.000 SFLU.DTE -999.250 ILM.OTE -999.250 ILO.DTE SP.DTE -999.250 IDPH.D'TE -999.250 IMPH.DTE -999.250 IFRE.OTE CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999..250 IIXD.DTE IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MTEM.DTE MRES.DTE -999.250 HTEN.DTE -999.250 DT. SDT -999.250 DTL.SDT DTLN.SDT -999.250 DTLFoSDT -999.250 DTCO.SDT -999.250 DTSM. SDT COHC.SDT -999.250 CDHS.SDT -999'250 COST.SDT -999.250 TT1.SDT T'TZ.SDT -999.250 TT3.SOT -999.250 TT4.SDT -999.250 LTTI.SDT LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4.SDT -999.250 SGR.SDT TENS.SOT -999.250 HTEN.SDT -999.250 SGR.NGT -999.250 CGR.N'GT THOR'NGT -999.250 POTA.NGT -999o250 URAN.NGT -999.250 WING.NGT WZNGoNGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.250 WSNG.NGT TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 DPHI.LDT RHOB.LDT -999.250 ORHO.LDT -999.250 PEF.LOT -999.250 QLS.LDT PAGE: 57 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 42.469 -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 42.625 -999.250 -999.250 -999.250 -999.250 -999.2S0 -999.2S0 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERIEICATION LISTING SCHLUMBERGER ALASK.~ COMPUTING CENTER QSS. LDT -999.2 50 LS.LDT LITH.LDT -999. Z50 SS1.LOT SSHV.LDT -999. 250 S! RH. LOT CALI.LDT -999. 250 GR.LOT MRES. LOT -999. Z 50 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.Z50 TNPH.CNL NPOR.CNL -999. 250 RCNT.CNL CFTC.CNL -999.250 GR. CNL GR. EPT -999.2 50 SA. EPT MTEM.EPT -999. 250 MRES.EPT IMPH.CQR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 4700.0 O0 SFLU. DIL SP.DIL -999.250 GR.DIL TT1.8HC -999. 250 TT2. BHC GR.BHC -999.250 SP.BHC TENS.CHL 314~o000 SFLU.DTE 5P.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I I R M. OT'E -999.250 SGR .OTE MRES.OTE -999.2 50 HT EN.DTE DTLN.SDT -999.250 DTLF.SOT COHC.SDT -999.250 COHS. SOT TTZ. SDT -999.250 TT3.SOT LTTZ.SOT -999.250 LTT3.SaT TENS.SOT -999.250 HTEN.SOT TMOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.Z50 CS.NGT RHOB.LDT -999.250 DRHO.LDT qSS. LO'T -999. 250 LS.LDT L ITH.LDT -999.250 S S!.LDT 5SHV.LDT -999.;~ 50 S1RH.LOT CALI.LOT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NP:OR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR.~PT -999.250 S~,.EPT MTEM. EPT -999. 250 MRES. EPT IMPH.COR -999. 250 SP.COR HTEN.COR -9'99. 250 24-APR-1989 18:07 -999.250 LU.LDT -999.250 -999.250 SSZ.LOT -999.250 -999.250 LSRH.LOT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL --999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 TT3.BHC -999.250 -999.250 TENS.BHC -999.250 -999.250 ILM.DTE -999.250 -999.250 IMPH. DTE -999.250 -999.250 IIRD. OTE -999.250 -999.250 TENS.DTE -999.250 -999.250 DT.SOT -999.250 -999.250 OTCO.SDT -999.250 -999.250 COST.SOT -999.250 -999.Z50 TT4.SOT -999.250 -999.,250 LTT4.SOT -999.250 -999.Z50 SGR.NGT --999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT ,-999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LOT -999.250 -999.250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LOT -999.250 -999.250 'TENS.LOT -999.250 -999.250 ENPH. CNL -999.250 -999.250 RCEF.CNL --999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999'250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 DEPT. 4600.000 SFLU.DIL -999.Z50 ILM.DIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.OIL -999.250 TT1.SHC -999.250 TTZ.BHC -999.250 TT3.BHC -999.250 GR.BHC -999.250 SP.BHC -99'9.250 'TENS.BHC -999.250 TENS.CHL 3164o000 SFLU.DTE -999.250 ILM.DTE -999.250 SP.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.OTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MRES.DTE -999.250 HTEN.OTE -999.250 DT.SDT -999.250 LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNI CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR IlO.OIl DT.BHC TT4.BHC GR.CHL IlO.OTE IFRE.OTE IIXO.OTE MTEM.DTE OTL. SDT DTSM.SDT TT1.SOT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI .LOT QLS .LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CaR ILO.OIL OT.BHC TT~.BHC GR.CHL ILO.OTE IFRE.OTE IIXD.DTE MTEM.DTE DTL. SOT PAGE: -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 28.3~4 -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 37.625 -999.250 -999.250 -999.250 -999.250 -999.250 58 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER DTLN. SOT -999.250 DTLF. SOT COHC.SDT -999.250 COHS.SOT TT2. SOT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS. SOT -999. 250 HTEN. SOT THOR.NGT -999.250 POTA.NGT WZNG. NGT -999.2 50 W3NG. NGT TENS.NGT -999.250 CS.NGT RHUB.LDT -999. Z 50 ORHO.LOT QSS.LDT -999. 250 LS.LDT LITH.LOT -999. 250 S S1.LDT S SHV.LDf -999.2 50 SIRH.LDT CALI.LOT -999.Z 50 GR.LDT MRES.LDT -999. 250 HTEN-LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999. 250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR. EPT -999. 250 SA. EPT MTEM. EPT -999. 250 MR ES. EPT ZMPH.CUR -999. Z50 SP.COR H T E N. C OR -999 . 250 DEPT. 4500.000 SFLU.DIL SP.UIL -999.250 GR.DIL TT1. BHC -999.250 TT2.8HC GR.BHC -999.250 SP.BHC TENS.CHL 310/+. 000 SFLU.DTE SP. DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.OTE -999. 250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN. SOT -999.2 50 DTLF.SDT COHC.SDT -999.250 COHS.SOT TT2. SOT -999. 250 TT3. SOT LTTZ.$DT -999.250 LTT3.SOT TENS. SD'T -'999. 250 HTEN.SOT 'THOR. NGT -999. Z 50 POTA. NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999. 250 CS- NGT RHO~.LDT -999.250 ORHO-LOT QSS.LDT -999. 250 LS.LDT LITH.LOT -999. 250 SS!.LDT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999. 250 GR.LOT MRE$.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPH~.CNL -999.250 TNPH.CNL N POR. CNL -999.2 50 RC NT. C NL CFTC.CNL -999. 250 GE.CNL GR. EPT -999.250 SA. EPT MTEM. EPT -999. Z 50 MR ES.EPT IMPH. COR -999. Z 50 SP.COR HTEN.COR -999. Z 50 2&-~PR-1989 18:07 -999.250 DTCO.SOT -999.250 COST.SOT -999.250 TT4.SOT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LOT -999.250 LU.LDT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 5NPH*CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 ILM.DIL -999. Z50 TENS.OIL -999.250 TT3.BHC -999.250 TENS.BHC -999.250 ILM.DTE -999.250 [MPH.DTE -999.250 IIRD.DTE -999.250 TENS.DTE -999.250 OT.SDT -999.250 DTCO.SDT -999.250 COST.SOT -999.250 TT4. SOT -999.250 LTT4.SDT -999.250 SGR.NGT -999.250 UR~N.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LOT -999.250 LU.LOT -999.250 SS2'LDT -999.250 LSRH.LDT -999. 250 TENS.LDT -999.250 ENPH.CNL -999.250 RCEFoCNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.Z50 HTEN.EPT -999.250 SGR.COR -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 -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 DTSM. SDT TT1. SOT LTT1.SDT SGR. SOT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV .LOT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS .CDR ILD.DIL DT.BHC 'TT4.SHC GR.CHL ILD.DTE IFRE.OTE IIXO.OTE MTEM. DTE DTL.SOT DTSM. SOT TTI.SD~T LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.CDR TENS.CDR P~GE. ' -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 50.625 -999.25'0 -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 59 .IS TAPE VERIFICATION LISTING ~CHCUMBERGER ALASKA COMPUTING CENTER DEPT. ~400.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1. BHC -999. Z 50 TTZ. BHC GR.BHC -999.Z50 SP.BHC TENS.CHL 3014.000 SFLU.OTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 LIMP.gTE ! IRM. DTE -999. 250 SGR.OTE MRES.DTE -999.250 MTEN.DTE DTLN.SDT -999.250 DTLFoSDT COMIC.SOT -999.250 COHS.SDT TT2. SOT -999.250 )T3. SOT LTTZ.SDT 250 LTT3' SOT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHO§.LDT -999.250 ORHO.LOT QSS.LDT -999.250 LS.LOT LITH.LDT -999. 250 S SI.LOT SSHV'LDT -999'250 SIRH'LOT CALI.LOT -999.2 50 GR.LDT MRES.LDT -999.2.50 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC. CNL -999. 250 GR. CNL GR. EPT -999. 250 SA. EPT MrTEM-EPT -999.250 MRES.EPT IMPH.CDR -999. Z 50 SP.CDR HTEN.COR -999.Z50 2.4-~PR-1989 18:07 -999.250 ILM.DIL -999.250 -999.250 TENS.DIE -999.250 -999.250 TT3.BHC -999.250 -999.250 TENS.BHC -999.250 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.gTE -999.250 -999.250 DT. SOT -999. 250 -999.Z50 DTCO.SDT -999.250 -999. ZSO COST.SOT -999.250 -999.250 TT4. SOT -999.250 -999'250 LTT4'SOT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NG~ -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999. 250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.EOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 --999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -'999.250 DEPT. 4300.000 SFLU.DIL -999.250 ILM.DIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.DIE -999.250 TTI.~HC -999.250 TTZ.BHC -999.250 TT3.BMC -999.250 GR.BHC -9'99.250 SP.BHC -999.250 TENS.BHC -999.250 TENS.CHL 3064.000 SFLU.DTE -999.250 ILM.DTE -999.250 SP.DTE -999.250 !DPH.DTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE '-999.250 MRES.DIE -999.250 HTEN.DTE -999.250 DT.SDT -999.250 D'TLN. SOT -999.250 DTLF.SDT -999.250 gTCO.SOT -999.250 COHC. SDT -999.2'50 COHS.SOT -999.250 COST.SOT -999.250 TTZ.SDT -999.250 TT3.SOT -999.250 TT4. SDT -999-2,50 LTTZ.SOT -999.250 LTT3.$OT -999.250 LTT4. SOT -999.250 TENS.SOT -999.250 HTEN.SDT -999.250 SGR.NGT -999.250 THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 WING. NGT -999.2 50 W3NG. NGT -999. 250 W4NG. NGT -999. ZSO TENS.NGT -999.Z50 CS.NGT -999.250 HTEN.NGT -999.250 RHOB.LDT .-999.250 DRHO.LDT -999.250 PEF.LDT -999.250 QSS. LOT -999. Z 50 LS .LOT - 999.250 LU. LOT -99 9. Z 50 LITH.LDT -999.250 SS1.LDT -999.250 SSI.LOT -999.250 SSHV.LDT -999.250 S1RH.LDT -999.. 250 LSRH.LDT -999.250 CALI.LDT -999.250 GR.LDT -999.250 TENS.LOT -999.250 ILO.OIL DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXO.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENR~.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC 'TT~.BHC GR.CHL ILO.gTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM,SDT TTI.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT OPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT PAGE: -999.250 -999.250 -999.250 45.563 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9N9.250 -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 -999o250 -999.250 ~1.219 -999.250 1-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999o250 -999.250 -999.250 -999.2~0 -999.250 -999.250 -999o250 -999.250 6O .15 I APE VERIFICATION LISTING ~CHLUM~ERGER ALASK~ COMPUTING CENTER MRES.LDT -999. 250 HT EN. LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CPTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.CDR -999.250 DEPT. 4200. gO0 SFLU.DIL SP.DIL -999. 250 GR. DIL TT1. BHC -999. 250 TT2. BHC GR.BHC -999.250 SP.BHC TENS.CHL ZgZO.O00 SFLU.DTE SP.DTE -999. 250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.DTE -999. 250 SGR.DTE MRES.DTE -999.250 HTEN.OTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TT Z. SOT -999.2 50 T T3 * SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999-250 W3NG.NGT TENS. NGT -999. 250 CS.NGT RHOB.LDT -999.Z50 DRHO.LOT QSS.LDT -999. 250 LS.LDT L ITH.LDT -999. Z 50 S S1.LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999. 250 GR.LDT MRES.LDT -999. 250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.Z50 TNPH.CNL NPOR.CNL -999. 250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR. EPT -999.250 SA. EPT MTEM.EPT '999.250 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 4100.000 SFLU.DIL SP.DIL -999. Z50 GR.DIL TTloSHC -999. ZSO TT2. BHC GR.BHC -999.250 SP.BHC TENS.CHL ZOZO.OOO SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. gTE -999.250 SGR. gTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ. SDT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT 24-~PR-1989 18:07 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999. 250 RCFT.CNL --999.250 -999. 250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999. 250 SGR.COR -999.250 -999.250 ILM. DII -999.250 TENS.DIL -999.250 TT3.BHC -999. Z50 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999.250 TENS.gTE -999.250 OT.SDT -999.250 DTCO.SDT -999.250 COST.$DT -999' Z50 TT4.SDT -999.250 LTT4. SOT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LOT -999.25D LU.LDT -999.250 SSZ.LOT -999. 250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99 9. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -99 9. 250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999. ,250 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 TT3.BHC -999.250 -999.250 TENS.BHC -999.250 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.2?50 IIRD.DTE -999.250 -999.250 TENS.gTE -999.250 -999.2.50 OT.SOT -99 9. 250 -999.250 OTCO.SOT -999.250 -999.250 COST.SOT -999.250 -999.2:50 TT4,.SDT -999.250 -999. 250 LTT4.SDT -999.250 E NR ~. CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS .EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO. DTE IF:RE.DTE IIXD.DTE MTEM.DTE OTL .SDT DTSM.SDT TT1.SOT LTT'I. SOT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH .LDT MTEM.LDT ENRA.CNL RCEN.CNL R'TNR. CNL CNTC. CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT. BHC' TT4.BHC GR.CHL ILO.gTE IFRE.OTE IIXD.DTE MTEM.DTE OTL. SOT OTSM.SDT TTlo SDT LTTI. SOT SGR. SOT PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 36.750 -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.ZS0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 28.984 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 61 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER TENS.SOT -999.250 HTEN.SDT THOR.NOT -999.250 PDTA.NGT WZNG. NGT -999.2 50 W3 NG. NGT lENS. NOT -999.2 50 CS. NGT R HOB.LOT -999. Z 50 DRHO.LOT QSS. LOT -999. 250 LS. LOT L ITH.LDT -999. 250 S S!. LOT SSHVoLDT -999. 250 S1RH.LOT CALI.LDT -999. Z50 GR.LOT MRES.LDT -999. 250 HTEN.LOT CFEC.CNL -999. Z 50 CNEC.CNL NPHI.CNL -999. ZSO TNPH.CNL NPOR.CNL -999. 250 RCNT. CNL CFTC.CNL -999. 250 GR.CNL GR.EPT -999.250 SA.EPT MT EM. EPT -999. Z 50 MR ES. EPT IMPH.COR -999. Z 50 SP.COR HTEN.COR -9 99. 250 DEPT. 4000.000 SFLU.DIL S P. DIL -999. Z:.SO GR. DIL T T1.BH~ -999.250 TT2.~HC GR.BHC -999.250 SP.BHC TENS.ertL 2750.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP. DTE -999. 250 CIMP. DTE IIRM. DTE -999.250 SGR. OTE MRES.DTE -999.250 HTEN.DTE DTLN. SOT -999.250 OTLF. SOT COHC.SDT -999.250 COHS.SDT TTZ. SDT -999. 250 TT3. SOT L'TTZ.SDT -999.250 LTT3.SOT TENS.SOT -999.Z50 HTEN.SDT THUR'oNGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT T ENS.NGT -999. Z 50 CS. NGT RHUB.LDT -999.250 DRHO.LDT qS S.LDT -999. 250 LS. LOT L ITH.LDT -999.2 50 SS1.LDT SSHV.LDT -999.250 SIRH.LDT CALI.LOT -999. Z50 GR. LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPNI.CNL -999.250 TNPH.CNL NPDR.CNL -999.250 RCNT.CNL CFTC. CNL -999. Z50 GR. CNL GR. ~PT -999.2 50 SA. EPT MTEM.EPT -999.Z50 MRES.EPT IMPH.COR -999. Z50 SP.COR HTEN.CUR -999.2.50 DEPI'. 3900.000 SFLU.OIL SP.DIL -999.250 GR.DIL TT1. BHC -999.2 50 TTZ. 8HC ER. BHC -999. 250 SP. BHC 24-~PR-1989 18:07 -999.250 SGR.NGT -999.250 -999. 250 URAN. NGT -999.250 -999. Z50 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEP.LOT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999. 250 LSRH. lOT -999. 250 -999.250 TENS.LDT -999.250 -999.250 ENPH.CNL -999.250 -999.Z50 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999. 250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 MTEN.EPT -999.250 -999.250 SGR.CDR -999.250 -999. Z50 ILM.DIL -999.250 -999.250 TENS ..OIL 999. 250 -999.250 TT3.BHC -999.250 -999.Z50 TENS.BHC --999.250 -999.250 ILM.DTE -999.250 -999..250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. Z50 OT. SOT -999. 250 -999.250 OTCO.SDT -999.250 -999.250 COST.SOT -999.250 -999. Z50 TT4. SOT -999.250 -999.250 LTT4.SDT -999.250 -999.250 SGR.NGT -999.250 -'999.250 URAN.NGT -999.250 -999. 250 W4NG. NGT -999. 250 -999.250 HTEN.NGT -999.2.50 -999.250 PEF.LDT -999.250 -999. 250 LU.LOT -999. 250 -999. 250 SSZ.LDT -999. 250 -999.250 LSRH.LOT -999.250 -999°250 TENS.LOT -'999.250 -999.250 ENPH.CNL -999.250 -999.Z50 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 CGR.NGT W1NG.NGT WSNG.NGT DPH[.LDT QL$ .LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.CDR TENS.CDR ILO.OIL DT.BHC TT4. B HC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL. SDT OTSM.SDT TT1.SOT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG. NOT DPHI.LDT QLS .LDT LL. LDT LSHV.LDT LURfl. LDT MTEM.LDT ENR~ .CNL RCEN.CNL RTNR.CNL CNTC .CNL FVR.EPT TENS. EP'T IOPH.COR TENS.CDR PAGE: -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 50.063 -999.250 -999.Z50 -999.250 -999.250 -999.250 -9~9.250 -999.250 -999o~50 -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 ILM.DIL -999.250 ILO.OIL -999.250 -999.250 TENS.DIL -999.250 DT.BHC -999.250 -999.250 TT3.BHC -999.250 TT6.BHC -999.25U -999.250 TENS.BHC -999.250 GR.CHL ~7.406 52 .IS TAPE YERIFICATION LISTING ~CHLUMBERGER ~LASKA COMPUTING CENTER TENS.CHL Z900.OOO SP.DTE -999.250 CIDP.DTE -999.250 IIRM.DTE -999.250 MAES.gTE -999.250 DTLN. SOT -999.2 50 COHC.SDT -999.250 TT2. SOT -999. 250 LTTZ.SDT -999.250 TENSoSDY -999.250 TMOR.NGT -99~.250 W2NG.NGT -~99. 250 TEN~.NG~ -999.250 RHOB. LDT -999 . Z 50 ~55.LDT -999.250 LITH.LOT -999.250 5SHY.EDT -999.250 C~LI.LDT -999.250 ~RES.LDT -999.250 CFEC.CNL -999.250 NPHI . 5NL -999.2,50 NPOR.~NL -999' 250 CFTC.CNL -999.250 GR.EPT -999.250 ~TEM. ePT -999.250 IMPH.~OR -999.250 HTEN.COR -999.250 DEPT. 3800.000 SP.DIL -999.250 'TTI. BHC -999. 250 GR. BHC -999. Z 50 TENS.CHL 2734.000 SP. gTE -999. 250 CIDP.DTE -999.250 fIRM.gTE -999.250 MRES.DTE -999,250 DTLN. SOT -999. 250 COHCo SDT -999.250 T1'2.SDT -999.250 LTTZ.SDT -999.250 TENS.SOT '-999. 250 THOR.NGT -999,250 WZNG.NGT -999.250 TENS.NGT -999.250 RHD~.LDT -999,250 QSS.LDT -999.250 LITH.LDT -999.250 SSHV.LDT -999.250 CALI.LDT -999.2 50 MRES.LDT -999.250 CFEC.CNL -999.250 NPHI.CNL -999. 250 NPOR.CNL -999.250 CFTC.CNL -999.250 SFLU.DTE IDPH .DTE CIMP.DTE SGR.DTE HTEN.DTE DTLF.SDT COHS.SDT TT3.SDT LTT3.SDT HTEN.SOT POTA.NGT W3NG.NGT CS .NGT DRHO.LDT LS.LOT SSI.LOT S1RH.LDT GR.LOT HTEN.LDT CNEC.CNL TNPH. CNI R C NT . C NL GR.CNL SA.EPT MRES.EPT SP.COR ~-~PR-1959 18:07 -999.250 ILM.DTE -999.250 IMPH.DTE -999.750 IIRO.OTE -999.250 TENS.DTE -999.250 DT.SDT -999.Z50 OTCO.SDT -999.250 COST.SOT -999.Z50 TT4.SDT -999. 250 LTT4.SDT -999.250 SGR.NGT -999. 250 UR~N.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LOT -999.250 LSRH.LDT -999. ZSO TENS.LDT -999.250 ENPH. CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999. 250 RCFT.CNL -999. ZSO NVR. EPT -999.250 C~LI.EPT -999. 250 HTEN.EPT -999.Z50 SGR.COR SFLU.OIL -999.250 ILM. DIL GR.OIL -999.250 TENS.DIL TT2.BHC -999. ZSO TT3.BHC SP.BHC -999. Z50 TENS.BHC SFLU.DTE -,999. 250 ILM.DTE IDPH.DTE -999.250 IMPH.DTE CIMP.DTE -999.250 IIRD.DTE SGR.DTE -999.250 TENS.DTE HTEN.DTE -999. 250 DT.SOT OTLF. SDT -999. 250 gTCO. SDT COHS.SOT -999. 250 COST.SOT TT3.SDT -999.250 TT¢.SDT LTT3.SDT -999.250 LTT4.SDT HTEN.SDT -999.250 SGR.NGT POTA.NGT -999.250 URAN.NGT W3NG.NGT -999.250 W4NG.NGT CS.NGT -999'2.50 HTEN.NGT ORHO.LDT -999.250 PEF.LDT LS.LOT -999. 250 LU.LDT SS1.LOT -999.250 SS2.LDT SIRH.LDT -999.250 LSRH.LDT GR.LOT -999. 250 TENS.LDT HTEN.LOT -999. 250 ENPH.CNL CNEC.CNL -999.250 RCEF.CNL TNPH.CNL -999.250 TNRA.CNL RCNT.CNL -999. ZSO RCFT.CNL GR.CNL -999. ZSO NVR.EPT -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 -99 9. Z 50 -999.250 -999.250 -999.250 -999.250 -999.25'0 -999.250 -999.250 -999,250 -999.250 -999.250 - 99 9. Z 50 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 ILD.DTE IF:RE.OTE IIXD.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1 .SDT LTT1. SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QL S. LDT LL.LDT LSHV .LOT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR-CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.DIL DT.BHC TT~.BHC GR.CHL ILO.gTE IFRE.OTE IIXO.OTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTTI.SDT SGR.SDT CGRoNGT WiNG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNE CNTC.CNL FVR.EPT PAGE: -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 ZB.906 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -99'9. 250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999.250 -999,250 -999.250 -999.250 63 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 3700.000 SFLU.DIL SP.DIL -999.250 GR.DIL TTI.BHC -999.250 TT2.BHC GR.BHC -999.250 SP.BHC 1ENS.CHL 2684.000 SPLU.DTE SP.OTE -999.250 IDPH.DTE CIOP.DTE -999.250 C]MP.DTE !IRM. DTE -999.Z 50 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SOT -999.250 OTLF.SDT COHC.SDT -999.250 COHS.SOT TTZ.SDT -999.250 TT3.SDT LTT2.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.~50 W3NG.NGT TENS.NGT -999;250 NGT RHOB.LDT -999.250 DRHO.LOT QSS.LDT -999.250 LS.LDT LITH.LDT -999. 250 SS1. LOT SSHV.LDT -999.250 SZRH.LDT CALI.LDT -999.250 GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 3600.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1.BHC -999.250 TT2.BHC GR.BHC -999.250 SP.BHC I"ENS.CHL 2660. 000 SFLU.DTE SP.DTE -999.250 IOOH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.DT~ -999.250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 OTLF.SDT COHC. SDT -999.250 COHS.SOT TTZoSDT -999.250 TT3.SDT LTTZ.SDT -999o250 LTT3.SDT TENS.SDT -999.250 HTEN.SDT THORoNGT -999.250 POTA.NGT WZNG.NGT -999.250 W]NG.NGT TENS.NGT -999.250 CS.NGT RHUB.LDT -999.250 9RHO.LDT 24-APR-lO89 18:07 -999.250 CALI.EPT -999.250 -999.250 HTEN. EPT -999.250 -999.250 SGR.COR -999.250 -999.250 ILM.DIL -999.250 -999. 250 TENS.OIL -999.250 -999.250 TT3.BHC -999.250 -999.250 TENS.BHC -999.250 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 DT. SOT -999. 250 -999.250 DTCO.SOT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4. SOT -999.250 -999.250 LTT4.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LOT -999.250 -999. 250 LU.LOT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LOT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 TT3.BHC -999.250 -999.250 'TENS. BHC -999.2.50 --999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.1250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 DT. SOT -999.25D -999.250 DTCO.SDT -999.250 -999.250 COST.SDT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4. SOT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 TENS.EPT IOPH.COR TENS.COR ILg. DIt DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SOT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPMI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LOT MTEM.LDT ENRAoCNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL DT.BHC TT~.BHC GR.CHL ILO.D'TE IFRE.DTE IIXD.DTE MTEM.DTE OTL. SOT OTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 J3.750 -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 28.219 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99.9-250 -999.250 -999.250 -999.250 -999.250 6¸4 .z~ mAPE VERIFICATION LISTING ~CHLUM§ERGER ALASKA COMPUTING CENTER 24-~PR-1989 1B:07 QSS.LDT -999.250 LS. LDT -999. 250 LU.LDT -999. 250 LITH.LDT -999.250 SS1.LDT -999.250 SSZ.LDT -999.250 SSHV.LDT -999.250 SIRH.LDT -999.250 LSRH.LDT -999.250 CALI.LDT -999.250 GE.LOT -999.250 TENS.LDT -999.250 MRES.LDT -999.250 HTEN.LDT -999.250 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RC.~T.CNL -999.250 CPTC.CNL -999.250 GR.CNL -999.250 NVE.EPT -999.250 GR.EPT -999.250 S~.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999.250 SGR CDR -999 250 HTEN.CQR -999.250 ' ' LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TE~S.EPT IDPH.COR TENS.COR DEPY. 3500.000 SFLU.DIL -999.250 ILM.DIL -999.250 ILD.DIL 5P.DIL -999.250 GE.DIE -999.250 TENS.OIL -999.250 DT.BHC TT1.BHC -999.250 TT2.BHC -999.250 TT3.BHC -999.250 TT~.BHC GR.BHC -999.250 SP.BHC -999.250 TENS.BHC -999.250 GR.CHL TENS.CHL 2430.000 SFLU.DTE -999.250 ILM.DTE -999.250 ILD.OTE SP.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 IFRE.DTE CIDPoDTE -9,99.25~0 CIMP-DTE IIRD. DTE -999.250 IIXO.OTE IIRM,.DTE' SGR"OTE '999'250 TENS.DTE -999.250 MTEM.DTE MRES.DTE -999.250 HTEN.DTE -999.250 DT.SDT -999.Z50 OTL.SDT DTLN.SDT -999.250 OTLF.SOT -999.250 DTCO.SDT --999.250 DTSM.SDT CDHC.SDT -999.250 COHS.SDT -999.250 COST.SOT -999.250 TTI.SDT TTZ.SDT -999.250 TT3.SDT -999.250 TT4.SDT -999.250 LTT1.SDT LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4.SDT -999.250 SGR.SDT TENS.SDT -999.250 HTEN.SDT -999.250 5GR.NGT -999.250 CGR.NGT THQR.NGT -999.250 PDTA.NGT -999.250 URAN.NGT -999.250 WING.NGT WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.250 WENG.NGT TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 DPHI.EDT RHUB.LDT -999.250 DRHO.LOT -999.250 PEF.LDT -999.,250 QL,S.LDT QSS.LOT -999.250 LS.LDT -999.250 LU.LDT -999.250 LL.LDT LITH.LDT -999.250 SS1.LOT -999.250 SS2.LDT -999.250 LSHV.LDT 5SHV.LDT -999.250 S1RH.LDT -999.250 LSRH.LDT -999.250 LURH.LDT CALI.LDT -999.250 GE.LOT -999.250 TENS.LOT -999.250 MTEM.LDT MRES.LDT -999.250 HTEN.LDT -999.250 ENPH'CNL -999.250 ENRA.CNL CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 RCEN.CNL NPHI..CNL -999.Z50 TNPH.CNL -999.250 TNRAoCNL -999.250 RTNR.CNL NPUR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 FVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 TENS.EPT MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IOPH.CDR IMPfl.CUR -999.250 SP.COR -999.250 SGR.COR -999.250 T:NS COR H'TEN.COR -999.250 DEPT. $400.000 SFLU.DIL -'999.250 ILM.DIL -999.250 ILD.DIL SP.DIL -999.250 GE.DIE -999.250 TENS.OIL -999.250 DT.BHC TI1.BHC -999.250 TTZ.BHC -999.250 TT3.BHC -999.250 TT4.BHC GR.BHC -999.250 SP.BHC -999.250 TENS.BHC -999.250 GR.CHL TENS.CHL 2524.000 SFLU.DTE -999.250 I<LM.DTE -999.250 ILO. OTE SP.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 IFRE.DTE CIDP.OTE -999.2,50 CIMP.DTE -999.250 IIRD.DTE -999.250 IlXD.DTE IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MTEM.DTE MRES.DTE -999.250 HTEN.DTE -999.250 DT.SDT -999.250 DTL.SDT PAGE: -9~9.250 -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 25.156 -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 -999.2510 -999.250 -999.250 -999.250 -999.250 -999.250 32.531 -999.250 -999.250 -999.250 -999.250 -999.250 65 .iS TAPE VERIFICATION LISTING ;CHLUMBERG~R ALASKA COMPUTING CENTER 24-APR-1989 18:07 DTLNoSDT -999.250 CDHC.SOT -999.250 TTZ.SDT -999.250 LTT2.SDT -999.250 TENS.SOT -999.250 THOR.NET -999.250 WZNG.NET -999.250 TENS.NET -999.250 RHUB.LDT -999.250 QSS.LDT -999.250 KITH.LOT -999.250 SSHV.LDT -999.250 CALI.LDT -999.250 MRES.LDT -999.250 CFEC.CNL -999.250 NPHI.CNL -999.250 NPUR.CNL -999.250 CFTC.CNL -999.Z50 DTLF.SDT -999.250 OTCO.SDT CDHS.SOT -999.250 COST.SOT TT3.SDT -999.250 TT4.SDT LTT3.S~T -999.250 LTT4.SDT HTEN.SDT -999.250 SGR.NGT POTA.NGT -999.250 URAN.NGT W3NG.NGT -999.250 W4NG.NGT CS.NGT -999.Z50 HTEN.NGT DRHO.LDT -999.250 PEF.LDT LS.LOT -999.250 LU.LOT SSI.LOT -999.250 SS2.LOT SIRH.LOT -999.250 LSRH.LDT GR.LOT -999.250 TENS.LOT HTEN.LOT -999.250 ENPH'CNL CNEC.CNL -999.250 RCEF. CNL TNPH.CNL -999.250 TNRA.CNL RCNT.CNL -999.250 RCFT.CNL GR.CNL -999.250 NVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT HTEN.COR -999'2:50 DEPT. 3300.000 SFLU.OIL -9'99.250 ILM.DIL SP.DIL -999.250 ER.DIE -999.250 TENS.OIL TTI.BHC -999.250 TT2.BHC -999.250 TT3.BHC GR.BHC -999.250 SP.BHC -999.250 TENSoBHC TENS.CHL 2420.000 SFLU.DTE -999.250 ILM.DTE SP.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE MRES.DTE -999.250 HTEN.DTE -999.250 DT.SDT DTLN.SD'T -999.250 DTLF.SDT -999.250 DTCO.SOT COHC.SDT -999.250 COHS.SOT -999.250 COST.SOT TT2.SDT -999.250 TT3.SOT -999.250 TT4.SDT LTTZ.SD'T -999.250 LTT3.SOT -999.Z50 LTT4.SOT TENS.SDT -999.250 HTEN.SDT -999.250 SGR.NGT THOR.NET -999.250 POTA.NGT -999.250 URAN.NGT WZNG'NET -999.250 W3NG.NGT --999.250 W4NG.NGT TENS.NGT -999.250 CS.NGT -999.250 HTENoNGT RHO§.LDT -999.250 ORHO.LOT -999.250 PEF.LDT USS. LOT -999. 250 LS.LOT -99'9. 250 LU.LDT LI'TH.LDT -999.250 SSI.LOT -999.250 SS2.LOT SSHV.LDT -999.250 SIRH.LOT -999.250 LSRH.LDT CALI.LDT -999.250 GR.LOT -999.250 TENS.EOT MRES.LOT -999.250 HTEN.LOT -999.250 ENPH.CNL CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF. CNL NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT MTEM.EPY -999.250 MRES.EPT -999.250 HTEN.EPT IMPH.COR -999.250 SP.COR -999.250 SGR.COR HTEN.COR -999.250 -999.250 DTSM. SDT -999.250 TT1.SDT -999.250 LTT1.SDT -999. Z50 SGR. SOT -999. Z50 CGR.NGT -999.250 WING.NET -999.250 WSNG.NGT -999.Z50 DPHI.LDT -999.Z50 QLS.LDT -999.Z50 LL.LDT -999.250 LSHV.LDT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 ENRA.CNL -999.250 RCEN.CNL -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 FVR.EPT -999.250 TENS.EPT -999.250 IDPM.COR 999-~250 TENS-COIf -999.250 ILD.DIL -999.250 DT.BHC -999.250 TT4.BHC -999.250 'GR.CHL -999. ZSO ILDo OTE -999.250 IFRE.DTE -999.250 IIXO.DTE -999.250 MTEM.DTE -999.250 DTL.SDT -999.250 DTSM.SDT -999.250 TT1.SDT -999.250 LTT1.SDT -999.250 SGR.SDT -999.250 CGR.NGT -999.250 WING.NGT -999.250 W5NG.NGT -999.250 DPHI.LDT -999.Z50 QLS.LDT -999.Z~0 LL.LDT -999.Z50 LSHV.LDT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 ENR~,.CNL -999.250 RCEN.CNL -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 FVR.EPT -999.250 TENS.EPT -999.250 IDPH.COR -999.250 TENS.CDR PAGE: 66 -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.~50 -999.250 -999.250 -999.250 36.250 -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 .IS TAPE VERIFICATION LISTING ~CHLUM§ERGER ALASKA COMPUTING CENTER 24-APR-1989 PAEE: 57 DEPT. 3200.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1. BHC -999.Z 50 TTZ. BHC GR. BHC -939. Z50 SP. BHC T ENS.CHL 2440. OOO SFLU. DTE SP. DTE -999.2. 50 IDPH. gTE CIDP.OTE -999.Z50 CIMP.DTE IIRM.DTE -999. 250 SGR.DTE MRES.gTE -999.250 HTEN.DTE DTLN. SOT -999.250 OTLF. SOT COHC.SDT -999.250 COHS.SDT TT2. SOT -999. 250 TT3. SOT LTT2.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT !HOR. NGT -999. Z50 POTA. NGT W2NG.NGT -999.Z50 W3NG.NGT TENS. NOT -999. 250 CS. NGT RHOB. LOT -999. 250 DR HO .LOT -999.250 ILM.DIL -999.250 TENS.OIL -999. 250 TT3.BHC -999.250 TENS.BHC -999.250 ILM.DTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999.Z50 TENS.gTE -999.250 DT. SDT -999.250 OTCO.SDT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4.SDT -999.Z50 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN. NGT -999. Z50 PEF.LDT -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 MRES.LDT -999.250 HTEN.LOT -999.Z50 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL --999.250 NPOR.CNL -999.250 RCNT.CNL -999..Z50 RCFT.CNL -999.250 CFTC.CNL -999.Z50 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.Z50 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN. EPT -999.250 IMPH.COR -999.250 SP.COR -999.Z50 SGR.COR -999 250 HTEN.COR -999.250 ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.gTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT OTSM.SOT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WENG.NGT DPHI.LDT QLS.LDT LL.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTN~.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR DEPT. 3100.000 SFLU.DIL -999.250 ILM. DIL -999.250 ILO.OIL SP.DIL -999.250 GR.DIL -999.250 TENS.DIL -999.250 DT.BHC TTI.BHC -999.250 TT2.BHC -999.250 TT3.BHC -999.250 TT~.BHC GR.BHC -999.250 SP.BHC -999.250 TENS.BHC -999.250 GR.CHL 'TENS.CHL 2464.000 SFLU.DTE -999.250 ILM. DTE -999.250 ILO.gTE 5P. DTE -999.250 IDPH.DTE '-999.250 IMPH.DTE -999.250 IFRE.DTE CIDP.OTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.25,0 IIXD.DTE IIRM.OTE -999.250 SGR.DTE -999.250 TENSoDTE -999.250 MTEM.DTE MRES.DTE -999.250 HTEN.DTE -999.250 DT.SOT -999.250 OTL.SDT DTLN.SDT -999.250 OTLF.SDT -999.250 gTCO.SOT -999.250 DTSM.SDT COHO. SDT -999.250 COHS.SDT -999.250 CDST.SD'T -999.250 TTI.SDT TTZ.SDT -999.250 TT3.SOT -999.250 TT4.SDT -999.250 LTT1.SDT L'TTZ.SDT -999.250 LTT3.SOT -999.250 LTT4.SDT -999.250 SGR.SDT TENS.SOT -999.250 HTEN.SOT -999.250 SGR.NGT -999.250 CGR.NGT THOR.NGT -999.250 POTAoNGT -999.250 URAN.NGT -999.250 W1NG.NGT W2NG.NGT -999.250 W3NG.NGT -999-250 W4NG.NGT -999.250 WSNG.NG'T TENS.NOT -999.250 CSoNGT -999.250 HTEN.NGT -999.250 DPHI.LDT RHOB.LDT -999.250 DRHO.LOT -999.250 PEF.LDT -999.250 QLS.LDT qSS.LDT -999.250 LS.LOT -999.250 LU.LDT -999.250 LL.LDT LITH.LDT -999.250 SS1.LDT -999.250 SSZ.LDT -999.250 LSHV.LDT SSHV.LD'T -999.250 S1RH.LDT -999.250 LSRH.LOT -999.250 LURH.LDT CALI.LDT -999.250 OR.LOT -999.250 TENS.LOT -999.250 MTEM.LDT -999.250 -999.250 -999.250 38.656 -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 38.406 -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 .IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 2~-APR-1989 18:07 PAGE: 68 MRES.LDT -999.250 HTEN.LDT -999.250 ENPH.CNL CFEC.CNL -999.Z50 CNEC.CNL -999.Z50 RCEF.CNL NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL CPTC.CNL -999.250 GR.CNL -999.250 NVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT IMPH.COR -999.250 SP.COR -999.250 SGR.COR HTEN.COR -999.250 UEPT. 3000.000 SFLU.OIL -999.250 ILM.DIL SP.DIL -999.250 GR.OIL -999.250 TENS.OIL TTI.BHC -999.250 TTZ.BHC -999.250 TT3.BHC GE.SHE -999.250 5P.BHC -999.250 TENS.SHE TENS.CML 2384.000 SFLU.DTE -999.250 ILM.DTE 5P.OTE -999.250 IDPH.OTE -999.250 IMPH.DTE CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE MRES.OTE -999,250 HTEN.OTE -999.250 DT.SDT DTLN.SDT -999.250 DTLF.SDT -999.250 DTCO.SDT C O_HC., 5.0[ ~.99.9~' 2_5_.0 CQH~.,.5~QI ~ 999-oZSQ TTZ' SDT -999'250 TT3 - 999' 250 TT~ ' SOT LTTZ.SOT -999.250 LTT3.SOT -999.250 LTT4.SDT TENS.SOT -999.250 HTEN.SOT -999.250 SGR.NGT THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT RHOB.LDT -999.250 DRHO.LDT -999.250 PEF.LOT QSS.LDT -999.250 ES.LOT -999.250 LU.LDT LITH.LDT -999.250 SSlo:LOT -999.250 SS2.LOT 5SHV.LDT -999.Z50 SIRM.LDT -999.250 LSRH.LOT CALI.LDT -999.250 GR.LOT -999.250 TENS.LOT MRES.LDT -999.250 HTEN.LDT -999.250 ENPH.CNL CFEC.CNL -999.250 CNEC.CNL -999. Z50 RCEFoCNL NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL CPTCoCNL -999.250 GR.CNL -999.250 NVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT IMPH.COR -999.250 SP.COR -999.250 SGR.COR HTEN.COR -999.250 DEPT. 2900.000 SFLU.DIL -999.250 ILM.OIL 5P.DIL -999.250 GR.DIL -999.250 TENS.DIE TT1.BHC -999.Z50 TT2.BHC -999.250 TT3.BHC GR.BHC -999.250 SP.BHC -999.250 TENS.BHC TENS.CML Z3tO.O00 SFLU.DTE -999.Z50 ILM.DTE 5P.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE CIOP.OTE -999.250 CIMPoDTE -999.250 IIRD. DTE IIRM.OTE -999.250 SGR.OTE -999.250 TENS.DTE MRES.DTE -999.250 HTEN.DTE -999.250 DT.SDT DTLN.SDT -999.250 DTLF.SOT -999.250 DTCO.SDT COHC.SOT -999.250 COHS. SOT -999.250 COST.SOT TTZ.SDT -999.250 TT3.SDT -999.Z50 TT~.SOT LTTZ.SDT -999.Z50 LTT3.SDT -999. Z50 LTT4.SOT -999.250 ENRA.CNL -999.250 RCEN.CNL -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 FVR.EPT -999.250 TENS.EPT -999.250 IOPH.COR -999.250 TENS.COR -999.250 ILO.OIL -999.250 DT.BHC -999.250 TT4.BHC -999.250 GR.CHL -999.250 ILD.OTE -999.250 IFRE.DTE -999.250 IIXD.DTE -999.250 MTEM.DTE -999.250 DTL.SDT -999.250 DTSM.SDT -999.2,50 -999.250 LTTI.SDT -999.250 SGR.SDT -999.250 CGR.NGT -999.250 WIN~.NGT -999.250 WSNG.NGT -999.250 DPHi.LDT -999.250 QLS.LDT -999.250 EL.LOT -999..Z50 LSHV.LDT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 ENRA.CNL -999.250 RCEN.CNL --999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 FVR.EPT -999.250 TENS.EPT -999.250 IDPH.COR -999.250 TENS.COR -999.250 ILO.OIL -999.250 OT.BHC -999.250 TT,6. BHC -999.'250 GR.CHL -999.25'0 ILD.OTE -999.250 IFRE.DTE -999.250 IIXD.DTE -999°250 MTEM.DTE -999.250 DTL.SDT -999.250 DTSM.SDT '-999.250 TT1.SDT -999.Z50 LTT1.SDT -999.250 SGR. SOT -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~0.094 -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 -9~9.250 -999.250 -999.250 -999.250 -999.250 -999.250 32.844 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 .IS 'TAPE VERIFICATION LISTING ~CHLUM~.ERGER ALASK~ COMPUTING CENTER 24-APR-1989 lB:07 TENS.SOT -999.250 HTEN.SOT -999.250 SGR.NGT THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT WZNG. NGT -999.250 W3NG.NGT -999.250 W4NG.NGT TENS.NOT -999.250 CS.NGT -999.250 HTEN.NGT RHOB.LOT -999.250 DRHO.LOT -999.250 PEP.LOT qSS-LDrT -999.250 LS.LgT -999.250 LU.LDT LITH.LDT -999.250 SSI.LDT -999.250 SS2.LDT SSHV.LDT -999.250 S1RH.LOT -999.250 LSRH.LDT CALI.LDT -999.250 GR.LDT -999.250 TENS.LOT MRES.LDT -999.250 HTEN.LDT -999.250 5NPH.CNL CFEC.CNL -999.250 CNEC.CNL -999.Z50 RCEF.CNL NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT MTEM.EPT -999.250 MRES.EPT -999.250 HTEN. EPT IMPH.COR -999.250 SP.COR -999.250 5GR.COR HTEN.COR -999.250 DEPT. Z800.000 SFLU.DIL -999.250 ILM.DIL ...... ,~?,_Q~L ..... ~999..2~ .......... GR.~L ....... 999-2S0 TEN-S-,.OtL TT 1. BMC -9'99' 250 TT2.BMC - 999. 250 TT3. BHC GR.BHC -999.250 SP.BHC TENS.CHL 2124.000 SFLU.DTE 5P.DTE -999.250 IDPH.OTE CIDP.DTE -999.250 CIMP.DTE I IRM. OTE -999. 250 SGR. OTE MRES.DTE -999.250 HTEN.OTE DTLN. SOT -999.250 OTLF.SDT COHC.SOT -999. ZEO COHS. SOT TTZ. SOT -999. 250 TT3. SOT L'TTZ. SOT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SOT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NOT -999. Z 50 CS. NOT RHOB.:LDT -999.250 ORHO.LOT QSS.LDT -999.2 50 LS.LOT LITH.LOT -999.250 SS!.LOT 5SHV.LDT -999.250 S!RH.LDT CALI.LDT -999. 250 GR. LOT MRES.LDT -999,,. 250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC. CNL -999. 250 GR. CNL GR.~PT -999.250 SA.EPT MTEM.EPT -999.Z50 MRES.EPT IMPH.COR -999. 250 5P.COR HTEN.COR -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999oZ50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPT. 2700.000 SFLU.DIL SP.OiL -999.250 GR.DIL TTI.BHC -999.250 TT2.BHC GR.§HC -999.250 SP.BHC -999.Z50 9.99~250 -999.250 -999.Z50 TENS.BHC -999.250 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD. DTE -999.250 -999.250 TENS.DTE -999.250 -999. Z50 DT.SDT -999.250 -999.250 DTCO.SDT -999.Z50 -999.250 COST.SOT -999.250 -999.250 TT4.$OT -999.250 -999. Z50 LTT4.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN. NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999.250 LU.LOT -999.250 -999.Z50 SS2.LOT '-999.250 -999.250 LSRH.LOT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 CGR.NGT WING.NGT WSNG.NGT DPHI.LOT QLS.LDT LL.LOT LSHV.LDT LURH.LDT MTEM.LOT ENRR.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.COR ILO.OIL DT-BHC TT4.BHC GR.CHL ILO.DTE IFRE.OTE IIX~.OTE MTEM.DTE OTL.SDT DTSM.SDT TT1.SDT LTT1.SOT SGR. SDT CGR.NGT WING.NGT WENG.NGT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC .CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR PAGE: -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -999.250 -999.250 -999.250 -999.250 -999.250 28.969 -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 ILM.DIL -999.250 ILD.DIL -999.250 -999.250 TENS.DIL -999.250 DT.BHC -999.250 -999.250 TT3.BHC -999.250 TT4.~HC -999.250 -999.250 TENS.BHC -999.250 GR.CHL 20.188 69 .IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 24-:~PR-1989 18:07 TENS.CHL 2134.000 SFLU.OTE -999.250 ILM.DTE SP. gTE -999.250 IDPH.DTE -999.250 IMPH.DTE CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE IIRM.DTE -999.Z50 SGRoDTE -999.250 TENS.gTE MRE$.DTE -999.250 HTEN.OTE -999.250 DT.SOT DTLN.SDT -999.250 OTLF.SOT -999. Z50 OTCO.SOT 5OHC.SDT -999.Z50 COHS.SOT -999.250 COST.SDT TTZ.SDT -999.290 TT3.SDT -999.2.50 TT4.SDT LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4. SOT TENS.EDT -999.250 HTEN.SDT -999.250 SGR.NGT THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT RHOB.LDT -999.Z50 DRHO.LOT -999. Z50 PEF.LDT LOT -999. Z50 LS.LOT -999. 250 LU.LDT LITH.LDT -999.250 SS1.LDT -999.250 SS2.LDT SSHVoLDT -999.250 SIRH.LDT -999.250 LSRH.LOT CALI.LDT -999.250 GR.LOT -999.250 TENS.LOT NRES.LDT -999.250 HTEN.LOT -999.250 ENPH.CNL CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL ~999-250 TNPH'-C-NL ~:~:Z'5~ NPOR'CNL -999'250 RC N'T°CNL -999,250 RCFT.C NL CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT GR.EPT -999.250 SA.EPT -999.250 CALI.EPT MTEM.~PT -999.250 MRES.EPT -999oZ50 HTEN.EPT IMPH.COR -999.Z50 SP.COR -999. 250 SGR CDR HTEN.CUR -999.250 ' DEPT. 2600.000 SFLU.DIL -999.250 ILN.DIL SP.DIL -999.250 GR.DIL -999.250 TENS.DIL TTI.BHC -999.250 TTZ.BHC -999.250 TT3.BHC [~R. BMC -999.250 SP.BHC -999.250 TENS.BHC TENS.CML 2150.000 SFLU.D'TE -999.250 ILM.DTE SP.DTE -999.250 IDPH.OTE -999.250 IMPH.DTE CIDP.DTE -999.250 CIMP.DTE -999.250 IIRO.OTE iIRM. DTE -'999.250 SGR.D'TE -999.250 TENS.DTE MRES.DTE -999.250 HTEN.DT5 -999.250 OT.SDT DTLN.SDT -999.250 DTLF.SDT -999.250 gTCO.SOT COHC.SDT -999.250 COHS.SDT -999.250 COST.SOT TTZoSOT -999.250 TT3.SOT -999.250 TT4.SOT LTTZ.SDT -999.Z50 LTT3.SDT -999.250 LTT4.SOT TENS.SDT -999.250 HTEN.SDT -999.250 SGR.NGT THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT WZNG.NGT '-999.250 W3NG.NGT -999.250 W4NG.NGT TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT RHOB.LDT -999.250 DRHOoLDT -999.250 PEF.LDT QS$.LDT -999.Z 50 LS.LDT -999. 250 LU.LDT LITH.LOT -999.250 SSl .LOT -999.250 SSZ.LOT SSHV.LDT -999.250 SIRH.LOT -999.250 LSRH.LDT CALro LD*T -999.250 GRoLDT -999.250 TENS.LD'T MRES.LDT -999.Z50 HTEN.LDT -999. 250 ENPH.CNL CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL NPMI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL NPOR.CNL -999.250 RCNT.CNL -999.Z50 RCFT.CNL CF'TC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 ILO.gTE -999.250 IFRE.OTE -999.250 IIXD.DTE -999.250 MTEM.DTE -999.250 DTL.SDT -999.250 DTSM. SOT -999.250 TT1.SDT -999.250 LTT1.SDT -999.250 SGR.SDT -999.250 CGR.NGT -999.250 W1NG.NGT -999.250 W5NG.NGT -999.250 DPHI.LOT -999.250 ~LS.LDT -999.250 LL.LDT -999.250 LSHV.LDT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 ENR~.CNL -999.250 RCEN.CNL '99'g; 250 -999.Z50 CNTC.CNL -999.250 FVR.EPT -999.250 TENS.EPT -999. 250 [DPM.COR -999.250 TENS.COR -999.250 ILO.OIL -999.250 DT.BHC -999.250 TT~.BHC -999.250 GR.CHL -999.250 ILO.gTE -999.250 IFRE.DTE -ggg.zso IIXD.OTE -999.250 MTEM. DTE -999.250 DTL.SDT -999.250 DTSM.SDT -999. 250 TT1. SD'T -999.250 LTT1.SDT -999.250 SGR.SDT -999.250 CGR.NGT -999.250 W1NG.NGT -999.250 W5NG.NGT -999.250 DPHI.LDT -999.250 QLS.LDT -999.250 LL.LDT -999. 250 LSHV.LDT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 ENRA.CNL -999.250 RCEN.CNL -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 FVR.EPT PAGE: 70 -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 ,~g.9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z5.656 -999.250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -9~9.250 -999.250 -999.250 -999~250 -999.2~0 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 -999.2~0 -999.250 -999.250 -999.290 -999.250 -IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASR~ COMPUTING CENTER 24-APR-1989 18:07 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.bOR -999.250 SP.COR -999.250 SGR.COR -999 250 HTEN.COR -999.250 ' DEPT. Z500.000 SFLU.DIL -999.250 ILM.DIL -999.250 SP.DIL -999.250 GR.D!L -999.250 TENS.DIE -999.250 TTI.BHC -999.250 TT2.BHC -999.250 TT3.BHC -999.250 GR.BHC -999.250 SP.BHC -999.250 TENS.BHC -999.250 TENS.CHL 223~.000 SFLU.DTE -999.250 ILM.OTE -999.250 SP.OTE -999.250 IOPH.DTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999. Z50 IIRD.DTE -999.250 IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MRES.DTE -999.250 HTEN.DTE -999.250 OT.SDT -999.250 DTLN.SDT -999.250 DTLF.SOT -999.250 gTCO.SOT -999.250 COHC.SDT -999.250 COHS.SOT -999.250 COST.SOT -999.250 TTZ.SDT -999.Z50 TT3.SOT -999.250 TT4.SOT -999.250 LTTZ.SOT -999.250 LTT3.SOT -999.250 LTT4.SDT -999.250 TENS.SDT -999.250 HTEN.SOT -999.250 SGR.NGT -999.250 THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 W2NG.NGT -999.Z50. W3NGoNGT -999.Z50 W.4NG'NGT 999.250 TENS*N:~ -999'.Z50 C$..NGT -999.250 HTEN'NGT -999'250 RHO~.LDT -999.250 ORHO.LDT -999.250 PEF.LDT -999.250 QSS.LDT -999.250 ES.LOT -999.250 LU.LDT -999.250 LITH.LDT -999.250 SSI.LOT -999.250 SS2.LDT -999.250 SSHV.LDT -999.250 S1RH.LOT -999.250 LSRH.LDT -999.250 CALI.LDT -999.250 GR.LDT -999.250 TENS.EDT -999.250 MRES.LDT -999.250 HTEN.LDT -999.250 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.Z50 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999. 250 NVR.EPT -999.250 GR'EPT -999.250 S4.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN. EPT -999.250 IMPH.COR -999.250 SP.COR '-999.250 SGR COR -999.250 HTEN.CUR -999.250 ' DEP'T. 2400.000 SFLU.OIL -999.250 ILM.DIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.DIE -999.250 TTI.SHE -999.250 TT2.BHC -999.250 TT3.BHC -999.250 GR.SHC -999.250 SP.BHC -999.250 TENS.BHC -999.25'0 TENS.CHL 2124.000 SFLU.OTE -999.250 ILM. DTE -999.250 SP. DTE -999.250 IDPH.D'TE -999.250 IMPH.DTE -999.250 CIDP.OTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DTE -999.250 SGR.DTE -999.250 TENS.D'TE -999.250 MRES.DTE -999.250 HTEN.D'TE -999.250 OT.SOT -999.2.50 D'TLN. SDT -999.250 OTLF.SOT -999.250 OTCO.SDT -999.250 COHC.SDT -999.250 COHS.SDT -999.250 COST.SOT '-999.250 TTZoSDT -999.250 TT3.SDT -999.250 TT4.SDT -999.250 LTTZ.SDT -999.250 LTT3.SOT -999.250 LTT4.SDT -999.250 TENS.SOT -999.250 HTEN.SOT -999.250 SGR.NGT -999.250 THOR.:NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 W2NGoNGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.250 TENS.NGT -999.250 CSoNGT -999.250 HTEN.NGT -999.25,0 RHUB.LDT -999.250 DRHO.LDT -999.250 PEF-LDT -999.250 TENS.EPT IOPH.COR TENS.COR ILO.OIL OT.3HC TT~.BHC GR.CHL ILO.gTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT W 5NG.N GT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM .LDT ENRA.CNL RCEN.CNL RTNR .CNL CNTC .CNL FVR.EPT TENS. EPT IDPH.CDR 'TENS. CDR ILD.gIL DT.SHC TT,~.SHC GR.CHL ILO.gTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SG~.SDT CGR.NGT WING.NGT WSNG.NGT DPHI .LDT QLS.LDT PAGE: 'TI -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 34.906 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999o25.-0 -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 Z5.063 -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 ,IS TAPE VERIFICATION LISTING i£tiLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: 72 '~SS.LOT -999.2 50 LITHoLDT -999.250 SSHV.LDT -999.250 CALI.LDT -999.250 MRES. LDT -999.250 CFIfC.CNL -999.250 NPHI.CNL -999.Z50 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.EPT -999.250 MTEM.EPT -999.250 IMPH.CQR -999.250 HTENoCOR -999.250 DEPT. 2500.000 SP.DIL -999.250 TT1.BHC -999.250 GR.BHC -999.250 TENS.CHL 2005.000 SP.DTE -999.250 CIDP.DTE -999. 250 MRES.DTE -999.250 OTLN.SDT -999.250 COHC.SDT -999.250 TTZ. SOT -999.250 LTTZ.SDT -999.250 TENS. SOT -999. 250 THOR. NGT -999. 250 WZNG.NGT -999.250 TENS.NGT -999.2 50 RHUB.LDT -999.250 QSS.LDT -999.250 LITH.LOT -999. 250 SSHV.LDT -999.2 50 CALI.LDT -999.250 MRES.LDT -999.250 CF:EC.CNL -999.2:50 NPHI.CNL -999.250 NPUR.CNL -999. 250 CFTC.CNL -999.25'0 GR.EPT -999.250 MTEM.EPT -999.250 IMPH.CUR -999.250 HTENoCQR -999.250 DEPT. 2200.000 SP.DIL -999.250 TT1.BHC -999o250 GR.OHC -999.250 TENS.CHL 2025.000 SP. DTE -999°250 CIDP.DTE -999.250 IIRM.OTE -999.250 MRES.DTE -999.250 LS.LDT SSI.LOT SIRH.LDT GR.LDT HTEN.LDT CNEC.CNL TNPH.CNL RCNT.CNL GR.CNL SA.EPT MRES.EPT SP.COR -999.250 LO.LOT -999.250 SSZ.LDT -999.250 LSRH.LOT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR SFLU.DIL -999. Z50 ILM. OIL GR.DIL -999.250 TENS.OIL TTZ.BHC -999.250 TT3.BHC SP.BHC -999.250 TENS.BHC SFLU.DTE -999.250 ILM.DTE [DPH.DTE -999.250 IMPH.DTE SGR.DTE -999'250 TENS':OTE HTEN.DTE -999.250 DT.SOT DTLF.SOT -999.250 DTCO.SDT COHSoSDT -999.250 COST.SDT TT3.SgT -999. Z50 TTa. SDT LTT3.SDT -999.250 LTT4.SDT HTEN.SgT -999.250 SGR.NGT POTA.NGT -999.250 UR~N.NGT W3NG.NGT -999.250 W4NG.NGT CS.NGT -999.250 HTEN.NGT ORHO.LDT -999.~50 PEF.LDT LS.LDT -999.250 LU.LDT SSI.LOT -999.250 SS2.LDT S1RH.LOT -999.250 LSRH.LDT GR.LDT -999.250 TENS.LOT HTEN.LOT -999.250 ENPH.CNL CNEC.CNL -999.250 RCEF.CNL TNPH.CNL -999.250 TNRA.CNL RCNT.CNL -999.250 RCFT.CNL GR.CNL -999.250 NVR.EPT SA.EPT -999.Z50 CALI.EPT MRES.EPT -999. Z50 HTEN.EPT SP.COR -9'99.250 SGR.COR SFLU.DIL -999.250 ILM.DIL GR.DIL -999.250 TENS.OIL T'TZ.BHC -999.250 TT3.BHC SP.BHC -999.250 TENS.BHC SFLU.OTE -999.250 ILM.OTE IDPH.DTE -999.250 IMPH.O'TE CIMP.DTE -999.250 IIRD.DTE SGR.DTE -999.250 TENS.DTE HTEN.DTE -999.250 DT.SOT -999.250 LL.LDT -999.250 LSHV.LDT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 ENRA.CNL -999.250 RCEN.CNL -999.250 RTNR.CNL -999.250 CNT£.CNL -999.250 FVR.EPT -999.250 IENS.EPT -999.250 IDPH.COR -999.250 TENS.CDR -999.250 ILO.OIL -999.250 DT.BHC -999.250 TT4.BHC -999.250 GR.CHL -999.250 ILO.gTE -999.250 IFRE.DTE - 250 I -999.250 MTEM. OTE -999.250 DTL. SDT -999.250 DTSM.SDT -999.250 TT1.SDT -999. 250 LTT1. SOT -999.250 SGR.SDT -999.250 CGR.NGT -999.250 WING.NGT -999.250 WENG.NGT -999.250 DPHI.LOT -999.250 QLS.LDT -999.250 LL.LDT -999.250 LSHV.LOT -999.250 LURH.LDT -999.250 MTEM.LDT -999.250 ENRA.CNL -999.250 RCEN.CNL -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 FVR.EPT -999.250 TENS.EPT -999.250 IDPH.COR -999.250 TENS.COR -999.250 ILO.OIL -999.250 DT.BHC -999.250 TT~.BHC -999.250 GR.CHL -999.250 ILO.gTE -999.250 IFRE.OTE -999.250 [IXD.DTE -999.250 MTEM.DTE -999.250 gTL.SDT -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 21.234 -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 24.578 -999.250 -999.250 -999.250 -999.250 -999.250 .I5 TAPE VERIFICATION LISTING ~CHLUM§ERGER ALASKA COMPUTING CENTER DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999. 250 COHS.SDT TTZ. SOT -999.250 TTS. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999. 250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS. NGT -999.2 50 CS.NGT RHOB.LDT -999.Z50 DRHO.LDT QSS.LDT -999. 250 LS.LDT LITH. LOT -999. 250 S S1.LDT SSHV.LDT -999. 250 SIRH.LOT CALI.LUT -999. 250 GR.LDT MRES.LOT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPUR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR. CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT I M P H. C O R -~ .Z50 S,P. C,OR HTENiCOR -99:9':, ZSO DEPT. 2100.000 SFLU.DEL SP. OIL -999. 250 GR.OIL TT1.BHC -999.250 TT2.BHC GR.BHC -999.250 SP.BHC TENS.CHL 1935.000 SFLU.OTE SP.DTE -999.250 IDPH.DTE CIDP.OTE -999.250 CiMP.DTE IIRM. DTE -999. 250 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SOT COHC.SDT -999.250 COHS.SOT TTZ.SOT -999. 250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS,SDT -999.250 HTEN.SOT THUR.NGT -999,250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999,250 C S.NGT RHOB..LDT -999.250 DRHO.LOT QSS.LDT -999. 250 LS.LOT LITH.LDT -999. 250 SS1. LDT SSHV.LDT -999.2:50 SIRH.LDT CALl. LOT -999. 250 'GR.LDT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999. 250 CNEC.CNL NPHI.CNL -9'99.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC. CNL -999. Z 50 GR. CNL GR. EPT -999.250 SA, EPT MTEM.EPT '-999.250 MRES.EPT IMPH, COR -999' 250 SP.CDR H'TEN.CUR -999.Z50 24-APR-lO89 18:07 -999.250 DTCO.SDT -999.250 COST.SDT -999.250 TT4.SDT -999.250 LTT4.SDT -999.250 SGR.NGT --999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU. LDT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999. 250 RCFT.CNL -999,250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250! SGR'COR -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 ILM.DIL -999.250 -999o250 TENS.DIL '-999. ZSO -999.250 TT3.BHC -999.250 -999.250 TENS.BHC -999.250 -999.250 ILM,DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 DT. SOT -999. 250 -999.250 OTCO.SDT -999.250 -999.250 COST. SOT -999.250 -999,250 TT4.SOT -999.250 -999.250 LTT4.SDT -999,250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEF.LDT --999.250 -999. 250 tU. LOT -999. 250 -999. 250 SSZ.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.25,0 -999,250 ENPH.CNL -999.250 -999. 250 RCEF. CNL -999,250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999,250 CALIoEPT , -999.250 -999.Z50 HTEN.EPT -999.Z50 -999. Z50 SGR.COR -999.250 DTSM. SDT TT1.SDT LTTI.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.CDR TENS,CDR ILO.OIL DT.BHC TT~.BHC GR.CHL ILD.DTE IFRE,DTE IIXD,DTE MTEM.DTE DTL.SDT DTSM. SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR,CNL CNTC,CNL FVR.EPT TENS.EPT IDPH,COR TENS,COR PAG,:_: 73 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.2~0 -999.250 -999,250 -999,250 -999.250 33.1BB -999,250 -999.250 '-999,250 -999..Z50 -999.Z50 -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 .iS TAP~ VERIPICAIION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 24-,{PR-1989 18:07 '?4 DEPT. SP.DIL TT1.BHC GR.BHC TENSoCHL SP.DTt CIDP.DTE IIRM.DTE MRES.DTE DTLN.SDT CDHC.SDT TTZ.SDT -LTT2.SDT TENS.SOT THOR.NGT WZNG.NGT TENS.NGT RHOB.LDT QSS.LOT LITH.LDT 5 SHY. LOT CALI.LDT MRES.LDT CFEC.CNL NPHI.CNL NPOR.CNL CFTC.CNL GRoEPT MTEM.EPT IMPH.COR HTEN.COR DEPT. SP.DIL TTI.§HC GR.~HC TENS.CHL SP.OTE CIDP.OTE IIRM.DTE MRES.DTE DTLN. SDT COHC.SDT TTZ.SD'T LTTZ.SDT TENSoSDT THOR.NGT W2NG.NGT TENS.NGT RHOB.LDT QSS.LDT LITH.LDT SSMV.LOT CALI.LDT ZO00.O00 SFLU.OIL -999.250 GR.DIL -999.250 TTZ.BHC -999.250 SP.BHC 1940.000 SFLU.DTE -999.2.50 IDPH.DTE -999.250 CIMP.DTE -999.250 SGR.DTE -999.250 HTEN.DTE -999.250 DTLF.SDT -999.250 COHS.SOT -999.250 TT3.SDT -999-2'~'' .... SOT .... -999.250 HTEN.SDT -999.250 POTA.NGT -999.250 W3NG.NGT -999.250 CS.NGT -999.250 DRHO.LOT -999.250 LS.LDT -999.250 SS1.LDT -9::99.250 S I~ RH' L D'T -999.250 GR.LDT -999.Z50 HTEN.LOT -999.250 CNEC..CNL -999.250 TNPH.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 SA.EPT -999. 250 MRES. EPT -999.250 SP.COR -999.250 1900.000 -999.250 -999.250 -999.2 50 1805.000 -999. Z 50 -999.250 -999.250 -999. Z50 -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 SFLU.DIL GR.DIL T T 2. B HC SP.BHC SFLU.DTE IDPH.DTE CIMP.DTE SGR .DTE HTEN.DTE DTLF.SDT CDHS.SDT IT).SDT LTT3. SOT HTEN.SDT PDTA .NGT W3NG.NGT CS.NGT DRHO.LOT LS .LOT SS1.LOT S1RH.LDT GR.LOT -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. Z50 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999'250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. Z50 -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 ILM.DIL TENS.OIL TT3.BHC TENS.BHC ILM.DTE IMPH.DTE IIRD.DTE TENS.DTE DT.SDT DTCO.SDT COST.SOT TT~.SDT ---t-l'~ SGR .NGT URAN.NGT W4NG.NGT HTEN.NGT PEF.LDT LU.LDT SS2.LOT LSRH.LDT TENS .LOT ENPH.CNL RCEF.CNL 'TNRA. CNL RCFT.CNL NVR.EPT CALI.EPT HTEN'EPT SGR.COR ILM'DIL TENS.OIL TT3.BHC TENS.BHC ILMoDTE IMPH.DTE IIRO.DTE TENS.DTE DT. SOT DTCO. SOT COST.SOT TT4.SOT LTT4oSDT SGR. NGT URAN.NGT W4NG.NGT HTEN.NGT PEF.LDT LU.LDT SSZ .LOT LSRH.LDT TENS.LOT -999.250 ILO.OIL -999,250 OT.BHC -999.25D TT~.BHC -999.250 GR.CHL -999.250 ILD.DTE -999.250 IFRE.DTE -999.250 IIXO.OTE -999.250 MTEM.DTE -999.250 DTL.SDT -999.250 DTSM.SDT -999.250 TT1.SDT -999.250 -999.250 -999.250 16.719 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LTTI.SDT -999.250 -999.250 ...... -S-GR-~ .............. '999.Z50 -999.250 CGR.NGT -999.250 -999.250 W1NG.NGT -999.250 -999.250 WSNG.NGT -999.250 -999.250 DPHI.LDT -999.250 -999.Z50 QLS.LDT -999.250 -999.250 LL.LDT -999.250 -999.Z50 LSHV.LDT -999.Z50 -999.250 LURH.LDT -999.Z50 -999.250 MTEM.LDT -999.250 -999.250 ENRA.CNL -999.Z50 -999.250 RCEN.CNL -999.250 -999.250 RTNR.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 FVRoEPT -999.250 -999.Z50 TENS.EPT -999.250 -999.250 IDPH.COR -999.250 -999.250 TENS.COR -999.250 -999.250 ILO.OIL -999.250 OT.BHC -999,250 TT4.BHC -999,250 GR.CHL -999.250 , ILO.DTE -999.250 IFRE.DTE -999,250 IIXD.OTE -999,250 MTEM. DTE -999.250 DTL.SDT -999.250 DTSM. SDT -999.Z50 'TT1. SDT -999,250 LTT1.SDT -999,250 SGR.SDT -999.250 CGR.NGT -999,250 WING.NGT -999,250 W5NG.NGT -999.250 DPHI.LDT -999,250 QLS.LDT -999. 250 LL.LDT -999,250 LSHV,LDT -999,250 LURH.LDT -999.250 MTEM.LDT -999.250 -999.250 -999.250 19.484 -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 .IS TAPE VERIFICATION LISTING ~CHLUM§ERGER ALASKA COMPUTING. CENTER 24-APR-1989 18:07 MRES.LDT -999.250 HTEN.LDT -999.250 ENPH.CNL -999.250 CFEC.CNL -999.Z50 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999. 250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -999 250 SGR CDR -999 250 HTEN.CDR -999.250 ' ' - DEPT. 1HO0.O00 SFLU.DIL -999.250 ILM.DIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.DIL -999.250 TT1.BHC -999.250 TT2.BHC -999.250 TT3.BHC -999.250 GR.BHC -999.250 SP.BHC -999.250 TENS.BNC -999.250 TENS.CML 1755.000 SFLU.DTE -999.250 ILM.DTE -999.250 SP.DTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DTE -999.250 SGRoDTE -999.250 TENS.DTE -999.250 MRESoDTE -999.250 HTEN.DTE -999.250 DT.SOT -999.250 DTLN.SDT -999.250 OTLF.SOT -999.250 OTCO.SOT -999.250 CUHC.SOT -999.250 CONS.SOT -999.250 COST.SOT -999.250 TTZ.SDT -999.250 TT3'SOT -999.250 TT4.SDT -999.250 LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4.SDT -999.250 TENS.SOT -999.250 HTENoSDT -999.250 SGR.NGT -999.250 THOR.NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 WZN~.NGT -999.250 W3NG.NGT -999.Z50 W4NG.NGT -999.250 TENS.NGT -999.250 CS.NGT -999.250 HTEN.NGT -999.250 RHOS.LDT -999.250 ORHO.LDT -999.250 PEF.LDT . -999.250 qSS.LD'T -999.250 LS.LDT -999.250 LU.LDT -999.250 IITH.LOT -999.250 SS1.LDT -999.Z50 SS2-LDT -999.250 SSHVoLDT -999.250 SIRH.LDT -999.250 LSRH.LOT -999.250 CALI.LOT -999.'250 GR.LOT -999.250 TENSoLDT -999.250 MRES.LDT -999.250 HTEN.LDT -999.250 ENPH.CNL -999.250 CPEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.2:50 NPHI.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.250 GR.EPT -999.250 SA.EPT -999.250 CALI.EPT -999.250 MTEM.EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.CDR -'999.250 SGR COR -999.250 HTEN.COR -999-250 DEPT. 1700.000 SFLU.OIL -999.250 ILM.DIL -999.250 SP.DiL -999.Z50 GR.DIL -999.250 TENS.OIL -999.250 TT1.BHC -999.250 TTZ.BHC -999.250 TT3.BHC -999.250 GR.BHC -999.25,0 SP.BHC -999.250 TENS.BNC -999.250 TENS.CHL 1755.000 SFLU'DTE -999.250 ILM.DTE -999.250 SP.DTE -999.2.50 IDPH.DTE -999.250 IMPH.DTE -999.250 CIDP.DTE -999.250 CIMP.DTE -999.250 IIRD.DTE -999.250 IIRM.DTE -999.250 SGR.DTE -999.250 TENS.DTE -999.250 MRES.DTE -999.250 HTEN.DTE -999.2:50 DT.SDT -999.250 DTLN.SDT -999.250 DTLF.SDT -999.250 gTCO.SOT -999.250 COHC.SDT -999.250 COHS.SDT -999.2:50 COST.SOT -999.250 TTZ. SDT -999.250 TT3.SDT -999.250 TT4.SDT -999.250 LTTZ.SDT -999.250 LTT3.SOT -9'99. 250 ET'T4. SOT -999.250 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPN.COR TENS.COR ILO.OIL DT.BNC TT4.BHC GR.CHL ILO.OTE IFRE.DTE IIXO.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SOT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LOT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTCoCNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.gTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT PAGE: '75 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 26.922 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2:50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2:50 -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 23.32:8 -999.250 -999. 250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 'TAPE VERIFICATION LISTING ~CHLUM~ERGER ~L~SKt COMPUTING CENTER 24-~PR-1989 1B:O7 '76 TENS.SOT -999.250 HTEN. SOT THOR.NGT -999.250 POTA.NGT WZNG. NGT -999.250 W3NG.NGT TENS. NGT -999. Z 50 CS.NGT RHOB.LDT -999. Z 50 ORHO.LOT QSS.LOT -999. ZSO ES .LOT LITH. LDT -999. Z 50 S SI.LOT SSHV.LDT -999. 250 SIRH. LOT C~LI.LDT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999. Z 50 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.2 50 GR.CNL GR.EPT -999.250 Sa.EPT MTEM.EPT -999.Z50 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 1600.000 SFLU.DIL SP.DIL -999.Z50 GR.OIL TT1 MC -999.250' T T 2' BMC GR.BMC -999.250 SP.BHC TENS.CML 1745.000 SFLU.DTE 5P.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 C'IMP.DTE IIRM.DTE -999.250 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ. 5DT -999. 250 TT3. SDT LTTZ.SDT -999.250 LTT3.SOT IENS.SUT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999. Z 50 CS. NGT RHUB.LD'T -999.250 DRHO.LOT qSS.LDT -999. 250 ES.LDT LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999. 250 GR. LOT MRES.LDT -'999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.Z50 RCNT.CNL CFTC.CNL -999. Z 50 GR. CNL GR.EPT -999.250 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999. Z 50 SP-COR HTEN. COR -999.250 DEP1. 1500.000 SFLU.DIL SP.DIL -999.250 GR.DIL TTI.~HC -999.250 TTZ.BHC GR.SMC -999.250 SP.BHC -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' 2:5:0 -999.250 -999.250 -999.250 -999. Z 50 -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.Z50 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 SGR.NGT URAN.NGT W4NG.NGT HTEN.NGT PEF.LOT LU.LDT SS2 .LOT LSRM.LDT TENS.LDT ENPH.CNL RCEF.CNL TNRA.CNL RCFT.CNL NVR.EPT CALI.EPT HTEN.EPT SGR.COR ILM.DIL TENS. OIL TT3. BHC TENS.BHC ILM.DTE IMPH.OTE IIRD.OTE TENS .DTE OT. SOT DTCD.SDT COST.SDT TT4oSDT LTT4.SDT SGR.NGT URAN.NST W4NG.NGT HTEN.NGT PEF.LDT LU.LDT SS2.LDT LSRH.LOT TENS-LOT ENPM.CNL RCEF.CNL TNRA.CNL RCFT.CNL NVR.EPT CALI.EPT HTEN.EPT 5GR.COR ILM.DIL TENS.DIL TT3.BHC TENS.SHE -999.Z50 -999.250 -999.Z50 -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 -99 9. 250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.25{] -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.Z50 -99 9.250 -999. ZSO -999.250 CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS .LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENR~ .CNL RCEN.CNL RTNR. CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BMC TT4.SHC GR.CHL ILO.DTE IFRE.OTE IIXO.OTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRAoCNL RCEN.CNL R'TNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.SHC TT~.SHC GR.CHL -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 Z0.016 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -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 34.625 .IS TAPE VERIPICATION LISTING iCHLUM§ERGER ALASK.~ COMPUTING CENTER TENS.CHL 1670.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP. DTE -999.250 CIMP. DTE IIRM. DTE -999. ZSO SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN. SOT -999.2 50 DTLF. SOT COHC. GDT -999.250 COHS.SDT TTZ.SOT -999. 250 TT3. GDT LTTZ.SDT -999.250 LTT3.SOT TENS. SOT -999. 250 HTEN. SOT THUR. NGT -999. 250 POTA. NGT W2NG. NGT -999. 250 W3NG. NGT TENS. NGT -999.250 CS.NGT RHOB.LDT -999.250 DRHO.LOT QSS.LDT -999. 250 LS.LDT LITH. LOT -999. 250 S S1.LDT SSM¥.LDf -999.250 SIRH.LDT CALI.LDT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH-CNL NPOR'CNL -999'250 RCNT'CNL CFTC.CNL -999. 250 GE. CNL GR. EPT -999. 250 SA. EPT MTEM. EPT -999.250 MRES.EPT I MPH.C'OR -999.2 50 SP.COR HT EN.CUR -999.2. 50 DEPT. 1~00.000 SFLU.DIL SP.DIL -999.Z50 GR.DIL TT1.BHC -999.250 TT2.BHC GR. 8HC -999. Z50 SP. BHC TENS.CHL 1590.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM. DTE -999. Z 50 SGR.DTE MRES.DTE -999.250 HTEN.DTE DTLN. SOT -999. 250 DTLF. SOT COHC. SDT -999.250 COHS.SDT TTZ. SDT -999. Z 50 TT3. SOT LTTZ.SUT -999.Z50 LTT3.SOT TENS.SOT -999.250 HTENoSDT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENS.NGT -999. 250 CS.NGT RHOB.LOT -999.250 DRHO.LDT QSS.LDT -999. 250 LS.LDT LITH.LOT -999. 250 SS1. LOT 5SHV.LDT -999.250 SIRH.LDT CALI. LDT -999.2 50 GR.LDT MRES.LDT -999.250 HTENoLDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL 24-APR-19B9 18:07 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.OTE -999.250 -")99. 250 DT. SOT -999. ;250 -999.250 DTCO.SOT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4.SDT -999.250 -999. 250 SGR.NGT -999.250 -999.250 UR~N.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 MTEN.NGT -999.250 -999.250 PEF.LDT -999.250 -999.250 LU.LDT -999. 250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LDT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999o250 TNRA.CNL -999. 250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 -999.250 ILM.DIL -999.250 TENS.DIL -999.250 TT3.BHC -999.Z50 TENS.BHC -999.250 ILM. DTE -999.250 IMPH.DTE -999.250 IIRD.DTE -999. 250 TENS.DTE -999. 250 DT. SOT -999.250 DTCO.SOT -999.250 COST.SOT -999.250 TT4.SDT -999.250 LTT4. SOT -999.250 SGR.NGT -999.250 UR~N.NGT -999.250 W4NG. NG'T -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU..LDT -999.2.50 SS2.LDT -999.250 LSRH.LDT -999.250 TENS.LDT -999.250 ENPH.CNL -999.2:50 RCEF.CNL -999. 250 TNRA.CNL -999. 250 RCFT.CNL -999. 250 NVR.EPT -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2S0 -999.250 -999.250 -999.2.50 -999.250 -999.2.50 '-999.250 --999.250 -999'250 -999.2.50 -999. 250 -999.250 -999.250 -999.2. 50 -99 9.250 - 99 9.2.50 -999.250 ILD. DTE IFRE.DTE IIXD.DTE MTEM.DTE OTL.SOT DTSM. SOT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL .LOT LSHV.LDT LURH.LDT MTEM.LDT ENRA .CNL RCEN.CNL RTNR .CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT. 5HC TT4. BHC GR. CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR .NGT W1NG.NGT W ENG. NGT DPHI.LDT @LS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT PAGE: 77 -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 22.825 -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 -9'99.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 .IS 'TAPE VERIFICATION LISTING ~CHLU~BERGER ALASKA COMPUTING CENTER GRoEPT -999.250 ' S~.EPT MTEM.EPT -999.Z50 MRESoEPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 1300. 000 SFLU. OIL SP.DIL -999. 250 GR.DIL TT1. BHC -999. 250 TT2. BMC GR.BHC -999.250 SP.BHC 1ENS.CHL 1500.000 SFLU.DTE SP. DTE -999.250 IOPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM. OTE -999. Z50 SGR. DTE MRES.DTE -999.250 HTEN.OTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SOT TT2. SOT -999.2 50 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR.NGT -999.250 POTA.NGT WZNGoNGT -999.250 W3NG.NGT TENS. NG:T - 999.250 CS ' N G T R HOI:f,. LOT -999.250 DRHO.LDT QSS.LDT -999.250 ES.LOT L ITH.LDT -999. 250 SS1. LOT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999.250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.'CNL -999. 250 CNECoCNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.Z 50 SR.CNL GR.EPT -999.250 SA.EPT MTEM. EPT -999.250 MRES.EPT I MPH.COR -999.2 50 SP.COR HTENoCOR -999. 250 DEPT. 1200.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1. BHC -999.250 TTZ.BHC GR. ~HC -999. Z 50 SP. BHC TENS.CHL 1~35.000 SFLU.DTE SPoDTE -999.250 IDPH.OTE CiOP.DTE -999.250 CIMP.DTE I IRM. DTE -999. Z 50 SGR. DTE MRES.DTE -999.Z50 HTEN.DTE DTLN.SDT -999.250 gTLP.SDT COHC. SOT -999.250 COHS.SOT TTZ. SDT -999. Z50 TT3. SDT LTTZ.SDT -999.Z50 LTT3.SDT TENS.SOT -999.250 HTEN.SOT THOR.NGT '-999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999.250 CS. NGT RHOB. LD'T -999.250 ORHO.LDT 2~+-APR-1989 1B:07 -999.250 CALI.EPT -999. 250 HTEN. EPT -999.250 SGR.COR -999.250 ILM.OIL -999.250 TENS.OIL -999.250 TT3.BHC -999.250 TENS.BHC -999.250 ILM.OTE -999.250 IMPH.DTE -999.250 IIRO.DTE -999.250 TENS.DTE -999.250 DT.SDT -999.250 OTCO.SDT -999.250 COST.SDT -999. 250 TT4. SOT -999.250 LTT~.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250. W~NG.NGT -'999'250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SSZ.LOT -999.250 LSRH.LDT -999.250 TENS.LOT -999.Z50 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRAoCNL -999.Z50 RCFT.CNL -999.250 NVR.EPT -999.250 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR -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 ILM.DIL -99'9.250 -999.250 TENS.OIL -999.250 - 999.2'50 TT3.BHC -999. 250 -999.250 TENS.BHC -999.250 -999.250 ILM.DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.OTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 DT. SOT -999. 250 -999. 250 DTCO. SOT -999' 250 -999.250 COST.SDT -999.250 -999.250 TT4.SDT -999.250 -999. 250 LTT4. SOT -999. 250 -999.250 5GR.NGT -999.250 -999.250 URAN.NGT -999.250 -999. 250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.Z50 -999.250 PEI=.LDT -999.250 TENS.EPT IDPH.COR TENS.COR ILO.DIL DT.BHC TT4.BHC GR.CHL ILO.DTE IFRE.DTE IIXD.OTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTTI.SDT SGR. SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT ~LS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL R'TNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILO.OIL DT.BHC TT4.~HC GR.CHL ILD.DTE IFRE.DTE IIXO.DTE MTEM.OTE DTL.SDT DTSM.SDT TT1.SDT LTTI.SOT SGR.SDT CGR.NGT WING.NGT WENG.NGT OPHI.LDT QLS.LDT PAGE' -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 17.844 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -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 28.953 -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 78 ,IS TAPE VERIFICATION LISTING ;CHLUM~ERG~R ~LASKA COMPUTING CENTER 2~-APR-1989 18:07 PAGE: 79 QSE.LOT -999.2 50 LS.LOT LITH.LDT -999. Z 50 S SI.LDT SSHV.LDT -999. ZEO SIRH.LOT CALI.LDT -999. 250 GR.LDT MRES. LOT -999.250 HT EN.LOT CFEC.CNL -999.Z50 CNEC.CNL NPHI.CNL -999.Z50 TNPH.CNL NPOR. CNL -999. Z 50 RCNT.CNL CFTC. CNL -999. Z 50 GR.CNL GR.EPT -999.250 SA.EPT MTEM. EPT -999. 250 MR ES. EPT IMPH.COR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 1100. 000 SFLU. Oil SP.OIL -999. 250 GR.DIL TT1. BHC -999.250 TT2. BHC GR.BHC -999.250 SP.BHC TENS.CHL 1370.000 SFLU.DTE SP.OTE -999.Z50 IOPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM'DTE -999- 250 SGR'OTE MRES.DTE -999.250 HTEN.DTE DTLN.EDT -999.Z50 OTLF.SOT COHC.SDT -999.250 COHS.SDT TTZ. SDT -999.250 TT3.SDT LTTZ.SDT -999.Z50 LTT3.SOT lENS.SOT -999.250 HTEN.SOT THOR. NGT -999. 250 POTA. NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999.2 50 CS. NGT RHOB.LOT -999.250 ORHO.LOT QSS.LDT -999.2. 50 ES .LOT LiTH. LDT -999. 250 SS1.LOT 5SHV.LDT -999.Z50 SIRH.LOT C~LI.LDT -999. 250 GR.LDT MRES.LOT -999. 250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.Z50 TNPH.CNL NPOR.CNL -999.250 RCNToCNL CFTC.CNL -999. 250 GR.CNL GR. EPT -999.2 50 SA. EPT MTEM. EPT -999.Z50 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN.COR -999.250 DEPT. 1000.000 SFLU.OIL SP.OIL -999.Z50 §R.OIL 'TTI.BHC -'999.Z 50 TTZ. BHC GR.BHC -999.250 SP.BHC TENS.CHL 13Z5.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.DTE -999. Z 50 SGR. DTE MRES.DTE -999.Z50 HTEN.DTE - 999. Z50 LU.LDT -999. ZEO -999.250 SS2.LDT -999.Z50 -999.Z50 LSRH.LDT -999.250 -999.250 TENS.LDT -999.250 -999. ZEO ENPH.CNL -999.250 -999.Z50 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.Z50 -999.Z50 RCFT.CNL -999.250 -999.Z50 NVR.EPT -999.250 -999.Z50 CALI.EPT -999.Z50 -999.250 HTEN.EPT -999.Z50 -999.250 SGR.COR -999.250 -999.Z50 ILM.OIL -999.250 -999.Z50 TENS.DIL -999.250 -999.250 TT3.BHC -999.250 -999.Z50 TENS.BHC -999.250 -999.Z50 ILM.OTE -999. Z50 -999. Z50 IMPH.DTE -999.25-0 -999oZ50 IIRD.DTE -999.250 -999' Z 50 .TENS. DTE -99 9' 2 SO -999. 250 DT.SOT -999. Z50 -999.250 DTCO.SOT -999.250 -999.Z50 COST.SDT -999.250 -999.250 TT4.SDT -999.250 -999.Z50 LTT4.SOT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.Z50 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.Z50 -999.Z50 PEF.LDT -999.250 -999.Z50 LU.LDT -999.Z50 -999.Z50 SS2.LDT -999.250 -999.250 LSRH.LOT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999. Z50 RCEF.CNL -999.250 -'999. Z50 TNRA.CNL -999. Z50 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.Z50 -999.Z50 CALI.EPT -999.2-50 -999.Z50 HTEN.EPT -999.250 -999.Z50 SGR.COR -999.250 -999.Z50 ILM.DIL -999.Z50 -999.250 'TENS.OIL -999.250 -999.250 TT3.BHC -999.Z50 -999.250 TENS.BHC -999.250 -999.250 ILM.DTE -999.250 -999.Z50 IMPH.DTE -999.250 -999.250 IIRO.DTE -999.250 -999.250 TENS.OTC -999.250 -999. 250 OT.SDT -999.250 LL.LOT LSHV.LDT LURH.LOT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.COR ILO.OIL OT.BHC TT4.BHC GR.CHL ILO.OTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SD'T SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCENoCNL RTNR.CNL, CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR IL~.DIL DT.~HC TT4.~HC GR.CHL ILD.DTE IFRE.OTE · IIXO.DTE MTEM.DTE DTL.SDT -999.250 -999.250 -999.Z50 -9~9.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 39.6Z5 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.Z50 --999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.250 30.203 -999.Z50 -999.250 -999.250 -999.250 -999.250 .I5 TAPE YERIFICATION LISTING ~CHLUMBERGER ALASKA COMPUTING CENTER DTLN.SDT -999.2.50 DTLF.SDT COHC.SDT -999.250 COHS.SOT TTZ. SOT -999.250 TT3o SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SOT I'HUR.NGT -999,250 POTA,NGT WZNG.NGT -999,250 W3NG.NGT TENS.NGT -999.250 CS.NGT RHDB.LDT -999.250 ORHO.LDT QSS.LDT -999,250 LS.LDT L ITH,LDT -999. 250 S S1,LOT SSHV.LDT -999,250 S1RH.LDT CALI.LDT -999.250 GR.LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPH[.CNL -999.250 TNPH.CNL NPOR,CNL -999,250 RENT,CNL CFTC.CNL -999,250 GR.CNL GR.EPT -999,250 SA.EPT MTEM. EPT -999.250 MRES.EPT IMPH,COR -999,2:50 SP,COR HTEN' COR -99'9 ' 2'50 DEPT. 900.000 SFLU.DIL SP.DIL -999.250 GR.DIL TT1, BHC -999, Z50 TT2, BHC GR.BHC -999.250 SP.BHC TENS.CML 1240.000 SFLU.DTE SP.DTE -999,250 IDPH.DTE CIDP.DTE -999.250 CIMP.OTE I IRM.DTE -999. 250 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SOT TTZ,SDT -999,250 TT3, SOT L'fTZ,SDT -999.250 LTT3.SDT TENS.SDT -999.250 HTEN.SOT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS. NGT -999.250 CS. NGT RHOB.LDT -999.250 gRHO.LDT q, SS.LD'T -999. 250 LS.LDT LITH.LOT -999. 250 SS1.LOT SSHV,LDT -999.250 S1RH.LDT CAL[.LDT -999.250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -9'99,2.50 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999. 250 GR.CNL GR.EPT -999,250 SA.EPT MTEM. EPT -999.250 MRESoEPT IMPH.COR -999. Z 50 SP. COR HTENoCOR -999.250 24-APR-19B9 lB:O? -999.250 DTCO,SDT -999.250 -999.250 COST,SOT -999.250 -999,250 TT4.SDT -999,250 -999. Z50 LTT4.SOT -999. Z50 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT --999.250 -999.250 W4NG.NGT -999.250 -999.Z50 HTEN.NGT -999.250 -999,250 PEF.LDT -999.250 -999. 250 LU. LOT -999.250 -999,250 SS2.LDT -999,250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999,250 ENPH.CNL -999,250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999,250 RCFT.CNL -999.250 -999,250 NVR,EPT -999,250 -999,250 CALI.EPT -999,250 -999.250 HTEN.EPT -999.250 -999,250 SGR,COR -999,250 -999,250 ILM.DIL --999,250 -999,250 TENS.OIL -999,250 -999.250 TT3,BHC -999.250 -999,250 TENS.BHC --999,250 -999,250 ILM.DTE -999,250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.OTE -999.250 -999.250 TENS.DTE -999.250 -999.250 DT. SOT -999. 250 -999,250 DTCOoSOT -999,250 -999.Z50 COST,SOT -999.250 -999.250 TT4.SDT -999.250 -999.250 LTT4.SDT -999.250 -999. 250 SGR.NGT -999,250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 MTEN.NGT -999.250 -999,Z50 PEF.LDT -999.250 -999. 250 LU.LDT -999. 250 -999.250 SS2,LDT -999.250 -999.250 LSRH.LDT -999.250 -999. 250 TENS.LDT -999.250 -999,250 ENPH.CNL -999,250 -999,250 RCEF.CNL -999,250 -999.250 TNRA.CNL -999.250 -999. 250 RCFT.CNL -999.250 -999.250 NVR. EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999. ZSO SGR.COR -999.250 DTSM.SDT TT1 .SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA .CNL RCEN.CNL RTNR.CNL CNTC .CNL FVR.EPT TENS.EPT IDPH.COR TEN$iCOR ILD.DIL DT.BHC TT4.BHC GR.CHL ILO. DTE IFRE.OTE IIXO.OTE MTEM.OTE DTL.SDT D'TS M. SDT TTI,SDT LTT1,SOT SGR.SOT CGR.NGT W 1 NG. NG'T WSNG.NGT DPHI.LDT QLS. LD'T LL .LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL C NTC. CNL FVR.EPT TENS. EPT IDPH.CDR TENS.COR PAGE: -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 ZZ.063 -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 -919.250 8O TAPE VERIPIC~TION LISTING iCHLUMBERGER ALaSK~ COMPUTING CENTER Z4-~PR-1989 lt:07 PAGE: DEPT. 800.000 SFLU.DIL SP.DIL -999.250 GR.DIL TI1. BHC -999. Z 50 TTZ. BHC GR. BHC -999. Z 50 SP. BHC T ENS.CML 1190. 000 SFLU. DTE SP. DTE -999. 250 [DPH.DTE C IDP. DTE -999.250 CI MP. DTE IIRM.DTE -999. 250 SGR.OTE MRES.DTE -999.250 HTEN.DTE DTLN. SOT -999.250 DTLF. SOT CDHC.SDT -999.250 CDHS.SDT TTZ. SOT -999. Z 50 TT3. SOT LTT2. SOT -999. 250 LTT3. SOT TENS. SOT -999. 250 HTEN. SOT THOR. NGT -999. 250 POTA. NGT W2NG.NGT -999.250 W3NG.NGT TENS. NGT -999.250 CS. NGT RHOB. LOT -999.250 DR HO.LOT QSS.LDT -999. Z 50 LS.LgT LITH.LOT -999.250 SS.I.LDT SSHV.LOT -9:9'9,2'50 : . SIRH"EDT CALi. LOT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999. 250 TNPH.CNL NPOR. CNL '-999.250 RCNT.CNL CFTC.CNL -999. Z50 GR.CNL GR.EPT -999.250 SA.EPT MTEM. EPT -999.250 MRES.EPT IMPH.COR -999. Z 50 SP.COR HTEN.CUR -999. Z 50 DEPT. ?O0.O00' SFLU.DIL SP. DIL -999. 250 GR.DIL TTI. 5HC -999.250 TTZ.BHC GR. BHC -999. Z 50 SP. BHC TENS.CHL 1115.000 SFLU.DTE SP. DTE -999. Z 50 IDPH. DTE CIDP.DTE -999.250 CIMP.DTE I IRM. DTE -999. g 50 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN. SOT -999. 250 OTLF. SOT COHC. GDT -999-250 COH.S.SOT TTZ.SDT -999.250 TT3. SOT LTTZ.SDT -999.250 LTT3.SDT TENS.SOT -999.250 HTEN.SDT THOR. NGT -999.2. 50 POTA. NGT W 2NG. NGT -999. Z 50 W3NGo NtT TENS. NGT -999. 250 CS. NGT RHOB.LDT -999.250 DRHO.LOT QSS. LOT -999.2 50 LS.LDT LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999.250 SiRH.LDT CALI.LDT -999. 250 GR.LDT -999.250 -999.Z50 -999.250 -999.Z50 -999.250 -999.Z50 -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 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ILM.DIL TENS.OIL TT3.BHC TENS.BHC ILM.OTE IMPH.OTE IIRD.DTE TENS.DTE DT.SDT DTCD.SDT COST.GDT TT4.SDT LTT4. SDT SGR.NGT URAN.NGT W4NG.NGT HTEN.NGT PEF.LDT LU.LDT S SZ. LDT LSRH.LDT TENS.LOT ENPH.CNL RCEF.CNL TNRA.CNL RCFT.CNL NVR.EPT CALI.EPT HTEN.EPT SGR.COR ILM.DIL TENS.OIL TT3.BHC TENS.BHC ILM. DTE IMPH.DTE IIRD.DTE TENS.DTE OT.SDT gTCO.SOT COST.SOT TT4.SDT LTT4.SDT SGRoNGT URAN.NGT W~NG.NGT HTEN.NGT PEF.LOT LO.LOT SSZ.LDT LSRH.LDT TENS.LOT -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.Z50 -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 -999.250 ILO.OIL DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE ~TEM.~TE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SG~.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT Lt. LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.COR ILO.OiL DT.BHC TT~.BHC GR.CHL ILO.OTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT T'T1.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT W 5NG. NGT DPHI .LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT -999.250 -999.250 -999.250 Z3.109 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999o250 -999.250 -999.250 -999.250 -999.250 Z6.219 -999.250 -999.Z50 -999.2~0 -999.250 -999.~50 -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 .IS TAPE VERIFICATION LISTING ~CHLUM~ERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: 32 MRES. LOT -999. Z 50 HTEN. LOT CFEC.CNL -999. 250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CFT(;. CNL -999.2 50 GR. CNL GR.EPT -999.Z50 SA.EFT MTEM.EPT -999.250 MRES.EPT IMPH.(;OR -999.250 SP.COR HTEN. COR -999.2 50 DEPT. 600.000 SFLU.OIL SP.DIL -999.250 GR.OIL TT1.BHC -999.250 TT2.BHC GR.BHC -999.250 SP.BHC TENS.CHL 1055.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIOP.OTE -999.250 CIMP.OTE IIRM.OTE -999.250 SGR.DTE MRES.OTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.SDT -999.250 COHS.SDT TTZ.SDT TT3'SDT LTT2.SOT -999.250 LTT3.SOT TENS.SOT -999.Z50 HTEN.SOT THOR.NGT -999.250 POTA.NGT W2NG.NGT -999.250 W3NG.NGT TENSoNGT -999.250 C5.NGT RHOB.LDT -999.250 DRHG.LOT ~SS.LDT -999.250 LS.LDT LITH.LDT -999.250 SSI.LOT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999.250 GR.LOT MRES.LOT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT'CNL CFTC.CNL -999.250 GR.CNL GR.EPT -999.250 SA.EFT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 500.000 SFLU.DIL SP.DIL -999.Z50 GR.OIL TT1.BHC -999.250 TTZ.BHC GR.BHC -999.250 SP.BHC TENS.CHL 1025.000 S~LU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE IIRM.OTE -999.250 SGR.OTE MRES.DTE -999.250 HTEN.OTE DTLN.SDT -999.250 DTLF.SOT COHC.SDT -999.250 COHS.SOT TTZ.SOT -999.250 TT3.SOT LTTZ.SDT -999.250 LTT3.SOT -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999. Z50 SGR.COR -999.250 -999.Z)0 IEM.OIL -999.250 -999.250 TENS.OIL -999.250 -999.250 TT3.BHC -999.250 -999. Z50 TENS.BHC -999.250 -999.250 ILM. DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 OT. SOT -999.250 -999.250 DTCO.SOT -999.250 -999oZ50 COST.GDT -999-250 -999'250 TT4.SDT -999.250 -999.250 LTT4. SOT -999.250 -999.250 SGR.NGT -999°250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999. 250 PEF.LOT -999.250 -999.250 LU.LDT -999.Z50 -999.250 SSZ.LOT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 ENPH.CNL -999.250 -999.250 RCEF.CNL -999.250 -999.250 TNR/~.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 -999. Z50 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 TT3.BHC -999.250 -999.250 TENS.BHC -999.250 -999. 250 ILM.DTE -999. 250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 BT. SOT -99 9. Z50 -999.250 DTCO.SDT -999.250 -999.250 COST.SOT -999.250 ,- 999. Z50 TT4. SOT -999. 250 -999.250 LT'TZ~. SOT -999.250 ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.COR ILO.OIL DT.BHC TT4.BHC GR.CHL ILO.OTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1. SOT SGR.SOT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EFT IgPH.COR TENS.CDR !LO.OIL DT.BHC TT&.BHC GR.CHL ILO.DTE IFRE.DTE IIXD.gTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12.95] -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2'50 -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 19.5~7 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASK~ COMPUTING CENTER TENS. SUT -999. Z 50 HT EN. SOT THOR. NGT -999. 250 POTA. NET WZNG.NGT -999.250 W3NG.NGT TENS. NET -999. Z 50 CS. NET RHOB.LOT -999. Z 50 DRHO.LOT QSS. LOT -999. 250 LS.LDT L ITH. LOT -999. Z 50 S S!. LOT SSHV.LDT -999. 250 S1RH. LOT C ~LI.LOT -999.250 GR. LOT MRES.LDT -999.250 HTEN.LDT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CPTC.CNL -999.2 50 GR. CNL GR.EPT -999.250 SR.EPT MTEMoEPT -999.250 MRES.EPT IMPH.COR -999. 250 SP.COR HTEN. CUR -999.2 50 DEPT. 400.000 SFLU.DIL S P. D IL - 999. Z 50 GR.D [L TT! ° BTIC -999. TT2' BHC GR.BHC -999.250 SP.BHC TENS.CHL 965.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE I IRM. DTE -999. 250 SGR. DTE MREE.DTE -999.250 HTEN.DTE DTLN. SOT -999. 250 DTLF. SOT COHC.SDT -999.250 COHS.SDT TTZ. 5DT -999. 250 TT3o SOT LTTZ.SDT -999.250 LTT3.SOT Tf~NSoSDT -999.250 HTEN.SOT THOR.NET -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT 1 EN5. NET -999. Z 50 CS.NGT RHOB.LDT -999.250 ORHO.LDT QSS'LD'T -999. 250 LS.LOT LITH.LOT -999. Z 50 S51.LOT 5SHV.LDT -999.250 SIRHoLDT CALI.LDT -999. 250 GR. LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHi. CNL -999.250 TNPH.CNL NPOR.CNL -999. 250 RENT.CNL CFTC.CNL -999. 250 GR. CNL ER. ~P'T -999. 250 SA. EPT MTEM.EPT -999.250 MRES.EPT IMPH..COR -999. 250 SP.COR HTEN.COR -999.250 DEPI. 300.000 SFLUoDIL SP.UIL -999.250 GR.DIL TT1.BHC -999.250 TTZ.BHC GRoBHC -999.250 SP.BHC 24-APR-1989 lB:07 -999.250 SGR.NGT -999.Z50 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LOT -999.250 LSRH.LOT -999.250 TENS.LOT -999.250 ENPH.CNL -999.Z50 RCEF.CNL -999.250 ~TNRA.CNL -999.250 RCFT.CNL -999.Z50 NVR.EPT -999.Z50 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR -999. Z50 ILM.OIL -999,- 50 TENS.DZL -999'~50 TT3'BHC -999.250 TENS.BHC -999.250 ILM-OTE -999.250 IMPH.OTE -999.250 IIRO.OTE -999.250 TENS.DTE -999. Z50 OT.SOT -999.250 DTCO.SOT -999.250 COST.SOT -ggg.zEo TT4-SDT -999.250 LTT~.SDT -999.250 SGR.NGT -999.250 URAN.NGT -999.250 W4NG.NGT -999.250 HTEN.NGT -999.250 PEP.LOT -999.250 LU.LDT -999.250 SS2.LOT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 ENPH.CNL -999.250 RCEF.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 NVR.EPT -999.Z50 CALI.EPT -999.250 HTEN.EPT -999.250 SGR.COR -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 -999.2S0 -999.250 -999.250 -999.250 -999.250 -99'9.250 -99 9. 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. Z 50 -999.250 -999.250 -999.250 -999.250 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 TT].BHC -999.250 -999.250 TENS.BHC -999.250 PAL;E: B3 CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS .LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS .CDR -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 ILO.OIL DT.SHC TT~.~HC GR.CHL ILO.DTE IFRE.DTE IIX~.OTE MTEM.DTE DTL. SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT WING.NGT WSNG.NGT DPHI.LDT QLS .LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IDPH.COR TENS.CDR ILD.DIL DT.SHC TT4.BHC GR.CHL -999.250 -999.250 '-999.250 14.570 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2S0 -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 18.750 TAPE VERIFICATION LISTING ;CHLUMBERG~R ALASKA COMPUTING CENTER Z4-APR-1989 18:97 TENS.CML 905.000 SPLU.DTE -999.250 ILM.OTE -999.250 SP.DTE -999.250 IDPH.DTE -999.250 IMPH-D~TE -999.250 CIDP.DTE -999.?.50 CIMP.DTE -999.250 IIRD.DTE -999.?'50 IIRM.DTE -999.250 SGR.DTE -999.?.50 TENS.DTE -999.250 MRES.DTE -999. ?.50 HTEN.DTE -999.250 BT.SOT DTLN.SDT -999.250 DTLF.SDT -999.250 DTCO.SDT -999.?.50 COHC.SDT -999.250 COHS.SDT -999.Z.50 COST.SBT -999.250 TTZ.SDT -999.?-50 TT3.SDT -999.250 TT4.SDT -999.?.50 LTTZ.SOT -999.250 LTT3.SDT -999.250 LTT4.SDT -999.?.50 TEN$.SDT -999.250 HTEN.SOT -999.250 SGR.NGT -999.250 THOR.NET -999.250 POTA.NGT -999.250 UR&N.NGT -999.?.50 WZNG.NGT -999.250 W3NG.NGT -999.250 W4NG.NGT -999.?.50 TENS.NGT -999.250 CS.NGT -999. 250 HTEN.NGT -999.?'50 RHOB.LDT -999.250 ORHO.LDT -999.250 PEF.LDT -999.250 QSS.LDT -999. ?.50 LS.LOT -999. 250 LU. LOT -999. 250 LITH.LDT -999.250 SSI.LOT -999.250 SS2.LOT -999.250 SSHV.LD! -999.?.50 SIRH.LDT -999.250 LSRH.LOT -999.250 CALI.LDT -999.250 ER.LOT -999. 250 TENS.LOT -999.250 MRES.LDT -999.250 HTEN.LDT -999.?.50 ENPH.CNL -999.250 CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.250 NPHI.CNL -999.250 TNPH.CNL -999-250 TNRA.CNL -999.250 NPI:}R.CNL -999'.:2:50 RCN'T,CNL -999'250 RCFT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999.250 NVR.EPT -999.?~50 GR.EPT -999.250 SA. E.~T -999.?.50 CALI.EPT -999.250 MTEM. EPT -999.250 MRES.EPT -999.250 HTEN.EPT -999.250 IMPH.COR -999.250 SP.COR -g99.?.50 SGR.COR -999.250 HTEN.COR -999.250 ILO. DTE IFRE.DTE IIXD.DTE MTEM.DTE Blt. SOT DTSM. SBT TT1.SDT LTT1.SDT SGR.SOT CGR.NGT WING.NGT WSNG.NGT DPHI .LOT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA .CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR. EP'T TENS.EPT IDPH.COR TENS.CDR DEPT. ZO0.O00 SFLU.DIL -999.250 ILM.DIL -999.250 ILO.OIL SPoDIL -999.?.50 ER.OIL -999.250 TENS.OIL -999.250 OT.BHC TTi. BHC -999.250 TT2.BHC -999.?.50 TT3.BHC -999.250 TT4. BHC GR.BHC -999.250 SP.BHC -999. ?.50 'TENS. 8HC -999.250 GR.CHL TENS.CML 880.000 SFLU.DTE -999.250 ILM.DTE -999.250 [LO.DTE SP.BTE -999.250 IDPH.DTE -999.250 IMPH.DTE -999.250 IFRE.DTE CIDP.OTE -999.?.50 CIMp.DTE -999.250 IIRD.DTE -999.250 IIXO.OTE IIRM.DTE -999.Z50 SGRoDTE -999.250 TENS.DTE -999.250 MTEM.DTE MRES-OTE -999.?.50 HTEN.DTE -999.250 BT.SOT -999.250 DTL.SDT OTLN.SDT -999.250 DTLF.SDT -999.250 DTCO.SDT -999.250 DTSM.SDT CDHC.SDT -999.250 CDHS.SDT -999.250 COST.SDT -999.250 TT1.SDT TiZ.SDT -999.250 IT).SOT -999.?.50 TT4.SDT -999.?~50 LTT1.SDT LTTZ.SDT -999.250 LTT3.SDT -999.250 LTT4.SDT -999.250 SGR.SDT TENS.SOT -999.250 HTEN.SDT -999.250 SGR.NGT -999.250 CGR.NGT THOt{. NGT -999.250 POTA.NGT -999.250 URAN.NGT -999.250 W1NG-NGT WZNG.NGT -999.250 W3NG.NGT -999.250 W~NG.NGT -999.250 W,SNG.NGT TENS.NET -999.250 CS.NGT -999.250 HTEN.NGT -999.250 DPHI.LDT RHOB.LDT -999.250 DRHO.LDT -999.Z50 PEF.LDT -999.250 QLS.LDT qSS.LDT -999.250 LS.LDT -999.250 LU.LOT -999.250 LL.LDT LITH.LDT -999.250 SS1.LDT -999.?.50 SS2.LBT -999.250 LSHV.LOT SSHV.LDT -999.250 SIRH.LDT -999°?.50 LSRH.LDT -999.250 LURH.LDT CALI.LD'! -999.250 ER.LOT -999.250 TENS.LOT -999.250 MTEM.LDT MRES.LDT -9'99.?.50 HTEN.LDT -999. 250 ENPH.CNL -999.250 ENRA.CNL CFEC.CNL -999.250 CNEC.CNL -999.250 RCEF.CNL -999.?~50 RCEN.CNL NPHI.CNL -999.250 T~!PH.CNL ,-999.?.5D TNR~.CNL -999.250 RTNR.CNL NPOR.CNL '999.250 RCNT.CNL -999.250 RCFT.CNL -999.?.50 CNTC.CNL CFTC.CNL -999.250 GR.CNL -999. 250 NVR.EPT -999.250 FVR.EPT PAGE: 8~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.?.50 -999.250 -999.250 -999o250 -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 17.594 -999.250 -999.250 -999.250 -999.250 -999.?.50 -999.?.50 -999.250 -999.250 -999.Z50 -999.250 -999.?.50 -999.250 -999.250 -999.250 -999.250 -999.?.50 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER aLASKA COMPUTING CENTER GR.EPT -999.Z50 SA.EPT MTEMoEPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR HTEN.COR -999.250 DEPT. 100.000 SFLU.OIL SP.DII -999.250 GR.DIL TTI.BHC -999.250 TTZ.BHC GR.BHC -999.250 SP.BHC TENS.CHL 1185.000 SPLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.OTE -999.250 CIMP.DTE IIRM.OTE -999. Z 50 SGR. DTE MRES.OTE -999.250 HTEN.DTE DTLN.SOT -999.250 OTLF.SDT COHC.SDT -999.250 COHS.SOT TTZ.SDT -999.250 TT3.SOT LTT2.SOT -999.250 LTT3.SOT TENS.SOT -999o250 HTEN.SOT THOR.NGT -999.250 POTA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NGT -999:'~2:50 CS'NGT RHOB.LDT -999.250 DRHO.LOT QSS.LDT -999.250 LS.LOT LITH.LDT -999.250 SSI.LOT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999.250 SR.LOT MRES.LDT -999.250 HTEN.LOT CFEC.CNL -999.250 CNEC.CNL NPHI.CNL -999.250 ~TNPH.CNL NPOR.CNL -999.250 RCNT.CNL CF'%C.CNL -999.250 GR.CNL GR.EPT -999.Z50 SA.EPT MTEM.EPT -999.250 MRES.EPT IMPH.COR -999.250 SP.COR H'TEN.COR -999.250 DEPT. 0.000 SFLU.DIL SP.DIL -999.250 GR.OIL TT1.BHC -999.250 TT2.BHC GR.BHC -999.250 SP.BHC TENS.CHL 1160.000 SFLU.DTE SP.DTE -999.250 IDPH.DTE CIDP.DTE -999.250 CIMP.DTE ! IRM. DTE -999.2 50 SGR. DTE MRES.DTE -999.250 HTEN.DTE DTLN.SDT -999.250 DTLF.SDT COHC.$DT -999.250 COHS.SDT TTZ.SDT -999.250 TT3.SDT LTTZ.SOT -999.250 LTT3.SOT TENS.SOT -999.250 HTEN.SOT THOR.NGT -999.250 PO'TA.NGT WZNG.NGT -999.250 W3NG.NGT TENS.NG'T -999.250 CS.NGT RHOB.LOT -999.Z50 DRHD.LDT 24-APR-1939 18:07 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.COR -999.250 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 TT3.BHC -999.250 -999. 250 TENS.OMC -999.250 -999.250 ILM. DTE -999.250 -999.250 IMPH.DTE -999.250 -999.250 IIRD.DTE -999.250 -999.250 TENS.DTE -999.250 -999. 250 OT. SET -999. 250 -999.250 DTCO.SDT -999.250 -999.250 COST.SOT -999.250 -999.250 TT4.SOT -999.250 -999.250 LTT4.SDT -999.250 -999. 250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.2,50 W4N:G. NGT -999.250 -999,2'50 HTEN,NGT -999.250 -999.250 PEF.LDT -999.250 -999.250 LU.LOT -999.250 -999.250 SSZ.LOT -999.250 -999.250 LSRH.LDT -999.250 -999.Z50 TENS.EOT -999.250 -999. 250 ENPH.CNL -999.250 -999.2.50 RCEF.CNL -999.250 -999.250 TNRA.CNL -999.250 -999.250 RCFT.CNL -999.250 -999..250 NVR.EPT -999.250 -999.250 CALI.EPT -999.250 -999.250 HTEN.EPT -999.250 -999.250 SGR.CDR -999.250 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 TT3.BHC -999.250 · -999.250 TENS'OMC -999.250 -999.250 ILMoOTE -999.250 -999o250 IMPH.OTE -999.250 -999.250 IIRO.OTE -999.250 -999.250 TENS'DTE -999.250 -999.250 OT.SDT -999.250 -999.250 OTCO. SgT --999o250 -999.250 COST.SOT -999.Z50 -999.250 TT4.SDT -999.250 -999.250 LTT4.SDT -999.250 -999.250 SGR.NGT -999.250 -999.250 URAN.NGT -999.250 -999.250 W4NG.NGT -999.250 -999.250 HTEN.NGT -999.250 -999.250 PEP.LOT '-999.250 TENS.EPT IDPH.COR TENS.CDR ILD.DIL DT.BHC TT4.~HC GR.CHL ILD.DTE IFRE.DTE IIXD.DTE MTEM.DTE DTL.SDT DTSM.SDT TT1.SDT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT WSNG.NGT DPHI.LDT QLS.LDT LL,LDT LSHV.LDT LURH.LDT MTEM.LDT ENRA.CNL RCEN.CNL RTNR.CNL CNTC.CNL FVR.EPT TENS.EPT IOPH.COR TENS.CDR ILD.DIL DT.BHC TT4.BHC GR.CHL ILD.DTE IFRE.DTE IIXD.OTE MTEM.OTE O'TL.SDT OTSM.SDT TT1.SOT LTT1.SDT SGR.SDT CGR.NGT W1NG.NGT W 5NG. NGT DPHI.LDT QLS.LD'T PAGE: 85 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 15. 672 -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 2.660 -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 .IS TAPE VERIFICATION LISTING iCHLUMUERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: 86 QSS.LDT -999.250 LS.LDT -999. 250 LU.LDT LITH.LDT -999.250 SSI.LDT -999.Z50 $SZ.LOT SSHV.LDT -999. Z50 SlRH.LDT -999.250 LSRH.LDT CALI.LDT -999.250 GR.LDT -999.Z50 TENS.LOT MRES.LDT -999.250 HTEN.LOT -999.Z50 ENPH.CNL CFEC.CNL -999. Z50 CNEC.CNL -999.250 RCEF.CNL NPHI.CNL -999.250 TNPH.CNL -999.Z50 TNRA.CNL NPDR.CNL -999.250 RCNT.CNL -999.Z50 RCFT.CNL CFTC.CNL -999.250 GR.CNL -999.Z50 NVR.EPT GR.EPT -999.Z50 SA.EFT -999.250 CALI.EPT MTEM.EPT -999.Z50 MRES.EPT -999.Z50 HTEN.EPT IMPH.COR -999.250 SP.COR -999.250 SGR.COR HTEN.COR -999.250 -999.250 LL.LDT -999.250 LSHV.LDT -999.250 LURH.LOT -999.Z50 MTEM.LOT -999.250 ENRA.CNL -999.250 RCEN.CNL -999.250 RTNR.CNL -999.250 CNTC.CNL -999.250 FVR.EPT -999.250 TENS.EPT -999.Z50 IgPH.COR -999.250 TENS.COR -999.250 -999.Z50 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 END O P DATA · ~-~ FILE TRAILER ~*~ PILE NAME : EDIT .001 SERVICE .' FLZC VERSION : O01AO2 DATE : ~9/04/23 MAX REC SIZE : 1096 FILE TYPE : LD LAST PILE : O~** FILE HEADER ~ FILE NAME : EDIT .OOZ SERVICE : FLIC VERSIUN : O01A02 DATE : 89/04/23 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : THIS DATA HAS NOT BEEN DEPTH SHIFTED- OVERLAYS FIELD PRINTS..""***~-.~.~. SCHLUMBERGER LOGS INCLUOEO WITH THIS FILE (EDIT.O02): <SEE FILE EDIT.O01 FOR 6" SAMPLED DATA) ELECTROMAGNETIC PROPAGATION E MICRO LOG (.EPT) FIRST TO LAST READING: 127'77' TO 11348' .IS TAPE VERIFICATION LISTING iCHLUMBERGER aLASKA COMPUTING CENTER 2~-APR-19B9 18:07 PAGE: 87 TABLE TIPE : CONS TUNI VALU DEFI CN FN WN A PIN FL SEC I' TOWN RANG COUN STAT NATI ENGI WITN SON PDAT EPD LMF APO EOF EGL TOD FT FT FT FT FT FT ARCO ALASKAt INC. WILDCAT PT. MCINTYRE STATE ~4 50-029-21912 146B' FSL, E 666' FEL I:~N NORTH SLOPE ALJ~SKA USA G. SARBER W. CAMPAIGN, G. COOPER 54843Z MSL O. D~ILLING FLOOR 4~.5 42.5 42.5 7. 1 2845. COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION ENGINEER "S NAME WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CURV DEPT EATT TPL FVD PVU NVD NVU PSUP PSDO MINV MNOR DEFI DEPTH CHANNEL NAME EFT ,ATTENUATION TIME OF PROPAGATION IN LOSSY FORMATION FAR VOLTAGE 'DOWN FAR VOLTAGE UP NEAR VOLTAGE DOWN NEAR VOLTAGE UP PHASE SHIFT UP PHASE SHIFT ~)OWN MICRO-INVERSE RESISTIVITY MICRO-NORMAL RESISTIVITY .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 24-APR-1989 18:07 PAGE: 88 DATA FORMAT SPECIFICATION RECORD ~ SET TYPE - 64EB ~ TYPE REPR COOE VALUE I 66 0 Z 66 0 3 73 44 4 66 ! 5 66 6 73 T 65 8 68 0.166 g 65 FT 11 66 24 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I NAME SERV ID SET TYPE - CHAN *:~ UNIT SERVICE API 6PI API gRDER e LOG TYPE CLASS DEPT FT 548432 O0 000 O0 EATT EPT OB/M 548432 09 130 01 TPL EPT NS/M 548432 09 132 19 PVD EPT V 5434'32 Og 430 11 FVU EPT V 548432 09 430 11 NVD EPT V 548432 09 430 10 NVU ~PT V 5484'32 09 430 10 PSUP EPT DEG 548432 09 430 10 PSDO EPT DEG 548432 09 430 11 MINV EPT OHMM 548432 Og 250 01 MNOR EPT ~HMM 54843Z 09 252 01 API FILE NUMB NUMB SIZE REPR MOO NUMB SAMP ELEM CODE PROCESS 'CHEX) 0 2 1 1 4~ 68 0 2 1 1 4 68 0 2 I 1 4 6 8 0 Z 1 1 4 6 8 0 2 1 1 4 68 0 2 1 1 4 68 0 Z I I 4 68 0 Z 1 1 ~+ 68 0 2 I I 4 68 0 2 1 1 4 68 0 Z 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DEPT. 12846.832 EATT.EPT FVU.EP'T 0.991 NVD.EPT PSDO.EPT 298.250 MINV.EPT DEPT. 12800.000 EATT.EPT FVU.~PT 0.991 NVD.EPT PSDO.EPT Z98.250 MINV.EPT 645.500 3.590 0.801 646.500 3.590 0.908 TPL.EPT NVU.EPT MNOR.EPT TPL.EPT NVU.EPT MNOR.EPT 1'7.344 3.723 0.971 17.344 3.723 1.043 FVD.EPT PSUP.EPT FVD.EPT PSUP.EPT 1.085 253.000 1.085 253.000 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASK.~ COMPUTING CENTER DEPT. 1ZTO0.O00 EATT.EPT FVU.EPT 0.519 NVD.EPT PSDO.EPT 293.750 MINV.EPT DEPT. 1 Z600. 000 EATT.EPT FVU.EPT 0.400 NVD.EPT PSDO.EPT Z43.250 MINV.EPT DEPT. 12500.000 E~TT.EPT FVU. EPT 0.584 NVD.EPT PSDO.EPT ZI4.625 MINV.EPT DEPT. !24 00. 000 EATT. EPT FVU.EPT 0.469 NVD.EPT PSDO.EPT 182.375 ~INV.EPT DEPT. 1 Z300. 000 EATT. E PT FVU.EPT 0.378 NVO.EPT P,SDOoEPT 185.125 MINV.EPT DEPT. 12200.000 EATT.EPT PVU.EPT 0.358 NVD.EPT PSDO.EPT 196.500 MINV.EPT DEPT. 12100.000 EATT.EPT FVU.EPT 0.440 NVO.EPT PSDU.~PT 2Z9.375 MINV.EPT DEPT. 1ZO00.O00 E~TT.EPT FVU.EPT 0.587 NVD.EPT PSDO.EPT 2'76.750 MINV.EPT DEPT. 11900.000 EATT.EPT FVU.EPT 0.341 NVO.EPT PSDO.EPT 194.250 M]NV.EPT DEPT. 11800.000 EATT.EPT FVU.EPT 0.503 NVD.EVT PSDO.EPT 3Z1.250 MINV.EPT DEPT. 11700.000 EATT.EPT FVU.EPT 0.465 NVD.EPT PSDO.EPT 180.125 MINV.EPT DEPT. 11600.000 EATT.EPT PVU. EPT 0.578 NVD.EPT PSDO.EPT Z64.750 MINV.EPT DEPT. 11500.000 EATT.EPT FVU.EPT 0.495 NVD.EPT PSDU.kPT Z71.500 MINV.EPT 24-APR-1989 18:07 55Z.000 TPL.EPT 2.691 NVU.EPT 0.780 MNOR.EPT 603.000 TPL.EPT Z.961 NVU.EPT 1.420 MNOR.EPT 371.750 TPL.EPT 1.809 NVU.EPT 4.805 MNOR.EPT 288.000 TPL.EPT 1.643 NVU.EPT 3.609 MNOR.EPT 262.500 TPL.EPT 1. 563 NVU. EPT 3.600 MNOR.EPT 343.000 TPL.EPT 1.813 NVU.EPT 3.494 MNOR.EPT 388.000 TPL.EPT 2.096 NVU.EPT 3.119 MNOR.EPT 550.000 TPL.EPT 3. O9,Z NVU. EPT 1.068 MNOR. EPT 3'81.250 TPL.EPT 1.786 NVU.EPT 13.625 MNOR.EPT 715.000 TPL.EPT 3.535 NVU.EPT 1.912 MNOR.EPT Z$5.ZSO TPL.EPT 1. 517 NVU. EPT 3.793 MNOR. EPT 473.250 TPL.EPT 2.600 NVU.EPT 1.004 MNOR.EPT 562. 500 TPL. EPT 2.754 NVU.EPT 0.918 MNOR.EPT 17.891 2.875 1.223 18.734 2.90~ 1.330 11.102 2.42O 5.535 10.836 1.518 4.832 11.35Z 1.443 5.238 12.047 1.759 6.293 13.617 2.057 4.602 1/+. 281 2.52.5 1.193 11.617 1.486 12.641 18.906 3.189 2.061 10.820 1.684 6.305 16.313 Z.521 1.390 17.078 2.893 1.41.4 FVD.EPT PSUP.EPT FVO.EPT PSUP.EPT FVO. EPT PSUP.EPT FVD. EPT PSUP.EPT FVO.EPT PSUP.EPT FVD.EPT PSUP.EPT FVO.EPT PSUP.EPT FVD.EPT PSUP.EPT FVD.EPT PSUP.~PT FVD.EPT PSUP.EPT FVD.EPT PSUP.EPT FVO.EPT PSUP.EPT FVO.EPT PSU~.EPT PAGE: 89 0.574 Z?4.750 0.583 351.750 0.633 138.1Z5 0.364 161.625 0.503 175.125 0.439 186.125 0.566 ZO3.ZSO 0 · 5'7'1 177.375 0.649 174.625 0.409 Z79.750 0. 418 163. 375 0.695 253.375 0.587 Z71.000 ,IS TAPE V~RIFICAIIO~' LISTING CHLUMBERGER ALASKA COMPUTING CENTER Z4-AP~-198~ 1~:07 PAGE= 9O DEPT. 11400.000 EATT.EPT FVU.EPT 0°524 NVO.EPT PSOO.EPT 244.625 MINV.EPT DEPT. 11300°000 EATT.EPT FVU.bPT 0.4A4 NVO.EPT PSDO.~PT 358.Z50 MINV.EPT DEPT. 11284°500 EATT.EPT FVU.EPT O.Z~O NVO.EPT PSOU. EPT 392.750 MINV.EPT 508.750 TPL.EPT 2.672 NVU.EPT 1.313 MNOR°EPT 514.500 TPL.EPT Z.467 NVU.EPT O. 000 MNOR.EPT 562.000 TPL.EPT 2.553 NVU.EPT 0.000 MNOR.EPT 15.219 FV D. '"-_- PT 2.572 PSUP.EPT 1.630 23.359 FVD.EPT Z.707 PSUP.EPT 0.000 Z4.547 ~VO.EPT 2.600 PSUP.EPT 0.000 0.588 Z38.875 0.534 3~3.250 0.Z90 386.500 END OP DATA -~-~ · =~= FtL~ TRAILER ~ FILl NAME : EDIT .002 ~ERVZCE : FLOC VERSION : 001A02 DATt~ : 89/04/23 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : ~*~ TAPE TRAILER ~ "' "' *-,- -,, .,- SERVICE NA~E : EOIT DATE : 89/0~/23 ORIGIN : I=LIC TAPI~ NAME : 73293 CONTINUA'T~ON *~ : 1 PREVIOUS TAP~ : COMMENT : ARCO ALASKA INC., WILDCAT, PT. MCINTYRE STA'TE #4, 50-029-21912 · ~*:~ REEL TRAILER SERVICE NAME : EDIT DATE : 8'9/04/23 ORIGIN : F:LIC REEL NA~E :' 732'93 CONTINUATION ~ : PREVIOUS REEL : COMMENT : .ARCO ALASKA ZNC., WILDCAT, PT. MCINTYRE STATE ~4~ 50-029-21912
