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HomeMy WebLinkAbout187-120Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/30/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 18-17 (PTD 187-120) RBT 11/27/2021 Please include current contact information if different from above. Received By: 01/03/2022 37' (6HW By Abby Bell at 9:43 am, Jan 03, 2022 BAN(,.R,ES 0 PRINT DISTRIBUTION LIST a GE company COMPANY BP Exploration Alaska Inc. WELL NAME 18-17 FIELD Prudhoe Bay Unit COUNTY North Slope BHI DISTRICT Alaska AUTHORIZED BY Dirk Zei lemaker EMAIL DIrk.ZelllemakergbakefhugheS com STATUS Final Replacement COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t '., BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Burka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc Attn: Ricky Elgarico PO Box 100360 Anchorage, AK 99510 3 Katalyst Data Management Attu: Exxon Mobil Tapes Operations 1110311 Westpark Dr. Houston, TX 77042 Email xom_tapeopsrakatalystdm.com Baker Hughes JV-2019-USONSHOR-288 4State of Alaska -AOGCC Attn: Natural Resources Technician 11 ,333 W. 7th Ave, Suite 100 Anchorage, :Alaska 99501 167120 3213 Ise sign and return one copy of this transmittal form to: Exploration (Alaska) Inc. rotechnical Data Center, LR2-1 I E. Benson Blvd. :horage, Alaska 99508 or AKGDMINTERNAL@bp.com LOG TYPE RPM:PNC3D LOG DATE December 19, 2019 TODAYS DATE March 11, 2020 Revision No Details: Rev. Requested by: FIELD/ FINAL CD/DVD FINAL PRELIM LOGS as, dlis, PDF, META, I SURVEY REPORT LOGS CG(lM, Final Surveys) (Compass) # OF PRIN I Ur PRIN # OF COPIES I# OF COPIES I# OF COPIES 4 V REC'eI A®GCC 5IDVR-Division of Oil&Gas **^ Q Q 1 Q Q Attn: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 5 BP Exploration (Alaska) Inc. Petrotechnicai Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: David Itter ro TOTALS FOR THIS PAGE: 0 1 4 0 0 BEDEWED STATE OF ALASKA . SKA OIL AND GAS CONSERVATION COM ,TION APR 0 8 2015 • REPORT OF SUNDRY WELL OPERATIONS � �{�+► C 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate 1=1 /Other L7 �� "O�'CC Z P� Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waived] Time Extension❑ - d Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development D Exploratory 187-120-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-21768-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028307 PBU 18-17 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary. Total Depth measured 11224 feet Plugs measured None feet true vertical 8981 54 feet Junk measured See Attachment feet Effective Depth measured 11200 feet Packer measured 10055.01 feet true vertical 8962.2 feet true vertical 8051 03 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 40 8-120.8 40 8-120 8 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 10314 7 9-5/8"47#L-80 35 5-10350 2 35 5-8283 82 6870 4760 Production None None None None None None Liner 1104 2 7"29#L-80 10117 8-11222 8100 48-8979 93 8160 7020 Perforation depth Measured depth See Attachment feet SCOW True Vertical depth See Attachment feet SCOW a Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 33 5-10174 88 33 5-8145 48 Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker S-3 Perm Packer 10055 01 8051 03 Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) 11100'-11141', 11145'-11159', 11163'-11177' Treatment descriptions including volumes used and final pressure 13 3 Bbls 14 0 ppg SqueezeCrete, 18 2 Bbls LARC, 11500 psi 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 371 35083 19 620 2007 Subsequent to operation Well Shut-In 300 507 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil D Gas p WDSPL p GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C O.Exempt: N/A Contact Garry Catron Email Garrv.Catron(a.BP.Com Printed Name Garry Catron Title PDC PE Signature (/,1.__1Y��_ C Phone 564-4424 Date 4/8/2015 � v r_ 4)j o//c RBDMSAA APR - 9 2015 Form 10-404 Revised 10/2012 Submit Onginal Only 18-17 187-120-0 Junk Attachment SW Name MD _ Date Description 18-17 11179 10/9/2007 RWO Milled Packer Debris 18-17 11228 10/9/2007 IBP Debris m co 0. o o Q 0 Cp O CO N I[) f— O I- C3) CO L[) C N r- V 4g8O- COLC?) c� CC') •7 CO C) • m •— COO M V- CO N M O CO CO CO CA CO V' Nt OM O) N- O) l[) N co N- N- O NI- CV O O) N— CO CO N CO co co O v- co co Lo co aO 4 co i+ r O N O f� N M N r— N < M co 1— cO `— oOv Ntt M O Cf N- co C 13 O 3 J o CI u) O00 Qco `n 0 U 2 CO J CAaON -0D � r U N MM N � � r 4 t O M M N J 0 M 0 CC W I- 0) C F- CO ? 2 QQ0 V 0 CC CC u_ LL Z ZWWQ H Z j D m I C/) (/) N N Ea Cr) TrCD N. 0) to N- CO O) — NTrTrCOO) toNPs- — LU CD M O to CO Q) CD N CO to to N- CO I- O CO N- Ti O O M Tr Co co O to M ,- co M M o• ODU) Ococo co 1.0 co000GOOOp000CCOOOODOOO) a) 0) 0) 0)) 0)) 0 0 co co co co co O O co co co co co CO Co co co co co co co co co co co re 0 LU W Z W H F 0 a- 5 5 5 U 0 o p 0 0 W Y Y Or 2 N � toN- U) 0) TrCDNO) NMMTrOO) LUcN N- J 0 U W W y to — N- C") 0) to N- CO O) to co 0 I� LO LO CD N- — O co M J J J d d to Z fr M � CDOO � I� OONTr � dOOr- tnN: 06 N: ¢ ¢ ¢ W C7 — L7 O MMCr) Mcg) TrtotnCDCocoOCocoGDGDG) 000) 0O - - M U U U J W W a CO CO CO CO OD OOOOOD ODODOGDOODODCD000) a) OO (J) Z Z Z 0 J J D 0 J o w w GD w GD GO w w GD m GO GD GD GD GD GO GD GD w GO GD GD GD GD < < < I p p a W a W W W a Z O Z 2 2 2 O U) Cl) c¢n Cl) v¢) m CO CO Ca to• to to to to to• to to to to to to to to O r--- Lo M O to O I� 4 t tol� a) �- �• MO � �• Mto000LNMM LUN C d Tr Tr Tr Tr Tr to N- ti N- N- N- CO CO CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 H L () a — - = H O� co J w +11o O co v) u) cn u) 00 Q 0N O c 17 to to to to to to to to to to to to to to O y O N Co GO O O N Tr CD OD O N O Oto N- to to Oto to N. 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I I : r = ƒ \ % 'T 2 ' L o « & 9 © CU ( 0 cco « m » % \ = 360023 , ± a. a / pU22CL< \ f > Ii > 2 -1c 0 � 2 co @R � � Q Oe • 2 � < m ± a0p0 p¥ � �\ � � Rk ® 0 (I) / / � R \ � \ \ & k / � : ƒ / El N & 7 W 2 \® \ / / / £ _ ƒ _ ƒ LU \ - CD 0 \ ƒ / / $ / E > 0 �� O CO E ± I / \ \ / W / / / LU k / / \ \ / \ ,_ \ \ / \ \ < O / \ / 0 a 2 \ / / j \ IE / I\ / \ 3 / 2 ± 2 2221 / I q - „ E � � / 2 _ _ ~ - ^ -0 \ » \ ƒ � � � w0kk \ \ � \ � Of 0 ƒ 2 0 0 Q \ \ > \ \ > to > \ \ \ \ / / 1- E- (Ni IX co a CL ƒ / 0 I ± a \ I \ = E - \ 2 / � / ± < O m ± 0 0 # 2 # / 2 � - c / UJLU3I / / 2 \ » 2j / 2 _ IvOi f ƒ f / E � k / : m m E : 6 E ± E 6 e % 6 m : i 2 �� 0 : t 2 I E ¢ 3 t # -1- ,- r o r r 0 \ r \ \ / CO R 6 & 2 - g 9 e » \ a (N a A TREE=r FMC WELLHEAD= FMC 18-17 8-17 SA._,Y NOTES: ""4-1/2'CHROME TUBING"" ACTUATOR= AXELSON OKB.ELEV.; 55' 13-3/8"CSG, H 78' I BF.H.EV= KOP= 1 200' 68#,K-55 BTC, Max Angle= 46"@ 6400' D=12.415" I I 2101' H4112"FBGASS LFT X NP,MADNDRRS=3.813" Datum MD= 1106T Datum TVD= 8800'SS CONDUCTOR #, ,D= — ? —� ST MD ND DEV TYPE VLV LATCH FORT DATE 3 3378 3054 41 MG DOME RK 16 09/08/14 13-3/8"CSG,72#,L-80 BTC,D=12.347" 3292' 2 6005 5053 41 MUG SO RK 20 09/08/14 1 9941 7962 38 MAG DMY RK 0 10/09/07 Minimum ID =3.725" @ 10160" - 4-1/2" HES XN NIPPLE 10022' H4-1/2"FBS X MP,D=3.813" 10052' —19-5/8"X 4-1/2"BKR S-3 PKR,0=3.875" ' 10087' H41/2'HES XMl'D=3.813' 10118' I7"LNR HGRw/10'TEBACKSLV,D=? TOP OF 7"LHR —I 10118' 1-11 I I 10160' H4-1/2"FES XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-S0 VAM TOP, —I 10172' I 10172' J--14-112"WLEG,0=3.958"_ .0152 bpf,D=3.958' 9-5/8'CSG,47#,L-80 BTRS,D=8.681' --{ 10350' I'--• , 10530' H7"MARKER JOINT PERFORATION SUMMARY REF LOG:CH CNL ON 01/07/88 ANGLE AT TOP PERF:36"t 11100' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2-1/8" 1 11040-11050 S 09/01/88'09/02/14 2-1/8" 1 11070-11084 S 09/01/88 09/02/14 2-1/8" 4 11098-11106 S 09/01/88 09/02/14 3-3/8" 6 11100-11125 0 02/23/15 2-1/8" 4 11114- 11132 S 09/01/88 09/02/14 3-3/8' 6 11125-11145 0 02/22/15 2-1/8" 4 11138-11158 S 09/01/88 09/02/14 11179' FSH-RWO/MLLED PACKER 2-1/8" 6 11162-11176 S 03/28/88 09/02/14 11179' —I FISH (10/09/07) 411kr 11228' -I FISH-BP DE3Rs PBTD --I 11200' 4., 7"LNR,29#,L-80 BTC,.0371 bpf,0=6.184' H 11222' (ATE REV BY COMMENTS DATE REV BY COW/V1TS PRUDHOE BAY UNIT 12/30/87 ROW 41 ORIGINAL COMPLETION 09/15/14 JNP M)GLV CJO(09/08/14) WH.L 18-17 03/15/88 RW0 02/23/15 JCIW PJC ADFERFS(02/22/15-02/23/15) FERMI-No:'1871200 10/09/07 D16 MO API No: 50-029-21768-00 03/04/14 CJNIJMD SET PXN RUG(02/23/14) SEC 24,T11 N,R14E 1241'FNL&146'FE. 09/05/14 MGS/PJC PULL PXN(08/17/14) 09/09/14 JCF/PJC GAT SQZ(09/02/14) BP Exploration(Alaska) STATE OF ALASKA V~~ ~ ~~""'~~~~ ALASKA OIL AND GAS CONSERVATION COMI~RSSION ~ ~ a07 ~~~ REPORT OF SUNDRY WELL OPERATIONS Masks O~II +~ Gas Gans, Clmlmissian 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 187-120 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21768-00-00 ' 7. KB Elevation (ft): 55.00 - 9• Well Name and Number: PBU 18-17 8. Property Designation: 10. Field /Pool(s): ADL 028307 - Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11224 ~ feet true vertical 8682 feet Plugs (measured) N/A Effective depth: measured 11200 feet Junk (measured} 11179' & 11228' true vertical 8962 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20" 109' 109' 1490 470 Surface 3292' 13-3/8" 3292' 2989' 3450/4930 1950 / 2670 Intermediate Production 10350' 9-5/8" 10350' 8284' 6870 4760 Liner 1104' 7" 10118' - 11222' 8101' - 8980' 8160 7020 ~~~ ~n~ ~ zoaa Perforation Depth MD (ft): 11040' - 11176' Perforation Depth TVD (ft): 8833' - 8943' 4-112", 12.6# 13Cr80 10172' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1 /2" Baker S-3 10052' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: Contact Paul Chan, 564-5254 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: W Sig ture Phone 564-4750 Date I (~ 3 ~ Sondra Stewman, 56a-4750 Form 10-404 Revised 04/2006 -____ - , `~ u it Original Only Digital Well File • ~ Page 1 of Well: 18-17 Well History Well Date Summary 18-17 9/1/2007 T/I/O = 0+/0+/0+. Temp = SI. Monitor WHP's, (eval TBG head adapter height for RWO). No AL line. Intergal installed on IA valve. It is 51"from the ground to TBG head adapter. 18-17 9/21/2007 T/I/0=108/179/72. Temp=S1. Monitor WHP's. (Pre-RWO). Integral installed on IA. OAP fluid to surtace. Well head scaffold removed, used ladder to access tree cap. 18-17 9/21/2007 """ WELL SHUT IN ON ARRIVAL `"` (pre rwo) RIG UP SLICKLINE /STANDBY FOR SCAFFOLDING CREW *** JOB CONTINUED ON 09-22-07 WSR *** 18-17 9/22/2007 T/I/O=S-line/160/100 Temp=S1 MIT OA PASSED to 2000 psi (Drlg Candidate) -Pumped 1.5 bbls crude to pressure up OA from 100 psi to 2000 psi. OA lost 30 psi in 1st 15 min. OA lost 50 psi in 2nd 15 min, Failed. On 2nd attempt pressured up OA from 1920 osi to 2000 sn i w/(Qidn't mane hhl cnuntPr) na i~~r 20 psi in 1st 15 min. OA lost 0 psi in 2nd 15 min, Passed. Bled OAP to 40 psi, all fluid -1.5 bbls. Verify casing valves open to gauges, tag well & notify operator. S-line still on well. Final WHP's=S-line/160/40 18-17 9/22/2007 **"JOB CONTINUED FROM 09-21-07 WSR "" (pre-rwo) RAN FLAPPER CHECKER TO TRSSSV @ 2156'SLM. SET 3 1/2" SS CATCHER @ 2204'SLM .BRUSHED TRSSSV @ 2156'SLM .SET Z5 LOCK OUT TOOL IN TRSSSV PROFILE @ 2163'SLM .ATTEMPT TO LOCK OUT TRSSSV. LATCHED Z-5 LOCK OUT TOOL W/ 3" JU W/O PRONG, CYCLED VALVE. VALVE STILL OPERATIONAL, LOST DOG SPRING OFF 3" @340' SLM WHILE POOH RAN 2.75" LIB TO 348' SLM IMPRESSION OF SPRING ON SIDE OF LIB RIH W/ BL BRUSH @ WIRE GRAB *** JOB CONTINUED ON 09-23-07 WSR *** 18-17 9/23/2007 T/I/0=110/180/70. Temp=Sl. Wellhead measurements (pre RIG eval). TB Head Adapter 48' from bottom of pad. 18-17 9/23/2007 "` JOB CONTINUED FROM 09-22-07 WSR **` (pre rwo) LOCKED OUT 3 1/2" TRDP TRSSSV Cc~ 2157'SLM . PULLED 3 1/2" SS CATCHER FROM 2204'SLM. DRIFTED W/2.70 CENT & SAMPLE BAILER ,TAGGED TOP OF PATCH Cad 4488'SLM . DRIFTED W/1.70 CENT & SAMPLE BAILER OUT EOT TO 10.800'SLM LOGGED PDS CALIPER FROM 10,800'SLM TO SURFACE. (BAD DATA) RE-RAN CALIPER TO 10,815' SLM, BEGIN LOGGING UP *** JOB CONTINUED ON 09-24-07 WSR *** 18-17 9/24/2007 T/IA/OA= 0/280/120 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RIG) PPPOT-T RU 2 HP bleed tools onto THA test void, 0 psi on void. Cycled LDS " ETstyle "all pins moved free no bent or damage. Flush void until clean returns achieved, pressure to 5000 psi for 30 min test, 5000/ 15 mins, 4900/ 30 mins. Bleed void to 0 psi, RD test equipment re-install Alemite caps. PPPOT-IC RU 2 HP bleed tools onto IC test void, 50 psi bleed to 0 psi. Cycled LDS " ET style "all moved free no bent or damage. Flush void until clean returns achieved, pressure to 3500 psi for 30 min test, 3400/ 15 mins, 3400/ 30 mins. Bleed void to 0 psi, RD test equipment re-installed Alemite caps. 18-17 9/24/2007 T/I/0=120/0/120. Circ-Out (RWO Prep) -Pumped 5 bbls neat methanol and 490 bbls 1 % KCL down IA and up tubing taking returns down flowline. Job Contiued on 9-25-07 WSR. 18-17 9/24/2007 *"` JOB CONTINUED FROM 09-23-07 WSR ""` (pre-rvvo) LOGGED PDS CALIPER FROM 10,815' SLM, TO SURFACE (GOOD DATA) *** LEFT WELL SHUT IN *** 18-17 9/24/2007 *"* WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 100/200/150 *`* CUT 3-1/2" TUBING AT 4479.5' WITH 2.5" POWER JET CUTTER. INAL T/I/O = 150/200/150 *** JOB COMPLETE*** 18-17 9/25/2007 Job Continued From 9-24-07 WSR Circ-Out (RWO-prep) Freeze protected lA with 153 bbls diesel and tubing with 22 bbls diesel, unable to pump freeze protect down IA and U-tube into tubing do to well going on vac. Freeze protected flowline with 73 bbls diesel. FWHP's=vac/vac/0. Annulas valves left open to gauges, notified DSO status of well. 18-17 9/27/2007 """WELL S/I ON ARRIVAL"*"(pre rwo) SET 2.812" CSA-2 PLUG IN TRDP - SSSV NIP 2 181' MD. PUMPED -22 BBLS F DIESEL TO PT PLU NSUGGF~~FI u PULLED EO. PRONG FROM 2181' MD. http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/31 /200 Digital Well File 18-17 9/27/2007 18-17 9/28/2007 18-17 9/28/2007 Print Date: 10/31/2007 • PULLED 2.812" CSA-2 PLUG BODY FROM 2181' MD. SET 3 1/2" WRP Cad 2,105' SLM LRS MIT-T WRP PLUG TO 2000#'S, (passed, see loa for details) ***CONTINUED ON 9-28-07 WSR*** Page 2 of T/I/0= 0/60/0 Temp= S/I Assist Slick line, MITT aQ 2000 psi. PASSED 3rd attempt (RWO prep) Pumped 7.1 bbls. 40* diesel down TBG to reach test pressure of 2000 psi. MIT T lost 40 psi. in 1st 15 min. and 20 psi. in 2nd 15 min. for a total loss of 60 psi., Bleed TBG pressure, Final WHP's 0/60/0, ---SLB still on well on departure--- "Annulus casing valves tagged & left open" ***CONTINUED FROM 9-27-07 WSR*** (pre rwo) ASSIST VEGO BPV CREW IN INSTALLING BPV IN 18-17 ***LEFT WELL S/I, NOTIFIED DSO*** Set 3 1/8 ISA BPV ,for rig move. Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/31/200' • • BP EXPLORATION Page 1 of 10' Operations Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To ~ Hours I Task I Code I NPT 9/24/2007 100:00 - 18:00 I 18.001 RIGD I P 18:00 - 00:00 I 6.00) RIGD I P 9/25/2007 100:00 - 00:00 I 24.001 MOB I P 9/26/2007 100:00 - 06:00 I 6.00 I MOB I P 06:00 - 00:00 I 18.001 MOB I P 9/27/2007 100:00 - 14:00 I 14.001 MOB I P 14:00 - 18:00 4.00 MOB P 18:00 - 23:00 5.00 MOB P 23:00 - 00:00 1.00 MOB P 9/28/2007 00:00 - 09:00 9.00 MOB P 09:00 - 00:00 15.00 MOB P 9/29/2007 100:00 - 02:30 I 2.501 MOB I P 02:30 - 07:00 I 4.501 MOB I P 07:00 - 08:00 I 1.001 RIGU I P 08:00-10:30 ~ 2.50~WHSUR~P Spud Date: 12/9/1987 Start: 9/24/2007 End: 10/9/2007 Rig Release: 10/9/2007 Rig Number: Phase Description of Operations PRE RD off of well slot E-27A. Back the Rig off and stage on the Pad. Perform general maintenance and work on work orders. Waiting on Doyon 14 to complete rig move and mats to be laid out. PRE Serviced Draworks and Top Drive, Iron Roughneck. Mechanic and Welder working on replacing Lines and Hoses on Pipe Skate and Repairing Hydraulic Tank in Pipe Shed. Install new Tie IN line on Arctic Dump Line in Hopper room. PJSM Prepare to and UD Derrick while waiting on Rig Mats to be layed out around reserve pits. PRE Lay rig mats around reserve pits, Move rig around reserve pit and stage by enterance of E-Pad. Wait on wind to die below 20 MPH to remove light post on DS 18 access road. Winds too high to remove well house on DS 18-17. Wind gusts 30-35 MPH. Continue to perform light maintenance on rig. Work on pipe skate hydraulic tank. Clean up and do maintenance to tanks. Perform plumbing repairs and mods in pits. Install front booster cage and front and rear boosters. Test steering. Inspect and make repairs on hydraulic lines. Remove stinger from pipe skate. Replace ram seal. Tighten ram packing on stinger. Clean rig. Change out fuel hose in fuel room. PRE Continue waiting on weather to remove light post on DS 18 access road to allow rig to move through. Clean and inspect pipe skate. Make minor repairs. Clean rig. Inspect and make repairs to rig hydraulic system. Inspect lifting cables and sheaves on pipe shed doors. PRE Continue waiting on weather. Replace hoses on pipe skate. Replace dies on iron roughneck. Continue working over pipe skate by fabricating and adding extra rollers. Remove and replace lifting cable on pipe skate. Wind condition remains the same with 30-35 MPH gusts. PRE Continue waiting on weather to remove light post on DS 18 access road to allow rig to move through. Wind gust @ 25 MPH. 20 MPH winds or less needed to remove light post. Continue changing out lifting cable on pipe skate. Make minor repairs. Clean and paint pit room and pump room. PRE Move-Camp from E-Pad to DS 18. PRE Move Primary Unit from E-Pad to DS 18. Wait on security escort. PRE Move Primary Unit from E- Pad to DS 18. PRE Continue moving Primary Unit from E-Pad to DS 18. PRE Wait on Pad prep to finish. Remove S-Riser, and level pad. Raise Derrick. Bring in gravel and build up pad level 8-12". PRE Continue waiting on Pad prep to finish. Level pad. Bring in gravel and build up pad level 8-12". Blade to Grade. PRE Lay out herculite over rig location. Spot rig mats. Move rig over well slot 17. Level and shim rig. PRE Spot Slop Tank. Install double valve on IA. R/U hose from OA to Slop Tank. Accept rig @ 0800-hrs. DECOMP Suck Tree dry. N/D Tree and Adapter Flange. Hanger appears in good condition. M/U 4-1/2" IF x 9" LH ACME crossover to Hanger with 6.5 turns. Break and UD crossover. M/U Blanking Plug w/ 5 turns. Measure to ensure test joints will fit below Printed: 10/23/2007 2:59:02 PM • • BP EXPLORATION:.. Page 2 of 10 Operations. Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Spud Date: 12/9/1987 Event Name: WORKOVER Start: 9/24/2007 End: 10/9/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/9/2007 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/29/2007 08:00 - 10:30 2.50 WHSUR P DECOMP VBRs during BOPE test (2" clearance). NORM Tree and send to Valve Shop for inspection (Tree will not be re-used). 10:30 - 13:30 3.00 BOPSU P DECOMP N/U BOPE. (3.5"x6" VBRs, Blinds, Annular Preventer) 13:30 - 19:00 5.50 BOPSU P DECOMP Pressure Test BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 minutes. AOGCC witness of test was waived by Chuck Sheve. Test was witnessed by Doyon Toolpusher and BPX WSL. Use 3-1 /2" and 4-1/2" test Test 1- Variable Pipe Rams w/ 4-1/2" Test Joint Test 2- Choke Valves 12, 13, 14, Annular Preventer, HCR Kill, and Lower IBOP Test 3- Choke Valves 9, 11, Manual Kill, and Upper IBOP Test 4- Choke Valves 5, 8, 10, Blind Rams, and TIW Valve Test 5- Choke Valves 4, 6, 7, and Dart Valve Test 6- Choke Valves 1 and 2 Test 7- Choke Valve 3 Test 8- HCR Choke Test 9- Manual Choke Test 10- Variable Pipe Rams w/ 3-1/2" Test Joint Accumulater Test- Starting Pressure- 3050 psi. After Accuation- 1850 psi. First 200 psi Recovery- 23 seconds. Full Recovery- 72 seconds 5 Nitrogen Bottles @ 2150 psi. 19:00 - 19:30 0.50 DHB P DECOMP M/U joint of DP to 4-1/2" IF crossover. RIH and mull Blanking 19:30 - 00:00 4.50 DHB P DECOMP M/U Lubricator to Lubricator Extension and test Lubricator to 500 psi. Attempt to pull BPV w/o success. C/O Pulling Tool and drain BOPE. Attempt to pull BPV w/o success. Center BOPE over top of TBG HGR ,and continue to attempt to sting into BPV profile w/o success 9/30/2007 00:00 - 03:00 3.00 DHB P DECOMP Continue attempting to sting into and retrieving BPV. R/D Flow Line and adjust BOPE Stack to center over TBG HGR. Call out FMC Rep. Remove Guide Skirt from Pulling Tool. RIH and retrieve BPV. No pressure on TBG or IA. 03:00 - 03:30 0.50 DHB P DECOMP R/D and UD DSM Lubricator, Extension, and Equipment. 03:30 - 06:00 2.50 DHB P DECOMP PJSM w/ SWS Slick Line Crew and Rig Crew. Discuss Wireline operations on the Rig and importance of communication between the Rig and W/L Unit. R/U Shooting Flange on BOPE, Bring SWS Lubricator, Extension, BOPE, Pump In Sub, Packoff, and equipment to Rig Floor and R/U. R/U SWS BHA of Jars, Spangs, and Puling Tool. Pressure Test SWS Lubricator to 250 osi Low Pressure and 2500 osi High Pressure Test. 06:00 - 08:00 2.00 DHB P DECOMP RIH w/ S-Line and Dull WRP Cad 2105' slm. POH w/ WRP. Check for pressure, break Lubricator, and UD WRP and toolstring. 08:00 - 10:00 2.00 DHB P DECOMP R/D SLB Slickline and N/D Shooting Flange. M/U Riser. 10:00 - 11:30 1.50 DHB P DECOMP R/U to Circulate Seawater. P/T Lines to 3500 psi. Circulate 314 Bbls of 120 degree seawater at 12 BPM and 1500 psi while taking returns to the Slop Tank. Clean returns seen. T and IA are on a vac. Well is dead. 11:30 - 12:00 0.50 PULL P DECOMP Multiple attempts to M/U Landing Joint and 9" LH ACME crossover to Hanger is unsuccessful. Call Baker Fishing to Printed: 10/23/2007 2:59:02 PM • BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 9/30/2007 11:30 - 12:00 0.50 PULL P 12:00 - 13:00 1.00 PULL P 13:00 - 14:00 1.00 PULL P 14:00 - 20:00 6.00 PULL P 20:00 - 21:00 1.00 PULL P 21:00 - 00:00 3.00 CLEAN P 10/1/2007 00:00 - 03:30 3.50 CLEAN P 03:30 - 04:00 0.50 CLEAN P 04:00 - 05:30 1.50 CLEAN P 05:30 - 07:30 2.00 PULL P 07:30 - 09:00 1.50 PULL P 09:00 - 10:30 1.50 PULL P 10:30 - 17:00 6.50 PULL P 17:00 - 19:00 2.00 FISH P 19:00 - 19:30 0.50 19:30 - 21:30 2.00 FISH N WAIT 21:30 - 22:00 0.50 FISH P 22:00 - 00:00 2.00 FISH P Spud Date: 12/9/1987 Start: 9/24/2007 End: 10/9/2007 Rig Release: 10/9/2007 Rig Number: Phase' Description ofi Operations DECOMP Spear and pull Hanger. DECOMP Wait on Baker Fishing to bring Spear. Pump across the top in order to get an hourly loss rate to the formation. Loss rate determined to be 80 BPH. R/U Spooier. DECOMP M/U Spear to a joint of 4" DP. RIH and spear Hanger. BOLDS. Pull and unseat Hanger with 40-K-Ibs P/U. Pull Hanger to the Floor with 35k-Ibs P/U. Hanger threads are in good condition. Uppermost pup and joint of 3-1/2" Tubing were packed with scale. DECOMP POH w/ 3-1/2" EUE Tubing down to the cut @ 4480' MD. UD singles into the Shed. Keeping hole full with continuous fill. Tubing looks in good condition. Recovered 142 joints of TBG, 1 SSSV, 1 GLM and pups, 37 SS bands, and (1) 15.05' cut off joint. Cut on cut off joint was clean and beveled out to 4-1/8". Loss Rate while POOH @ 75 BPH. DECOMP Clear and clean Rig Floor. P/U and set Wear Ring. Bring Baker Fishing Tools to Floor and prep. DECOMP P/U BHA #1 (Overshot Assembly) consisting of Shoe Guide., Hollow Mill Container w/ Dress Mill installed, Overshot w/ Grapple, Overshot Extension, Overshot Top Sub, Bumper Sub, Jars, X/O, (9) 6-1/4" Drill Collars, X/O, Accelerator Jars, X/O to HT-38 Drill Pipe. Total Lengh of BHA #1- 325.99' DECOMP RIH w/ BHA #1 (Overshot Assembly) on 132 joints of 4" HT-38 Drill Pipe picked up from Pipe Shed to 4469'. Losses while RIH @ 80 BPH. DECOMP Establish fishing parameters of Up Wt- 117,000 Ibs; Dwn Wt- 100,000Ibs; Rt Wt- 110,000 Ibs at 30 RPM with 3500 ft-Ibs Torque; Pump Rate @ 2 BPM w/ 50 psi. RIH and tag Tubing Stub @ 4475'. Rotate over TBG Stub at 30 RPM. With 2000 s rotary torque increased to 5000 ft-Ibs while dressing off Tubing Stub Flare to 4476'. Stop rotation and slide over Tubing Stub to 4482'. P/U string weight with 12,000 Ibs overpull to 175,000 Ibs. Hit once with jars. Pull TBG free at 180,000 Ibs.. Continue pulling TBG out of PBR. DECOMP CBU at 10 BPH with 1075 osi. Dynamic losses (7a 110 BPH. DECOMP POOH and rack back 4" HT-38 Drill Pipe in derrick. DECOMP S/B Drill collars. L/D BHA components. DECOMP PJSM. POH w/ 3-1/2" EUE Tubing and 2-3/8" STL Patch. Cut Patch into 4 pieces using cold cutter. Patch recovered in its entirity. A hole -1/4" diameter was found at -4530' MD. DECOMP POH w/ 3-1/2" EUE completion while L/D Tubing into the Pipe Shed. Filling hole w/ seawater at 40 BPH. FL shot at 1300-hrs and found FL @ - 558' MD. Retrieved everything above PBR. Cut off joint- 15.96' DECOMP Brake out Overshot Assembly. L/D same. DECOMP Bring BHA #2 tools and equiment to Rig Floor. DECOMP Attempt to M/U Spear. Excess Torque required to M/U. Examined threads, threads gaulded. Repair spear and return to rig. DECOMP PUMU BHA #2: Spear (Type D), Pump Out Sub, Oil Jars, and (9) 6-1/4" Drill Collars. Total length of BHA #2- 326.18' DECOMP RIH with BHA #2 on 4" HT-38 Drill Pipe. RIH to 4500' with pipe Printed: 10/23/2007 2:59:02 PM i ~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Spud Date: 12/9/1987 Event Name: WORKOVER Start: 9/24/2007 End: 10/9/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/9/2007 Rig Name: DOYON 16 Rig Number: Date I From - To I Hours ( Task (Code I NPT Phase I Description of Operations 10/1/2007 22:00 - 00:00 2.001 FISH P 10/2/2007 00:00 - 06:00 6.00 FISH P 06:00 - 07:00 I 1.001 FISH I P 07:00 - 08:30 I 1.501 FISH I P 08:30 - 13:00 4.50 FISH P 13:00 - 15:00 I 2.001 FISH I P 15:00 - 19:00 I 4.001 FISH I P 19:00 - 20:30 I 1.501 FISH I P 20:30 - 00:00 I 3.501 FISH I P 110/3/2007 100:00 - 06:00 I 6.001 FISH I P 06:00 - 09:00 I 3.00 I FISH I P 09:00 - 09:30 I 0.501 FISH I P DECOMP from Derrick. Continue RIH P/U singles from Pipe Shed. DECOMP Continue RIH to spear K-Anchor and PBR with 4" HT-38 Drill Pipe single from Pipe Shed to 10,037'. Fill pipe while RIH at 4500' and 7300'. Fluid losses while RIH were down to 3 BPH. Hole staying full with pipe displacement. At 8000' losses increased to 90 BPH. Monitor well and continue RIH. Using constant hole fill while RIH. DECOMP Establish fishing parameters of Up Wt- 212,000 Ibs; Dw Wt- 136,000Ibs. Continue RIH and tag Top of PBR ~ 10,060'. Engage Spear and work scale off by hitting with jars and bumping on Fish 3 times. Rotate on K-Anchor with 25 rotations and 6000 ft-Ibs torque. K-Anchor came free. Up Wt-214,000 Ibs. DECOMP Drop ball and rod to open pump out sub. CBU at 10 BPM and 1470 psi. DECOMP POH with BHA #2 and Fish while S/B DP into the Derrick. Losses are at 55 BPH. Recover and L/D Fish: PBR, XO, and K-Anchor. Total length of PBR/K-Anchor assembly- 16.47' DECOMP M/U BHA #3 (Packer Milling Assembly with PRT Spear) consisting of 8.5" PRT Packer Milling Assembly, (3) 7" Boot Baskets, Bit Sub, Pump Out Sub, Bumper Sub, Oil Jars, and (9) 6-1/4" Drill Collars, 6-1/4" Accelerator Jars. Total Length of BHA #3- 344.57' DECOMP RIH with BHA #3 to mill Brown 3H Packer on 102 stands of 4" HT-38 Drill Pipe from Derrick to 10,025'. DECOMP PJSM, hang Blocks, and slip and cut Drill Line. Inspect Draw Works and Top Drive. DECOMP P/U Stand 103. Establish SPR. Establish milling parameters of Up Wt- 225,000 Ibs; Dw Wt- 137,000 Ibs; Rt Wt- 174,000 at 60 RPM with 10,000 ft-Ibs free torque; Pump Rate @ 3 BPM with 210 psi. Ta to of Packer 10,074'. Swallow Packer to 10,079'. Commence milling on Brown 3H Packer with 1,000 Ibs WOB and 60 RPM/ 14,000 ft-Ibs torque, pump rate at 2 BPM with 330 psi. Increase pump rate to 5 BPM with 730 psi. Losses while milling at 2-5 BPM- 32 BPH. DECOMP Continue milling on Brown 3H Packer to 10,079.5'. Packer appears to be spinning. Varied parameters: pump rate from 0 to 5 BPM with 700 psi; WOB from 2000 to 26,000 Ibs; RPM- 40 to 70 rpm's (over 70 rpm's rattles OP against casing); torque varied from 12,000 to 16,000 ft-Ibs. Jarred with 50,000 Ibs overpull and spudded on Packer in attempt to keep Packer from spinning. Loosing -2 bph while circulating and hole with slight fluid lose when static. DECOMP Dry Mill on Packer, vary rotary speed between 30-70 rpm's and vary weight on bit from 10k-25k in attempt to get packer to mill up. Slight fluid lose while dry drilling. Kick on pumps briefly every hr to keep hole full during milling operations DECOMP Able to mill on packer. Push packer down hole easily- move about 20 feet. Fluid level fell with packer moving. Kick on pumps and establish circulation at 5 bpm at 300 psi. Fluid loss while circulating '1 bpm. Printed: 10/23/2007 2:59:02 PM • C BP EXPLORATION. Page 5 of 10 Operations Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Spud Date: 12/9/1987 Event Name: WORKOVER Start: 9/24/2007 End: 10/9/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/9/2007 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/3/2007 09:30 - 10:00 0.50 FISH P DECOMP P/U on Drill String and attempt to move packer up hole. Packer moves easily down hole. Make two jar licks at 50,000 Ibs over string weight to get packer moving up hole. Pump 20 bbl High Visc to circ out cuttings and chase out of hole at 11 bpm and 2500 psi. 10:00 - 14:00 4.00 FISH P DECOMP Notice fluid aain aftPr~_cir_ ic~~la.~ drill pine volume, Shut Down Pumps and observed flow. Shut in well with Hydril. Notified _ Jim Willingham, Paul Chan, & Lou Grimaldi with AOGCC.. 14:00 - 16:30 I 2.501 FISH I P 16:30 - 19:00 I 2.501 FISH I P 19:00 - 21:30 I 2.501 FISH I P 21:30 - 22:30 I 1.00 I FISH I P 22:30 - 00:00 I 1.501 FISH I P 110/4/2007 100:00 - 03:00 I 3.001 FISH I P 03:00 - 03:30 0.50 FISH P .03:30 - 06:00 2.50 FISH P Manual Stra indicated 11 bbl ain. SIDPP built to 130 psi and SICP to 320 psi. Clrculate out gas through choke at 3.0 bpm. Once gas bubble circ out. Shut down pumps and shut-in well. Monitor well and open choke and watch for flow - no flow. DECOMP Continue to watch for flow out annulus. With no flow open drill pipe to and monitor for flow - no flow. Open hydril -fluid level down hole. Pump Down Drill Pipe and IA to fill hole with '25 bbls. Circulate Bottoms Up at 4 bpm at 390 psi, some gas seen in returns. Flow Check Well -fluid level falling. DECOMP POOH w/ one joint to make full stand. Had to one spot which required 3 jar licks to get through. Stand Back Drill Pipe in Derrick. M/U Top Drive and PUH -40'. Circulate bottoms up at 6 bpm and 890 psi. No Gas seen in returns. Flow Check Well - No Flow. Fluid Level Falling at 60 bph both dynamic and static. DECOMP POOH 3 stands and racked in Derrick. Packer pulled freely. Well not swabbing. M/U Top Drive and PUH 30'. Circulate bottoms up at 6 bpm with 860 psi. No gas seen in returns. Shut down Pumps and Flow Check Well- No Flow. Monitor DECOMP POOH with 20 stands and racked in Derrick. Packer pulled freely. DECOMP M/U Top Drive and circulate bottoms up at 9 bpm with 1575 psi. Dynamic Loss Rate- 10 bph. No gas in retums. Shut down Pump and Flow Check Well- No Flow. Monitor Static Losses @ 6 bph. DECOMP B/D Top Drive and pull 84 stands out of the hole. Rack back 4" HT-38 Dnll Pipe in Derrick. Losses at 7 bph while POOH. Packer pulled freely without any problems. DECOMP R/U and circulate bottoms up at 8 bpm with 700 psi. Dynamic Losses @ 5 bph. No gas in returns. Monitor Well, static losses @ 9 bph, no sign of gas. DECOMP PJSM with Rig Crew and Baker Fisherman. Discuss the possible problems of bringing the Packer through the Wellhead and BOPE. Discuss safety. precautions. B/D Top Drive and POOH. Packer hung up at 25'. Attempt to work Fish through Wellhead without success. Work Packer down to 34' where Packer hung up going down. Break out Jars and M/U TIW \/a hie RhuT well in 06:00 - 07:00 1.00 FISH P DECOMP P/U DP Pup Jt, TIW, HT38 x 4-1/2 IF XO and Make Up to Fishing Jar. Rig Up Drill String in Prep to Jar Fish out of the hole. 07:00 - 08:30 1.50 FISH P DECOMP Wait on Orders, Pre Job Safety Meeting on Fishing Packer and UD Fish once on Surface. Consult town on options to fish packer and tail pipe from well. Decide to mill down on fish Printed: 10/23/2007 2:59:02 PM • BP EXPLORATION Page 6 of 10 Qperations Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To 1 Hours ~ Task :'Code, NPT 10/4/2007 07:00 - 08:30 1.50 FISH P 08:30 - 09:00 0.50 FISH P 09:00 - 10:00 I 1.001 FISH I P 10:00 - 11:30 I 1.501 FISH ( P 11:30 - 12:00 I 0.501 FISH I P 12:00 - 14:00 I 2.001 FISH I N 14:00 - 16:00 I 2.001 FISH ( P 16:00 - 16:30 0.50 FISH P 16:30 - 17:30 1.00 FISH P 17:30 - 22:00 4.50 FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 00:00 1.50 FISH P 10/5/2007 00:00 - 04:00 4.00 FISH P 04:00 - 04:30 0.50 FISH P 04:30 - 06:00 1.50 FISH N Spud Date: 12/9/1987 Start: 9/24/2007 End: 10/9/2007 Rig Release: 10/9/2007 Rig Number: Phase I Description of Operations DECOMP either to free up or mill up. DECOMP Establish Rotation at 30 rpm's and 2,000 ft -Ibs of torque. Pump rate at 1.5 bpm and 150 psi. Slowly S/O, tag top of packer at 34' and set down 3,000 Ibs WOB. Fish Fell -5 ft and caught on PRT. S/O and Tag up on Fish again at -39 ft in from RT. Fish fell, again. Shut Down Rotation and S/O another 10 ft. Did not tag up on packer. P/U only seeing a little over 40,000 Ibs on weight indicator. Slowly POOH. Drain Stack and look for Packer -Not Visible. Lost Fish. DECOMP L/D BHA#3, Clean Out Boot Baskets, and Inspect Packer Mill / PRT. Recovered --3 gallons of metal cuttings from Boot Baskets, Mill had slight wear but in good shape, and a little scaring observed on the top of PRT but shear ring still in place. DECOMP Change out Saver Sub in Top Drive. Inspect IBOP Threads and Grabber Dies, all in good shape. DECOMP Pull Wear Ring and Rig Up to Tes__t__BOPE used Burning well control circ out. DECOMP Set Test Plug and Pressure Test Hydril and Choke Valve #5. Test Plug Leaking. Pulled Plug and found rubber element chewed up. Call out to FMC for new Test Plug. Attempt to reset test plug and try pressure test again white waiting on new test plug. DECOMP New test plug on location, set test plug. Pressure Test Hydril and Choke Valve #5 Choke line Manual Valve and Ghoka Line HCR to 250 psi Low and 3500 osi Hiah for 5 mins. pond DECOMP R/D BOP Testing Equipment. Pull Test Plug and set Wear Ring. DECOMP M/U BHA #4 (PRT Packer Mill Assembly) consisting of PRT Packer Mill assembly, (3) 7" Boot Junk Subs, Bit Sub, Pump Out Sub, Bumper Sub, Oil Jars, X/O, (9) 6-1/4" Drill Collars, X/O, 6-1/4" Accelerator Jars, X/O to HT-38 Drill Pipe. Total Length of BHA #4- 344.56' DECOMP RIH with BHA #4 on 103 Stands of 4" HT-38 Drill Pipe from Derrick to fish Brown 3H Packer. RIH to 10,055'. Loss Rate while RIH- 3.5 BPH. DECOMP Establish SPR. Establish Fishing Parameters of Up Wt- 223,000Ibs; Dw Wt- 139,000 Ibs; Rt Wt- 168,000 Ibs at 20 RPM with 8000 ft-Ibs torque. Continue RIH, tag top of Packer at 10,096'. Sting into Packer and latch up at 10,099'. Stack 20,000 Ibs on Fish. P/U with 5,000 Ibs extra weight. DECOMP P!U 12' and CBU at 9 BPM with 1820 psi. No Losses. No Gas in Returns. Shut down Pump and Monitor Well for Flow- No Flow. Loss Rate @ 1 BPH. DECOMP Confirm Fish and pull off bottom with New Up Wt at 228,000 Ibs (5000 Ibs over) and 2000 Ibs drag while pulling on Fish. Continue POOH standing back 4" HT-38 Drill Pipe in Derrick. DECOMP POOH with BHA #4. Stand back 3 Stands of 6-1/4" Drill Collars. Clean out Boot Baskets, recover 3 gallon metal cuttings. No Fish Recovered. Inspect PRT .Grapple and found to be in good condition. RREP DECOMP C/O Saver Sub and Grabber Dies due to being over torqued when making a joint of drill pipe for fishing packer. Printed: 10/23/2007 2:59:02 PM • BP EXPLORATION Page 7 ofi 10' Operations Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Spud Date: 12/9/1987 Event Name: WORKOVER Start: 9/24/2007 End: 10/9/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/9/2007 Rig Name: DOYON 16 Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT 10/5/2007 106:00 - 07:00 1.00 I FISH I P 07:00 - 11:30 I 4.501 FISH I P 11:30 - 12:00 0.50 FISH P 12:00 - 13:30 I 1.501 FISH I P 13:30 - 17:00 3.50 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 20:00 2.00 FISH P 20:00 - 21:00 I 1.001 FISH I P 21:00 - 00:00 I 3.001 FISH I P 110/6/2007 100:00 - 05:00 I 5.001 FISH I P 05:00 - 06:00 ~ 1.00 ~ FISH ~ P 06:00 - 06:30 I 0.501 FISH I P Phase I Description of Operations DECOMP P/U BHA #5; 2-7/8" Reg Bull Nose, Itco Spear with 4.805" Nominal Grapple, Pump Out Sub, Bumper Sub, Oil Jars, 9 6.25" DC's, Intensifier. Total Length = 324.01'. DECOMP RIH w/ BHA #5 w/ 4" DP from Derrick. DECOMP Take Initial Parameters; 133,000 Ibs Dw Wt, 225,000 Ibs Up Wt, 3 bpm at 210 psi. Slow Pump Rates #1 = 30 stk/min @ 140 psi, 40 stk /min @ 250 psi. Slow Pump Rate #2 = 30 stk/min @ 200 psi, 40 stk /min @ 390 psi. Tag Up on Top of Packer at 10097' set down 10,000 Ibs. P/U and set down again with 20,000 Ibs able to slide in another 4' to 10101'. P/U and see -10,000 Ibs over pull. S/O and set down 40,000 Ibs, P/U and see -10,000 Ibs over pull. DECOMP Circulate Bottoms Up with fish off bottom at 8 bpm and 1720 psi. No sign of gas with circulation. Lost -1 bbl while circulating. Shut-Down Pumps and Monitor well for 15 mins. No Flow, Fluid dropped - 4 inches in flow nipple. DECOMP POOH with 4" DP and Stand Back in Derrick. DECOMP Stand Back Drill Collars. L/D remain components of BHA #5. DECOMP B/O and L/D Fish. Retrieved 9-5/8" Brown H-3 Production Packer, Mill Out Extension, 22 Joints of 3-1/2" Tbg, and "D" Nipple. Packer Length- 3.78', Millout Extension- 6.22' with X/O on bottom. Four pieces of slip cones recover in bottom of Millout Extension one brought up in the PKR. One small piece of slip recovered in the PKR. The upper section of PKR twisted off. The rest of the PKR body was not recovered (Rubber, Slip Cones, and Slips). 22 Joints of 3-1/2" TBG was in good condition. DECOMP R/D Doyon Tubing handling equipment. Clear and Clean Rig Floor. DECOMP Gather up Tools and Equipment for BHA #6 (Mill and CSG Scraper Assembly) consisting of 6" Bladed Junk Mill, (2) 5" Boot Junk Subs, Bit Sub, X/O, 11 Stands of 4" HT-38 Drill Pipe from Derrick, X/O, X/O, (3) 7" Boot Junk Sub, 9-5/8" Scraper, Bit Sub, Pump Out Sub, 6-1/4" Bumper Sub, 6-1/4" Jars, X/O, (9) 6-1/4" Drill Collar, and X/O to 4" HT-38 Drill Pipe. Total Length of BHA #6- 1415.47' DECOMP Continue RIH with BHA #6 (Mill and CSG Scraper Assembly) on 92 Stands of 4" HT-38 Drill Pipe from Derrick. Continue RIH picking up 31 Joints of 4" HT-38 Drill Pipe from Pipe Shed to 11,119'. Losses while RIH @ 1 BPH. At 02:00 and 7785' in the hole, losses immediately increased to 75 BPH DECOMP Tagged solid Junk at 11,119'. S/O 10,000 Ibs. M/U to Top Drive and Establish Parameters of Up Wt- 245,000 Ibs; Down Wt- 145,000 Ibs; Rot Wt- 175,000 at 30 RPM with 7000 ft-Ibs Torque; Pump Rate @ 6.5 BPM with 870 psi. Up Wt while Pumping- 205,000 Ibs; Down Wt while Pumping- 165,000 Ibs. Work on Junk with 3000 to 5000 Ibs WOB and 7500-10,000 ft-Ibs Torque. DECOMP Mill on Junk from 11,119' to 11,179'. 9-5/8" Casing Scraper worked down to 10072'. Junk was not solid, would take weight and mill for a minute then break through and would be able to S/O with no weight. Started taking weight consistenly below perforation at 1.1176'. Printed: 10/23/2007 2:59:02 PM • • BP EXPLORATION Page 8 of 10 Operations Summary:Report Legal Well Name: 18-17 Common Well Name: 18-17 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 ..Date From - To Hours Task Code NPT 10/6/2007 06:30 - 08:00 1.50 FISH P 08:00 - 08:30 0.50 FISH P 08:30 - 09:00 0.50 FISH P 09:00 - 13:00 4.00 FISH P 13:00 - 15:00 2.00 FISH P 15:00 - 15:30 0.50 FISH P 15:30 - 16:30 1.00 FISH N RREP 16:30 - 17:30 1.00 FISH P 17:30 - 22:00 4.50 FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 00:00 1.50 FISH P 10/7/2007 00:00 - 03:00 3.00 CASE P 03:00 - 03:30 0.50 CASE P 03:30 - 04:30 1.00 CASE P Spud Date: 12/9/1987 Start: 9/24/2007 End: 10/9/2007 Rig Release: 10/9/2007 Rig Number: Phase. Description of Qperations DECOMP Pump 20 bbl High Visc Sweep and chase out of the hole at 9.3 bpm and 2430 psi. A good amount of schmoo, scale, metal shavings and rubber seen in returns over the shakers. DECOMP Monitor Well for 15 mins. Fluid Level Falling -- 10 bbl loss in 15 mins. Blow Down Top Drive. DECOMP POOH and L/D Extra Joints of DP. Took - 25,000 Ibs over pull around 10847'. M/U Top Drive and Kick on Pumps at 9 bbl/min for 5 mins and was able to POOH w/ no over pull. DECOMP POOH and Stand Back Drill Pipe. 111 Stand of 4" DP in Derrick. DECOMP L/D 6-1/2" DC's, B/O and UD Boot Baskets and 9-5/8" Casing Scraper. Boot Baskets under scraper had - 3 gallons of scale, metal shavings, and small pieces of rubber. L/D 6" Mill and 4" Boot Baskets. Recovered -1.5 gallons of metal shavings from lower boot baskets. DECOMP Service Rig DECOMP Change out Saver Sub DECOMP Pull Wear Ring and Set Test Plug. R/U BOP Test Equipment and Tools. DECOMP Test BOPE to 250 psi Low Presure and 3.500 psi High Pressure. Each Test was held for 5 Minutes. Test was witnessed by AOGCC Inspector Bob Noble, Doyon Toolpusher, and BPX WSL. Test 1-Choke Valves 1, 12, 13, 14, Annular Preventer, and HCR Kill Test 2- Pipe Rams with 4" Test Joint Test 3- Choke Valves 9, 11, Blind Rams, Manual Kill, and Upper IBOP Test 4- Choke Valves 5, 8, 10, and Lower IBOP Test 5- Choke Valves 4, 6, 7, and TIW Valve Test 6- Choke Valve 2 and Dart Valve Test 7- Choke Valve 3 Test 8- HCR Choke Test 9- Manual Choke Test 10- Pipe Rams with 4-1/2" Test Joint Accumulater Test: Starting Pressure- 3,100 psi; After Accuation- 1,800 psi; First 200 psi Recovery- 16 Seconds; Full Recovery- 79 Seconds 5 Nitrogen Bottles at 2,100 psi. DECOMP R/D BOPE Testing Equipment, pull Test Plug, and Set Wear Ring. DECOMP Bring HES RBP to Rig Floor. P/U HES RBP and RIH on 4" HT-38 Drill Pipe from Derrick. DECOMP Continue RIH with HES RBP to test Casing on 106 Stands of 4" HT-38 Drill Pipe from Derrick to 10,075'. Loss Rate while RIH @ 2 BPH. DECOMP Establish Parameters of Up Wt- 195,000 Ibs; Dw Wt- 130,000 lbs. Set HES RBP at 10,075' with 2 LH rotations. Release from Running Tool and POOH 2 Stands Drill Pipe in Derrick. Confirm confidence test. DECOMP R/U Equipment to test Casing. Test 9-5/8" Casing to 3,500 psi and hold for 30 charted minutes. Good Test. R/D Testing Equipment. Printed: 10/23/2007 2:59:02 PM • BP EXPLORATION Page 9 of 10; Opelrations Summary Report Legal Well Name: 18-17 Common Well Name: 18-17 Spud Date: 12/9/1987 Event Name: WORKOVER Start: 9/24/2007 End: 10/9/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/9/2007 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/7/2007 04:30 - 05:30 1.00 CASE P DECOMP Slip and Cut 101' of Drill Line. Inspect Top Drive. 05:30 - 06:30 1.00 DHB P DECOMP P/U and RIH with HES Storm Packer on 1 Stand of 4" HT-38 Drill Pipe from Derrick to 90'. Set Storm Packer and test to 1000 si for 10 chart mi 06:30 - 08:00 1.50 WHSUR P DECOMP Drain Stack and N/D Flow Riser. Double Check OA Pressure - OA on Vac. N/D BOP's and Tubing Spool from Casing Spool. 08:00 - 12:30 4.50 WHSUR P DECOMP M/U Pack Off Retrieval Tool on Jt of DP. RIH and Engage 9-5/8" x 13-3/8" Manderal Pack Off. Pull Pack Off, Clean and Inspect, Install New 9-5/8" x 13-3/8" FMC Manderal Pack Off. Test Pack Off and Tbg Spool Connection to 5000 psi for 30 mins. 12:30 - 13:00 0.50 DHB P DECOMP M/U Running Tool, RIH and Release Storm Packer. POOH and L/D. 13:00 - 15:30 2.50 FISH P DECOMP RIH w/ 2 Stands of DP from Derrick. PJSM w/ Rig Crew and Vac Truck Drivers on Circ Out. Reverse Circ clean seawater into well at 7 bpm and 1140 psi 15:30 - 16:00 0.50 FISH P DECOMP S/O another 10 ft and engage HES RBP. Make 3 rt hand turns and Pick Up 30,000 Ibs over String weight to Pull RBP. 16:00 - 18:00 2.00 FISH P DECOMP Circulate Bottoms up at 7 bbls per min and 920 psi. 18:00 - 00:00 6.00 FISH P DECOMP POOH and L/D 4" HT-38 Drill Pipe. 10/8/2007 00:00 - 03:00 3.00 FISH P DECOMP Continue POOH w/HES RBP and L/D 4" HT-38 Drill Pipe. L(D HES RBP. Avera a Losses while POOH- 40 BPH 03:00 - 05:30 2.50 RUNCO RUNCMP Clear and Clean Rig Floor. P/U and M/U Doyon Torque Tum Equipment. Make final check of Completion Jewelry and Tubing. 05:30 - 06:00 0.50 RUNCO RUNCMP PJSM Running Completion 06:00 - 16:30 10.50 RUNCO RUNCMP P/U and RIH with 4-1/2", 12.6#, 13Cr80, Vam Top Completion String. Run WLEG, 4-1/2" XN Nipple, 4-1/2" X Nlpple, 9-5/8" x 4-1/2" Baker S-3 Packer, X Nipple, 3 GLM's 4-1/2" x 1-1 /2" MMG's, 4-1/2" X Nlpple and Tubing Hanger. 16:30 - 17:00 0.50 RUNCO RUNCMP M/U 4-1/2" TC-II Candling Joint to FMC 11" x 4-1/2" Tbg Hanger. Up Wt = 155,000 Ibs Down Wt = 115,000 Ibs. Land Tubing Hanger and RILDS 17:00 - 18:00 1.00 RUNCO RUNCMP Rig Up Circulating Equipment, and Circ Head. Line Up Valves to Reverse Circ. PJSM with Vac Truck Drivers and Rlg Crew. Spot Trucks. 18:00 - 22:00 4.00 CONDH P OTHCMP Pressure Test Lines to 3500 psi. Reverse Circulate 115 bb)s Seawater and 550 bbls of Corrosion Inhibited Seawater at 3 bpm with 110 psi. 22:00 - 22:30 0.50 ZONISO P OTHCMP Drop Baker ball and rod. Set Baker S-3 Packer. 22:30 - 23:00 0.50 ZONISO P OTHCMP Test 4-1/2" Tubing to 3500 psi. Hold test for 30 minute. Chart Results, Good Test. Bleed Tubing pressure to 1500 and shut in. 23:00 - 23:30 0.50 ZONISO P OTHCMP Test Baker S-3 Packer to 3500 psi. Hold test for 30 minutes. 23:30 - 00:00 110/9/2007 100:00 - 01:00 01:00 - 02:00 0.50 DHEOP P OTHCMP Bleed off Tubing Pressure and shear DCR Valve at 1000 psi (2500 psi differential pressure).. Reverse circulate and pump long through sheared DCR Valve to confirm communication. 1.00 WHSUR P OTHCMP P/U and Set TWC with FMC Req. Test to 1.000 psi from below and 3500 psi #rom above. Hold Tests for 10 minutes each, chart results, Good Tests. R/D Test Equipment. 1.00 WHSUR P OTHCMP N/D BOPE and Secure Printed: 10/23/2007 2:59:02 PM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 18-17 Common Well Name: 1 8-17 Spud Date: 12/9/1987 Event Name: WORKOVER Start: 9/24/2007 End: 10/9/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/9/2007 Rig Name: DOYON 16 Rig Number: Date From - To -Hours Task Code NPT Phase Description of Operations 10/9/2007 02:00 - 04:00 2.00 WHSUR P OTHCMP P/U and N/U Adapter Flange and Test Void to 5000 psi. Hold Test for 30 minutes. Good Test. 04:00 - 05:30 1.50 WHSUR P OTHCMP P/U and N/U Production Tree. Test to 5000 psi. Hold Test for 10 minutes. Good Test. 05:30 - 06:00 0.50 WHSUR P OTHCMP P/U DSM Lubricator and Equipment. Test Lubricator to 500 asi. Good Test. Pull TWC. R/D DSM. 06:00 - 08:30 2.50 WHSUR P OTHCMP Rig Up Little Red. Pressure Test Lines to 1500 psi . Pump 135 bbls of diesel at 1.5 bpm and 400 psi down IA and taking returns up tubing. 08:30 - 09:30 1.00 WHSUR P OTHCMP Shut-in to Little Red and U -Tube Diesel. 09:30 - 10:30 1.00 WHSUR P OTHCMP Monitor Well, Rig Down Circulating Lines, and Set BPV. Pressure Test BPV to 1000 psi from below with Little Red. 10:30 - 12:00 1.50 WHSUR P OTHCMP Blow Down and Rig Down Circulating Lines, RD Llttle Red. Remove Annulus Valve and Install Flanges and Gauges on Wellhead. Rig Down Cellar. Release Rig at 12:00 hrs 10/9/07. Printed: 10/23/2007 2:59:02 PM Digital Well File ~ • Page 1 of Well: 18-17 Well History Well Date Summary 18-17 10/9/2007 Pulled 4" CIW type H BPV, post rig Set at 96"deep 18-17 10/19/2007 Pulled C/1N Type H BPV, Pulled good. 18-17 10/25/2007 *** WELL SI ON ARRIVAL *** (Post RWO) PULLED BALL/ROD FROM RHC PLUG BODY @ 10,137' SLM PULLED RK-DGLV FROM STA #2 @ 5994' SLM *** JOB IN PROGRESS/ CONT ON 10-26-07 WSR *** 18-17 10/26/2007 *** CONT FROM 10-25-07 WSR *** (post rwo) PULLED RKP DCR FROM STA #3 @ 3365' SLM SET GENERIC GL DESIGN IN STA'S 3 & 2 PULLED RHC PLUG BODY FROM XN-NIP @ 10,141' SLM DRIFTED W/ 3.50 CENT, TEL & S-BAILER, LOC TT @ 10,152' SLM + 19' = 10,171' MD. TAG TD @ 10,162' SLM- 10,181' MD (5' RATHOLE).S-BAILER EMPTY *** WELL LEFT SI, DSO NOTIFIED OF WELL STATUS *** Print Da te: 10/31/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/ReportslReportViewer.aspx 10/31/200' ,. TREE = FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 55' '18-~ 7 +~ompletion SAFETY NOTES: 4-1/2" CHROMETBG DATE 10!26107 10!26/07 10/09/07 DATE REV BY COMMENTS DATE REV 8Y COMuE1~fTS 12/30/87 ORIGINAL COMPLETION 10!09/07 t}is RWO 03/15/88 LAST WORKOVHt 10/10/07 ITCH CORRECTIONS 05/22/01 RN/TP CORRECTIONS 10/26/07 OAV/I'L.H GLV GO 06/15/02 CWS/TP ECLIPS PKRILOW PATCH ASSY 06/18/02 JAFlTP ECLIPS PKR/UP PATCH ASSY 07/16!05 RWUTLH GLV C/O PRUDHOE BAY UNff WELL: 18-17 PERMIT No: 1871 200 API No: 50.029-2t 768-00 SEC 24, T11 N, R'i 4E, 962.69 FEt 246'V :34 FNL BP Exploration (Alaska) BOPE Test Report Maunder, Thomas E (DOA} From: Regg, James B (DOA) '~"~~1, - \~-~ j Sent: Monday, October 08, 2007 8:19 AM To: NSU, ADW Drlg Rig 16; aogcc_prudhoe_bay@admin.state.ak.us Cc: Maunder, Thomas E (DOA) Subject: RE: BODE Test Report Page 1 of 1 Thank you for the report. For future reference, you do not need to provide the report of those BOPE components tested following use of equipment for well control unless you are testing the entire stack. Please make sure a copy of the test chart is in your records and the daily drilling report documents the testing of the equipment used during well control. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~~~~,J ~~~ ~. v~ 2~~7 From: NSU, ADW Drlg Rig 16 [mailto:NSUADWDrIgRig16@BP.com] ~ ~ ` " Sent: Thursday, October 04, 2007 10:58 PM To: Regg, James B (DOA); aogcc_prudhce_bay@adminstate.ak.us Subject: BOPE Test Report Mr. Regg Attached is a BOPS Test Report from testing equipment used during a well controt event that occurred 10/3107 on well 18-17. In attempt to mil! and fish a production packer a gas bubble trapped underneath of it was circulated up hole. The weN was shut in using the annular preventer and the well was circulated through the choke. Mr. Lou Grimaldi with AOGCC was notified a# the time of the event as welt as BP ADW RWO Supervisors. Once out of the with the drill string, all components used during the event were test to 250 psi low and 3500 psi high pressure tests as per standards. This included the annular preventer, choke tine manual valve and HCR, and valves used in the choke manifold. Mr. Grimaldi requested that a BOPE Test form be filled out for the test and forward on to you. If you have any questions please feel free to salt. Mike Aivano Well Site Leader- Doyon 1& 907-659-4168 907-659-4163 Fax «Doyon 16 BOP Test 10-04-2007.x1s» 10/8/2007 18-17 (PTD #1871200) Classified as Problem Well ) ) Subject: 18-17 (PTD#1871200) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> . ....,'i.'.~~ Date: Sat, 12 Mar 2005 20:12:47 -0900 ">:I~'~'~' . To: "GPB,FSl DS Ops Lead" <GPBFSIDSOpsLead@BP.com>, "Schmoyer, AI" 'II:~';~~ .' <SçhmoyAL@BP.com>, "NSU, ADW Well OperationsSupervisór" <NSUADWWellOperationsSupervisor@BP.com>, "GPB,·Wells .Opt Eng" <QrBWellsOptEng@BP.com>,"NSU, ADW WL &~ompletîon Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB', Ops Mgr" <GPBOpsMgr@BP.com>; "RÖssberg,R Steven" <RossbeRS@BP.com>, "AOGCCWinton Aubert (E-mail)" <w:inton_aubert@admin.state~ak.us>,"AOGCC Jim Regg (E-mail)" <j~regg@admin.stattUtk:~us>, . "G:rB, FSlISIP/STP Area ]\1gr" <GPBFSITL@BP.com> CÇ:"NSU, ADW' Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP;com>, "Reeves, IJonald' F" . <ReevesDf@BP.com> Hello all. Well 18-17 (PTD #1871200) has sustained casing pressure on the IA and has been classified as a Problem well. Shut-in well pressures on 03/12/05 were T/I/O = 2520/1930/690. We will review the well with Anchorage Engineering on Monday and develop a remediation plan. Attached is a wellbore schematic. Please call if you have any questions. «18-17.ZIP» Joe Anders, P.E. Well Integrity Coordinator BP Exploration (Alaska), Inc 1-907 -659-51 02 anders22@bp.com ,..... If"' do ~'l--H...~ 1t:11~ k\ P I", .)~ ' 'I n [H: .'\j ~¡.1!·..u \1 ~ \Hç:.~J {-.-t 1: ...1 4: L U J ,J I of 1 3/22/2005 1 :47 PM ) TREE = WB..LHEAD = A CTUA TOR = KEf ËlË\i ~ . BF. ELËV= KOP= 'Max"Arïgïé .;.. OatumMO = OatumTVD = FMC FMC AX8..S0N ··......·--·55' 1200' "'~1ä"@"'64Ö()i' 11067' 8800' SS 18-17 «8 13-3/8" CSG, 72#, L-80, 10 = 12.347" l-i 3292' ~ ~ L Min imum ID = 1.75" @4500' + 4620' 2.74" ECLIPSE RETRIEVABLE PKRS 1 TOP OF 7" LNR 1-1 10118' 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-i 10350' ~ 3-1/2"TBG-FC,9.3#, L-80,0.0087bpf,ID=2.992" 1-1 10774' 1 ÆRFORA TION SUM\IIARY REF LOG: CH CNL ON 01/07/88 ANGLE AT TOP PERF: 36 @ 11040' Note: Refer to Production DB for historical perf data SIZE SFf NTffiVAL Opn/Sqz ()ð. TE 2-1/8" 1 11040-11050 0 09/01/88 2-1/8" 1 11070- 11084 0 09/01/88 2-1/8" 4 11098-11106 0 09/01/88 2-1/8" 4 11114-11132 0 09/01/88 2-1/8" 4 11138-11158 0 09/01/88 2-1/8" 6 11162-11176 0 03/28/88 1 PBID 1-1 11200' 7" LNR, 29#, L-80, 0.0371 bpf, 10=6.184" 1-1 11222' ~I ~ -/ I ) SAFETY NOTES: TROUBlEWB.L - T x IA COMMUNICATION, TBG LEAK AT 4536', FTS. 2181' 1-1 3-1/2" CAMCOTRDPSSSV NIP, D=2.812" 1 GA S LIFT I\ILA. NDRB..S ST IVD TVO DEV 1Y Æ V LV LA TCH PORT ()ð. TE 1 4025 3550 39 KBUG BK-2 2 9962 7978 38 M\IIG-2 RKP 4500' 4620' 10067' 10083' .. 1- ECLIPSE PKR W/UPPER PA TCH ASSY w /2-3/8" lBG PA TCH, ST-L,L-80, 10 = 1.75", OAL=119.33' (06/15/02) I-iECLlPSE PKR W/LOWER PA TCHASSY (06/10/02) 1 l-i 3-1/2" BAKffi PBRASSY 1 1--1 9-5/8" X 3-1/2" BAKER BOT 3H A<R 1 10764' 1-1 3-1/2"CAMCODNIP,D=2.75" 1 ~ 10773' l-i 3-1/2" BAKffi SH~ROUTSUB ~ i 10774' 1-1 3-1/2" 1UBNGTAL I I 10770' 1-1 B..MD TT LOGGED 03/28/88 1 I 11228' H FISH-IBPJUNK 1 REV BY ()ð. TE REV BY CO M\II ENTS 06/15/02 CWSfTP ECLlPS PKRlLOW PATCH A SSY 06/18/02 JAFfTP ECLlPS PKRlUP PATCH ASSY Z "I j ~ I DATE 12/30/87 03/15/88 01/09/0 1 02/22/01 OS/22/01 SIS-lsl SIS-LG RN'TP CO MrvENTS ORIGINAL COI'vPLEfION LAST WORKOVER CONVERTEOTO CANVAS REV IS ION CORRECTIONS I J: J:. J:. J:. I .....'......................<.......................... .-.. ~ mUDHOE BAY UNIT WB..L: 18-17 PE~IT No: 1871200 API No: 50-029-21768-00 SEC 24, T11 N, R14E, 962.69 FB.. 2461.34 FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ TUBING PATCH Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~]e, AK 99519-6612 5. Type of Well: Development _X Explorato~__ Stratigraphic_ Service__ 4. Location of well at surface 1239' FNL, 145' FEL, Sec. 24, TllN, R14E, UM At top of productive interval 2300' FNL, 700' FEL, Sec. 23, T11N, R14E, UM At effective depth 2455' FNL, 930' FEL, Sec. 23, T11N, R14E, UM At total depth 2461' FNL, 963' FEL, Sec. 23, T11N, R14E, UM (asp's 691622, 5960623) (asp's 685816, 5959418) (asp's 685591, 5959258) (asp°s 685558, 5959249) 12. Present well condition summary Total depth: measured true vertical 11224 feet Plugs (measured) 8982 feet Effective depth: measured true vertical Casing Length Conductor 109' Surface 3255' Production 10313' Liner 1104' 11166 feet Junk (measured) 8935 feet 6. Datum elevation (DF or KB feet) RKB 55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-17 9. Permit number / approval number 187-120 10. APl number 50-029-21768 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Tagged PBTD @ 11166' MD (03/23/1999) Fish - IBP Junk @ 11228' Size Cemented Measured Depth True Vertical Depth 20" 1687# Poleset 146' 146' 13-3/8" 3500 sx CS III, 600 sx Class 'G' 3292' 2989' 9-5/8" 875 sx Class 'G' 10350' 8284' 7" 400 sx Class 'G' 10118'- 11222' 8101'- 8980' Perforation depth: measured Open Perfs 11040'-11050', 11070'-11084', 11098'-11106', 11114'-11132', 11138'-11158', 11162'-11176' true vertical Open Parrs 8833'-8841', 8857'-8869', 8880'-8886', 8893'-8907', 8912'-8928', 8932'-8943' Tubing (size, grade, and measured depth) 3-1/2" 9.3# k-80 PC-TaG @ 10774'. ,!:i'~i~ ;L {,,,,.~ i!'~::: ~'~' .. ,~, Packers & SSSV (type & measured depth) 9-5/8" x 3-1/2" Baker BeT 3H Packer @ 10083'. 2.74" ECLIPSE RETRIEVABLE PKRS @ 4500' & 4620' (TBG,~at~,h,, Set :--- 06-15-2002). 3-1/2" Camco TRDP SSSV Nipple @ 2181' MD. 13. Stimulation or cement squeeze summa~ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Well Shut-In Subsequent to operation 06/24/2002 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 3295 15875 0 443 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil __X Gas_ Suspended_ Service 17. I hereby certify that the foregoing is true,nd correct to the best of my knowledge. DeWa~/ne R. Schnorr Form 10-404 Rev 06/15/88 · Date June 251 2002 ~ Prepared b~/DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 18-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/23/2002 PATCH TUBING / LINER: TUBING TAIL PLUG 06/10/2002 PATCH TUBING / LINER: PATCH TUBING / CASING 06/14/2002 PATCH TUBING / LINER: PATCH TUBING / CASING 06/15/2002 PATCH TUBING / LINER: PATCH TUBING / CASING 06/18/2002 PATCH TUBING / LINER: AC-MITIA 06/22/2002 PATCH TUBING / LINER: GAS LIFT--FOR RATE EVENT SUMMARY O5/23/O2 PULL CA2 BLANKING PLUG FROM D- NIPPLE @ 10,749' WLMD <<< WELL READY TO POP >>> 06/10/02 SET ECLIPSE SERIES THREE PACKER (LOWER PIECE OF PATCH ASSEMBLY) AT 4620' (CENTER OF ELEMENT). CCL TO CE = 13.7'. TAGGED TOP OF PACKER. PACKER SPECS: 2.67' OAL, 1.75" ID. NOTIFY PAD OP OF WELL STATUS: LEFT SHUT IN. 06/14/02 BOP TEST COMPETE, BLEED AND KILL IA WITH SH20, MEOH WATER AND DIESEL. KILL TUBING, SPOT FLO-PRO. NO FLOW TEST, MU ECLIPSE PATCH 06/15/02 SET PATCH AND UPPER PACKER @ 4500.6' CTD, OAL = 119.33', BOTTOM STUNG INTO ANCHOR @ 4620' ELM. PUMP MULTIPLE BALLS, PUMP FOAM PIG, SET PACKER. TESTS OF TUBING TO COIL ANNULUS ARE GOOD. UNABLE TO RELEASE FROM PACKER, PUMP FOAM PIG #2 AND RELEASE FROM PACKER, POOH. MIT IA 1500 PSI / 30 MIN, GOOD, PSI INCREASED TO 1650 PSI, BLEED BACK TO 500 PSI. <<<LEFT SHUT-IN>>> 06/18/02 MIT-IA PASSED TO 2000 PSI. (POST PATCH SET) O6/22/O2 PULL DGLV FROM STA #1. SET 1, S/O (20/64" PORT). <<<RETURN WELL TO DSO FOR PROD.>>> Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 2 TESTS) 10 NEAT METHANOL 12 METHANOL 10 50/50 METHANOL WATER 497 DIESEL 86 SEA WATER 650 1% KCL WATER 4O FLO-PRO 13O7 TOTAL Page I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1239' FNL, 145' FEL, Sec. 24, T11N, R14E, UM At top of productive interval 2300' FNL, 700' FEL, Sec. 23, T11N, R14E, UM At effective depth At total depth 2461' FNL, 963' FEL, Sec. 23, T11N, R14E, UM 5. Type of Well: Development__X Exploratory_ Stratigraphlc_ Service__ 6. Datum elevation (DF or KB feet) RKB 55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-17 9. Permit number / approval number ,'37-/2o 10. APl number 50-029-21768 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 109' Surface 3237' Production 10295' Liner 1104' 11224 feet Plugs (measured) 8982 feet 11166 feet Junk (measured) 8935 feet Tagged PBTD @ 11166' MD (3/23/1999) ORIGINAi Size Cemented Measured Depth True vertical Depth 20" 1687# Poleset 109' 109' 13-3/8" 35oo sx cs H~ & 6oo sx c~ass G 3292' 2989' 9-5/8" 875 Sx C~ass 6 10350' 8284' 7" 4oo Sx Class G 11222' 8980' Perforation depth: measured 11040'- 10050'; 11070'- 11084'; 11098'- 11106'; 11114'- 11132'; 11138'- 11158'; 11162'- 11176'. true vertical 8833' - 8841'- 8857' - 8869'; 8880' - 8886'; 8893' - 8907'; 8912' - 8928'; 8932' - 8943'. Tubing (size, grade, and measured depth) 3-1/2"9.3#, L-80 PCT @ 10774' MD. Packers & SSSV (type & measured depth) 9-5/8" X 3-1/2" BAKER BOT 3H PACKER @ 10084' MD. 3-1/2" CAMCO TRDP SSSV @ 2182' MD. RECEtVE[ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Anchorage 14. OiI-Bbl Prior to well operation (shut in) Subsequent to operation (shut in) Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ~X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service Signed Erin Oba 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2,,Title ARCO Engineering Supervisor Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 18-17 DESCRIPTION OF WORK COMPLETED SET TUBING PATCH Date Event Summary 3/23/1999: 10/0911999: 10/18/1999: RIH & tagged PBTD @ 11166' MD. RIH & set Eclipse Tubing Patch f/4527' - 2552' MD. TI FL failed. Well is currently shut in and future well work options are being evaluated. RECEIVED DF.C 01 1~99 l~,e: Wells capable of unassisted flow. Subject: Re: Wells capable of unassisted flow. Date: Fri, 04 Jun 1999 11'19:12 -0800 From: Blair Wondzell <Blair_Wondzell@admin.state.ak.us> Organization: SOA-AOGCC To: PRB Problem Wells <P 1041 @mail.aai.arco.com> Jerry, I just finished reading your comments on these wells. Your proposal sounds fine to me. I agree you should proceed as you've proposed Blair 6/4/99 ' PRB Problem Wells wrote: > > Blair: This is a summary of the requests I have from Engineering to temporarily > flow wells that are capable of unassisted flow: > DS 3-34: Post packer cement squeeze; determine if capable of unassisted flow to > surface. Has broken gaslift valve in station 4 Flow period approximately > 1-week. ' > DS 11-25: Documented hole below 5 1/2" x 3 1/2" crossover, needs patching. Needs > flow testing after add perforations to determine if additional wellwork is > needed prior to patching. Wireline tools will not be able to get below patch > once installed. Flow period request for 2-4 weeks. > DS 13-33: Documented hole in tubing, not economic to repair. Passed CMIT T x IA. > Need flow ~s? to determin, e if. worthy to apply for Sundry Notice to continue > flowing wir ~nown communication (capable of unassited flow). Flow period for > 2-3 weeks. · DS 16-31: SI since 1994 with leaking patch over GLM #10. Need flow test to · determine if worthy to apply for Sundry Notice to continue flowing with known · communication (capable of unassited flow). Flow period for 2-3 weeks · DS 18-17: Documented T x IA communication through corrosion holes. R'equest to · flow well with corrosion probe installation for 4-6 weeks to determine corrosion. · rate for engineering study. This well is capable of unassisted flow. · DS 18-25: Documented T x IA communication through corrosion holes. Request to · flow well with corrosion probe installation for 4-6 weeks to determin~ corrosion · rate for engineering study. This well is capable of unassisted flow. · I can provide more detail, but the main concern is that these wells are, or may · be, capable of unassisted flow and have known communication. At the termination · of these flow tests the wells will be SI and secured. Let me know if you need · additional information, and whether these short-term flow tests are worth · bothering you wi th. Thanks! · Jerry Dethl els > · Blair Wondzell <Blair_Wondzell@admin.state.ak.us> on 05/24/99 10:34:46 AM · · To: PRB Problem Wells/AAI/ARCO · CC: · Subject: Re: Wells capable of unassisted flow. · · Jerry, · · These types of problems are in a poorly defined area of our regulation, · therefore my practice has been to check on the regulation goals of · protection of casing. If the casing appears to be protected, then agree · that the request is appropriate. For example if you have a "minor" · tubing leak in a gas lift well, this is not much different than having a · choke in a gas lift mandrel - so no problem. · · My suggestion is that by E-mail you provide data on the the specific · wells such as depth of leak, severity, type of lift, why annulus will · not be subjected to well bore fluids and similar thoughts that come to · mind. · We can evaluate and advise (on most I'm sure) that there is no problem · with continued production. · · Lets give this a try. Thanks. Blair. · · PRB Problem Wells wrote: 1 of 2 6/4/99 11:21 A .,.e: Wells capable of unassisted flow. (' > > Blair: As a production well develops T x IA communication it has always been our > practice to SI the well except for very short periods of time we may need to do > diagnostics. The wells have been repaired and tested prior to resuming routine > production. As you have noticed, recently we have been evaluating several wells > with iow future potential, especially due to the cost of RWO's. It has been > great to get approval for some of these wells (14-40, 14-06) to continue to flow > with known communication problems. I expect more of these requests to come your > way. > As part of the process to develop a Sundry we have found it necessary to flow > these wells for a limited period of time prior to submission of the 10-403 to > figure out if they are even worth producing on a routine basis. In addition, I > receive requests periodically from the Engineering staff to flow other wells > capable of unassisted flow that have not yet been repaired, or have some other > diagnostic or evaluation requirement needed. Since the frequency of these > requests have increased, I feel some guidance from you is in order so we don' t > risk operating wells out of compliance. > I currently maintain a list with my alternate of wells that have been requested > for flow by Engineering. This list now has 7 wells capable of unassisted flow, > of which 2 wells are currently on line. The list includes the well name, purpose > of flowing the well, approximate duration (1-6 weeks) the date brought on line, ' > and the mechanical condition or problem with the well. Our criteria is based on > flowing the well no longer than is needed to obtain the requested data; in other > words, flowing for production of oil is not a legitimate request. At the > termination of the flow period the well is SI, secured, and removed from the > list. > Do you want to be informed of the wells on this list, given the short duration > of these tests? This is a fairly new procedure for us to use, but has be very > useful for tracking' these situations. Should you want to be kept informed at > this level of detail, I could periodically forward the list to you Let me know ' > what you prefer. Thanks! > Jerry Dethlefs > ARCO Problem Wells Specialist 2 of 2 6/4/99 11:21 A1 ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 .i May 25, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Flow testing of wells capable of unassisted flow to the surface. Dear Mr. Wondzell: This letter is in response to your emails on May 25 regarding justification for flow testing of wells capable of unassisted flow to the surface. The following text provides a brief reason for the flow test, as well as arguments why casing damage should be minimal. In all cases, the wells will be tested for a limited duration and then shut-in and secured until approved by your office for some action (via 10-403) or the xvell is repaired. Tracking of the flow testing duration will be done from the Problem Wells Specialist office. DS 3-~Had a failed packer, which has recently been cement squeezed to regain pressure integrity to the tubing string. It has subsequently been tested to not be capable of unassisted flow to the surface, so an exemption for flowing is not requested. DS 11-25: Has a documented hole below the 5 1/2" x 3 1/2" crossover as per LDL 5/4/98. This single hole needs patching, since the well is capable of unassisted flow to the surface. Casing damage is not expected to be a concern, since the well will require gaslift and the annulus will be gas filled. Flow testing is requested prior to patching since perforations were added and need to be evaluated before a patch is set. Additional perforations or a squeeze may result post flow-test. A patch in the 3 1/2" tubing will not allow further downhole work without the patch being pulled, and subsequently reset before sustained production. The flow period request is for. 2-4 weeks. DS 13-33: Has a documented hole in the tubing at a failed non-retrievable patch set over GLM #10 in 1990. The well has been shut-in since 1995, and does not have the reserves to justify a RWO to replace the tubing. The xvell passed a CMIT T x IA to 3000 psi in 1995. This is a candidate well for a Sundry 10-403 application to continue to flow with a known T x IA communication problem. The request is to flow test for 2-3 weeks to determine if production rates are sufficient to apply for Sundry Notice and/or determine if the well is capable of unassisted flow. The well will require gaslffi from a deep valve, so the casing will be protected from production flow by the gas-filled annulus. DS 16-31: SI since 1994 with leaking patch over GLM #10. This is a candidate well for a Sundry 10-403 application to continue to flow with a known T x IA communication problem. The request is to flow test for 2-3 weeks to determine if production rates are sufficient to apply for a Sundry Notice and/or determine if the well is capable of unassisted flow. The well will require gaslift from a deep valve, so the casing will be protected from production flow by the gas-filled annulus. A CMIT T x IA passed to 3000 psi in 1994. DS 18-17: Has documented T x IA communication through a corrosion hole at 4546'. The request is to flow the well after a corrosion probe installation for 4-6 weeks to determine the corrosion rate for an engineering study of the corrosion mechanism in the gravity drainage portion of the field. This well is capable of unassisted flow to the surface. Due to the GOR of the well and the single leak point, the annulus is expected to be gas-filled during the study period, which should minimize casing exposure to production fluids. The well will be SI and secured after the study is completed. I DS 1 ~-1~.' Has documented T x IA communication through a corrosion hole at 7244'. The request is to flow the well after a corrosion probe installation for 4-6 weeks for the corrosion mechanism study in the gravity drainage portion of the field. This well is capable of unassisted flow to the surface. Due to the GOR of the well and the single leak point, the annulus is expected to be gas-filled during the study period, which should minimize casing exposure to production fluids. The well will be SI and secured after the study is completed. I hope this letter provides enough explanation for approving a flow-test of these wells for a limited period of time. Please call or email if you need additional information. ethlefs em Well Specialist TRSSSV Tubing-PC Casing Casing Gas Lift MandrelNalve 1 Gas Lift Mandrel/Dummy Valve 2 ..... PBR ....... PKR NIP Liner SOSUB TTL Perf ' Perf ...... -- Perf ..'.:' -- Perf ' = 18-17 18-17 Spud: 112J9187 KOP:I 0.00 ftKB i Orig Compltn:112/30/87 PBTD:t 11224.00 ftKB Annular Diesel/SW f Last W/O:I 3/15/88 TD: 11224.00 ftKB Reference Log: CH CNL Ref Log Date:I 1/7/88 Max Hole Angle: 46 deg @ 6400 Last I Last Ta.q Date:l Angle ~ TS:! 38 de.q ~ 10548 Rev Reason: GLV Corrections I Last Update:l 4/16/98 I Angle ~, TD:! 36 deq ~, 11224 Elevations KB 55 ft Cas Flnq 0 ft Grd 17 ft T db Head 0 ft KB-Grd 38 ft - All ID Type ', Description 2.812 TRSSSV 3-1/2" Camco TRDP SSSV Nipple 0.000 . PBR ~ 3-1/2" Baker PBR Assembly 0.000 [PKR [ 9-5/8" x 3-1/2" Baker BOT 3H Packer 2.750 [NIP ,3-1/2" Camco D Nipple 0.000 I SOSUB 3-1/2" Baker Shearout Sub General Notes TTL 3-1/2" Tubin¢~ Tail Note Item 9.625 in Casing Item 7.000 in Liner 10764 Min ID = 2.750" (3-1/2" Camco D Nipple) 10770: ELM Tubin( ICTION Top I 0.00 LINER Top i (ffKB) ! 10118.001 SURFACE Daterun: 1987-12-30 Btm Wt47.00 10350.00 Btm I Wt29.00 (ffKB) 11222.00 Grd L-80 Grd L-80 Item 13,375 in Casing - TUBING Item 3.500 in Tubinq-PC Top i Btm (ftKB~.00 (ftKa) 3292.00 Wt 72.00 Top 0.00 Bottom I Len 0774 (ffKa) (ftKa) (ft) l 10774.00 Grd L-80 Wt 9.30 Grd L-80 Gas Lift Mandrels/Valves Man Type Vlv Mfr Vlv Type CA E ' CA RKED Perforations Summary Interval Zone Status Feet~ 11040 - 11050 ZONE 2 O 10 11070- 11084 ZONE2,ZONE O 14. lB 11098 - 11106 ZONE lB 'O 11114 - 11132 ZONE lB O© O i 18 11138 - 11158 ZONE lA 20', 11162 - 11176 ZONE lA 14! Latch I Vlv I Vlv TROI Vlv Run Port BK-2 0.000 0.0 1/1/60 RKP I o,oool o.o, 1/1/60 SPFI Date Type ~ Comment 1/219/1/88 I RPERF ; 1/219/1/88 ! RPERF 4 9/1/88 RPERF i -- 4 9/1/88 l RPERF i 419/1/88 I RPERF 1 613/28/88 I IPERF I ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-10-93 0~ REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 5-25 ,_ 8-2-92 6-4 ~ ~>~~ 12-28-92 15-20~' ~ 8-1-92 18-17~ ~t° 8-17-92 TMD Run 1 ~ Job#L84759-4 TMD ~. 5-Run 1~o ~' Job#L84599-9 TMD %~a~- R~m 1~ Job#L84757-2 TMD I~ R~_~_n 1,lsd' Job#L84770-4 Please sign and return the attached copy as receipt of data. RECEIVED BY~~~t~~ Have A Nice Day! Sonya Wallace APPROVED_ ATO- 1529 Tr~_ns# 93101 # CENTRAL FILES (CH) CHEVRON D&M ~0~ OC~S (Oa/~) # EXXON MARATHON MOBIL # pm~.T.TPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINAI~ ~3-31 -~-~-~3-31 -2 ~-9 5-25 ~/5-~, ~ 6-4 ~-~_? *_14-23 ~-q- ~~15-20 ~{~~~1~ /16-14 6-14 10-17-92 PSGT - Computed Results Run 1, 10-17-92 PSGT Run 1, 1-25-93 PSGT - Computed Results Run 1, 1-25-93 PSGT R~_m 1, 2-19-93 PSGT - Computed Results Run 1, 2-19-93 PSGT R~m 1, 7-24-93 PSGT - Computed Results R~_m 1, 7-24-92 PSGT Run 1, 2-18-93 PSGT - Computed Results R~m 1, 2-18-93 PSGT R~_m 1, 2-21-93 PSGT - Computed Results' R~m 1, 2-21-93 PSGT R~m 1, 1-24-93 PSGT - Computed Results R~m 1, 1-24-93 PSGT Run 1, 8-2-92 TMD R~_m 1, 12-28-92 TMD R~m 1, 12-9-91 TMD R~_n 1, 8-1-92 TMD R~_m 1, 9-17-92 PSGT - Computed Results Run 1, 9-17-92 PSGT R~m 1, 8-17-92 TMD Run 1, Please sign and return th~ attached copy as r~eceipt of data. RECEIVED BY .... ,,_ ' Have A Nice Day! APPROVED_ffffff___ Trans# 93047 # PHILLIPS PB WELL FILES # BPX # STATE OF ALASKA * The coreect APl# for 14-23 is 50-029-20757-00. 11 5' 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" ARCO ALASKA, INC. F'.O. BOX t00360 ANCHORAGE, ALASKA 9,..,, 0 DATE · 7-3t -gJ REFERENCE' ARCO CASED HOLE FINALS t B 6-26-9 ~ -22 T-3-9~ ~ -.-°4 6-27-9] ~ -25 ?-4-9~ 2-9 6-29-9t 5-3 6-23-9i 9-2 7-8-9i 9-35 7-8-9i i3-t0 7-6-9J t 4-i 4 7-5-9i * i 7-i i 6-20-9i i 7-i t 6-20-9i t8-7 7-5-9t i 8-~ 7 7-5-9t -~.~ 8-24 7-3-9i PROD PROFILE PROD F'ROFILE F'ROD F'ROFILE PROD PROFILE F'ROD PROFILE LEAK DETECT LEAK DETECT LEAK DETECT LEAK DETECT LEAK DETECT CASING INSPECTION CALIPER LEAK DETECT PROD F'ROFILEE PROD PROFILE F'ROD F'ROFILE 0 RUN Rc C?../V RUN RUN Nssk~ Oil & G~s Goos. Gommis~ N An~o~ R U N RUN RUN' RUN RUN RUN RUN RUN RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA, RECEIVED BY HAVE A NICE DAY! SONYA WALLACE AT0-i529 TRANS$ 9 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CFIEVRON D &M EXTENSION EXF'LORATION EXXON HARAI'HON MOBIL PHILLIPS F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO * THE CORRECTED BOTTOM [.OG INTERVAL IS 4,900 FEET I::'~0~ BOX ~r30S60 ANCHORAC;E, AL.A~'KA ~95t0 DATE' 6-22-98 Rli'.'FE:RENC]E: ARCO MA6NETIC TAF:'E(,S') WITH .., .... ,.:'. 3 .... c,:,,,.,, C N T-' I) ( 4 F'A,.?,S' ) , R J 0 B .';: 43 '? .5 J 0 B ¢: 73890 I:'I..FA,~;E ;~I(.;N AND F;,'F'f'URN THE AT'FACHED COF'Y A,S' I"'(FCEIF'f' OF DATA., R E C. E I VIE D BY ......... EE' EI"¥"E D HAVE A Nzc[:: DAY! ,,~'/ .,. ,.?AI...LY I..IOF'F[.i:CKERJUN 8 1 1990 AF'F'~:~:ovr.-::~) ,~ A 'lr' 0 t "-'" o - -":'. ~' Alaska Oil & Gas Cons. Commission T R A N,S' :. 9 ( Anchorage A 'f'l_ A,?;' ,S' C H D I ,S' T R I B [J T I 0 N ARCO AL.A:'?KA, ];NC, P. 0. B (] X i ,:~;,,:.} :_~ 6,3 ANCHORAGE, ALA£'KA 995i(~ D~TE' 6/7/9~ REFERENCE' ARCO CASED HOLE FINALS F'WDWi-2 ,--..-~o-o~:,_. .,.., , .., ~:[.,~t..IEEZE. PERF Rt..tN PWDW!-2 5-29-9¢3 BRIDGE F'LUG SETTING REC RUN i, i--ti 6-2-9('~ COMP NELITRON G/R RUN i , 5" i-2.?,. 6-2-90 COMP NELJTRON G/'R RUN ,..:,-, 6-3-.9(D COMP NEUTRON .... G/'R RIlN t, ~',. 3.-'27 S-'24- 9 ~,:) COMP NEU'¥RON RUN 4-33 5-i9-9(~ POST INJ TEMF' RUN t, ':.2' 6-2 ~-'2."..f,-9¢.~ COMF' NEUTF(ON RUN W, 5' 7-..i 6 "c-24-9~..... COMF' NELJTRON RUN t 2.-t 8 5-3(-}-9(D COLLAR. RUN i , S' t8-i7 _q;,-2.3-.ge COMP NEUTRON RUN i, i8-t9 ~-') .I:U !,_ RUN ,..5-9~ COMP N- 'l':;'r~N , F'I_EAS;E 5.,'IGN AND RETURN 7'FIE ATTACFIED COPY AS RECEIF'T OF DATA, RECEIVED HAVE A NICE DAY ! JUN 1 4 1990 ALL Y HOFFECK El;'. Alaska 0il & 6as Oo~s. Gomm~iofi T O- ~ 5 2 ~ ~nchomge AF'F'ROVE~ TRANS~ 9r',)2t S ~' C H A'i LAZ A 'i'l_ A.? A T L_.A ;~.' 2'CH H R .-"'.'; &' C 14 $CFt A '[ i_ A.'~' ~'CH SCI.-I DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL F'HILLIF'$ F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO DATE · 4--'26-09 Rli:'FERENCE: ARCO PRESSURE DAFA 2- t 0 4 - i ..- 89 B ttF ..... ,?'rA l' I C G R A I) I E:' N T -4.-29 2-22-89 BHI= ..... F'LOWI' Nt; GRAD.IiENT _"',~-.-t e 3-.27-.89 BHF ...... SI'AI'IC GRADIENT 6-3 4.- J -89 BHF ..... $'FA T I C (.l F:AI) I ENT it'-t6 4-"~'?-89 BHF" ..... STATIC [;RADIE:NI' t I -" t '? .4 '- t '?- 89 B H F: ...... .S' T A T I C [; R A D I E N'F i i -' t 8 4" i '? -' 89 B H F ...... ,$' T A l' I C G R A I) I El N l' t t-24 3-"20-'89 BHF: ....... .S"¥AI'IC L';I:(ADIENT f 2- t 8 4 -' t O-' 89 Bl"l F ........ $ l'A l' I C (; R A D I E N T t 2-'26 3'-3G-89 BHF'-'"'$TAI'IC GF;..'ADIENT ~ 3'-t 4'"2-89 BI"IF ...... ,?'I'AI'IC (;RAI)IENT I 3.-t 0 4.'-3-89 BHF ...... STAlrlt] GRADIK'NT t4--tt 4-..t-89 BHF ..... ,.?TAI'IC GRADIENI' t 4.-t 2 4..-J-89 BHF ....S rATIC GI:~ADII!:'Nr 4 4 - 2 t 4 -.. 4 .- 89 B H F ..... ,S' T A 'ir I c G R A I) I E N T t .5.-t eA 4-2-.89 BI.4F ...... ,S"I'A';'ICGRADI'ENT t5-.t9 4 .... 2-89 BHF' ..... ,.?TATIC GRADIENT t 5.-22 4-2..-89 BI.4F ..... ,S'TATIC GRADIENI' t 5 .... 2.5 4-3-89 BHF' .... S'I'AI'IC GRAI)IEN'I' t 8-4 3-29-89 BHF'--,S'I'ATIC GRADIEN l' t8.-8 3-29-89 BHF ........ ,.?TATIC GRADIENT t 8-t t 3.--30-89 BI.4P--S'rAI'IC GRADIENt t8 .... t7 Z'~-.29-89 BHF ...... S'rAI'IC GRAI)IENT t J)'-2J 3-29-89 BHF'--$TAI'IC GRADIENT F'I...EASE SIGN AND RETUF;~N I'FIE ATTACHEI) C.)FY AS OTIS C A H C C) CAHCO C A H C O CAHCO CAMCO CAHCO C A H C [) C A H C' 0 0 T I S OTIS 0 'r I ;~' 0 l'I 0 I" I ,S' C A H C.'. 0 .. CAHCO CAHCO CAHCO 0 'r I S CAHCO 0 l' I ,~' CAHCO CAHCO RECIEIF'I' (:IF'" DATA, RF=CEIVED BY HAVE A NICE DAY. . , A'ro-- J 529 ~slm Oil & Gas Oo,s. Commissio~l I'R~N$~ 89'~- Anchm'age DISTRIBLJI'ION CEN'FRAL FILES '~ I:' .. HII_LIF'S CHEVRON F:'B, WEL. L F Il. ES · ,,-g & M ~ R & D F:'XTFN,S' ! ON EXPL. OI"~AI'I [.iN '" BF'X 'ir ~, FXXI]N ~ STAI'E OF' ALASKA HARAI'HON ' · " I'EXACO · ,- HOBIL ARCO ALASKA, INC. F'.O. BOX t~0360 ANCHORAGE, ALASKA DATE' 3-29-89 REFERENCE: ARCO PRESSURE DATA 4-2 2-t 0-8,0 BHP--FLOWING GRADIENT CAMCO 4-i9 t-3t-8,0 BHP--STATIC GRADIENT CAMCO 5-t7 2-t 6-8,° BHF'--STATIC GRADIENT CAMCO 6-8 2-5-85> BHF'--S'[ATI C GRADIENT CAMCO 5>-3 t -t 5-89 BHF'--STATIC GRADIENT O'rlS 9-tt t-J~-8,0 BHP--$TATIC GRADIENT CAMCO ,0-tt 3-5-8? BHF'--FLOWING GRADIENT CAMCO ~t-t t2-2!-88 BHP--STATIC GRADIENT OTIS t1-tt J-t?-8,0 BHP--STATIC GRADIENT OTIS tt-t6 ~-t4-89 BHP--STATIC GRADIENT OTIS t2-t5 2-tt-89 BHP--STATIC GRADIENT CAMCO t2-2J 2-t 5-89 BHP--STATIC GRADIENT CAMCO t4-28 2-5-8,0 BHP--STATIC GRADIENT CAMCO t6-~ J-tt-89 BHP--PRE$SURE BUILD-UP OTIS t8-t? 2-tJ-89 BHP--FLOWING GRADIENT CAMCO F'WDWt-t J-J-8,0 BHP--STATIC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 APPROVED ..._'~ .... Commissio~ Anchorage DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTEN$'ION EXF'LORAT I ON · " EXXON MARATHON .-'- MOBIL · ,- PHILLIPS F'B WELL FILES ~- R & D A F' · .' SA C STATE OF ALASKA TEXACO DATE: 3-2-89 REFERENCE: ARCO CASED HOLE FINALS 3-t2 2-2i-89 PRODUCTION PACKER RUN i 4-2 2-t0-89 PRODUCTION PROFILE RUN i 4-i2 2-ii-89 PRODUCTION F'ROFILE RUN i ii-2 2-3-89 INJECTION PROFILE RUN ii-3 2-i-89 PRODUCTION PROFILE RUN tt-3 ~-'~-no~ ~ ~. 'FEMP SURVEY RUN ti-4 2-2-89 PRODUCTION PROFILE RUN i ti-5 2-6-89 PRODUCTION PROFILE RUN i ii-? 2-3-89 INJECTION PROFILE RUN i ii-J2 2-3-89 TEMF' SURVEY RUN i ii-iS ~-~-89 TEMP SURVEY RUN i i2-3t 2-i?-89 CBT RUN i ~2-3i 2-i?-89 CET RUN i t4-i8 ~-'~o-~~ ~ ~_CNL-GAMMA RUN i4-i9 ~ ~-~-~Q-- CNL-GAMMA RUN i i4-28 2-5-89 TEMP RUN i t4-29 ~-~-89~ CNL-GAMMA RUN i t4-~3 ~-~'~-=~-~ ~. CNL-GAMMA RUN i i~-22 t-23-89 PRODUCI'IDN PROFILE RUN i i8-4 2-i2-8~ PRODUCTION PROFIkE RUN i i8-i? 2-i3-89 F'RODUCTION F'ROFILE RUN i , 5' 5m 5m , 2"&5" ~m 2m 2m ~m ~m PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 TRAN$ ~89~9 APPROVED DISTRIBUTION A'FLA~ CAMCO CAMCO CAMCO CAMCO CAMCO CAHCO CAMCO CAMCO CAMCO CAMCO $CH SCH ATLAS ATLAS CAMCO ATLAS ATLAS CAMCO CAMCO CAMCO CENTRAL FILES. CHEVRON D &M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES SAF'C STATE OF ALASKA TEXACO ARCO Alaska, Inc~(' Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 11, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 18-17 Approval No. 8-645 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve ~'O.F.~, DFS/TPA/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 18-17)W1-3 WELLS3/36 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C i" STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COM : REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Alter Casing '%.. Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1242' FNL, 146' FEL, Sec. 24, TllN, R15E, UM At top of productive interval 2300' FNL, 700' FEL, Sec. 23, TllN, R14E, UM At effective depth 2336' FNL, 980' FEL, Sec. 23, TllN, R14E, UM At total depth 2338' FNL, 995' FEL, Sec. 23, TllN, R14E, UM Plugging ~_.-~ Perforate - Pull tubing 5. Datum elevation (DF or KB) 55' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 18-17 8. Approval number 8-64.5 9. APl number 50-- 029-21768 10. Pool Feet Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11224 feet 8981 feet Plugs (measured) Effective depth: measured 11193 feet true vertical 8956 feet Casing Length Size Junk (measured) Cemented Measured depth True Vertical depth Conductor 80' 20" Surface 3252' 13-3/8" Production 10320' 9-5/8" Liner 1104' 7" 1687# Poleset 3500 sx CS III & 600 sx Class G 875 sx Class G 400 sx Class G 109' 3292' 10350' 11222' 109' 2989' 8283' 8979' Perforation depth: measured 11040-11050'; 11070-11084'; 11098-11106'; 11114-11132'; true vertical 8833-8841'; 8857-8868'; 8880-8886'; 8892-8907'; 8912-8928' ~bing(size, grade and measured depth) 3~"; 9.3#, L-80, PCT @ 110774' MD Packers and SSSV(type and measured depth) Baker PRB packer @ 10067'; MD; Camco TRDP SSSV @ 2181' MD 11138-11158'; 11162-11176' ; 8931-8942' 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 -- 2234 1455 0 Tubing Pressure 836 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 WELLS3/36 Title Operations Engineering Manager T. P. Allen, 263-4837 Date Submit in Duplicate~ Drill Site 18-17 Description of Work Performed TREATMENT: OBJECTIVE: TREATMENT DATE: Mud Acid Treatment To Stimulate Zone I and 2 September 19, 1988 10. 11. 1. Performed emulsification and sludging tests of the oil and acid system prior to pumping. 2. Because this well did not flow prior to stimulating, the pre-capacity was not attainable. 3. Loaded 12% HCl and 12%-3% HCI-HF acids with additives Titrate each acid and tested for iron content. 4. Loaded 2% NH4Cl water. 5. MIRU pump trucks, transports, N2 unit and CTU. 6 RIH with CTU to 11140' MD. 7. Rolled all acid compartments before pumping starts. Pressure test the hardline to 4500 psi. 8. Pumped the following fluids through the coiled tubing: A. 12 bbls of 12% HCL w/additives B. 1 2 bbls of 12% HCL-3% HF w/additives C. 3 6 bbls of 12% HCL w/additives D. 76 bbls of 12% HCl-3% HF w/additives E. 6 8 bbls of 2% NH4Cl water with 2 gals/1000 gals of surfactant 9. Displaced the stimulation fluids from the coil tubing with 30 bbls of diesel. Nitrogen lifted well using a total of 21,000 SCF of nitrogen. Left location with well flowing. Obtained capacity after all stimulation fluids have been removed. ARCO Alaska, Inc.~'' Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 22, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 18-17 Approval Number: 8-191 Enclosed are the Report of Sundry Well Operations and Well Completion Report detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/MKM:sd Enclosures cc: Standard Alaska Production Company JoAnn Gruber, ATO 1478 , File PI(DS18-17)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C -' ~"' STATE Oi': ALASKA Ji' ALAJ'.,,-~ OIL AND GAS CONSERVATION CO SSION · REPORT OF SUNDP, Y WELL OPERA T/IONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforato/~ Pull tubing [] Alter Casing [] Other 2. Name Of Operator ARCO Ala.~ka. Tnn. 3. Address VOS~: Office Box 100360, Anchorage; AK 99510 4. Location of well at surface 1242'FNL, 146'FEL, Sec. 24, T11N, R15E, UN 5. Datum elevation (DF or KB) KK, ~VR Feet 6. Unit or Property name Prudhoe 8ay Unit 7. Well number 18-17 interval FEL, Sec. 23, Tll N, R14E, UM N, R14E, UM N, R14E, UM At top of productive 2300'FNL, 700' At effective depth 2336'FNL, 980'FEL, Sec. 23, Tll At total depth 2338.' FNL~ 995' FEL~ Sec. 23, Tll 11. Pres~:nt well conditir)n .m~mmary Total depth: measured 11224 feet Plugs (measured) true vertical 8981 feet 8. Approval number Q_IO1 9. APl number 50-- 029-2[768 10. Pool Prudhne Bay {lil Pnnl Effective depth: measured 11193 feet Junk (measured) true vertical 8956 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 1687# Poleset 109' 109' Surface 3292' 13-3/8" 3500 sx CS 111 & 3292' 2989' 600 sx Class G Production 10320' 9-5/8" 875 sx Class G 10350' 8383' Liner 1104' 7" 400 sc Class G 11222' 8979' 12. Perforation depth: measured 11040-11050, 11070-11084', 11098-11106', 11114-11132', 11138-11158', 11162-11176' true vertical 8778-8786', 8802-8813', 8824-8831', 8837-8852', 8857-8873', 8876-8887' Tubing (size, grade and measured depth) 3½"; 9.3#, L-80, PCT @ 10774'MD ". Packers and SSSV.(type and measured depth) Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data. OiI-Bbl Gas-Mcf Water'-Bbl Casing Pressure Tubing Pressure 0 0 0 0 Well Not 0 0 0 0 Producing 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ Form 10-404 Rev. 12-1-85 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,.1,.!,!¢,¥.,,~' / ,= ~ Signed Y~~2~~ Title Operations Engineerin, Mana,er Date /~'/~* 18-17/STA'F17 M K Melton (265-6810) Submit in Duplicate . . ARCO ALASKA, F'.O. BOX ANCHORAGE, ALASKA DATE: 9-9-88 REFERENCE: ARCO CASED HOLE FINAL 2-i 4 8-3i-88 2-t 6 8-3t-88 '~-3-5 8-22-88 3- t 2 8-29-88 ~3-25 8-2'7-88 4- ~ 8-3 ~ -88 4-9 8- ~ 9-88 4- ~ ~ 8-22-88 ~5-~2 8-4-88 ~- ~ 3 8-4-88 ~6-~ 2 8-~ 7-88 ~7-8 8-~ 7-88 ~7-~5 8-~ ~-88 ~7-33 9-'7-88 9-~ 3 8-J 8-88 ~.t t -~ 5 9-'~ t 3-t8 8-2t -88 ~ 4-3 8-26-88 ~tD-t 8-3t-88 ~t 5-2 t 8-29-88 ~t8-3 ~--t-88 t8-~7 COMPLETION RECORD--GAMMA RAY PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION TEMP FLOWMETER--GAMMA RAY PITS INJECTION F'ROFILE TEMP SURVEY INJECTION F'ROFILE CONTINUOUS FLOW SLIRVEY CONTINUOUS Fl_OW SURVEY F'I TS PRODUCTION PROFILE F'RODUCTION PROFILE COLLAR COLLAR PFC INJECTION F'ROF'ILE TEMP SURVEY LEAK DETECTION PRODUCTION F:'RC)F ILE CCL--GAMMA RAY COLLAR/F'ERF i"l=i:(F' ORA'i- i NG RECOI~D 'F'LEASE SIGN AND REI'URN THE A'¥TACHED COF'Y AS RECEIF'T OF RUN t , 5· RUN t , 5 · RUN ~ , 5' RtJN ~ , 2 · RUN t, .5' RUN t, 5 · RUN t , 5' RtJN t, 5" RUN t, 5 · RtJN ~ , 5 · RUN ~ , 5 · RUN t , 5' RUN ~, 5' RUN ~ , 5 · RUN t, 5 · R~JN ~, 5 · RUN t, 5 · RUN ~ , t ·&5' RUN t , 5" [';:UN 'i ,5" RUN t , 5" I"..t..,Ix '> 5: -'-,,, l" DATA. SCH CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO GEAR GEAR CAMCO CAMCO CAMCO ATLAS, CAMCO' ATLAS CAMCO CAMCO CAMCO CAMCO ATLAS ~CH RECEIVED BY HAVE A NICE DAY! £ALLY HOFFECKER AT0-t529 TRANS ~88568 AF'F'ROVED... DISTRIBUTION $ CENTRAL FILES '"' CHEVRON l) & M ~~ EX'FENS, ION laXF LORA'/ION ~ EXXON MARATHON ~,':. Fi 0 B I L.. ...'"' PHILLIPS F'B WELL I'-ILES R & D ~- SAF'C ~ STATE C)F' AL..A~I<A · ~ TEXACO ARCO Alaska, Inc( Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 19, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 18-17 Permit Number: 87-120 Enclosed is the Application for Sundry Notice detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JWP/sd Enclosures cc: Standard Alaska Production Co. JoAnn Gruber, ATO 1478 File PI(DS 18-17)W1-3 STAT17:A ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ¢ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging E3 Stimulate ,~ Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 1242'FNL, 146'FEL, Sec. 24, T11N, R15E, UN At top of productive interval 2300'FNL, 700'FEL, Sec. 23, T11N, R14E, UM At effective depth 2336'FNL, 980 At total depth 'FEL, Sec. 23, T11N, R14E, UM 2338'FNL~ 995'FEL, Sec. 23~ T11N~ R14E, UM 11. Present well condition summary Total depth: measured 11224 feet true vertical 8981 feet Plugs (measured) Effective depth: measured 11193 feet Junk (measured) true vertical 8956 feet 5. Datum elevation (DF or KB) 55' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 18-17 8. Permit number 87-120 9. APl number 5o- 029-21768 10. Pool Prudhoe Bay Oil Pool feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 1687# Poleset 109' 109' Surface 3252' 13-3/8" 3500 sx CS 111 & 3292' 2989' 600 sx Class G Production 10320' 9-5/8" 875 sx Class G 10350' 8;283' Liner. 1104' 7" 400 sc Class G 11222' 8979' Perforation depth: measured 11040-11050', 11070-11084', 11098-11106', 11114-11132', 11138-11158','11162-11176' true vertical 8833-8841', 8857-8868', 8880-8886', 8892-8907', 8912-8928;, 8931-8942' Tubing (size, grade and measured depth) 3½"; 9.3#, L-80, PCT @ 10774'MD Packers and SSSV (type and measured depth) Baker PBR Packer @ 10067'MD; Camco TRDP SSSV @ 2181'MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch[] 13. Estimated date for commencing operation June, 1988 14. If proposal was verbally approved Name of approver la :.. .,L .: :'.,,;Y!, 'i".i,- ,T;., ,' ,. Date approved 15. I hereby/q~ertify that the fore. going is true and correct to the best of my knowledge ~~~/~ Title Operations Engineering Manager Date Signed Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. ~ · [] Plug integrity [] BOP Test [] Location clearanceI '-' , . ..oRIGiNAL SIGNED BY A~pp,~ove.d COpy Returned .... ", by order of Commissioner the commission Date ~-c,~.,~'"' 18-17/STAT17 J. W. Pierce (265-6471) Form 10-403 Rev 12-1-85 Submit in triplicate Drill Site 18-17 Mud Acid Stimulation Treatment ARCO Alaska, Inc. propos6$ to perform the following stimulation treatment: 1. Obtain an oil sample from DS 18-4 (Well 18-17 will not flow).Perform..: emulsification and sludging tests of the oil and acid system prior to pumping. 2. Because this well does not flow a pre-stimulation capacity will be unattainable. 3. Load 1500 gals of 12% HCI acid and 3500 gals of 6%-1.5% HCI-HF acid with additives Titrate acid and test for iron content. 4. Load 3000 gals. of 2% NH4CI water. 5. MI and RU pump trucks, transports, N2 unit and CTU. 6 RIH with CTU to 11140' MD. 7. Roll all acid compartments before pumping starts. Pressure test the hardline to 4500 psi. 8. Pump the following fluids through the coiled tubing: A, B. C. D. E. 500 gals of 12% HCL w/additives 500 gals of 6% HCL- 1.5% HF w/additives 1000 gals of 12% HCL w/additives 3000 gals of 6% HCI - 1.5% HF w/additives 3000 gals of 2% NH4CI water with 2 gals/1000 gals of surfactant 9. Displace the stimulation fluids from the coil tubing with crude or diesel. 10. Immediately start lifting the well with nitrogen. Ensure that the well will flow prior to pulling the coiled tubing out of the hole. POH with coiled tubing. 1 1. Obtain capacity after all stimulation fluids have been removed. 4 2 COILED 'rOBINg UNIT BOP E0U l PIdEN'r 1. 5000 PSI '7" W£LLH[.AD CONNECTOR 2. 5000 PSI 4 1/16" PiPE RAHS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSi 4 1/6" SHEAR RAHS 5. ~)00 PSI 4 1/6" BLIND RAHS 6. 5000 PSI 4 1/16" STUFFING BOX · iiiii i H]REL]NE BOP EOU]PHENT 1. ~OOO PSI ?" W£LLHEAJ~ CONN£CIOR IrLANG[ 2. 5000 PSI WIRELIN£ RAUS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF D&TF · 7 '-- ? t5 "-.q.(:l RHP--RT&I' 1' F: F; I:;.' ~:.~ 1') 1' I::' i'J T FII.-IF ..... R'I'&'T"rI": [;E'ADTF'NT F;HF .....K'T~%TI'F: F;[;:&BI'F'NT P, N F:'-- ,~'r A l' 'r E i'; i:~' A B, 'r F N'r F: I.-I F'--.?')' ~N T 1' C F; !:~' ~ 1~ T Fi hO l' ri T T R F:AMF:F) F: f~ M E [1 n T F.' I:-'. ['. I::i T V I::l I) R Y .................................................................... l-ltqVF7 ¢q NTf21'-' E, AYm F:' F F; ('; Y R I::i N hO I::' 'Y")' ~'1' F) .... t ':~ 5.~ 9 f': F:' H T !:;.' ~ I t::' T I I::' R I": I..I I:' V I;.' fl 19 '.'t: 1') & hi F'W, TF:N&"I'Fli4 I::'x'F:'I flR't~'F'r flhJ ~: F:' 'K ~:' Fl N :,",: M F) l./T I STATE OF ALASKA ~ ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well REV 15 ED** OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 87-120 3. Address 8. APl Number P, 0. Box 100360r Anchorage~ AK 99510 50- 029-2176~ 4. Location of well at surface 9. Unit or Lease Name 1241' FNL, 146' FEL, Sec.24, T11N, R14E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2378' FNL, 567' FEL, Sec.23, TllN, R14E, UM 1~-17 At Total Depth 11. Field and Pool 2460' FNL~ 962' FEL~ Sec.23, T11N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool RKB 55'I ADL 28307 ALK 2317 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1 2/10/87 1 2/24/87 03/28/88*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11224'MD/8981 'TVD l1200'MD/8962'TVD YES [~ NO []I 2181 feet MD 1~00' 22. Type Electric or Other Logs Run GR~ CET, Compensated Ne~;ron; GCT. GR. CBT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-4O ~,,rf lflq' ~n,, !687 # Po!esot 1;~-3/8" 68.0/72.0# K-5.5/I-Rd .~,,r'f . t?q?' !7-!/?_''' 3500 S× CS ]]! & 600 sx C~.~ss C 9-5/8" 47.0# I.-00 S,,rf lr)~q/~, !2-!/~.'' 875 sx C]_~ss G 7" 29.0# "' L-80 10110' 11777' R-1/?" ~,r~r~ ~ r~l~ ¢. , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforated w/½ spf, 0°phasing SIZE DEPTH SET (MD) PACKER SET (MD) 11041 '-11051 'MD/8833'-8841 'TVD 3-1/2" 10774' 10083' , ,. 11071 ' -11085 'MD/8858 ' -8869' TVD Perforated w/4 spf, 0° phasing 26. ACID, FRACTURE, CEMENT SOUEE'ZE, ETC. l1099'-11107'MD/8880'-8887'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11115 ' -11133 ' MD/8893 ' -8908 'TVD N/A 11139' -11159 'MD/8913 ' -8929 ' TVD Perforated w/6 spf, 0° phasing 11163 ' -11177 ' MD/8932 ' -8943 'TVD 27. N/A PRODUCTION TEST . . Date First Production I Method of Operation (Flowing,. gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL .GAS-'MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO . TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (c'o~r) Press. 24-HOUR RATE 28. CORE DAT.A Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wate r-Submit core chips- None R ~, ( ~"! ~ ~" L f~ .;~;.~¢(a Oi~ & Gas Cons. ,, Anchora0Je WNOTE: Drilled RR 12/30/87. Tubing run 3/16/88. Perforated well 3/28/88, **NOTE: Revised for surface location. Form 10-407 (Dani) TEMP3/WC95 Submit i.n duplicate9 Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . 29. 30. NAME Top Sadlerochit Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 10548 ' 11178' 31. LIST OF ATTACHMEN'TS NONE TRUE VERT. DEPTH 8439' 8944 ' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and .gravity, GOR, and time of each phase. N/A 32, I hereby certify that the foregoing is true and correct to the best of my knowledge 'Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In.- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 STATE OF ALASKA (i' " 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. 87-120 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21768 4. Location of well at surface ~1~,_ Pit-~/~. .~ ~¢¢~ ~,. ¢~ ~ r- 9. Unit or Lease Name 1241' FNL, 146' FEL, Sec.24, T11N, R1/~E, UN ~J~,316~p~, Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2378' FNL, 567' FEL, Sec.23, T11N, R14E, UM 18-17 At Total Depth 11. Field and Pool 2460' FNL, 962' FEL~ Sec.2~;~ T11N~ R14E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 55' ADL 28307 ALK 2317 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 12/10/87 12/24/87 03,/28/88*I N/A eet MSLI 1 17. Total Depth (M D+TVD)18.Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set ,I 21. Thickness of Permafrost 11224'MD/8981 'TVD 11200'MD/8962'TVD YES [~ NO [] 2181 feet MD ' 1900' (approx) 22. Type Electric or Other Logs Run GR, CET, Compensated Neutron, GCT, GR, CBT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# 'H-40 Surf 113q' ~{3" 1687 # pol_eset 13-3/8" 68.0/72.0# K-SS/L-RO Surf ~,?q?' 17-1/?" 3500 5~ CS !!! & 600 ~_x P_l.~_~_s C. 9-5/8" 47.0# , L-80 Surf 10~,9z~' 17-1//~" RT~; ~× C. 1R~ C. 7" 29.0# L-80 10118~ 11222' 8-1/2" /~00 ,~x £1~.~.~ 6 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforated w/½ spf, 0°phasi ng SIZE DEPTH SET (MD) PACKER SET (MD) 11041 ' -11051 ' MD/8833, ' -8841 ' TVD 3-1 / 2" 10774 ' 10083, ' . 11071 ' - 11085 ' MD/8858 ' - 8 869 ' T VD .. '" Perforated w/4 spf, 0°. phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 11099'-l1107'MD/8880'-8887'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11115 ' -11133 ' MD/8893 ' -8908 'TVD N/A 11139 ' -11159 ' MD/8913, ' -8929 ' TVD Perforated w/6 spf, 0° phasing 11163 ' -11177 ' MD/8932 ' -8943 ' TVD 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ ...... Flow Tubing Casing Pressure CALCULATED.l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JUN 8 ]988 *NOTE: Drilled RR 12/3,0/87. Tubing run 3/16/88. Perforated well 3,/28/88, AlaskaOil&l~asCo~s, commissio._ ... ~nr. hnr,,na Form 10-407 (Dani) TEMP3/WC95 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Sadlerochit Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 10548' 11178' 31. LIST OF ATTACHMENTS NONE TRUEVERT. DEPTH 8439' 8944' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- in.g and tbe,,Ioca,1;ion of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Iniection, Shut-in Other-explain. Item 28.; If.no oores.taken, indicate "none". Form 10-407 ~r TELECO 1 Teleco Oilfield Services of Alaska Inc. / 6116 Nielson Way  Anchorage. AK 99502 (907) 562-2646 December 22, 1987 JOB #603 ARCO ALASKA WELL: DS18, Well #17 PRUDHOE BAY RIG: ROWAN #41 Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, · "~' '" ,. ~ ,/// ' · . ~ ,.' ' _ ~"2 ,' ..., ,.~ / ?. Dave Reimer Field Service Supervisor .DR/el Enclosures .... .~, , ':',5. %'~i'~'?:"': ........ . ~,, %..; -~,., A ~? COMPANY Date 12/21/87 TELECO OILFIELD SERVICES JOB 603 SURVEY CALCULATIONS Page Company: Well'. Locatioh: Rig: ARCO ALASKA D.S.18 WELL #17 PRUDHOE BAY ROWAN # 41 TELECO Job # 603 Grid Correction: · Magnetic Declination: Total Correction: Proposed Direction: TAK 0.00 degrees 31.00 degrees 31.00 degrees 259.70 degrees RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE IN TO VERTICAL 950.00 0.0 240.9 S 60 54 W 950.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD SURVEYS 1054.00 3.1 240.9 S 60 54 W 1053.94 2.66 1.36S 2.45W 2.81 S 60.958W 2.981 1238.00 9.4 251.8 S 71 48 W 1236.76 22.11 9.38S 20.77W 22.79 S 65.686W 3.469 1425.00 15.9 251.1 S 71 06 W 1419.12 62.62 22.40S 59.57W 63.65 S 69.389W 3.477 1610.00 18.4 252.8 s 72 48 w 1595.88 116.66 39.30S 111.43W 118.16 s 70.571W 1.378 1796.00 21.4 254.2 S 74 12 W 1770.76 179.60 57.28S 172.13W 181.41 S 71.593W 1.633 TELECO Job # 603 TAK 12/21/87 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 1982.00 26.2 254.2 S 74 12 W 1940.89 254.29 77.68S 244.34W 256.39 S 72.363W 2.581 2165.00 28.8 254.6 S 74 36 W 2103'.20 338.43 100.40S 325.72W 340.85 S 72.868W 1.424 2351.00 33.5 253.5 S 73 30 W 2262.33 434.15 126.84S 418.21W 437.02 S 73.128W 2.545 2600.00 38.4 254.6 S 74 36 W 2463.85 579.57 166.99S 558.72W 583.14 S 73.359W 1.985 2793.00 40.0 255.6 S 75 36 W 2613.41 701.15 198.36S 676.59W 705.07 S 73.660W 0.891 3016.00 41.5 257.0 S 77 00 W 2782.34 846.45 232.83S 818.01W 850.50 S 74.112W 0.788 3238.00 41.7 256.7 S 76 42 W 2948.35 993.66 266.36S 961.53W 997.74 S 74.516W 0.127 3532.00 40.5 257.4 S 77 24 W 3169.89 1186.71 309.67S 1149.87W 1190.84 S 74.927W 0.437 3901.00 39.6 258.1 S 78 06 W 3452.35 1424.00 360.04S 4177.00 38.4 259.1 S 79 06 W 3666.84 1597.66 394.37S 1381.90W 1428.03 1552.16W 1601.48 S 75.397W 0.273 S 75.744W 0.491 4485.00 37.4 259.9 S 79 54 W 3909.88 1786.86 428.85S 1738.19W 1790.31 S 76.140W 0.362 .... 4764.00 37.0 260.9 S 80 54 W 4132.11 1955.52 456.98S 1904.50W 1958.56 S 76.507W 0.260 5040.00 43.2 261.6 S 81 36 W 4343.12 2133.15 484.01S 5346.00 43.6 259.2 S 79 12 W 4565.45 2343.36 519.07S 5654.00 42.5 260.6 S 80 36 W 4790.52 2553.61 555.94S 2080.12W 2135.69 2287.41W 2345.57 2494.40W 2555.60 S 76.901W 2.252 S 77.215W 0.554 S 77.435W 0.473 5960.00 41.3 263.7 S 83 42 W 5018.28 2757.75 583.85S 6267.00 46.0 260.2 S 80 12 W 5240.35 2969.40 613.51S 2696.81W 2759.29 2906.54W 2970.58 S 77.784W 0.782 S 78.081W 1.721 TELECO Job # 603 TAK 12/21/87 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 6637.00 43.5 261.3 S 81 18 W 5503.10 3229,82 655.38S 3163.61W 3230.79 S 78.296W 0.707 6943.00 44.6 258.8 S 78 48 W 5723.03 3442,55 692.14S 3373.15W 3443.43 S 78.404W 0.672 7250.00 42.8 259.9 S 79 54 W 5944.97 3654.63 731.33S 3581.59W 3655.49 S 78.459W 0.636 7560.00 43.0 261.5 S 81 30 W 6172.06 3865.61 765.43S 3789.83W 3866.35 S 78.582W 0.357 7898.00 43.9 261.6 S 81 36 W 6417.44 4097.93 799.59S 4019.73W 4098.49 S 78.750W 0.267 8207.00 42.8 262.3 ' S 82 18 W 6642.13 4309.87 .829.29S 4229.75W 4310.28 S 78.907W 0,389 8482.00 40.8 263.0 S 83 00 W 6847.13 4492.91 852.74S 4411.53W 4493.19 S 79.060W 0.747 8834.00 40.2 264.0 S 84 00 W 7114.79 4721.02 878.62S 4638.67W 4721.15 S 79.275W 0.251 9142.00 40.1 262.8 S 82 48 W 7350.20 4919.18 901.44S 9452.00 40.0 263.4 S 83 24 W 7587.51 5118.30 925.40S 4835.93W 4919.23 5033.96W 5118.31 S 79.441W 0.253 S 79.584W 0.129 9759.00 39.0 262.7 S 82 42 W 7824.40 5313.24 949.03S 5227.79W 5313.24 S 79.711W 0.357 10066.00 38.2 260.9 S 80 54 W 8064.32 5504.63 976.35S 5417.36W 5504.63 S 79.784W 0.449 10339.00 38.1 260.9 S 80 54 W 8279.00 5673.23 1002.95S 5583.89W 5673.25 S 79.817W 0.041 TELECO OilFi~ld S~mvio~s VERTiC^L PROJECTION 0 0 i000 2O00 3000 4000 5000 W 8000 ! 000 2000 3000 4000 5000 6000 I I , i --k--,-- -- ~--" .--+-.~--i. . .... ? ..... ~.'-~ '--r .... t I i _.w ...... ;, ....... ~ -1 . · ~,- . ~ . ,-~-..~ ....... ~ ..... ~ · ~ ~ ..... F. ' ........ ~ _.', ,,~ ~ ~', '~"',~ ~r~' "i ~..~ ....... ~ ......... t ..... ~ .... : ...... ~ ............... ~ .... = ...... ~.....-.~-=~ .... ~ .... ~ ......... t .... ~ .......... ~ ........... , ..... ~ ........... . ........... ~ , ~ . .... ~ ......~ ..... ~....e .... e..-~ '7000 ; ' 8000 go00 VERTICAL SECTION TELECO 0 i I ~ i m 1 d PLAN VIEW Services 9600 8000 ,6400 4800 3200 1600 0 WEST 1600 @200 4B00 1- 8000 9600 1 1200 12880 SUB. SURFACE DIRECTIONAL SURVEY ['~ UIDANCE ~'~ ONTINUOUS ~-f~ OOL Company ARCO ALASKA~ INC. Well Name DRILLSITE 18-17(~z~1~ Fr~.146' FEL~SEC 24.TllN.R14£.I]M) Field/Location PRUDHOE BAY. NORTH SLOPE;, ALASKA / Job Reference No. Date 72602 6-JAN-88 ~ Computed By: SCHWARTZ KRUWELL * $CHbU~BERGER ~ GCT DIRECTIONAb SURVEY CUSTOMER EISTING FOR ARCO ALASKAw fNC, D.S, 18'17 PRUDHOE BAY NORTH SLOPE,AbASKA SURVEY DATE: 06-dAN-88 ENGINEER: G, SCHWARTZ METHODS Of' COMPUTATION TOOL bOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPObATION{ bINEAR ~ VERTICAb SECTION: HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 79 DEG 43 MIN WEST ARCO ALASKA, INC, [)HOE BAY NORTH SbOPE,ALASKA COMPUTATION DATE; 21-FEB-SB PAGE 1 DATE OF SURVEYI 06-UAN,88 KELLY BUSHING ELEVATION; 55,00 FT ENGINEER; G, SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG MIN VERTICA6 DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 dO 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 BOO O0 go0 O0 0 O0 100 O0 200 O0 299 99 399 99 499 98 599 98 699 97 799 97 899 96 -55 O0 0 0 45 O0 0 16 145 O0 0 ]0 244 99 0 30 344 99 0 31 444,98 0 32 544,9B 0 33 644.97 0 35 744.97 0 38 844.96 0 43 h 0 0 E S 0 5 E S 12 24 W S 12 7 W S 9 57 W S 12 14 W S 11 29 W S 16 51 W S 18 15 w S 22 56 w 0,00 -0,02 0,30 0,64 0.96 1,30 1,67 2,07 2,59 3,16 0 O0 0 89 0 07 0 10 0 11 0 04 0 06 0 20 0 12 043 0,00 N 0,07 S 0,87 $ 1 74 S 2 61 S 3536 4 505 5 46 S 6 50 S 7 56 S 0,00 E 0 03 E 0 15 w 0 33 W 0 50 W 0 68 W 0,88 W 1,11 W 1,45 k 1,83 W 0,00 N 0 0 E 0,08 $ 23 0 £ 0,88 S 9 30 W 60 S 10 ~ 57 S l{ 78 S 13 37 W 1000 O0 1100 160~ 170 i °g .90 999 94 944,94 1 50 O0 1099 77 1044,77 4 49 O0 1199 10 1144,10 B 15 O0 1297 57 1242,57 11 52 O0 1394 73 1339,73 15 17 O0 1490 52 1435,52 17 39 O0 1585 46 1530 46 18 54 O0 1679 67 1624 67 20 12 O0 1773 13 1718 13 21 34 O0 1865'41 181041 24 0 S 44 57 w S 63 16 W S 69 0 w S 7O 51 W S 70 13 w S 70 16 W S 71 49 W S 72 42 w S 73 28 W S 73 25 W 4 52 9 63 20 82 37 94 61 19 89 47 120 51 153 75 189 07 227 34 ].31 ,96 2,94 3,29 ,30 ,53 1,46 1,17 1,62 3,12 9,18 S 2,93 W 12,1{ S 7,59 W 16,62 S lB 15 W 22,49 S 34 48 W 30,33 S 56 68 W 40.09 S 83 65 W 50,29 S 113 35 W 60,46 S 145 29 W 70,79 $ 179 81,67 S 16 9,b3 S 17 43 W 14.31 S ,~3 W 24,60 S47 31 W 41,17 S 56 53 w 64,29 $ 61 51 W 92,76 S 64 23 W 124.01 S 66 4 W 157;37 S 67 24 w 32 W 192,78 S 68 27 W 24 W 231,14 $ 69 18 W 2000 O0 1955 71 1900,71 26 47 O0 2044 28 1989,28 28 9 2076.79 30 15 220 230O 2400 2500 2600 2700 2800 2900 O0 2131 O0 2217 O0 2300 O0 2382 O0 2461 O0 2539 O0 2615 O0 2692 79 02 2152 02 32 32 42 2245:42 34 27 O0 2327,o0 36 17 49 2406.49 38 16 04 2484,04 39 45 72 25b0,72 40 1 10 2637,10 40 14 S 72 0 W 269.99 S 71 51 W 315,94 S 73 9 W 363,95 S 72 21 W 415,84 S 72 56 W 470.57 S 73 20 W 528,04 S 73 B W 588,31 S 73 36 W 651,03 S 74 28 W 714,91 S 75 11 w 779,22 2 49 I 21 3 O4 2 09 2 09 2 26 I 93 0 93 0 48 0,59 94 33 S 257 28 W 274 03 S 69 51 W 109 O0 S 301 32 w 320 43 S 70 6 W 123 138 155 172 189 207 225 242 39 S 347 51 w 368 85 S 397 44 W 421 50 S 450 04 W 476 10 $ 505 43 w 533 64 $ 563 50 W 594 83 S 623,95 W 657 42 S 685,69 W 721 30 S 747.98 W 786 76 S 70 27 W 00 S 70 44 W 15 S 70 56 W 93 S 71 1'''~, 56 S 71 2. 66 S 71 34 d 79 $ 71 4B W 25 S72 3 W 3000 O0 2768 63 2713,63 39 50 3100 O0 2845 15 2790,15 40 45 3200 O0 2920 28 2865,28 41 32 3300 O0 2995 09 2940,09 41 30 340O 35O0 36O0 3700 38O0 390O O0 3070 O0 3145 O0 3222 O0 3298 O0 3375 O0 3452 11 3015,11 41 B 86 3090.86 40 23 17 3167,17 40 16 44 3243,44 40 11 15 3320,15 39 40 38 3397,38 39 10 S 75 20 W 843,40 S 75 32 W 907.59 S 75 53 W 973.42 I S 76 lB W 1170~77 S 76 47 W 1235.30 S 77 14 W 1299.91 S 77 35 W 1364.01 S 78 9 w 1427,50 0 72 ! 54 0 28 0 26 0 69 0 7O 0 '44 0 49 .:0 49 0 45 258 61 S BlO 25 W 850 52 S 72 !7 W 274 81 S 872 55 W 914 BO S 72 31 W 12 S 936 50 W 9BO 70 S 72 43 W 2~9 323 338 353 368 382 395 22 S 1000 26 S 1065 89 S 1128 94 S 1191 44 S 1254 44 S 1316 77 S 1379 87 W 1046 40 w 11 25 w 1242 28 W 1307 89 W 1371 O0 w 1434 96 S 72 56 W 99 S73 6 W 19 S 73 17 W 72 S 73 27 W 28 S 73 37 w 30 S 73 48 W 67 S73 59 w AR~O ALASKA, IN¢, DHOE BAY NORTH SLOPE;ALASKA COMPUTATION DATE{ 21-FEB-SB PAGE 2 DATE OF SURVEY{ 06-dAN-88 KEbbY BUSHING EEEVATIONI 55,00 FT ENGINEERi G, SCHWRRT[ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAl, DOGbEG RECTANGUbAR COORDINATES HORiZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4000 O0 3530 08 3475,08 38 54 4100 O0 3608 11 3553,11 38 29 4200 O0 3686 60 3631,60 38 4300 O0 3765 26 3710,26 38 14 4400 O0 3843 96 3788,96 37 51 4500 O0 3923 03' 3868,03 37 37 4600 O0 4002 44 3947,44 37 16 4700 O0 4082 18 4027 18 36 53 4800 O0 4162 31 4107:31 36 58 4900 O0 4241 25 4186,25 39 54 5000 O0 4315 32 4260,32 43 3 5100 O0 4388 46 4333,46 42 48 52OO 53OO 5400 5500 5600 5700 58O0 5900 O0 4461 O0 4533 O0 4606 O0 4678 O0 4751 O0 4825 O0 4899 O0 4973 49 4406,49 43 33 76 4478,76 43 40 18 4551,18 43 31 85 4623,85 43 17 88 4696,88 42 45 52 4770,52 42 37 23 4844,23 42 14 71 4918,71 41 31 6000 O0 5048,82 4993.82 41 11 6100 O0 5123.31 5068.31 43 12 6200 O0 5194.15 5139.15 45 58 6300 O0 5263 39 5208,39 46 17 6400 O0 5332 49 5277,49 46 23 6500 O0 5401 37 5346,37 46 21 6600 O0 5471 47 5416,47 44 14 6700 O0 5543 79 5488,79 43 34 6800 O0 5615 94 5560,94 44 24 6900 O0 5687 07 5632,07 44 36 7000 O0 5758 25 5703,25 44 38 7100 O0 5829 96 5774,96 43 50 7200 7300 7600 7700 78OO 7900 O0 5902 13 5847,13 43 23 5920,0 8 5993.17 O0 5975 O0 6048 O0 6121 O0 6194 O0 6267 O0 6339 oo 6412 08 43 7 17 42 57 46 6066,46 42 46 71 6139.71 43 13 46 6212.46 43 23 83 6284.83 43 44 02 6357,02 43 49 S 78 23 W 1490,43 S 78 35 W 1552,97 S 78 39 W 1614,90 $ 78 46 W 1676,64 S 78 54 ~ 1738,33 $ 78 55 ~ 1799,54 S 78 59 W 1860,31 $ 79 11W 1920,65 S 79 36 W 1980,49 $ 79 27 W 2041,85 S 79 35 W 2109,00 $ 80 10 W 2177.20 S 78 17 W 2245 51 S 78 10 W 2314 59 S 78 40 W 2383 53 S 79 3 w 2452 21 S 79 16 W 2520 5! S 80 4 w 2588 17 $ 81 36 W 2655,74 S 82 18 W 2722.41 S 82 43 w 2788 34 S 81 5 w 2854 S 79 14 W 2925 S 79 14 W 2997 S 79 57 w 3069 S 8O 34 W 3142 S 80 38 W 3213 s 80 51 w 3282 S 78 2O w 3352 S 78 2O ~ 3422 98 53 69 97 46 75 79 O3 29 S 78 19 W 3492,51 S 78 50 W 3562,19 S 79 21 W 363!,40 S 79 34 W 3699,79 S 80 8 W 3768,05 $ 80 2 N 3836,08 S 80 18 W 3904,16 S 80' 47 ~ 3972,76 S 80 35 W 4041,75 S 80 36 W 4110,95 0,33 0,29 0,31 0.30 0,33 37 0,58 03 0 65 0 44 1 40 0 49 0 42 0 23 0 91 I O! 0 79 0,67 0,31 4,15 1,15 0,63 0,61 0,79 2,23 ,97 0~,47 0 52 0 6O 1 24 0 25 0 56 0 29 0 7O 0 32 0 408 53 S 1440 64 W 1497 45 S 74 10 W O1 $ 1501 93 W 82 $ 74 20 W 42 1 433 24 S 1562 445 32 S 1623 457 25 S 1683 469 03 S 1743 48O 68 S 1803 492,13 S 1862 503.12 S 1921 514,19 S 1981 526 538 551 565 579 592 605 617 628 637 1559 66 W 1621 22 k 1683, 75 W 1744. 82 w 1805 47 W 1866, 72 W 1926, 54 W 1986 89 W 2047 61 $ 74 30 W 20 $ 74 39 W 73 $ 74 8O $ 74 ~ 31 S 7 51 S 75 27 w 52 S 2047.91 w 2114,51 S 75 34 w 46 S 2115,04 w 2182,51 S 75 42 W 07 S 2182 18 w 2250,69 S 75 49 w 46 S 224979 W 2319.76 $ 75 53 W 25 S 2317 34 W 2388.64 S 75 57 W 48 S 2384 75 W 2457.25 S 76 2 W 40 S 2451 82 W 2525,46 S 76 7 w 59 S 2518 37 W 2592,99 S 76 13 W 29 $ 2585 1! W 2660,36 S 76 20 W 60 S 2651 17 W 2726,77 S 76 28 W 646 11 S 2716 63 W 2792 41 S 76 37 W 655 17 S 2782 72 W 2858 80 $ 76 45 W 667' 681 694 706 717 728 741 755 44 S 2852 20 W 2929 25 S 76 49 W 07 S 2923 05 W 3001 35 S 76 53 W 13 S 2994 15 W 3073 55 S 76 56 W 97 S 3135 95 W 3217,09 S 77 ~ 89 S 3204,14 W 3286.00 S 77 11 d 37 S 3272,24 W 3355,18 S 77 14 W 71S 3341,05 W 3425.45 $ 77 15 W 769 96 S 3409,83 W 3495 783 76 $ 3478,14 W 3565 796 93 S 3546,09 ~ 3634 809 36 S 3613,35 W 3702 ~!! 44 i 3680. 37 09 3747 ~i ~ I~ , 38 78 3814 39 3882, 39 6712 40 78 47 ~ 3950 ~i ARCO ALASKA, INC. UDHOE BAY NORTH SbOPE,ALASKA COMPUTATION DATE: 21-FEB-88 PAGE 3 DATE OF &URVE¥t 06-JAN-88 KELLY BUSHING EbEVATIONI 55,00'FT ENGINEERI Ge SCHWARTZ INTERPOLATED VALUES f'OR EVEN 100 FEET Of' MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH PEPTH DEPTH DEPTH pEG HIN DEG MfN FEET DEG/IO0 FEET FEET FEET PEG HIN 8000 O0 6484 31 6429,3[ 43 33 O0 6556,87 6501 87 43 24 O0 6629,78 6574 78 42 51 6703, 6778, 6853, 6929, 820 8300 8400 8500 8600 8700 8800 8900 O0 57 6648 O0 20 6723 O0 68 6798 O0 96 6874 O0 7006.40 6951 O0 7082,82 7027 O0 7159,35 7104 57 42 3 20 41 26 68 40 30 96 40 12 40 40 9 82 40 5 35 40 3 9000 00 7236,02 7181,02 39 54 9100 00 7312,68 7257,68 39 59 9200 O0 7389,27 7334,27 39 59 9300 00 7465,77 7410.77 40 7 9400 O0 7542,29 7487.29 39 59 9500 O0 7618.98 7563,98 39 42 9600 00 7696,09 7641,09 ]9 31 9700 O0 7773,34 7718,34 3q 16 9800 O0 7850,97 7795,97 38 52 9900 O0 7929,04 7874,04 38 32 10000 O0 8007.41 7952.41 38 19 10100 O0 8086.00 8031.00 37 59 10200 O0 8164 83 8109,83 37 56 10300 O0 8243 79 8188,79 37 47 10400 00 8322 63 8267,63 38 20 10500 O0 8401 06 8346,06 38 3 10600 O0 8480 16 8425,16 37 31 10700 O0 8559 5b 8504,56 37 17 10800 O0 8639 40 8584,40 36 41 10900 O0 8719 81 8664.81 36 18 1t000,00 8800,43 8745,43 36 15 lllO0.O0 8881.09 8826.09 36 9 11200,00 8961,70 8906,70 36 18 11224.00 8981.04 8926.04 36 18 $ 80 47 w 4180 03 S 81 2 W 4248 82 S 8! 22 w 4317 24 $ 81 35 a 4384 71 S 81 53 W 4451 22 S 82 24 ~ 4516 75 S 82 35 W 4581 34 $ 82 30 W 4645 74 ,5 82 27 W 4710 14 S 82 18 W 4774,46 S 82 7 W 4838,60 ,5 82 4 W 4902,74 S 82 0 W 4967,00 $ 81 55 W 5031,35 S 81 49 W 5095,67 S 81 32 W 5159.81 S 81 14 W 5223.46 S 81 4 W 5286.95 $ 80 51 W 5349,97 S 80 30 W 5412,43 S 80 8 W 5474,56 S 79 51W 5536,39 S 79 47 W 5597,91 S 79 59 W 5659,28 S 79 49 W 5720,79 S 79 31W 5782,82 S 79 16 W 5844,03 S 79 5 W 5904,80 S 78 43 w 5965,02 S 78 11W 6024.44 S 77 37 W 6083,58 $ 77 10 W 6142,65 S 77 10 W 6201,77 S 77 10 W 6215,97 0,17 0,44 0,78 0,69 0,48 0.71 0.23 0.15 0.17 0.37 0.10 0.29 0,42 0.i0 0.14 0 69 0 33 0 41 0 47 0 17 0.71 0.17 0.49 0.31 0.49 0.86 0.32 0.43 0,69 0.46 0.46 2.02 0.00 0.00 910 97 S 4222 920 97 S 4289 930 55 S 4355 939 51S 4420 947 87 S 4484 956 22 $ 4548 964 63 S 4612 973 16 $ 4675 981.87 S 4739 990,71 S 4803 999.62 S 4866 1008,65 S 4930 1017 75 ,5 4994 1027 O0 $ 5057 1036 55 S 5120 1046 33 $ 5183 1056 23 S 5245 1066 35 ,5 5307 44 W 05 W 44 03 w 4518 16 w 4583 09 W 4647 02 w 4711. 84 W 4776 49 W 96 36 ,5 77 77 ,5 77 ~ N 25 S 78 52 $ 78 7 W 82 S 78 1! ~ 04 ,5 78 14 W 45 W 4840 09 S 78 17 W 03 N 4904 14 S 7820 W 72 W 4968 49 w 5032 21 W 5096 71 W 5160 67 W 5224 42 W 5287 67 w 5350 32 W 5413 32 S 78 23 W 60 S 78 26 w 86 S 78 28 W 93 S 78 31 W 53 S 78 33 W 97 S 78 35 W 9b S 78 36 W 39 ,5 7838 W 1076 74 S 5368 58 w 5475 49 S 78 39 W 1087 5J S 5429 46 W 5537 30 S 78 40 W 1098 1109 1120 1131 1142 1153 1165 1177 48 S 5490 22 $ 5550 03 S 5610 12 S 5672 40 ,5 5732 83 S 5791 39 $ 5850 23 S 5909 O0 w 5598 42 W 5660 98 w 5721 01 W 5783 17 W 5844 86 w 59O5 96 W 5965 21 w 6025 82 S 78 41 W 17 S 78 41 W 67 S 78 42 W 70 $ 78 4.~-~ 90 S 78 4 67 S 78 4~ ,; 89 S 78 44 W 33 S 78 43 W 1189,58 $ 5967,07 W 6084,49 S 78 43 W 1202,53 S 6024,75 ~ 6143,59 S 78 42 W 1215.67 S 6082.4b W 62062.75 S 78 ii W 1218.82 .5 6096.31 W 621 ,96 S 78 1 W ARCO AbA.SEA, INC. D S 18,-17 NORTH SI,OPE~ALASKA COMPUTATION DATE: 21-FEB-88 PAGE 4 DATE OF SURVE¥I 06-jAN-.88 KELLY BUSHING EbEVATIONI 55,00 FT ENGINEER: G, SCHWARTZ INTERPOLATED VAbUES FOR EVEN 1000 FEET DF HEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DES MIN LEG MIN 0 O0 0.00 -55.00 0 0 1000 O0 999,94 944 94 1 50 2000 O0 1955.71 1900 71 26 47 3000 O0 2768,63 2713 63 39 50 4000 O0 35]0.08 3475 08 38 54 5000 OO 4315,32 4260 32 43 3 6000 O0 5048.82 4993 82 41 11 7000 O0 5758,25 5703 25 44 38 8000 O0 6484.31 6429 31 43 33 9000 O0 7236.02 7181,02 39 54 10000.00 8007.41 7952.41 38 19 11000.00 8800.43 '8745,43 36 15 11224,00 8981,04 8926,04 36 18 VERTICAl, DOGLEG RECTANGUbAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST LIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG N 0 0 E 0,00 S 44 57 ~ 4,52 S 72 0 W 269,99 S 75 20 W 843.40 S 78 23 W 1490,43 S 79 35 W 2109,00 S 82 43 W 2788,34 S 78 19 W 3492,51 S 80 47 W 4180,03 $ 82 7 W 4838,60 S 80 8 W 5474,56 S 77 37 W 6083,58 S 77 10 W 6215,97 0 O0 2 31 2 49 0 72 0 33 0,65 0,31 0,52 0.17 0,10 0,71 0,46 0,00 0,00 N 258,61 ~ 85 408 53 ~ 810 25 ~ . 1440 64 149 646 11 2716 63 2 -769 96 $ 3409 83 W 3495 889 63 $ 4086 87 W 4182 981 87 S 4739 45 W 4840 0,00 E 0 O0 N 0 0 E '63 7 43 W 03 ~ 1 69 51 w 52 72 17 w 74 51 S 75 ~ ~ 76 3, ~ 68 S 77 16 w 57 S 7743 W 09 $ 78 17 W 1076,74 S 5368,58 W 5475,49 S 78 39 W 1189,58 S 5967,07 W 6084,49 S 78 43 W 1218,82 $ 6096,31 W 6216,96 S 78 41W ARCO ALASKA, INC, D.S. 18-17 PRUDHOE BAY NORTH SLOPE,ALASKA COMPUTATION DATEI 21-FEB-88 PAGE 5 · DATE OF SURVEYI 06-JAN-B8 KELLY BUSHING EbEVATIONI 55,00 FT ENGINEERI G, SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 O0 255 01 3 O1 555 02 655 O2 755 O3 855 O4 0 O0 55 O0 i55 00 255 00 355 00 455 00 555 O0 655 00 755 OU 855 O0 -55,00 0 0 N 0 0 E 0,00 0 5 S 49 7 E 100,00 0 29 S 13 41W 200,00 0 30 S 12 17 W 3o0,00 0 30 S 10 7 w 400.00 0 32 S 10 51W 500,00 0 35 S 12 35 W 600,00 0 33 S 13 9 W 700.00 0 37 S 17 53 W 800,00 -0 38 S 20 t0 W 955 05 955 O0 900,00 1055 11 1055 O0 1000,00 1 1358 1462 156] 167 1780 1888 1 6 51 1155 63 1255 93 1355 78 1455 85 1555 73 1655 53 1755 61 1855 3 16 O0 1100.00 6 48 O0 1200,00 10 !0 O0 1300,00 13 53 O0 1400,00 17 0 O0 1500,00 18 29 O0 1600,00 19 54 O0 1700,00 21 15 O0 1800,00 23 39 S 32 53 w S 57 57 W S 67 17 W S 70 24 W S 70 29 W 87O 4 w S 71 19 W S 72 30 w S 73 21W S 73 29 w 1999 2!12 2227 2345 2466 259t 2720 2851 2982 3113 20 1955 O0 1900.00 26 46 15 2055 02 2155 28 2255 70 2355 2455 36 2655 24 2755 02 2855 O0 2000,00 28 17 O0 2100,00 30 57 O0 2200.00 33 23 O0 2300,00 35 39 O0 2400,00 38 7 O0 2500,00 39 51 O0 2600.00 40 12 O0 2700,00 39 54 O0 2800,00 40 58 S 72 0 w S 72 2 w $73 Ow S 72 22 w S 73 22 W S 73 7 w S 73 48 S 74 50 w S 75 20 w S 75 33 w VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DES/100 FEET FEET FEET DES 3246 3379 3773 3903 4032 4159 4286 4413 42 2955 O0 2900 O0 41 35 1 3055 ~7 3155 05 3255 80 3355 38 3455 3655 95 3755 99 3855 0.00 -0,03 0.15 0 48 0 82 I 14 1 51 1 88 2 35 2 88 3,67 6,67 15,11 29,74 0,95 8.50 110,32 144,80 182.03 222,76 269 63 321 61 377 7O 440 29 508 65 583 21 664 29 747 87 832 05 916 O9 , S 75 57 W !004 17 O0 3000,00 41 16 $ 75 59 W 1092 41 O0 3100,00 40 20 S 76 21 w 1,7~ 50 O0 3200,00 40 18 $ 77 0 W 1263 12 O0 3300,00 39 45 $ 77 27 ~ 1347 28 O0 3400,00 39 9 S 78 10 W 1429 63 O0 3500,00 38 48 S 78 27 h 1510,53 O0 3600,00 38 14 S 78 36 W 1590,09 00 3700,00 38 12 S 78 45 W 1668,58 O0 3800,00 37 49 S 78 54 W 1746.91 0,00 1,15 0,15 0,11 0,10 0,03 0,15 0,07 0,10 0,23 !,30 ' 29 51 48 2,05 I:2' 17 .1,49 3,04 2 52 I 84 1 94 0 77 0 67 0 61 1 24 0 O8 0 67 0 52 0 35 0 33 0 44 0 52 0 48 0 26 0,00 00l N 0 49 S 134 S 2 22 S 3 12 S 4,06 5,02 6,02 7,07 8 31S 10 62 S 14 19 26 36 47 57 68 80 0,00 E 0 03 E 0 06 W 0 25 W 0 43 W 0 59 W 0 80 W 1 O0 W 1 29 k 1 64 W 2 23 W 4 86 W 0,00 N 0 0 E o.o . O; 9 S 6 52 w S 11 13 W 6,16 S i2 6 W 7,26 S 13 3 W 46 S 12 74 $ 26 83 3 46 30 S 73 05 S 103 76 S 136 11 64 w 59 W 113 68 W 148 52 W 85 82 W ~26 8 60 S 14 59 W 67 S94 35 W 7 S 41 21W ~6 S 53 28 w 04 $ 60 13 W 70 $ 63 37 W 77 S 65 34 W 38 S 67 5 W 72 S 68 16 W 55 S 69 13 w 94 21 S 256 94 W 273,67 S 69 51W i~80 S 306 76 W 326.152 5 $ 70 8 W 41S 360 75 ~ 38 , 9 S 70 32 W 146 38 S 420 92 W 445,65 S 70 49 W 166 53 S 486 74 W 514,44 S 71 6 W 1 S 636 75 W 670,97 $ 7 3t 234 18 3 717 59 W 754.83 S 7 55 . 55~3 S 799 23 W 839,15 S 72 15 W 276 94 S 880,80 w 923,31 S 72 32 W 34O 360 378 396 412 428 443 458 60 S 966 39 W 1011 06 $ 1052 W t099 72 $ 1135 25 S 1218 82 S 1300 21S 1381 S 146~ 90 S 16 !W 1185 W 1270 4 W 1354 08 w 1436 5 7 w 1753 S 72 49 W 7 S 73 4W 92 S 73 ~ W 52 $ 73 W 9 S 7~ 45 W S 7 59 W 5 S 74 38 W S 74 49 w ARCO ALASKA; D S ~8-17 NORTH SbOPE;ALASKA COMPUTATION DATEI 21-FEB-88 PAGE 6 DATE OF SURVEY1 06-JAN-88 KEbL¥ BUSHING EbEVATZONI 55,00 FT ENGZNEERI G, SCHN~RTZ INTERPObATED VAbUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAb DOGbEG RECTANGUbAR COORDINATES HORZZ, DEPARTURE MEASURED VERTICAb VERTICAb DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH' DEG ~IN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4540 4665 4790 5467 5604 5740 58 6995 7134 7272 7409. 7545 7682 7821 7959 8097 8234 8369 8501 8632 8763 8894 9024 155 ~285 94t6 9546 9676 9805 3955 00 3900 4055 00 4000 86 4155 20 4255 32 4355 05 4455 36 4555 23 4655 25 4755 08 4855 ,00 37 27 · 00 37 2 00 4100,00 36 52 00 4200,00 40 50 00 4300,00 42 58 00 4400,00 43 29 O0 4500,00 43 36 00 4600,00 43 20 00 4700,00 42 43 O0 4800,00 42 34 O0 4955 O0 4900.00 41 39 21 5055 O0 5000.00 41 15 05 5155 85 5255 66 5355 99 5455 46 5555 92 5655 43 5755 77 5855 O0 5100,00 44 47 O0 5200,00 46 t5 O0 5300,00 46 27 O0 5400,00 44 49 O0 5500,00 43 35 o0 5600,00 44 40 oo 5700,00 44 40 o0 5800,00 43 54 47 5955 O0 5900.00 43 7 42 56 32 6055 66 6i55 88 6255 O0 6355 55 6455  2 6555 3 6655 O3 6755 74 6855 O0 0000,00 O0 6100,00 42 51 O0 6200,00 43 2i O0 6300,00 43 45 O0 6400 O0 43 40 oo 65oo:oo 43 O0 6600,00 ~2 35 O0 6700,00 41 35 O0 6800,00 40 29 78 6955 O0 6900,00 40 9 62 7055 O0 7000,00 40 8  2 7155 40 3 4 7255 26 7355 91 7455 58 7555 73 7655 29 7755 18 7855 O0 7100.00 O0 7200,00 39 55 O0 7300,00 40 3 O0 7400,00 40 8 O0 7500.00 39 59 00 7600,00 39 31 00 7700.00 39 21 O0 7800,00 38 50 S 78 57 W 1824 12 $ 79 5 W 1900 18 S 79 35 w 1974 S 79 25 w 2053 S 79 57 w 2146 $ 78 27 w 2239 S 78 21W 2334 $ 78 58 ~ 2429 S 79 17 w 2523 S 80 45 ~ 2615 99 77 10 34 85 74 40 33 $ 82 7 W 2705 85 S 82 41 W 2793 74 $ 80 4 w 2885 S 79 11W 2988 S 80 9 W 309 3 S 80 37 ~ 3197 $ 8O 33 w 3293 $ 78 14 ~ 3390 S 78 18 w 3489 S 78 56 W 3586 57 89 63 68 43 61 30 30 S 79 33 W 3680.96 S 80 10 W 3774 40 S 80 4 W 3867 06 $ 80 45 W 3961 S 80 33 W 4056 S 80 43 W 4152 $ 81 2 w 4247 S 81 26 W 4340 S 8! 47 W 4430 $ 82 25 W 4517 01 27 15 O5 53 71 88 $ 82 34 w 4602 46 S 82 30 W 4686 73 S 82 19 w 4770 S 82 5 w 4854 $ 82 0 w 4938 $ 81 55 W 5022 $ 81 47 w 510 S 81 22 w 5i89 S 81 6 w 5271 s 80 50 w 535 3 80 46 26 28 32 57 93 22 0 48 0 42 0 89 5 35 0 66 1 73 0 47 0 34 0 97 1 46 ,87 ,59 ,72 ,75 ,47 ,10 1,88 0,41 0,36 0,30 0,28 0.32 0,13 43 0~84 0,64 0,68 0 19 0 24 0 33 0 13 0 16 0 06 0 14 0 24 0 31 ~-0 53 473,75 S 1767 95 N 1830 32 S 74 59 W 488,27 S 1842 ~t W 19~ t~ S 75 9 W 502.13 S 19t6 W 19 S 75 la8 ~ 5t6 38 S 1993 61 N 20595, 40 S 753~..e-,~'" W 21 75 533 549 569 588 605 622 13 S 2084 80 S 2176 58 S 2269 20 S 2362 94 $ 2454 13 S 2545 41 5 w 224 69 W 2434 66 W 2528 15 W 2620 635 37 $ 2034 74 W 27:{.0 646 79 S 2722 O0 W 27 97 660 679 698 715 730 749 769 788 17 S 2812 42 S 2914 20 S 3017 34 S 3120 55 S 3214 30 S 3310 31S 3406 41S 3501 90 W 2889 41W 2992 46 k 3097 51 S 52 S 75 4' O0 S 75 5~ ~ 35 0B S 76 15 W 27 S 76 26 W 79 S 7638 W 33 8 76 ~7 W 56 S 7652 W 18 $ 76 58 W 09 3201 5 $ 77 5 W 65 k 3296.62 S 77 11W 02 W 3393,77 $ 77 14 W 68 N 3492,47 S 77 16 N B0 W 3589,46 S 77 18 W 805 94 S 3594 83 W 3684 06 S 7! ~{ W 822 53 S 3686 78 W 3777 42 87~ 25 W 838 46 S 3778 07 W 3869 99 S 7 29 W 854 10 $ 3870 72 W 3963 83 S 77 33 W 885 15 S 4059 34" 4154. 72 S 7~ 4'~'~, 900~2 S 4153 06 N 4249 50 S 77 4t 914 44 S 4245.48 N 4342 84 S 77 50 ~ 927 62 S 4334,74 ~ 4432 88 $ 77 55 N 939 66 S 4421.15 N 4519 90 S 78 0 H 950 60 $ 4505 13 W 4604 33 S 78 5 W 961 57 S 4588 79 W 4688 45 S 78 9 W 972 984 995 1007 1019 1031 1044 1056 67 S 4672 05 S 4755 63 S 4838 37 S 4921 27 S 5004 42 S 5087 01 $ 5168 75 S 5248 ½w 4772 w 4855 24 w 4939 50 w 5023 75 W 5107 16 W 5190 57 W 5272 88 ~ 5354 38 S 78 14 W 92 S 78 t8 W 62 S 78 22 W 54 S 78 25 W 49 S 78 29 W 67 S 78 32 w 20 $ 7 ARCO ALASKA~ INC. D.S. 18'17 PRUDHOE BAY NORTH SEOPE~AEASKA CONPUTATION DATE~ 21'FEB'88 PAGE 7 DATE OF SURVEY{ 06-JAN-88 KELLY BUSHING ELEVATION{ 55.00 FT ENGINEERI G, SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA VEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAD VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN DEG ~IN 993~ 17 7955 O0 7900,00 39 28 10060 65 8055 O0 8000 38 7 1018~ 1011 1044i 1056 10694 ~08 11067 52 8155 i9 8255 31 8355 26 8455 26 8555 45 8655 ,00 O0 8100,00 37 57 O0 8200,00 37 47 O0 8]00,00 ~8 24 O0 8400,00 ~7 38 O0 8500,00 37 19 64 8755 O0 65 8855 VERTICAL DOGBEG RECTANGULAR COORDINATES HORXZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN S 80 25 w 5433 i0 S 79 55 W 5512 S 79 45 w 5590 S 79 57 W 5667 S 79 44 W 5746 $ 79 20 w 5824 S 79 5 w 5901 S 78 39 w 5976 S 78 0 ~ 6050 15 23 97 47 68 33 62 25 55 O0 8600,00 36 34 8700,00 36 t6 O0 8800,00 36 14 S 77 14 W 6123 11224,00 8981,04 8926,04 36 18 S 77 10 W 6215,97 0,44 0 58 0 44 0 31 0 35 0 45 0 41 0 51 0 17 o.12 1069,7~ S 5327,70 W 5434 04 S 78 38 W 1083.28 S 5405,60 W 5513 08 S 78 40 W 1097,11 S 5482 44 W 5591 13 S 78 41 W ~198~31 $ bO06 11 W 61 48 $ 78 43 W 24 0,00 1218,82 $ b096,31 W 6216.9b S 78 41W ARCO ALASKA, INC. DHOE BAY NORTH SL, OPig,ASASKA MARKER TOP SAG RIVER TOP SHUBbIK TOP SADLEROCHIT TOP ZONE 3 TOP ZONE 2 G/O CONTACT TOP ZONE lB BASE SADLEROCHIT PBTD TD COMPUTATION DATE: 21-FEB-88 PAGE 8 DATE OF SURVEY1 06-JAN-g8 KEbLY BUSHING ELEVATIONI 55.00'FT ENGINEERI G, SCHWARTZ INTERPOLATED VALUES FUR CHOSEN HORIZONS MEASURED DEPTH BEbOW KB SURFACE bOCATION AT ORIGIN= 1241FNL, 146 FEb. SEC 24. T11N R14E,UM TVD RECTANGUbAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 1040O O0 10464 O0 10548 O0 oo 64 O0 oo 11 81 O0 O0 O0 11224,00 8322,63 8372,79 8438,96 8583.44 8610.58 8649,02 8865.76 8943.97 8961.70 8981.04 8267 63 8317 79 8383 96 8528 44 8555 58 8594 02 8810 76 8888 97 8906 70 8926 04 1120 03 S 1127 10 $ 1136 52 S 1157 27 $ 1161 19 S 1166 78 8 1200 05 S 1212 78 S 1215 67 $ 1218 82 S 610 650 700 8O9 5829 5857 6013 6069 6082 6096 6 ~ 80 99 W 80 W 75 W 46 W 3~ w ARCO ALASKAv INC. DIS. 18-17 PRUDHOE BAY NORTH SLOPEvALASKA RARAER TOP SAG RIVER TOP SHUBbIK TOP $AD~EROCHIT TOP ZONE 3 TOP ZONE 2 G/O CONTACT TOP ZONE lB BASE SADLEROCHIT PBTD TD COMPUTATION DATEJ 2J-FEB-88 PAGE DATE OF SURVEY~ 06-JAN-88 BUSHING ELEVAT~ONI 55,00 ENGINEER~ G, SCHWARTZ MEASURED DEPTH BELOW KB 10400,00 10464,00 10548,00 10730.00 10764,00 oo 110 O0 11178 O0 11200 O0 11224 O0 SURFACE LOCATION AT ORIGINm 1241 FNL~ 146 FEL. SEC 24~ TllN. R14E,UM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH 8322.63 8372.79 8438.96 8583,44 8610,58 8649,02 8865,76 8943,97 8961,70 8981,04 8267 63 8317 79 8383 96 8528 44 8555 58 8594 02 8810 76 8888 97 8gOb 70 8926 04 1120.03 5 1127.10 $ 5650 1136,52 S 5700 1157,27 S 5809 1161,19 S 5829 1166,78 S 5857 1200.05 S 6013 1212,78 S 6069 1215,67 S 6082 1218,82 S 6096 5610 98 W 99 BO W '75 ~ 46 ~ FINAL WELL LOCATION AT TO: TRUE St]B-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11224.00 8981,04 8926,04 H(3~IZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG ~IN 621b,96 S 78 41 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. 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PROJECTION ON VERTICAL PLANE 260. - 80. SCALEO IN VERTICAL OEPTHS HORIZ SCALE = 1/2000 IN/FT ARCO AI...A$1<A, INC~ F'., O. .BOX ANCHORAGE, ALAXKA DATE: 4-t 5-88' . REFERENCE: ARCO CASED HOLE FINAl_ '~ :~-- ,'...). 7 4-6-88 CBT ~ :3-27 4-6-88 CEIT. (,..ALTPER LOG ~4--t 9 4-9-86 CBT ,,,,mmm 4- t 9 4-9-8[4 ~- ..~, ~ t R-- t ~ ~.-. 2 ?-.. 88 F:' '" r' F:'I...EASE ,?I('.;N ANT)F~'l!('l'lll:~'. RE::['.F ]' V F.D DY I"IAVIE A NIC I::'IE O(.'; Y BE:NJ A T ¢3 '- t 5, 29 Oil & Gas Cons. Commission Anchorage · r R'AN,%., -, :~ F:.~f!i 2 :~ 6.. ~ AF:'F. I.,.OVE. I) ............................................................... D I S T R ;1: B I..I 1' :1; O N ,.~CH A'T'I...A,.~ .., I.-.. N 1 R A I.. F:' :1: I.,. E ,S' '"' f..'. 14 [','; V R (3 N .#. I) & M E. X 1 F. N,.. ]. 0 N E X I::' L. (.. R A Y I (:.1N E X X 0 N H~R~THON M C) B I !... T ' F:' I"1 .. I... ~... :1: F:' ,_~ F:' R W E". L.. I... F:' '[ IL,. E". S' :,":,. ,~"I'A'T'E-.'. r)F AI,..A,.~I.A ~: 't" .F]X A C. II REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ,~ Stimulate ~ Plugging ~ Perforate r~ Pull tubing Alter Casing ~_ Other X~ COHPLETE 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1241' FNL, 146' FEL, Sec.24, T11N, R15E, UN At top of productive interval 2378' FNL, 567' FEL, Sec.23, T11N, R14E, UM At effective depth 2457' FNL, 948' FEL, Sec.23, TllN, R14E, UM At total depth 2460' FNL~ 962' FEL~ Sec.23~ T11N~ R14E~ UM 11. Present well condition summary Total depth: measured 11224'ND true vertical 8981 'TVD Effective depth: measured 11200 ' ND true vertical 8962 ' TVD feet feet feet feet 5. Datum elevation (DF or KB) RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 8. Approval number 8-19 9. APl number 50I 029-2176,8 10. Pool Prudhoe Bay Oil Pool Plugs (measured) None Junk (measured) None Feet Casing Length Size Conductor 80 ' 20" Surface 3252 ' 1 3-3/8" Production 10358' 9-5/8" Liner 1104' 7" Cemented Measured depth True Vertical depth 1687# Pol eset 109 ' MD 109' TVD 3500 sx CS III & 3292'MD 2989'TVD 600 sx Class G 875 sx Class G 10394'MD 8318'TVD 400 sx Class G 10118'-11222'MD 8100'-8979'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 3-1/2", L-80, tbg w/tail (~ 10774' Packers and SSSV (type and measured depth) 3H pkr ~ 10083' & TRDP-1A-SSA SSSV @ 2181' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Inj, ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Hi story w/Addendum, dated 1/21/88) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ]~2 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Gyro Form 10-404 Rev. 12-1-85 ~ Title Associate Engineer (Dani) SW03/65 Date 4'7- Submit in Duplicate ADDENDUM WELL: 1/8/88 18-17 RU Schl, rn CET f/11,195'-10,133'. Rn Compensated Neutron f/11,193'-10,100'. Rn GCT gyro f/11,106'-11,140' GR f/ll 193'-10,100' RD Schl Drill~ ARCO Oi~,..,ld Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "'Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when eperatlone ere suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion end representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State ARCO Alaska, Inc. NORTH SLOPE AK Field I Lease or Unit ~ Well no. PRUDHOE BAY FIELD [ ADL: 28307 DS 18-~7 Auth. or W.O. no. ITitle AS1771 I COMPLETION API: 50-029-21768 Operator A.R.Co. W.I. ARCO 21. 0000 Spudded or W.O. begun Date ACCEPT 03/14/88 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O. 2015 MRS Date and depth as of 8:00 a.m. 03/17/88 ( TD: PB:l1200 SUPV:SC/WM Complete record for each day reported NORDIC [ RIG RELEASED 7"@11222' MW: 8.5 SEAWATER/DIESEL SET PACKER. TEST TUBING TO 3000 PSI. TEST ANNULUS TO 2500 PSI. SET BPV. ND STACK. NU TREE AND TEST TO 5000 PSI. RELEASED RIG @ 1315 HRS, 3/16/88. DAILY:S36,551 CUM:$2,222,387 ETD:S2,222,387 EFC:$2,342,000 Old TD Released rig Classifications (oil, gas, etc,) Producing method Potential test data New TD P8 Depth Date Kind of rig Type completion (single, dual, etc,) Of c al reservoir name(s) IWell no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Clloke size T.P, C,P, Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation/~d distribution, see Procedures ManJJ~[I, Section 10, Drilling, Pages 86 arrd 87. ASSOOA~ ENGINEER AR3B-459-3-C INumber all daily well history forms consecutively Page no as they are prepared for each well. DIvlIioI1 ol AtlentlcR IchfteldCompany ARco, olra~ ~as'Company, 4~" ./ Inalmetl~ltl: Prepare and submit the "l,llill RIIIelI" on the first Wednesday after a well is spudded or workover operations are ~t~rted. Daily work prior to sPudding should be summarized on the form giving inclusive dates only. District ~CO Al&ska, Inc. Field PRUDHOE BAY FIELD lCounty, parish or borough NORTH SLOPE Lease or Unit ADL: 28307 Title COMPLETION IstateAK l Well no. DS 18-~7 Auth. or W.O. no. AS1771 Operator ~CO API: 50-029-28307 I ARCO W.I. IPrlor status if a W.O. IDate 03/14/88 IH°ur 2015 HRS II 21'°°°° Spudded or W.O. begun ACCE P T Date and depth as of 8:00 a.m. 03/15/88 ( TD: ?B:l1200 SUPV:SC/WM 03/16/88 ( TD: PB:ll200 SUPV:SC/WM Complete record for each day reposed NORDIC i RU TO RUN TUBING 7"@11222' MW: 9.1 NACL MOVED RIG FROM DS 18-16 TO DS 18-17. ACCEPTED RIG @ 2015 HRS, 3/14/88. ND TREE. NU BOPE & TESTED. LOADED PIPE SHED WITH 3-1/2" TUBING. STRAP & INSTALLED SEAL RINGS. TAKE ON SEAWATER & MIX CORR. INHIBITOR. RU FLOOR TO RUN TUBING. DAILY:S18,000 CUM:$1,885,786 ETD:S1,955,000 EFC:$2,272,786 PREPARE TO SET PKR 7"@11222' MW: 9.1 SEAWATER/DIESEL RAN 3-1/2", 9.3~/FT, L-80, TUBING WITH TAIL @ 10774', SSSV @ 2181', BAKER PKR @ 10083'. LANDED TUBING. DISPLACED WELL TO 8.5 PPG SEAWATER TREATED WITH 10 GAL/100 BBLS C-193 INHIBITOR FOLLOWED WITH 244 BBS DIESEL TREATED WITH 10 GAL/100 BBLS C-120 CORR. INHIBITOR. BACK FLOWED 150 BBLS INTO ANNULUS. SITP - 400 PSI. DROPPED BALL AND ALLOWED TO FALL. RU TO SET PACKER. DAILY:S300,050 CUM:$2,185,836 ETD:S2,255,050 EFC:$2,272,786 The above Is correct Signature For form preparat~n' a~nd distribution, see Procedures ~l~lnual, Section 10, Drilling, Pages 8~'and 87. IDate ASSOCIATE ENGIINEL=I=I AR3B-459-1-D Number all dally well history forms consecutively ~Page no. as they are prepared for each well. I I ARCO Alaska, Inc.{ Prudhoe Bay ~.ngineerincj Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 18-17 Permit Number: 87-120 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very_truly yours, a. F. Scheve DFS/MKM:sd Enclosures cc: Standard A1 aska Production Co. JoAnn Gruber, ATO 1478 File P1(18-17)W1-3 ARCO Alaska, Inc. is a Subsidiary of AflanticRichfieldCompany AR3B--6132-C i~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 7- Suspend - Operation Shutdown ~_ Re-enter suspended well -' Alter casincl/'- Time extension ~ Change approved program ,~. Plugging ~ Stimulate -' Pull tubing - Amend order - Perforate~ Other - 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 55' RKB feet 3. Address 6. Unit or Property name Post Office Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location, of well at surface 1242 FNL, 146'FEL, Sec. 24, T11N, R15E, UM At top of productive interval 2300'FNL, 700'FEL, Sec. 23, T11N, R14E, UM At effective depth 2336'FNL, 980'FEL, Sec. 23, T11N, R14E, UM At total depth 2338'FNL, 995'FEL, Sec. 23, T11N, R14E, UM 7. Well number 18-17 8. Permit number 87-120 9. APl number 5O-- 029-21768 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11224 feet 8982 feet 11200 feet 8963 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' Surface 3252' Production 10358' Liner 1104' 20" 1687# Poleset 13-3/8" 3500 sx CS 111 & 600 sx Class G 9-5/8" '875 sx Class G 7" 400 sc Class G 109' 109' 3292' 2989' 10394' 8323' 10118-11222' 8106-8980' Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments ~,itAR I ? !.,r,.:,i Alask~ Oil & 6as Cons, Anchorage: Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation March 1988 14. If proposal was verbally approved .... ~ "'"Ti/'"¢''~' .'~,~9~'~01",:'C;:[~ Name of approver ~;',(,;~.~,~,~'~,~,,,, ,:~., ~' .. - ~_ ~:,' ~,~',d' ,~-/~- ~ "~1/~, ~ Date approved 15. I hereb~certify that4he focegoing is true and correct to the best of my knowledge Signed¢~ ~~~ Title Operations Engineering Manager Commission Use Only Approved by Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ~,pproved Copy Returned - ORIGINAL SIGNED BY ~_~ --~.~/.~"~ ~ I ONNIE C. SMITH Commissioner Form 10-403 Rev 12-1-85 18-17/STAT17 M. K. Melton (265-6810) Date by order of the commission Dat~ ~'"~-'~ ~:~ ~,..~./) Submit in triplicat~ DS 18-17 PROPOSED INITIAL PERFORATIONS APl # 50-029-21768 PERMIT # 87-120 ARCO Alaska, Inc. proposes to perforate within the Sadlerochit interval in well 18-17. The proposed perforation intervals are as follows: Intervals to be Shot Shot Density Zone SS Interval 11040-11050 MD 11070-11084 MD 11098-11106 MD 11114-11132 MD 11138-11158 MD 1 ! 162-11176MD 8778-8786 SS 1/2 SPF 2 8' 8802-8813 SS 1/2 SPF 2/1 1 1' 8824-8831 SS 4 SPF 1 7' 8837-8852 SS 4 SPF 1 15' 8857-8873 SS 4 SPF 1 16' 8876-8887 SS 6 SPF 1 1 1' .Ref Log: CH CNL-SWS 1/7/88 A 5000 PSI WP wireline lubricator and BOP, tested to 4000 PSI working pressure prior to the job, will be utilized for this operation. m' 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W I REL I NE BOP EQU I PMENI' _ St0084006 REV. LIST OF CO-OWNERS Mr. M. H. Harris Standard Alaska Production Company P.O. Box 196612 Anchorage, AK 99519-6612 Mr. J. C. Bowen EXXON Company, U.S.A. P.O. Box 5025. Thousand Oaks, CA 91359 Mr. T. A. Edmondson Chevron U.S.A., Inc. P.O. Box 8200 Concord, CA 94520 Mr. W. E. Pritchard Mobil Oil Corporation P.O. Box 5444, Terminal Annex Denver, CO 80217 Mr. J. D. Owen Phillips Petroleum Company 8055 E. Tufts Avenue Parkway Denver, CO 80237 Mr. C. A. Dowden Marathon Oil Company P.O. Box 102380 Anchorage, AK 99510 Mr. R. W. Mullins Amerada Hess Corporation P.O. Box 2040 Tulsa, OK 74101 Mr. R. Iden ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Mr. Robert J. Chebul The Louisiana Land and Exploration Company Western Division 1675 Broadway, Suite 2100 Denver, CO 80202 Mr. S. M. Buchanan Division Petroleum Engineer Texaco, U.S.A. 3350 Wilshire Blvd. Los Angel es, CA 90010-9990 Mr. R. G. Hollis SHELL WESTERN E & P INC. Pacific Frontier Division P.O. Box 527 Houston, TX 77001 British Petroleum Alaska Expl orati on Company One Maritime Plaza, Suite 500 San Franciso, CA 94111 Attention: Joint Interest Corp. WJP4/iO F'~ O, BOX ANCHORAGE, AI_.A,.~K A 995t I)ATE · 2-t t-88 REFERENCE: ARCO MAGNETIC TAF'E~ W/LISTING i 2-24-87 MAI..,TAF'E~87t.'2...24 CNP/.I.,R/ROP/CAI... RI. IN t PI...EA~E SIGN ANn RETURN THE ATTACHE~ COPY A,~ RECEIPT OF DATA, RECEIVED BY D .T. ,~TR ;r );~l.l'f' I ON CENTRAl... F I I...E,S' CHEVRON · .. , o.. , F'., H(...F HE.E TF:. R,., EXXON MARATHON MOBIl... ,,..'"' F'H I I.I....T, PS F'B WEI...I.. FTI,,,EX R & D '"' ,.~AP[';, , , ',':!~ ~: ' ,.~TAI',F; OF AI..,A,S'KA I'EXAC..O ARCO AI..A,.~KA, INC, ( F',O, BOX tOOS60 ANCHORA[.;E, AI..A,~KA 99.5t 0 DATE' 2-fi-R8 REFERENCE: ARCO OPEN HOLE FINALS t2-24-87 ~FD/CNF'/GR-HD Fi,'I.!N t. c;, PI..EA..~E ,.~IGN AND RETURN THE ATTACHED COF'Y AS RECEIPI' [iF' DATA, F'EG6Y BENNETT ATO- t 529 TRAN,~ ~88i ~!2 ~ AF'F','EOVIED DISTRIBU'FION BAROT. D CENTRAl... FILES CHEVRON D & M EXTE,4..ION EXF'L. ORATION EXXON MARATHON MOBIl._ AR'P. fl AI..A.S'KA: TNf':. F'. f"l, l~flX ~ (.)OX/,O ANf]H£~RA~,I::', Al A.t,~K A 995 ~ (.) BAI'F ' '2-%- RR RFFEREWCE" ARP, FI OI'REK:T'f[INAI. DATA 7-?7 11~-~ MWB DTR[-".C.T'[ONAI. ,S'I.IRVI..--.Y Mb. lB D.TR'FC'f'TI~NAI .S'I IR'VFY Mklf) T)I'RFI':T'I'FIN¢~I .~'III:;'VF'Y A F:' I::' ~' O. \! E fJ .. l) ! ,.?TR T 'IFil IT1 nN TI!!' I. FCR TFI E P.f'l T I:" I 1::1".13 ANCHORAGE AI_.A$1.A 99.5t (-) DATE' t-~.0-88 REFEREN..,E ARCO MAGNETIC 'TAF'EE$ W/I...ISTIiNG MAGTAF .F.'.~- 7.,: .... 64 NC, T./CNTH/GR' '¥NRI. I CA,?IN(.; PI..EA,.~E .?I;F.,N AND I=(ETI..IR'.N TI-IF.: A'f"f'A RECEIVED BY_ HAVIE A NICE'.'. DAY! I-EGGY BENNETT ATO .... t 529Fr __R E f;'.. f.=.; ;f. F' '!' 0 F' D A T A ,. A P F R r..) V E D ..................... '_~)_ .................................... D I ,.? 'T R .'!7. B I..i T 1 I';.1 N ( '2 ) ..,I::.NTRAI... I='II...l:'. .... C I"1E V R 0 N D & M ( t ) F' MCI- HF.':.E TER,.. · ,,."" E X X C) N MARA'TI40N M 0 B I L K(~ STATE OF ALASKA ~" ALAS OIL AND GAS CONSERVATION COMN!'.,,$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown EX Re-enter suspended well ,~. Alter casing ~--_' Time extension ;-- Change approved program ~ Plugging ~ Stimulate '~ Pull tubing Z Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 50' feet 3. Address 6. Unit or Property name P. 0. Box 100360, Anchorage, AK 99510-0360 Prudhoe Bay Unit 4. Location of well at surface 1242' FNL, 146' FEL, Sec.24, At top of productive interval 2300' FNL, 700' FEL, Sec.23, At effective depth 2336' FNL, 980' FEL, Sec.23, At total depth 2338' FNL, 995' FEL, Sec.23, TllN, R15E, UM T11N, R14E, UM T11N, R14E, UM T11N, R14E, UM 7. Well number 18-17 8. Permit number 87-120 9. APl number 50-- 029-21 768 10. Pool Prudhoe Ba~/ Oil Pool 11. Present well condition summary Total depth: - measured true vertical 11224'MD 8982'TVD Effective depth: measured 11 200 ' MD true vertical .8963'TVD Casing Length Size Conductor 80 ' 20" Surface $252 ' 1 3-3/8" Producti on 1 0358 ' 9-5/8" Li ne r 11 04 ' 7" feet Plugs (measured) None feet feet Junk (measured) None feet Cemented 1687# Poleset 3500 sx CS II I & 600 sx Class G 875 sx Class G 400 sx Class G Measured depth 109'MD 3292'MD 10394'MD 10118'-11222'MD True Vertical depth 109'TVD 2989 ' TVD 8323'TVD 8106'-8980'TVD Perforation depth: measured None true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation June, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ f~/)?/~(~ ~~¢.~ Title Associal;:e E naineer Commission Use Only (Dani) Date /-/~ -~ SA3/46 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I ORIGINAL SIGNED BY Approved by [oN'NIl: C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned Commissioner by order of ~ ~: the commission Date /'-'..~//- ~ ~ Submit in triplicate ARCO Oil and Gas Company,~," Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday attar a well is SDUdded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough ARCO Alaska, Inc. I NORTH SLOPE Field ILease or Unit PRODHOE BAY I ADL: 28307 Auth. or W.O. no. ITitle AS1771 ~ DRILL API: 50-029-21768 Operator ARCO I Sta~.K l Well no. DS 18-17 Spudded or W.O. begun IARCO w.i. 21.0000 Prior status if a W.O. SPUD Date and depth aa of 8:00 a.m. 12/10/87 ( TD: 250' ( IDate IHour 12/10/87 0330 Complete record for each day reported ROWAN 41  DRILLING O) MOVE IN AND RIG UP ROWAN 41. 20"@ 109' MW: 8.5 VIS:250 ACCEPTED RIG AT 1900 HRS, SURV:JH , , · 12/11/87 ( TD: 1620'( 1 SUPV=JH 12/12/87 ( TD: 2385'( SUPV:JH 12/13/87 ( TD: 3305'( SUPV:JH 12/14/87 ( TD: 3305'( SUPV:JH 12/15/87 ( TD: 3820'( SUPV:JH ) 70) ) 65) ) g20). 0) ES) 12/16/87 (7) TD: 5743'(1923) SUPV:JH 12/17/87 ( 8) TD: 7062' (1319) SUPV:SC 12/09/87. NO HYDRIL AND DIVERTER SYSTEM. MIX MUD. PU BHA. SPUDDED @ 0330 HRS, 12/09/87. DRILLED 17-1/2" HOLE F/ 110, - 250'. DAILY:S206,958 CUM:$206,958 ETD:S206,958 EFC:$2,342,000 DYNA-DRILLING 20"@ 109' MW: 9.5 VIS:110 DRILLED 17-1/2" HOLE TO 655' POH FOR BIT. REAMED 60' TO BOTTOM. DRILLED TO 959'. CIRC. POH. PU DYNA-DRILL. TIH. DYNA-DRILLED 17-1/2" HOLE TO 1620' DAILY:$58,838 CUM:$265,796 ETD:S265,796 EFC:$2,342,000 DRILLING 20"@ 109' MW: 9.3 VIS: 87 DYNADRILL 17-1/2" HOLE TO 2385' DAILY:S57,337 CUM:$323,13'3 ETD:S323,133 EFC:$2,342,000 POOH TO RUN CASING 13-3/8"@ 3292' MW: 9.7 VIS: 73 DYNADRILL 17-1/2" HOLE TO 2704'. CHANGE BHA. DRILLED 17-1/2" HOLE TO 3305'. CBU. POOH TO RUN 13-3/8" CASING. DAILY:S47,741 CUM:$370,874 ETD:S370,874 EFC:$2,342,000 INSTALLING CSG HEAD 13-3/8"@ 3292' MW: 0.0 VIS: FINISH POOH. RUN 79 JTS 13-3/8", 72%, L-80, BTC CASING. CEMENT WITH 3500 SX OF CS III 12.2 PPG LEAD. FOLLOWED BY 600 SX OF CLASS G 15.8 PPG TAIL. FS @ 3292' . BUMP PLUG WITH 2000 PSI. INSTALLING CASING HEAD. DAILY:S345,323 CUM:$716,197 ETD:S716,197 EFC:$2,342,000 DRILLING 13-3/8"@ 3292' MW: 8.7 VIS: NU AND TEST BOPS. TEST 13-3/8" CASING TO 2500 PSI FOR MIN. DRILL OUT FLOAT EQUIPMENT. DRILL 12-1/4" HOLE TO DAILY:S43,874 CUM:$760,071 ETD:S760,071 EFC:$2, DRILLING 13-3/8"@ 3292' MW: 9.2 VIS: DRILL 12-1/4" HOLE TO 4837'. PU DD. DYNADRILL 12-1/4" TO 5743'. DAILY:S44,435 CUM:$804,506 ETD:S804,506 EFC:$2,342,000 DRLG 12-1/4" HOLE 13-3/8"@ 3292' MW: 9.2 VIS: 40 3 0 3820 37 HOLE DRILLING 12-1/4" HOLE TO 7062' DAILY:S52,210 CUM:$856,716 ETD:S856,716 EFC:$2,342,000 The above Is correct For form preparation an I'butlon, see Procedures Manual, ~::tlon 10, Drilling, Pages 86 and 87.~, IDate [ Title / Associate Engineer ARCO Oil and Gas Companyv" ally Well History--Interim · Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO Alaska, Inc. ICounty or Parish [Stat~kK NORTH SLOPE Lease or Unit DS 18-1['/JWell no. PRUDHOE BAY Date and depth as of 8:00 a.m, 12/18/87 ( TD: 7983'( SUPV:SC 12/19/87 ( 1 TD: 8665'( SUPV:SC 12/20/87 ( 1 TD: 9785'( 11 SUPV:SC 12/21/87 TD:10405' ( SUPV:SC 12/22/87 TD:10405' ( SUPV:SC 12/23/87 ( 1. TD:10405' ( SUPV:SC 12/24/87 ( 1! TD:11224' ( ~ SUPV:JWH 12/25/87 ( 1~ TD:11224' ( SUPV:JWH Complete record for each day while drilling or workover in progress ROWAN 41 )21) DRILLING 13-3/8"@ 3292' MW: 9.4 VIS: 42 DRILL 12-1/4" HOLE TO 7983' DAILY:S44,503 CUM:$901,219 ETD:S901,219 EFC:$2,342,000 )) ~82) L) L20) DRILLING 12-1/4" HOLE 13-3/8"@ 3292' MW: 9.9 VIS: 42 DRILLED 12-1/4" HOLE TO 8546'. POH & CHANGED BHA. TIH. CONTINUED DRILLING 12-1/4" HOLE TO 8665'. DAILY:S43,555 CUM:$944,774 ETD:S944,774 EFC:$2,342,000 DRILLING 12-1/4" HOLE 13-3/8"@ 3292' MW: 9.9 VIS: 46 DRILLED 12-1/4" HOLE TO 9785' WITH NUMEROUS PUMP REPAIRS. :) ~20) DAILY:S76,516 CUM:$1,021,290 ETD:S1,021,290 EFC:$2,342,000 POH FOR 9-5/8" CASING 13-3/8"@ 3292' MW:10.2 VIS: 37 DRILLED 12-1/4" HOLE TO 10405' (AGAIN WITH PUMP REPAIRS). CIRCULATE. POH FOR 9-5/8" CASING. DAILY:S46,191 CUM:$1,067,481 ETD:S1,067,481 EFC:$2,342,000 ND BOPE TO PLACE TBG SPOO 9-5/8"@10394' MW:10.2 VIS: 36 POH. CHANGED LOWER RAMS TO 9-5/8~ RAN 240 JTS 9-5/8", 47#, L-80, BTC CSG W/ SHOE @ 10394' AND FC @ 10305'. CMTD W/875 SX CLASS G. CIP @ 0245 HRS, 12/22/87. ND BOPE. DAILY:S346,744 CUM:$1,414,225 ETD:S1,414,225 EFC:$2,342,000 DRLG CMT IN 9-5/8" CSG 9-5/8"@10394' MW: 9.1 VIS: 30 ND BOPE; TESTED PACKOFF TO 5000 PSI. NU BOPE. CHANGED RAMS TO 5" & TESTED. CUT DRILL LINE. PU 8-1/2" BHA & RIH. TAGGED CMT @ 10222' LOWERED MUD WT. TESTED CASING TO 3000 PSI - OK. DRILLING CMT IN 9-5/8" CASING. DAILY:S38,279 CUM:$1,452,504 ETD:S1,452,504 EFC:$2,342,000 ) 19) RUN REPEAT LOG W/MWD 9-5/8"@10394' MW: 9.0 VIS: 36 DRILLED CMT, FC, FS & 10' NEW FORMATION. TESTED FORMATION TO 12.5 PPG EMW. DRILLED 8-1/2" HOLE TO 11224'. CIRC. PUMPED OUT OF HOLE TO 9-5/8" SHOE. WASHED & REAMED TO 10588'. REPEAT LOG WITH MWD F/10588'-10728'. DAILY:S45,935 CUM:$1,498,439 ETD:S1,498,439 EFC:$2,342,000 0) RIH W/8-1/2" BHA 9-5/8"@10394' MW: 8.9 VIS: 40 RAN BAROID REPEAT LOG F/10728'-11224' CBU. POOH. UNLOADED MWD DATA. RU SCHLUMBERGER. GIH W/DIL/BHC/GR/SP. UNABLE TO GET PAST 10369' RD SCHLUMBERGER. PU 8-1/2" BHA. RIH. DAILY:S72,539 CUM:$1,570,978 ETD:S1,570,978 EFC:$2,342,000 The above is correct Signature I Date For form preparation and dls~bution see Procedures Manual Sect~ln 10, Drilling, Pages 86 and 87 Title Associate Engineer ARCO Oil and Gas Company ~ Uaily Well History--Interim Instluctlons: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field I County or Parish ARCO Alaska, Inc. '1 NORTH SLOPE I Loase or Unit PRUDHOE BAY Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 12/26/87 ( 1 TD: 11224' ( SUPV: JWH 12/27/87 ( 1 TD: 11224' ( SUPV: JWH ROWAN 41 7) 0) POOH W/7" LINER 9-5/8"@10394' MW: 9.0 VIS: 42 RIH W/8-1/2" BHA. WASHED F/11109'-11224' CBU. POOH TO 9-5/8" SHOE. SPOTTED PILL. POOH. RU & RUN 24 JTS 7", 29.0#, L-80, BTC, CASING. ROH ON 5" DP. HIT BRIDGE @ 10423'. UNABLE TO WORK PAST. POH WITH 7" LINER. I Well no. D~ 1R-I~ o) DAILY:S66,484 CUM:$1,637,462 ETD:S1,637,462 EFC:$2,342,000 RIH W/7" LINER 9-5/8"@10394' MW: 9.0 VIS: 44 POOH. STAND BACK 7" LINER.. PU 8-1/2" BHA. RIH. REAMED OUT TIGHT SPOTS. MAKE 10 STD SHORT TRIP. CIRC. & SWEEP 12/28/87 ( 1 TD:11224' ( SUPV:JWH 12/29/87 ( 2 TD:11224' ( SUPV:JWH )) o) o) HOLE, POH. RU & RUN 24 JTS 7", 29#, L-80, BTC CASING. RIH. DAILY:S41,462 CUM:$1,678,924 ETD:S1,678,924 EFC:$2,342,000 CIRC. BOTTOMS UP 7"@11222' MW: 9.0 VIS: 44 FINISHED RUNNING 7" LINER F/10118'-11222' CMTD LINER W/400 SX CLASS G. BUMPED PLUG. POOH. DAILY:S95,638 CUM:$1,774,562 ETD:S1,774,562 EFC:$2,342,000 POOH LDDP 7"@11222' MW: 0.0 VIS: CIRC. POOH. LD 30 JTS HWDP. GIH WITH 6" BIT AND SCRAPER. CLEAN LINER TO 11200 '. CIRC. TEST LINER TO 3000 PSI. DISPLACE WITH 9.1 PPG BRINE. POOH LDDP. DAILY:S57,674 CUM:$1,832,236 ETD:S1,832,236 EFC:$2,342,000 The above is correct For form preparation and di~Zl~butlon see Procedures Manual Sec{iJ~n 10, Drilling, Pages 86 and 87 -- Date ITitle Associate Engineer ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repor~ completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation il space is available. I Accounting cost center code District I Statl ARCO Alaska, Inc. Field ICounty or Parish NORTH SLOPE Lease or Unit Title ADL: 28307 DRILL PRUDHOE BAY Well no. DS 18-~7 Auth. or W.O. no. AS1771 API: 50-020-21768 I Icost center prior to plugging and I I ARCO 21. 0000 labandonment of this well I Spudded or W.O. begun Date our Prior status If a W.O. SPUD 12/10/87 / 0330 I Date and depth aa of 8:00 a.m. Old TD Released rig 12/30/87 ( 2 TD:11224'( SUPV:JWH Complete record for each day reported ROWAN 41 o) RIG RELEASED 12/30/87 7"@11222' MW: 9.1 VIS: FIN LDDP. CO CURRENT IMBALANCE RELAY. PULL WEAR RING & SET DUt~Y HGR W/BPV. C/O UPPER RAMS TO 5". N/D BOP & N/U LOWER TREE. FREEZE-PROTECT W/130 BBLS DIESEL. SECURED WELL. RELEASE RIG @ 0115 HRS, 12/30/87. DAILY:S35,550 CUM:$1,867,786 ETD:S1,867,786 EFC:$2,342,000 New TD Date IPB Depth Kind of rig Classifications (oil, gas, etc.) Producing method Type completion (single, dual, etc.) Official reservoir name(s) Potenti.~l' test data .. Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day _.. Pump size, SPM X length Choke size T,P. C,P, Water % GOR Gravity Allowable Effective date corrected The above Is correct Signature For form preparation and/~strlbution, see Procedures Manual, {¥ctlon 10, Drilling, Pages 86 and 87'5. IDate ITitle /-//--~ Associate Engineer ARC(] AL. ASKA, F'. O. BOX t ANCHORAGE, AI..ASKA 995t0 DATE: t-t2-88 REFERIENCE · ARCO [)FEN HOI..E F.T. NAI...S t2-24-87 ~ 2-24-87 t 2-24-87 t 2-24-87 EWR/GR TOOI...~284RN6-2 EWR./GR TOOL.~548RDN6 CNP/GR CNP/GR/NF-OVERL. AY RUN RI.IN RIJN RI. tN F'I...EASE SIGN AND RETURN 'THE A'¥TAC;FIEI) COF'Y AS RECEIF'T OF DATA, TRAN$ $88~28 APPROVED DIS'rRIBI.ITZON CENTRAl._ FILES CHEVRON D & M EXTENSION EXF'I...ORA'/I ON EXXON MARATHON MOB I i... · ,-'"' F'I"I I I...I... I F'S FF.. WELL. FII...F.'.S; -'"-,,- R & D · .-'"' ,~ A F' ('.'. '"'.,,- STATE [)F AI...ASI<A -,,-'"' 'l" .F. iXA C(] BAROID BARO;[D BAROID BARO]D ARP. O AI...A.~ A.. T. NC , P,O, BOY ~A~ ANCHORAGE, ALASKA 995t DATE' ~-~-88 RFFERENCE' ARCO CA£ED HOLE FINAL 9-3;4 ' 9-~4 ~-7-88 GAMMA RAY./GL.M ~URVEY ~-7-88 PRODI.ICTION LOG t-9-88 CBT/VARIABLE DENSITY LOG ~-6-88 CET ~-7-88 NATURAL ~AMMA RAY ~-?-88 COMPENSATED NELITRON LOG RI.IN RLIN RI.IN RUN RUN PLEA,.~E ,DIGN AND RETURN THE ATTACHED COPY A,D RECF..IPT OF DATA.. HAVE A N P E.,., Y ~ EN N~T ~ .... ~omge ATO-~ 529 TRAN$ ~88G~9 APF'R. OVED .... D I ,.~TR TI BI. IT .T. ,~CH ,.~P.,H ,~CH .~' .C.H ,~CH CENTRAl... FILES CHEVRON D&M EXTEN£~ON EXPI...ORATION EXXON MARATHON MOBIL. ~ PI-t I I...!.. I P,.g' F'B WEI:..I... FII..E,~ '"' ,.t". AF'C '"-"."?',.~TATE OF AI_AS'KA · '- TEXACO ARCO AI..A~KA, INC~ F'.,O. BOX t08~60 ANCHORAGE, AI...A~KA 9~5t0 .DATE' '~ 2-,,~-87 REFERENCE: ARCO OPEN HOL. E FINAL,.~ '~:~'~:" t2-24-87 GAMMA RAY IN [.'.A~.~ING RLIN t, 2" & 5' ,~CH F'I...EASE SIGN AND RETURN THE ATTACHED COPY A,.~ RECEIPT OF I)ATA~ RECEIVED BY HAVE A NICE DAY! PEGGY BENNETT AT0-t529 TRAN~ ~877t9/5-~ AF'F'ROVF I) Anchorage DISTRIBUTION C. EN'!'F?.ALF I I...E,.S' CHEVRON .l) & M EXTENSION EXPI...ORATION EXXON MARATHON MOBIL, F' H I I... I.., :[ P ,.~ F'B WEI...I... FII...E,S' R & D ,.~TATE OF ALASKA TEXACO ~RCO AI_A,.~KA, .TNC,~ F'.,O., BOX t(')G~60 ANCHORAGE~ AI..A,.~KA 99..5t (') DATE: ~ 2-:28-87 REF-"ERENCE' ARCO OPEN HOLE FINALS ~8-~7 ~2-~0-87 MWD/RE$-GAM-F'I...I..I,~ DIRECTIONAL. RUN ~ , 2' & 5' TEL..EC.O HAVF..: A NI (~. A¥~t~ska Oil & Gas Cons. COlllmiSsiOll ~ Anchorage FEGGY BENNF..TT ATO- ~ 529 TRA N,.t.' ~87707 AF'F'ROVEI)___ D I ,S'TR ! BI. IT .T ON ~,,. CENTRAl... FII...E,~ ~ C H i.'-.'; ¥ R 0 N ~ E X'FE N,~ I (.'Cl. N EXF'I.,. OF;:AT I ON ~ EXXON '"' MARAI'HON ~" M 0 B I L November 30, 1987 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit DS 18-17 ARCO Alaska, Inc. Permit No. 87-120 Sur. Loc. 1242.'FNL, 146'FEL, Sec. 24, TllN, R14E, UM. Btmhole Loc. 2330'FNL, 866'FEL, Sec. 23, Ti1N, R14E, U~. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indenn~ify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the weI1 site. 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. !~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below tile shoe of the conductor pipe. C V. Chatt .... . ertoTM Chairman of Alaska Oil and Gas Conservation Con~nission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA L.,_ AND GAS CONSERVATION Cd".' ,¢IlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test Re-Entry ~ Deepen~1 Service [] Developement Gas [] Single Zone [] Multiple Zone F_3 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 50', PAD 17'GLfeet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oil Poo P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28307~/'ALK 2317 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC25.025) 1242'FNL, 146'FEL,Sec.24,T11N,R14E,UM(appro;__.,_ ) Prudhoe Be), Unit Statewide At top of productive interval (..~-T'0L¢'O}¢..4-~ 8. Well nu .mber Number 2300'FNL, 700'FEL,Sec.23,T11N,R14E,UM DS 18-17 #8088-26-27 At total depth 9. Approximate spud date Amount 2330'FNL, 866'FEL,Sec.23,T11N,R14E,UM-~ ~ ...~../~c¢cr'/')~'1/:'['- i, l~)<~'7 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Prop_osed depth (MD and TVD) property line 1 1 086 ' MD 866' (~ TD feet 18-3 54' ¢ 1074'MBfeet 2560 8891'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1 000 feet Maximum hole angle 410 Maximum surface 3020 psig At total depth (TVD) 3900 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26" 20" 94# H-40 Weld 80' 33' 33' 113' 113' 200 ft3 Poleset 17-1/2 13-3/8 72#/ L-80 BTC 3263' 33' 33' 3296' 3000' 3000 sx CS III & 68# K-55 (2 jts) 600 sx Class G 12-1/4 9-5/8 47# L-80 TC/BTC~Mod 10~.44' 31' 31' 10275' 8278' 500 sx Class G 8-1/2: /" 29# L-80 BTC 1111 ' 9975' 8052' 11086' 8891 ' 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate ~(~')~/ ~ 0 Production ,.t,! :.,.,e, .... Liner Anc~,0rage Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analYSiS [] Seabed report [] 20 AAC 25.050 requirements [] 21.1 hereby certify tha/,t.t)h~:~_~.going is true and correct to the best of my knowledge/¢,~¢,¢-~_~ Signed "~//~~ Title Regional Drilling Engineer Date/~//'~:~,-- /'A Commission Use Only (GSW) PD2/59 Permit Number PI number I Approval date J See cover letter t~'~'-/ZO/5°--J ;~;I./30/87 J for other requirements Conditions of approval Samples required [] Yes ~Y'['4o Mud Icg required [] Yes Hydrogen sulfide measures [] Yes Eb'Y~No Directional survey required li~"'Yes [] No R equiredwor~/~.,~~SM; 5M; E3 10M; E3 15M Other: by order of Approved by % -~/', ~ ~/~,-.~~-~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 SubZ ;ate DS 18-17 PROPOSED DRILLING PROGRAM 1) MI and RU Rowan 41. 2) NU 20" diverter and function test same. 3) Drill 17-1/2" hole to about 1000'. Kickoff and build angle to 40o51' @ S79°43'W. Drill to 3296'MD/3000'TVD. 4) Set and cement 13-3/8" casing to surface with 3000 sx CS III and 600 sx Class G. 5) NU and test 13-5/8" 5000 WP RSRRA preventer. 6) TIH w/12-1/4" assembly. Test casing to 2000 psi. 7) Drill out float equipment and 10' of new hole. Perform formation test to leak off. 8) Drill 12-1/4" hole to top of Sadlerochit at about 10275'MD. 9) Set and cement 9-5/8" casing with 500 sx Class G. 10) Test casing to 3000 psi and drill out. Perform leak off test. 11) Drill 8-1/2" casing to TD of about 11086'MD. 12) Run open hole logs. 13) Set and cement 7" liner with 300 sx Class G. 14) Clean out cement and test casing and liner to 3000 psi. 15) Displace mud with completion brine and release rig. 16) Run cased hole logs. 17) Complete well with 3-1/2" tubing. 18) Perforate and stimulate as necessary. PD2/59a 11/13/87 NOV 2 0 1987 Oil & Gas Cor~s, ,Anchorage NOTE: a) In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic pack upon the completion of the fluid disposal process. b) Wells within 200' of the proposed well are: DS 18-2 60' @ surface DS 18-3 54' @ 1074 'MD Tract Well 24-11-14 180I @ surface DS 18-19 120' @ surface DS 18-5 95' @ 2634 'MD c) The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. d) Maximum surface pressure is based upon BHP and a full column gas to TD (0.10 psi/ft). e) Based upon previous logs on DS 18, no potential productive zones are anticipated above 5000'TVD. PD2/59a 11/13/87 Depth (TVD) Plas Density Visc. #/~al (CP) Surf 8.8 Funnel to to 100- 13-3/8" 9.2 250 Csg Point 13-3/8" 8.8 Minimum 2 Csg Shoe to Possible to to 9.4 4 K-10 DS 18-17 MUD PROGRAM Yield Point Initial 1OM FL % % #/1 O0 ft2 Gel Gel CC/30M Oi 1 Sol i ds · , 40-60 30+ 50+ 25 2 5 25 to to to 4 10 10 0 8 pH and T~/pe of Mud Gel-Benex Spud Mud 3.5 Low solids/ to non-dispersed 6.5 K-10 9.2 10 6 to TD to to to 9-5/8" 9.8 20 10 Csg Poi nt 4 8 8 to to to 8 12 4 9-5/8" 8.8 10 6 4 8 10 Csg Shoe to to to to to to to TD 9.2 20 10 8 12 4 2 4 pH 9-10 to to Low solids/ 5 8 non-dispersed 2 4 Low solids/ to to non-dispersed 5 8 EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaner and centrifuges PD2/58b ROWAN 41 MUD SYSTEM MIXING PIT #1 MIXING PIT #2 (145 BBLS) (145 BBLS) I PIT #3 PILL PIT PIT #4 SUCTION (60 BBLS) (115 BBLS) (115 BBLS) PIT #5 TRIP TANK INJECTION PIT -r. (145 BBLS) (145 BBLS) O ~ PIT #6 (90 BBLS) ~ PIT #8 c~ (40 BBLS) ~ PIT #7 (90 BBLS) BRANDT DOUBLE-DECKER SHALE SHAKERS (3) DEMCO DESANDER WITH THREE 12" DIAMETER CONES DEMCO DESILTER WITH FOURTEEN 6" DIAMETER CONES DRILCO DEGASSER PIONEER CENTRIFUGE MAIN PUMPS: NATIONAL 12-P-160 (2) GASBUSTER JG 11/10/87 D818-17 0 1000 2000 ~000 4000 5000 6000 7000 8000 ,ooo = ~00 7.5  12.5 ALA,SKA, INC. 22.~) II~&l ~ i IN a iaaa ~1 ;~000 2000 ~ -, 2/.5 12.5 SILL: 1242 ~ 145' ~ L, '37.5 EOC TVB - 24~$ NiD - 2~4 DE ~ -- EBB SEC. 24, 11N, ~14E, UI~ ~L: 2300 FN~ 700' , ~;r 2~ ~-~M a~4~. tJ · 3000 3000 · . {000 I~'.~IA' Q~IHt ~O 130DCI' Mo i3296 B$~ I 992' {000 . , 5000 S000 ~ I~t ~il 41 II1~ ~ ~ I0 Oil I1 Mil 8000 1-10 TVD - $B~8 MD ,. 8460 OEP - 4383 7000 7000 K' 5 ~O I 74411 MD i 0178 )EP, I 483I 8000 ~U ~lZ ' 8108 MD ' 10050 DEF ' ~10 ~ AIVER T~ 'D - 8188 M~ - 101~0 DEl - SHUBUK q VD ' 821~ MD - 1018g DIP ' 5501 g-~ 8' ~$INO TVD -- 8275 ~ ) - 10275 DEP - TOP SA ~L$RO~H~ T'~O - 828B ~ ~ - 10288 Di~P - 5~8 9000 BA, ;E SADLEROC 4IT TVD I ~; 7~ MD I lOGiC OEP 1,6gt I0 ~/7'CSG ~ TVD-18glMD-11(88 DEP-S(87 ~0000 ~0000 ....................................................................... 0 ~000 2000 3000 ~000 5000 6000 VE~TICRL 5~CTION £ - W OOOROINR]~£S -6000 -5000 -4000 -3000 -2000 -tO00 0 !000 r~ Z III1''''' IIIllllll IIIIllll IIIllll J 'iitili lllllll IIIllll - 0518-'~-~' ' / g: ' I . E - ~ OOOROINflTES E - W COOROINFITES -8000 -7000 -6000 -5000 -~:000 -3000 -2000 -lO00 0 lO00 /, '"-~ .......~ ,... ! BS 18.-'t . /77~~t5 ./6986 ~I: .......................... ..... ',,, '~,~[[[5~[~[15 lS-I~ /~2~ /7303~[~3 l: ,.,,",,'a (.., ?,~7 / 7876 Il ~. c',',..'~,.~. ~" /8590 . _ -8000 -7000 -6000 -5000 -'~000 -3000 -2000 - ! 000 0 ! 000 E - N OOOROINflTES ~,~ ~-~ Z Z 0 C~ oo 500 -500 i i iii 10[ 997 O0 C~ OS'i 17 3002 834 9,0O 0 C~ I DS C~ I -600 -5OO -400 -300 E-N -200 OOORB I NR'I'ES -I00 ~8 3574 100 E - W COOROINFITES -600 -500 -,400 -300 -200 - ! O0 0 l O0 D$"l f,.,o ... ~ 106 ~ 1997 2~ 290 ~ O0 ~45 /~ 18=53574 t 3752 . ~3 3921 1~0 / 4UU2 ~. f ~4 4079 i .... ,,, ,, ,,,,, ,'' i i i i i i i i i i ! i i i i i ! 1 i i i i i i i I -600 -500 -400 -300 -200 - 1 O0 0 1 O0 SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I RISER IFLOWLINE I I / 2000 Ps~ / 10" BALL VALVE 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 WELL O ~, O mr- RIG MODULES 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 A¢CYMUI. ATOR CAPACITY TEST_ · I I&NNULAR 1 PREY[NTER PI pi: RAI~ BLI ND RAMS DRILLING SPOOL PI PE RAMS DRLG SPOOL CSG SPOOL 15-3/8" IRTIO HEAD AIL BOP EQUIPMENT 5000 PSI RATED 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. Z. ASSURE THAT ACCUMULATOR PRESSURE IS :5000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. :5. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 12:00 PSI REMAINING PRESSURE. 1~-5/I~' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. Z. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING ,JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUO ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. $. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TES'F AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO $000 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 $ MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST $ MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PI PE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST $ MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PI PE RAMS. BACK OFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST :5 MI NUTES. 1:5.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. 1 ?.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8-26-85 11. 12. ARCO Alaska, Inc.I'" Post Office E~ux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 22, 1987 Mr..C.V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: Conductor As-Built Location Plat - DS 18 (Wells 13, 15, 16, 17) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG'pk GRU1/85 Enclosure If you have OCT 2 6 i Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRtchfieldCompany 17l 13 /8 /9 · 15 ®13 o .z z ¢3 VICINITY MAP NO SCALE .. pg 3-4. WELLS No. 13 15 16 , , LOCATED IN SEC. 19, T.I N.,R.15E.,UMIATMERIDIAN: , [w.,, ,x, 5,960,832.3~[ 692,13~.~7 70° 17' 51.035" 148° 26'38.331" ~045' 371' 12.2 ~;'~ [,~,,o,~.~,,~,o~.~ ~o~,;:~,.,,~.,~,o~,~o,o,,,, ,,,, ,,,, ,,.~ ~,~ /,,~,,,,,.,,[.~.o,,.~ ~oo, ,,.,..,~,~,, .~, .,,,,., WELLNo. 17 LOCATED IN SEC. 24, T. IIN.,RI4E.,UMIAT MERIDIAN. NOTES I. ALL cOoRDINATES ARE A.S.P. ZONE 4. 2.ALL DISTANCES ARE TRUE. 3.ELEVATIONS ARE ARCO DATUM. 4. O.G. ELEVATIONS ARE FROM DWG 60000000 Pt.D- 1745 - 00001 .5. SURVEY BY LOUNSBURY& ASSOC. 9/87. 6. REF FIELD BOOK LPB 87-7'1:~ 33,39,59, I..P887-8 Pod Elev 17.4 17.5 17.6 IWell I 'Y' ASP's 'X' 17 15,960,623.14I 691,67.1.30 LATI,TUDE [ LONGITUDE 70017 49.10~1 148026'53.40~' Dist FNL 1241' Dist FEL 146' O.G. Elev 12.1 Pad Elev 16.2' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LANO SURVEYING IN THE STATE OF ALASKA ANO THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNOER MY SUPERVISION, AND THAT ALL OIMENSIONS ANO OTHER OETAILS ARE CORRECT AS OF 9/9/87. REVISED SECTION LINE OFFSETS O~SCRIPTIOM --.~ o~ a~.. ,~. I ARCO ALASKA, INC. ~ ,~q~,T¥,~-eee®eeee '_h ~ I ~.~- .-' A eee'~l. I Subsidiary of A tlonticRichfieldCompanY ~"' ~ ".:'~ %1 ,,.o.o~ ~c,u~,~ ~o~Ec~- .~o.o~ ,. *' T~ ~.-..~ DRILL SITE No. 18 ~ GeroldL. L ;, : WELLS No. I~ 15,16, ~ 17. L~ 4419 AFE/CC.e. 1541' DATE PJW SCALE DLL 87023 N TS ~o~ o~me ~. PBFG-O000-CEA'1700034 I~T'I O~ I (8) ~~) . (14 za) ..... (2.9 r. nmz 31) ret: 01/28/87 6.0ll IS fha pe_~: fee 2. Is ~ to be locaued iu a a~nad pool ............................. ~. Is ~ locatad proper ~ntanc=_ ~ pr~.~ ?lina .................. 4. is w~]:! ].or. ar. ad p .~ d'inr, z~.c.a ~ other ~!l:~ .................... 5. Is suffi~u undadicauad a~-~_a~e av~l~bia in ~ pool 6. Is well us be daviauad and ,is ~_llbare piau ina!udad ................ 7. Is operator uha only ~Feaued parr7 ................................. 8. Cm~ p~i: be =~. ~u~uced be_form f~ ~aen-day ~mi: ...................... 9. Does 10. Is a conse_~ca~_cn or~]er naedad ...................................... !! Is a~!~-a~Y_v~ a~:rarm,--~-needad 13. .. 25' 26. ~ ~ ~ ~~!~u p~~ ~~ - T~U ~ ~0o0 ps~ .. ~ 27. ~ ~ ~ ~ifold ~ly w/~I ~-53 ~ 84) .................. ~o~ 29. ~ ~ ~~d ~ ~u~~ ~~ z~s? ................. /~ . 30. ~ s~c ~mt~ ~ ~~d ~ s~ll~ ~ z~o~ .... , .....~ ~l. ~ m o~s~ ~c., m ~ ~~ o~ s~ed ~~ ~~~ I.Lb~.u .-! ©/c Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. .o COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 18-17 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292176800 REFERENCE NO : 97510 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/12/16 ORIGIN : FLIC REEL NA~E : 97510 CONTINUATION # : PREVIOUS REEL : COMPIENT : ARCO ALASKA INC, D.S. 18-17, PRUDHOE BAY, 50-029-21768-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/12/16 ORIGIN : FLIC TAPE NAME : 97510 CONTINUATION # : 1 PREVIOUS TAPE : COMS]ENT : ARCO ALASKA INC, D.S. 18-17, PRUDHOE BAY, 50-029-21768-00 TAPE HEADER Prudhoe. Bay CASED HOLE WIRELINE LOGS WELL NAME: D. S. 18-17 API NUMBER: 500292176800 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 16-DEC-97 JOB NUMBER: 97510 LOGGING ENGINEER: John Majcher OPERATOR WITNESS: J. Dethl els SURFACE LOCATION SECTION: 24 TOWNSHIP: 1 iN RANGE: 14E FNL: 1242 FSL: FEL: 146 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 48. O0 DERRICK FLOOR: 45.50 GROUND LEVEL: 17. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 13. 375 3292.0 72. O0 2ND STRING 9. 625 10350.0 47. O0 3RD STRING 7. 000 11222.0 29. O0 PRODUCTION STRING 3. 500 10774.0 9.30 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 24-DEC- 87 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 11136.5 11135.0 11130.0 11129.5 11127.5 11125.5 11122.0 11114.5 11112.5 11108.0 11106.0 11104.5 11101.5 11098.5 11096.5 11095.0 11091 5 11087 0 11086 5 11085 0 11079 0 11077 0 11066.0 11060.5 11056.5 11053.5 11047.5 11041.0 11035.5 11032.5 11028.5 11027.0 11022.0 11021.0 11019.5 11019.0 11016.0 11010.5 11005.0 11004.0 10993.0 10988.0 10986.5 10978.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.5 11137.0 11135.0 11129.0 11125.5 11111.0 11108.5 11105.0 11101.0 11097.0 11094.5 11091.5 11087.0 11085.0 11079.0 11077.0 11066.0 11060.5 11057.5 11054.0 11050.0 11039.5 11034.5 11030.0 11022.0 11020.0 11016.0 11011.5 11004.0 10993.0 10986.5 10978.5 88888.0 11135.0 11129.0 11125.0 11122.5 11112.5 11108.5 11105.5 11094.5 11091.5 11087.0 11085.0 11066.5 11060.5 11057.5 11054.0 11050.0 11039.5 11034.5 11030.0 11022.0 11020.0 11016.0 11011.5 11006.5 10993.0 10986.5 10978.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10970.5 10964.5 10964.0 10956.5 10950.5 10940.5 10938.5 10937.0 10925.0 10923.5 10919.5 10918.0 10914.0 10909.5 10902.5 10900.5 10900.0 10897.0 10888.0 10886.0 10884 0 10878 0 10873 5 10870 0 10867 0 10862 5 10860 0 10852 0 10847.5 10839.5 10829.5 10823.5 10812.5 10807.0 10801.0 10788.5 10788.0 10784.0 10782.5 10777.0 10773.5 10771.0 10766.5 10763.0 10755.5 10753.0 10750.5. 10743.0 10742.5 10731.0 10727.5 10724.0 10720.0 10719.5 10705.5 10704.5 10969.5 10969.5 10965.5 10965.5 10957.0 10957.0 10952.0 10941.5 10941.5 10939.5 10924.0 10919.5 10911.5 10938.5 10925.5 10919.5 10914.5 10905.5 10905.0 10901.0 10901.0 10895.5 10895.5 10888.0 10884.5 10884.5 10882.0 10882.0 10878.5 10878.5 10873.0 10873.0 10870.5 10867.0 10861 5 10859 0 10850.5 10850 5 10844.0 10844 0 10838.5 10838 5 10829.5 10829 5 10822.0 10822 0 10813.5 10813 5 10807.5 10807.5 10798.5 10798.5 10788.5 10788.5 10784.5 10784.5 10779.5 10776.0 10776.0 10772.5 10772.5 10766.0 10766.0 10763.0 10756.0 10756.0 10751.5 10751.5 10743.0 10743.0 10730.5 10730.5 10728.0 10725.5 10725.5 10720.5 10720.5 10706.0 10706.0 I6-DEC-1997 12:08 PAGE: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 10699.5 10697.5 10697.5 10691.0 10692.5 10690.0 10692.5 10683.0 10683.5 10683.5 10680.0 10681.0 10681.0 10670.5 10671.5 10672.0 10666.0 10667.0 10656.5 10657.0 10652.5 10654.0 10654.0 100.0 101.5 101.5 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO ALASKA'S WELL DS 18-17. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN BASE PASS #1 GRCH AND THE BCS GAMblA RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAlatiA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11144.0 10650.0 TDTP 11156.0 10650.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP ............................ $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: REMARKS: THIS FILE CONTAINS TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** N~.'IE SERV UNIT SERVICE API API API API FILE I~EIMB 31'r.~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 1 1 I 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 1 1 I 4 68 0000000000 TCANTDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELD CODE (HEX) TSCF TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1094403 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 11160 000 -999 250 -999 250 -999 250 -999 250 -999 250 DEPT. 10640.000 SBHN. TDTP -999.250 SDSI. TDTP -999. 250 TCAF. TDTP -999. 250 TSCF. TDTP -999. 250 TENS. TDTP -999.250 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCND. TDTP -999. 250 TCFD. TDTP -999.250 TSCN. TDTP INND. TDTP -999. 250 INFD. TDTP -999.250 GRCH. TDTP CCL.TDTP -999.250 GR.BCS 100.323 -999.250 -999.250 -999.250 -999.250 -999.250 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 INND. TDTP -999.250 INFD, TDTP -999.250 GRCH. TDTP -999.250 CCL. TDTP -999. 250 GR. BCS 21.196 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11145.0 10650.0 TDTP 11158.0 10650.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88887.5 11151.5 11151.0 11146.5 11146.5 11135.5 11135.0 11135.0 11135.0 11132.0 11132.0 11131.0 11130.0 11129.0 11128.5 11122.5 11122.0 11116.5 11116.0 11114.5 11113.0 11112.0 11111.0 11108.5 11108.5 11108.0 11108.0 11105.0 11106.0 11103.5 11102.0 11096.0 11095.0 11095.0 11094.0 11092.0 11091.5 11091.0 11091.0 11088.5 11088.5 11088.5 11085.5 11085.0 11084.5 11084.5 11081.0 11079.5 11070.0 11071.0 11066.0 11066.0 11063.0 11062.0 11061.0 11060.5 11056.0 11057.5 11056.5 11054.0 11054.0 11053.0 11053.5 11048.0 11050.0 11046.5 11049.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 11040.0 11042.0 11037.5 11037.5 11033.0 11032.5 11032.5 11030.5 11025.0 11024.5 11021.5 11022.5 11019.5 11020.0 11017.5 11019.0 11015.5 11016.0 11013.5 11013.5 11010.5 11011.5 11006.0 11006.5 11005.5 11007.0 10993.5 10994.5 10990.5 10993.0 10985.5 10987.0 10983.5 10982.5 10979.0 10978.5 10977.5 10978.0 10973.0 10974.5 10970.0 10969.5 10968.5 10968.0 10964.5 10965.0 10958.0 10955.5 10950.0 10952.0 10942.0 10942.0 10941.0 10941.5 10937.0 10938.5 10928.5 10927.5 10925.0 10925.5 10917.5 10918.0 10917.5 10916.0 10914.5 10910.5 10911.5 10906.5 10908.5 10903.5 10905.5 10900.5 10901.0 10900.0 10900.5 10897.5 10895.5 10896.0 10895.0 10893.0 10891.0 10889.5 10888.0 10884.5 10884.5 10880.5 10880.5 10873.5 10873.0 10863.5 10861.5 10861.0 10860.0, 10860.0 10859.5 10855.0 10852.5 10846.5 10843.5 10844.5 10844.5 10840.5 10839.0 10837.0 10835.0 10836.0 10838.5 10833.5 10832.5 10830.5 10829.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 10822.0 10821.0 10818.0 10817.0 10809.0 10806.5 10801.0 10799.5 10797.5 10790.0 10787.5 10786.0 10784.5 10780.0 10778.0 10773.5 10773.0 10771.0 10769.0 10768.5 10767.5 10765.5 10762.0 10758.5 10756.5 10753.0 10750.0 10742.5 10737.0 10733.5 10729 5 10727 5 10720 5 10720 0 10718 0 10708 0 10706.0 10705.0 10700.0 10694.5 10693.5 10691.5 10690.5 10681.0 10680.0 10674.5 10673.0 10668.5 10657.5 10653.0 10651.5 100.0 $ 10822.5 10818.5 10809.0 10798.5 10796.0 10787.0 10784.5 10776.5 10770.0 10746.5 10763.5 10758.0 10756.0 10751.5 10738.0 10735.5 10730.5 10720.5 10717.0 10709.5 10706.0 10697.5 10694.0 10692.5 10681.0 10675.0 10654.0 101.0 10821.0 10816.5 10806.5 10799.0 10796.0 10789.5 10788.0 10779.5 10777.5 10775.5 10772.0 10769.0 10765.5 10759.5 10743.0 10728.0 10720.5 10706.0 10694.0 10692.5 10681.0 10674.0 10669.5 10657.0 10653.0 101.5 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 10 DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1094403 O0 000 O0 0 2 1 I 4 68 0000000000 SIGC TDTP CU 1094403 O0 000 .00 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TSCN TDTP CPS 1094403 TSCF TDTP CPS 1094403 INND TDTP CPS 1094403 INFD TDTP CPS 1094403 GRCH TDTP GAPI 1094403 TENS TDTP LB 1094403 CCL TDTP V 1094403 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11157. 500 SIGM. TDTP 17. 519 TPHI. TDTP 35. 788 SBHF. TDTP SBHN. TDTP 48.246 SIGC. TDTP 2. 367 SIBH. TDTP 55. 638 TRAT. TDTP SDSI. TDTP O. 409 BACK. TDTP 202. 415 FBAC. TDTP 54. 362 TCAN. TDTP TCAF. TDTP 13014.561 TCND. TDTP 22437. 813 TCFD. TDTP 6643. 661 TSCN. TDTP TSCF. TDTP 2379. 029 INND. TDTP 2543 . 881 INFD. TDTP 426. 483 GRCH. TDTP TENS. TDTP 1390. 000 CCL. TDTP O. 000 DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 10651 000 -999 250 -999 250 -999 250 -999 250 -999 250 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP CCL. TDTP -999. 250 44.784 1.901 35840.078 6254.939 -999.250 -999.250 -999.250 -999.250 -999.250 45.469 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 12 FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11145.0 10650.0 TDTP 11158.0 10650.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11151.0 11146.0 11141.0 11135.0 11134.5 11131.0 11127.5 11125.5 11121.5 11121.0 11113.5 11111.5 11108.0 11107.5 11096.0 11094.0 11091.5 11090.5 11088.0 11086.5 11086.0 11084 5 11076 5 11070 0 11069 5 11065 5 11059 5 11053 5 11047 5 11046.5 11036.5 11033.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.5 88889.0 11135.0 11126.0 11123.5 11121.0 11111.0 11108.5 11094.5 11091.5 11088.5 11087.0 11069.5 11066.0 11060.5 11054.0 11050.0 11036.5 11034.5 11152.0 11146.5 11141.5 11135.5 11130.5 11125.5 11122.5 11113.0 11108.5 11093.5 11091.0 11087.0 11084.5 11079.5 11070.5 11055.0 11049.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 13 11030.5 11025.0 11021.0 11018.5 11017.0 11016.0 11012.5 11010.5 11006.0 11005.5 10994.0 10988.0 10985.0 10982.5 10982 0 10978 0 10972 5 10967 5 10962 5 10959 0 10949.5 10947.0 10941.5 10938.5 10936.5 10926.0 10925.0 10918.0 10916.5 10914.5 10912.0 10906.0 10905.5 10899.5 10896.5 10896.0 10887.0 10879.5 10879.0 10877.5 10873.0 10872.5 10860.0 10859.5 10849.0 10845.0 10844.0 10837.5 10835.0 10829.5 10828.0 10823.5 10816.0 10815.5 10809.0 11025.0 11020.0 11018.0 11016.0 11011.5 11006.5 10987.0 10978.5 10969.5 10947.5 10941.5 10927.0 10925.5 10919.5 10917.0 10907.0 10901.5 10895.5 10881.0 10878.5 10873.0 10859.5 10851.5 10844.0 10838.0 10829.0 10822.5 10813.5 10807.5 11031.0 11019.5 11014.0 11006.5 10994.0 10986.5 10982.5 10978.0 10968.0 10965.5 10960.5 10951.5 10942.5 10938.0 10917.5 10913.0 10908.0 10901.0 10895.0 10886.0 10880.5 10872.5 10859.5 10843.5 10835.0 10828.0 10816.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 14 10806.0 10800.5 10797.0 10792.5 10791.0 10786.5 10784.0 10780.0 10773.0 10768.5 10768.0 10765.5 10761.0 10759.0 10757.0 10751.5 10751.0 10748.5 10746.0 10742.0 10738.0 10732.5 10730.5 10727.0 10724.0 10720.5 10719.0 10717.5 10716.5 10714 0 10709 5 10707 5 10704 0 10698 0 10695 0 10692 5 10692 0 10690 0 10686.0 10685.5 10679.5 10673.0 10672.0 10668.5 10668.0 10665.5 10656.5 10652.5 10651.5 100.0 $ REMARKS: 10798.5 10792.5 10791.0 10784.5 10776.0 10769.5 10763.0 10759.0 10751.5 10747.5 10736.0 10730.5 10721.0 10716.0 10709.5 10696.5 10694.0 10692.5 10683.5 10675.0 10669.5 10654.0 101.5 10806.0 10796.0 10788.0 10780.0 10769.5 10765.5 10760.0 10752.0 10747.0 10743.0 10730.5 10728.0 10725.5 10720.5 10718.0 10715.5 10709.0 10706.5 10694.0 10692.5 10688.5 10681.0 10674.0 10669.5 10667.0 10657.0 10653.5 102.0 THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 15 BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELi~I CODE (HEX) DEPT FT 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INND TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1094403 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11159.000 SIGM. TDTP 20.847 TPHI.TDTP 36.508 SBHF. TDTP 39.037 SBHN. TDTP 45.384 SIGC. TDTP 3.718 SIBH. TDTP 49.144 TRAT. TDTP 1.853 SDSI. TDTP 0.765 BACK. TDTP 250.931 FBAC. TDTP 61.021 TCAN. TDTP 33393.953 TCAF. TDTP 11167. 627 TCND. TDTP 20103. 074 TCFD. TDTP 5725. 689 TSCN. TDTP 4582. 927 TSCF. TDTP 1688.762 INND. TDTP 2438.230 INFD. TDTP 427.401 GRCH. TDTP -999.250 TENS. TDTP 1400. 000 CCL. TDTP O. 000 DEPT. 10651.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD.TDTP -999.250 GRCH. TDTP 53.938 TENS. TDTP -999. 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 17 FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11145.0 10650.0 TDTP 11158.0 10650.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11146.0 11134.5 11134.0 11131.5 11115.0 11112.5 11109.0 11108.0 11105.5 11105.0 11092.0 11087.5 11086.5 11080 0 11065 5 11060 5 11059 0 11056 5 11053 5 11048 5 11041 5 11040 5 11034 5 11032 5 11024 0 11016 5 11012 5 11011 0 10995 0 10983 0 10982 0 10973 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88889.0 88888.5 11135.0 11132.0 11111.0 11108.0 11105.0 11091.5 11086.5 11079.0 11066.0 11060.5 11054.5 11050.0 11039.5 11034.5 11022.5 11016.0 11011.5 10994.5 10981.0 10969.5 11146.5 11134.5 11130.0 11113.0 11108.0 11106.0 11091.5 11087.0 11079.0 11067.0 11061.0 11054.5 11049.0 11039.5 11034.5 11031.5 11022.5 11016.0 11011.5 10980.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 18 10972.0 10966.0 10960.0 10958.5 10948.5 10945.0 10943.5 10941.5 10940.5 10934.0 10925.5 10925.0 10917.0 10910.0 10908.5 10900.5 10900.0 10893.5 10893.0 10888.5 10880.5 10878.0 10877.0 10873.5 10873.0 10870.5 10860.0 10859.0 10855.0 10851.0 10846.5 10840.0 10836.0 10835 0 10820 5 10812 5 10808 0 10804 5 10797 0 10795 0 10786.5 10785.0 10769.5 10769.0 10762.5 .10759.0 10758.5 10755.0 10752.0 10744.5 10744.0 10735.0 10730.0 10729.0 10724.5 10967.5 10957.0 10942.0 10940.0 10932.5 10925.5 10911.5 10901.0 10895.5 10889.5 10878.5 10876.5 10872.5 10861.0 10852.0 10838.0 10822.5 10813.5 10809.5 10805.5 10796.0 10787.5 10770.0 10764.0 10759.0 10755.5 10751.5 10744.5 10730.5 10965.5 10957.0 10952.0 10948.0 10942.0 10936.0 10926.5 10917.0 10910.5 10901.0 10894.5 10889.5 10880.5 10878.5 10872.5 10860.0 10853.0 10844.0 10839.0 10835.5 10813.0 10806.5 10796.5 10788.0 10769.0 10762.5 10759.0 10755.5 10751.5 10745.0 10735.5 10731.0 10725.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 19 10720.0 10720.5 10719.5 10720.5 10716.5 10717.0 10715.5 10716.0 10705.5 10706.0 10704.5 10706.0 10702.5 10703.5 10703.5 10697.0 10697.5 10697.5 10693.0 10694.0 10694.0 10690.5 10692.5 10684.5 10683.5 10681.0 10681.0 10680.0 10681.0 10671.0 10671.5 10670.5 10671.5 10665.0 10663.5 10657.5 10657.5 10656.0 10658.0 10652.5 10654.0 10652.0 10653.0 100.0 101.5 101.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE 2O TYPE REPR CODE VALUE 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELE~ CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT 1094403 SIGM TDTP CU 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 1094403 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11158.500 SIGM. TDTP 28.256 TPHI.TDTP 55.545 SBHF. TDTP 42.159 SBHN. TDTP 47. 251 SIGC. TDTP 2.180 SIBH. TDTP 53. 380 TRAT. TDTP 2. 025 SDSI. TDTP 1 . 033 BACK. TDTP 235. 261 FBAC. TDTP 55. 986 TCAN. TDTP 28432. 340 TCAF. TDTP 8141 . 301 TCND. TDTP 19003. 453 TCFD. TDTP 4938. 677 TSCN. TDTP 3 613. 345 TSCF. TDTP 1063. 207 INND. TDTP 2397. O17 INFD. TDTP 423. 386 GRCH. TDTP - 999. 250 TENS. TDTP 1440. 000 CCL. TDTP O. 000 DEPT. 10651 . 000 SIGM. TDTP 17. 693 TPHI. TDTP 24. 087 SBHF. TDTP 49. 949 SBHN. TDTP 59.813 SIGC. TDTP 1.516 SIBH. TDTP 77.919 TRAT. TDTP 1.510 SDSI.TDTP 0.669 BACK. TDTP 244.565 FBAC. TDTP 52.247 TCAN. TDTP 22194.426 TCAF. TDTP 10536.379 TCND. TDTP 18306.227 TCFD. TDTP 6703.541 TSCN. TDTP 5069.955 TSCF. TDTP 2406. 864 INND. TDTP 2771 . 181 INFD. TDTP 530. 619 GRCH. TDTP -999. 250 TENS. TDTP 1385. 000 CCL. TDTP O. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PA GE: 21 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMFL~RY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11145.0 10650.0 TDTP 11158.0 10650.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88889.0 88888.0 11156.0 11156.0 11152.0 11151.5 11146.5 11146.5 11141.5 11142.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 22 11136.5 11134.5 11131.0 11128.5 11121.5 11114.0 11112.0 11108.0 11105.0 11096.0 11091.5 11091.0 11088.5 11087.5 11079.5 11075.5 11070.5 11068.0 11062.5 11060.5 11057.5 11057.0 11056.0 11051.0 11050.0 11049.0 11041.5 11037 5 11034 0 11032 5 11024 0 11023 5 11018 0 11016.0 11012.5 11010.0 11007.5 11007.0 11000.5 10991.0 10982.0 10978.5 10975.5 10967.0 10966.5 10960.5 10948.0 10947.0 10944.5 10941.5 10936.5 10925.0 10916.5 10905.0 10903.0 11137.5 11135.0 11129.0 11111.0 11108.5 11094.5 11091.5 11087.0 11079.0 11071.5 11068.5 11060.5 11056.0 11054.0 11051.0 11034.5 11022.5 11018.0 11016.5 11011.5 11008.0 11002.5 10993.0 10978.5 10966.5 10948.0 10945.5 10925.5 10905.5 11130.0 11122.0 11113.0 11106.0 11091.0 11089.0 11075.5 11064.0 11058.0 11054.0 11049.5 11040.0 11037.5 11031.5 11024.5 11012.0 11005.5 10989.5 10979.5 10972.0 10965.5 10960.5 10950.0 10942.5 10938.5 10917.0 10906.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 23 10900.0 10901.0 10899.5 10901.0 10895.0 10895.5 10883.5 10884.0 10881.0 10881.0 10879.0 10881.0 10877.0 10878.0 10875.5 10876.5 10874.5 10874.5 10873.0 10873.0 10860.5 10860.0 10860.0 10860.0 10857.0 10856.5 10852.0 10852.0 10849.0 10846.5 10839.5 10839.0 10838.0 10838.0 10830.0 10829.5 10829.5 10829.0 10825.5 10824.5 10812.5 10813.0 10811.0 10809.5 10806.5 10806.0 10804.5 10803.5 10802.0 10801.0 10795.5 10796.5 10786.5 10787.5 10783.5 10784.5 10780.5 10781.0 10769.0 10770.0 10769.5 10766.5 10766.5 10761.5 10763.0 10758.5 10759.5 10756.5 10756.0 10751.0 10751.0 10749.0 10749.0 10745.0 10745.0 10743.5 10744.5 10742.0 10743.0 10732.5 10730.5 10727.5 10728.0 10726.0 10725.0 10724.5 10725.5 10720.0 10720.5 10719.5 10720.5 10708.0 10710.0 10705.5 10706.0 10699.0 10700.0 10696.5 10697.5 10693.5 10694.0 10690.5 10692.5 10686.5 10688.0 10684.0 10683.5 10680.0 10681.0 10672.5 10674.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 24 10670.5 10671.5 10668.0 10669.5 10657.5 10657.0 10657.0 10658.0 10652.5 10654.0 10652.0 10653.0 100.0 101.5 I01.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS ~2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SIGCTDTP CU 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 1094403 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 11158 000 48 358 0 731 9908 871 1442 328 1425 000 SIGM. TDTP 22.098 TPHI.TDTP 46.719 SBHF. TDTP 42.317 SIGC. TDTP 3. 265 SIBH. TDTP 55. 891 TRAT. TDTP 1. 999 BACK. TDTP 255. 409 FBAC. TDTP 55. 786 TCAN. TDTP 32194. 996 TCND. TDTP 20156. 887 TCFD. TDTP 5362. 671 TSCN. TDTP 4345. 702 INND. TDTP 2337. 977 INFD. TDTP 398. 995 GRCH. TDTP -999. 250 CCL. TDTP O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 26 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SU~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11145.0 10628.0 TDTP 11158.0 10628.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11147.5 11143.0 11135.5 11133.0 11132.0 11129.0 11126.5 11114.5 11113.0 11109.5 11106.5 11095.5 11093.0 11092.0 11088.0 11079.0 11072.0 11071.0 11066.0 11065.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.0 88887.0 11132.0 11126.0 11111.0 11108.5 11094.5 11091.5 11087.0 11079.0 11071.5 11064.0 11146.5 11143.0 11134.5 11130.5 11124.0 11113.0 11108.0 11106.0 11091.0 11070.5 11067.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 27 11063.5 11064.0 11061.0 11060.5 11057.5 11057.5 11054.0 11054.0 11054.0 11049.0 11049.5 11041.0 11039.5 11038.5 11037.5 11036.0 11034.5 11035.5 11034.5 11028.5 11027.5 11022.5 11021.5 11016.5 11013.5 11013.5 11011.5 11011.5 11011.0 11006.5 11005.5 11004.0 11004.0 11003.0 11001.5 10998.0 10995.5 10993.5 10992.5 10991.0 10989.5 10986.0 10983.0 10982.5 10980.0 10981.0 10980.0 10976.5 10972.0 10970.0 10971.5 10968.0 10965.5 10961.0 10960.0 10949.0 10951.5 10947.5 10947.5 10942.5 10942.5 10937.5 10937.5 10931.0 10931.0 10921.0 10922.5 10919.0 10917.5 10914.0 10915.5 10904.0 10905.5 10901.0 10901.0 10901.0 10895.0 10895.5 10892.5 10892.5 10880.5 10881.0 10880.5 10875.0 10873.5 10862.5 10861.5 10860.5 10860.0 10855.5 10853.5 10853.0 10852.5 10846.5 10844.5 10841.5 10839.0 10839.0 10838.5 10837.5 10836.0 10830.5 10829.0 10826.5 10826.0 10825.5 10822.5 10808.0 10807.5 10807.0 10806.5 10803.0 10801.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 28 10800.0 10798.5 10798.0 10796.0 10791.0 10791.0 10788.0 10788.0 10785.0 10784.5 10773.0 10772.0 10770.0 10770.0 10769.5 10769.0 10767.5 10766.5 10762.5 10763.5 10759.5 10759.0 10756.0 10756.0 10752.5 10751.5 10746.0 10745.0 10743.0 10743.0 10729.5 10730.5 10728.5 10728.0 10724.0 10725.0 10721.0 10720.5 10720.5 10720.5 10718.5 10716.5 10717.0 10716.5 10709.5 10710.5 10709.0 10709.0 10707.0 10706.0 10701.5 10701.0 10691.5 10692.5 10692.5 10687.0 10688.5 10681.0 10681.0 10679.0 10679.5 10675.5 10677.0 10673.0 10674.0 10671.5 10671.5 10669.0 10669.0 10668.5 10668.5 10661.5 10663.5 10657.0 10657.0 10656.5 10658.0 10653.5 10654.0 10653.5 100.0 100.5 100.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 29 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN TDTP CU 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TCANTDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 1094403 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 3O ** DATA ** DEPT. 11157.000 SIGM. TDTP 15.706 TPHI.TDTP 36.304 SBHF. TDTP 31.603 SBHN. TDTP 50.554 SIGC. TDTP 1.860 SIBH. TDTP 60.873 TRAT. TDTP 1.956 SDSI.TDTP 0.448 BACK. TDTP 262.677 FBAC. TDTP 58.386 TCAN. TDTP 29746.051 TCAF. TDTP 11096.125 TCND. TDTP 23657.613 TCFD. TDTP 7097.339 TSCN. TDTP 6915.519 TSCF. TDTP 2579.685 INND. TDTP 2463.311 INFD. TDTP 409.902 GRCH. TDTP -999.250 TENS. TDTP 1440.000 CCL.TDTP 0.000 DEPT. 10640. 000 SIGM. TDTP 11 . 603 TPHI. TDTP 10. 597 SBHF. TDTP 53. 612 SBHN. TDTP 67. 772 SIGC. TDTP O. 424 SIBH. TDTP 84. 043 TRAT. TDTP 1 . 205 SDSI. TDTP 0.283 BACK. TDTP 261 . 568 FBAC. TDTP 60.115 TCAN. TDTP 36948. 359 TCAF. TDTP 24831 . 719 TCND. TDTP 22785. 418 TCFD. TDTP 11872. 723 TSCN. TDTP 8899.193 TSCF. TDTP 5980. 842 INND. TDTP 2697. 507 INFD. TDTP 601 . 984 GRCH. TDTP - 999. 250 TENS. TDTP 1355. 000 CCL. TDTP 0. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 7 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH ......................... GRCH 11145.0 TDTP 11158.0 STOP DEPTH 10650.0 10650.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 31 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11146.5 11141.5 11135.0 11131.0 11127.0 11126.0 11122.0 11114.5 11111.5 11108.5 11105.5 11105.0 11096.0 11092.0 11091.0 11088.0 11087.0 11084.0 11071.5 11060.0 11054.0 11053.5 11047.5 11047.0 11034.5 11028.0 11022.5 11021.0 11015.5 11012.5 11011.0 11008.5 11005.0 11003.0 10994.5 10986.0 10985.5 10979.5 10976.0 10973.5 10967.5 10964.0 10954.0 10945.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.0 88888.5 11147.0 11142.5 11135.0 11130.0 11125.5 11125.0 11122.0 11113.5 11111.0 11108.5 11105.0 11106.0 11095.0 11091.5 11091.0 11088.5 11087.0 11084.5 11071.0 11060.5 11060.5 11056.0 11054.0 11049.5 11050.0 11037.5 11030.5 11022.5 11022.0 11016.0 11013.5 11011.5 11011.5 11006.5 11004.0 10994.5 10986.0 10987.0 10980.0 10978.5 10975.0 10967.5 10965.5 10955.5 10948.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 32 10943.5 10942.0 10941.5 10936.5 10928.0 10925.0 10917.0 10914.5 10909.5 10908.0 10907.0 10903.0 10900.0 10899.5 10896.5 10895.5 10890.0 10889.5 10883.0 1O88O.O 10874.5 10872.0 10867.5 10861.5 10859.0 10853.5 10846.5 10843.0 10835.0 10833.0 10829 0 10822 0 10809 5 10808 0 10807 5 10797 5 10795 0 10786.0 10784 0 10780 0 10774 0 10769 0 10767 5 10765 5 10758 5 10753 0 10747 5 10745 0 10743 0 10742 5 10729 5 10728 0 10726.0 10724.5 10720.0 10943.0 10931.0 10919.5 10911.5 10905.5 10901.0 10895.5 10889.0 10881.0 10873.0 10867.0 10861.0 10852.0 10844.0 10835.0 10809.5 10807.5 10796.0 10784.5 10776.0 10769.5 10766.5 10752.0 10747.5 10743.0 10731.0 10725.0 10720.5 10945.0 10942.0 10938.5 10926.0 10917.5 10911.0 10908.5 10901.0 10896.0 10888.5 10882.5 10880.5 10874.0 10858.5 10843.5 10833.0 10829.0 10820.5 10806.5 10796.0 10788.0 10780.0 10769.0 10765.5 10759.0 10745.0 10743.0 10728.0 10725.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 33 10719.5 10720.5 10717.0 10717.5 10716.0 10716.0 10710.0 10709.5 10709.0 10709.0 10705.0 10706.0 10699.5 10697.0 10699.0 10697.5 10693.5 10694.0 10692.5 10690.5 10690.5 10692.5 10688.0 10688.0 10686.5 10683.5 10682.0 10681.0 10680.0 10681.0 10671.0 10671.5 10668.5 10670.0 10669.5 10657.0 10657.0 10654.0 10654.0 10652.5 10653.0 100.0 100.0 100.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP FLOWING PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 34 TYPE REPR CODE VALUE 16 66 1 0 66 I ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM TDTP CU 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN TDTP CU 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC TDTP CU 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 INND TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 INFD TDTP CPS 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 TENS TDTP LB 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 CCL TDTP V 1094403 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11158. 500 SIGM. TDTP 17. 094 TPHI. TDTP 36. 543 SBHF. TDTP SBHN. TDTP 44. 701 SIGC. TDTP 2. 731 SIBH. TDTP 47. 594 TRAT. TDTP SDSI. TDTP O. 504 BACK. TDTP 38. 636 FBAC. TDTP 11.291 TCAN. TDTP TCAF. TDTP 12103. O14 TCND. TDTP 23024. 703 TCFD. TDTP 6614. 435 TSCN. TDTP TSCF. TDTP 2265.303 INND. TDTP 2784.265 INFD. TDTP 422.161 GRCH. TDTP TENS. TDTP 1365. 000 CCL. TDTP O. 000 40.659 1.980 35574.219 6265.953 -999.250 DEPT. 10650. 000 SIGM. TDTP -999. 250 TPHI. TDTP -999.250 SBHF. TDTP - 999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999,250 GRCH. TDTP 19. 625 TENS. TDTP -999. 250 CCL. TDTP -999. 250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 35 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 8 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 8 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11145.0 10645.0 TDTP 11158.0 10645.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88886.5 88887.5 11147.0 11146.5 11141.5 11142.0 11136.5 11135.0 11135.0 11135.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 36 11132.5 11126.5 11122.5 11122.0 11115.0 11110.5 11108.5 11106.5 11104.5 11094.5 11092.0 11091.0 11089.0 11086.5 11086.0 11080.5 11079.5 11071.0 11065.0 11060.5 11055.5 11053 5 11052 5 11048 0 11047 0 11044 5 11035 0 11031.0 11029.5 11025.0 11021.5 11019.5 11015.5 11013.0 11010.0 11005.5 11005.0 11003.0 10996.5 10994.0 10986.0 10979.0 10974.0 10970.5 10967.5 10964.5 10958.5 10956.5 10954.0 10946.5 10941.5 10938.5 10937.0 10925.0 10917.5 11121.0 11111.0 11108.5 11105.0 11094.5 11091.5 11088.5 11085.0 11079.0 11066.0 11060.5 11057.5 11054.0 11050.0 11030.0 11025.0 11020.5 11016.0 11011.5 11006.5 11004.0 10994.5 10978.5 10969.5 10965.5 10959.0 10948.0 10940.0 10925.5 11131.5 11125.0 11122.0 11113.0 11105.0 11091.0 11087.0 11082.0 11071.0 11054.5 11049.5 11045.5 11037.5 11030.5 11022.0 11013.5 11006.5 10994.0 10986.0 10975.0 10968.0 10957.0 10952.0 10942.0 10938.5 10917.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 37 10911.5 10911.5 10910.0 10911.0 10903.0 10905.5 10906.0 10900.0 10901.0 10901.0 10896.5 10895.5 10895.0 10892.0 10894.0 10889.5 10888.0 10886.0 10885.5 10883.5 10884.5 10880.0 10880.5 10879.5 10881.0 10877.5 10878.5 10873.0 10873.0 10871.0 10872.0 10859.5 10859.5 10858.5 10858.0 10855.0 10853.0 10853.0 10852.5 10846.0 10843.5 10840.5 10839.0 10837.5 10838.5 10836.0 10835.0 10827.5 10827.5 10825.5 10825.5 10820.5 10820.5 10816.0 10814.0 10816.5 10808.5 10806.0 10807.5 10806.0 10801.5 10800.0 10798.0 10796.5 10796.0 10787.0 10788.0 10782.5 10781.0 10780.0 10780.0 10776.0 10776.0 10775.5 10776.0 10769.0 10769.5 10769.0 10765.5 10765.5 10763.0 10763.5 10762.5 10762.0 10759.5 10759.5 10751.0 10751.5 10747.5 10746.5 10743.0 10743.0 10735.0 10736.0 10731.0 10731.0 10729.0 10730.5 10728.0 10728.0 10725.5 10725.0 10720.5 10720.5 10720.0 10720.5 10715.5 10716.0 10709.5 10709.5 10705.0 10706.5 10704.5 10706.0 10694.0 10696.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 38 10691.5 10692.5 10686.5 10689.0 10683.5 10683.5 10680.5 10681.0 10674.0 10673.0 10673.5 10673.5 10671.0 10671.5 10668.5 10669.0 10657.0 10657.0 10653.5 10654.0 10652.5 10653.0 100.0 100.5 100.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP FLOWING PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 39 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM TDTP CU 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI TDTP PU-S 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF TDTP CU 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 SBHNTDTP CU 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC TDTP CU 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH TDTP CU 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT TDTP 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI TDTP CU 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TCAN TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TCND TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 INND TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 INFD TDTP CPS 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 TENS TDTP LB 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 CCL TDTP V 1094403 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11157 SBHN. TDTP 48 SDSI. TDTP 0 TCAF. TDTP 12435 TSCF. TDTP 2188 TENS. TDTP 1380 DEPT. 10645 SBHN. TDTP 50 SDSI. TDTP 0 TCAF. TDTP 20375 TSCF. TDTP 5080 TENS. TDTP 1390 500 SIGM. TDTP 18. 556 TPHI. TDTP 39. 747 SBHF. TDTP 560 SIGC. TDTP 2. 359 SIBH. TDTP 56. 349 TRAT. TDTP 539 BACK. TDTP 190. 958 FBAC. TDTP 61 . 672 TCAN. TDTP 400 TCND. TDTP 22289. 797 TCFD. TDTP 6435. O14 TSCN. TDTP 758 INND. TDTP 2652. 396 INFD. TDTP 403.195 GRCH. TDTP 000 CCL. TDTP O. 000 500 SIGM. TDTP 15.220 TPHI. TDTP 13. 851 SBHF. TDTP 853 SIGC. TDTP 1 . 201 SIBH. TDTP 57. 303 TRAT. TDTP 389 BACK. TDTP 274. 391 FBAC. TDTP 71. 444 TCAN. TDTP 438 TCND. TDTP 27496.516 TCFD. TDTP 12285.881 TSCN. TDTP 275 INND. TDTP 3505. 492 INFD. TDTP 835. 405 GRCH. TDTP 000 CCL. TDTP O. 000 41.523 1.957 36558.391 6072.785 -999.250 40.704 1.307 35138.781 8761.268 23.203 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 40 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 9 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, TDTP $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1,2, & 3 OF THE TDTP TOOL. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 41 TYPE RBPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PNAV CU 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PNAV PU-S 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PNAV CU 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 SBHN PNAV CU 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PNAV CU 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PNAV CU 1094403 O0 000 O0 0 9 I 1 4 68 0000000000 TRAT PNAV 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PNAV CU 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 BACK TDTP CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC TDTP CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 INND PNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PNAV CPS 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 GRCH TDTP GAPI 1094403 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11156.000 SIGM. PNAV 14.436 TPHI.PNAV 30.604 SBHF. PNAV 40.482 SBHN. PNAV 48.598 SIGC. PNAV 1.609 SIBH. PNAV 55.938 TRAT. PNAV 1.869 SDSI.PNAV 0.374 BACK. TDTP 111.458 FBAC. TDTP 28.745 TCAN. PNAV 35367.359 TCAF. PNAV 14011.758 TCND. PNAV 25032.762 TCFD.PNAV 7792.233 TSCN. PNAV 7721.993 TSCF. PNAV 3059.430 INND. PNAV 2670.018 INFD.PNAV 450.582 GRCH. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 42 DEPT. 10651.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 177.205 FBAC. TDTP 42.974 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 33.906 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... TDTP 11180.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 10650.0 14-SEP-97 CP 44.2 1044 14-SEP-97 11174.0 11170.0 10650.0 11165.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 43 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS 862 TDIC 816 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 3292.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Crude 45.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS : BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP 20 CRUDE, LOG BASE PASS 2 PUMP 19 CRUDE, LOG BASE PASS 3 PUMP 185 BORAX PUMP 25 CRUDE, LOG BORAX PASS #1. PUMP 21 CRUDE, LOG BORAX PASS #2. PUMP 20 CRUDE, LOG BORAX PASS #3. THIS FILE CONTAINS THE RAW DATA FOR BASE LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 44 PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS1 CU 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS1 PU 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS1 CU 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 SBHN PS1 CU 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS1 CU 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS1 CU 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS1 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS1 CU 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TCNDPS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PA GE: 45 NAFIE SERV UNIT SERVICE API API API API FILE NUM~ NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) ....................................................................................... INFD PS1 CPS 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS1 LB 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS1 GAPI 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS1 V 1094403 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 11160.000 SIGM. PS1 36.167 TPHI.PS1 45.700 SBHF. PS1 SBHN. PS1 48.390 SIGC. PS1 2.908 SIBH. PS1 55.963 TRAT. PS1 SDSI.PS1 1.322 BACK. PSi 132.131 FBAC. PS1 38.372 TCAN. PS1 TCAF. PS1 6695.876 TCND.PS1 17800.555 TCFD. PS1 4633.151 TSCN. PS1 TSCF. PS1 765.171 INND.PS1 2788.586 INFD.PS1 419.441 TENS.PSi GR.PS1 23.188 CCL.PS1 0.000 DEPT. 10649 SBHN. PS1 53 SDSI.PS1 0 TCAF. PS1 12725 TSCF. PS1 2851 GR. PS1 30 000 SIGM. PS1 18.651 TPHI.PS1 27.288 SBHF. PS1 582 SIGC. PS1 0.901 SIBH. PS1 65.473 TRAT. PS1 476 BACK. PSI 178.637 FBAC. PS1 42.858 TCAN. PS1 816 TCND.PS1 22832.598 TCFD.PS1 7986.218 TSCN. PS1 997 INND. PS1 2893.912 INFD.PS1 585.953 TENS.PSi 359 CCL.PS1 0.000 45.372 1. 636 22339.117 2340. 080 1430.000 45.275 1.603 28583.684 6405.921 1345.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 46 FILE AU3M~ER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INC~: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11183.0 10649.0 TDTP $ LOG HEADER DATA DATE LOGGED: 14-SEP-97 SOFTWARE VERSION: CP 44.2 TIME LOGGER ON BOTTOM: 1044 14-SEP-97 TD DRILLER (FT) : 11174.0 TD LOGGER (FT) : 11170.0 TOP LOG INTERVAL (FT) : 10650.0 BOTTOM LOG INTERVAL (FT) : 11165.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAiV~IA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER ........... CGRS 862 TDIC 816 3292.0 Crude 45.0 THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 47 BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS: BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP PUMP PUMP PUMP PUMP PUMP THIS PASS $ LIS FORMAT DATA 20 CRUDE, LOG BASE PASS 2 19 CRUDE, LOG BASE PASS 3 185 BORAX 25 CRUDE, LOG BORAX PASS #1. 21 CRUDE, LOG BORAX PASS #2. 20 CRUDE, LOG BORAX PASS #3. FILE CONTAINS THE RAW DATA FOR BASE #2. ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE 48 ** SET TYPE - CHAN ** NAIVE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS2 CU 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI PS2 PU 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS2 CU 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNPS2 CU 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS2 CU 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS2 CU 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PS2 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS2 CU 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TCANPS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TCND PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 INA~PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS2 CPS 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS2 LB 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS2 GAPI 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS2 V 1094403 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 11160.000 SIGM. PS2 33.527 TPHI.PS2 50.934 SBHF.PS2 SBHN. PS2 48.901 SIGC. PS2 2.569 SIBH. PS2 57.123 TRAT. PS2 SDSI.PS2 1.055 BACK. PS2 198.494 FBAC. PS2 62.762 TCAN. PS2 TCAF. PS2 6584.441 TCND.PS2 17233.449 TCFD. PS2 4480.553 TSCN. PS2 TSCF. PS2 785.318 INND. PS2 2583.683 INFD. PS2 430.826 TENS.PS2 GR.PS2 232.875 CCL.PS2 0.000 DEPT. 10648.500 SIGM. PS2 18.176 TPHI.PS2 26.752 SBHF. PS2 SBHN. PS2 52.415 SIGC. PS2 1.025 SIBH. PS2 63.215 TRAT. PS2 SDSI.PS2 0.487 BACK. PS2 220.217 FBAC.PS2 55.860 TCAN. PS2 TCAF. PS2 12901.807 TCND.PS2 22907.574 TCFD.PS2 8043.236 TSCN. PS2 TSCF. PS2 2929.324 INND.PS2 2748.792 INFD. PS2 561.715 TENS.PS2 GR.PS2 39.563 CCL.PS2 0.000 44.360 1.769 22328.039 2531.717 1395.000 41.220 1.612 28860.531 6552.714 1335.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 49 **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11184.0 10646.0 TDTP $ LOG HEADER DATA DATE LOGGED: 14-SEP-97 SOFTWARE VERSION: CP 44.2 TIME LOGGER ON BOTTOM: 1044 14-SEP-97 TD DRILLER (FT) : 11174.0 TD LOGGER (FT) : 11170.0 TOP LOG INTERVAL (FT) : 10650.0 BOTTOM LOG INTERVAL (FT) : 11165.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlenA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER CGRS 862 TDIC 816 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 5O DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 3292.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Crude 45.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS: BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP PUMP PUMP PUMP PUMP PUMP THIS PASS $ LIS FORMAT DATA 20 CRUDE, LOG BASE PASS 2 19 CRUDE, LOG BASE PASS 3 185 BORAX 25 CRUDE, LOG BORAX PASS #1. 21 CRUDE, LOG BORAX PASS #2. 20 CRUDE, LOG BORAX PASS #3. FILE CONTAINS THE RAW DATA FOR BASE #3. LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 51 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM PS3 CU 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI PS3 PU 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF PS3 CU 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 SBHN PS3 CU 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC PS3 CU 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH PS3 CU 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT PS3 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI PS3 CU 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 BACK PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TCAN PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TCAF PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TCND PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TCFD PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF PS3 CPS 1094403 O0 000 O0 0 12 I 1 4 68 0000000000 INND PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 INFD PS3 CPS 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 TENS PS3 LB 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 GR PS3 GAPI 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 CCL PS3 V 1094403 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 52 ** DATA ** DEPT. 11160.000 SIGM. PS3 SBHN. PS3 48.809 SIGC. PS3 SDSI.PS3 1.054 BACK. PS3 TCAF. PS3 6624.735 TCND. PS3 TSCF. PS3 681.457 INND.PS3 GR.PS3 182.250 CCL.PS3 DEPT. 10645.500 SIGM. PS3 SBHN. PS3 53.180 SIGC. PS3 SDSI.PS3 0.369 BACK. PS3 TCAF. PS3 16448.637 TCND.PS3 TSCF. PS3 3778.534 INND.PS3 GR.PS3 40.781 CCL. PS3 36.915 TPHI.PS3 2.486 SIBH. PS3 253.360 FBAC. PS3 16780.906 TCFD. PS3 2567.198 INFD.PS3 0.000 15.064 TPHI.PS3 1.230 SIBH. PS3 253.865 FBAC. PS3 23970.305 TCFD.PS3 3035.699 INFD. PS3 0.000 49.020 SBHF. PS3 56.915 TRAT. PS3 66.024 TCAN. PS3 4309.349 TSCN. PS3 409.695 TENS. PS3 18.143 SBHF. PS3 62.402 TRAT. PS3 60.349 TCAN. PS3 9457.779 TSCN. PS3 556.006 TENS.PS3 43.858 1.675 23096.797 2186.394 1415.000 50.056 1.443 31829.914 7311.878 1340.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~VARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 11182.0 10648.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 53 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 14-SEP-97 CP 44.2 1044 14-SEP-97 11174.0 11170.0 10650.0 11165.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS 862 TDIC 816 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 3292.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX 45.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 54 LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS: BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP PUMP PUMP PUMP PUMP PUMP THIS PASS $ 20 CRUDE, LOG BASE PASS 2 19 CRUDE, LOG BASE PASS 3 185 BORAX 25 CRUDE, LOG BORAX PASS #1. 21 CRUDE, LOG BORAX PASS #2. 20 CRUDE, LOG BORAX PASS #3. FILE CONTAINS THE RAW DATA FOR BORAX #1. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT iS 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPECLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM BX1 CU 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX1 PU 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX1 CU 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 SBHNBX1 CU 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX1 CU 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH BX1 CU 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX1 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 55 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SDSI BX1 CU 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 BACK BX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TCAF BX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TCND BX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TCFDEX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN BX1 CPS 1094403 O0 000 O0 0 13 I 1 4 68 0000000000 TSCF BX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 INFD BX1 CPS 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX1 LB 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX1 GAPI 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 CCL BX1 V 1094403 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 11160.000 SIGM. BX1 38.239 TPHI.BX1 56.565 SBHF. BX1 41.490 SBHN. BX1 52.343 SIGC. BX1 1.442 SIBH. BX1 64.932 TRAT. BX1 1.720 SDSI.BX1 1.396 BACK. EX1 233.324 FBAC. BX1 57.947 TCAN. BX1 20436.184 TCAF. BX1 5861.280 TCND.BX1 17082.844 TCFD.BX1 4325.904 TSCN. BX1 2205.375 TSCF. BX1 653.131 INND.BX1 2522.208 INFD.BX1 389.749 TENS.BX1 1440.000 GR.BX1 54.156 CCL.BX1 0.000 DEPT. 10648.000 SIGM. BX1 16.316 TPHI.BX1 22.840 SBHF.BX1 48.256 SBHN. BX1 63.433 SIGC. BX1 1.330 SIBH.BX1 83.681 TRAT.BX1 1.507 SDSI.BX1 0.442 BACK. EX1 241.100 FBAC.BX1 51.749 TCAN. BX1 24222.434 TCAF. BX1 11774.189 TCND.BX1 18707.672 TCFD.BX1 7063.386 TSCN. BX1 5530.185 TSCF. BX1 2688.146 INND. BX1 2586.431 INFD.BX1 508.167 TENS.BX1 1360.000 GR.BX1 46.938 CCL.BX1 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 56 **** FILE HEADER **** FILE NAFiE : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 14 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11186.0 10649.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 14-SEP-97 CP 44.2 1044 14-SEP-97 11174.0 11170.0 10650.0 11165.0 1800.0 TOOL NUMBER CGRS 862 TDIC 816 3292.0 BORAX 45.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 57 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS: BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP PUMP PUMP PUMP PUMP PUMP THIS PASS $ LIS FORMAT DATA 20 CRUDE, LOG BASE PASS 2 19 CRUDE, LOG BASE PASS 3 185 BORAX 25 CRUDE, LOG BORAX PASS #1. 21 CRUDE, LOG BORAX PASS #2. 20 CRUDE, LOG BORAX PASS #3. FILE CONTAINS THE RAW DATA FOR BORAX #2. ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 LIS Tape Verifica~ion Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 58 TYPE REPR CODE VALUE .............................. 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 SIGM BX2 CU 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TPHI BX2 PU 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 SBHF BX2 CU 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 SBHNBX2 CU 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 SIGC BX2 CU 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 SIBH BX2 CU 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TRAT BX2 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 SDSI BX2 CU 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 BACK BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 FBAC BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TCANBX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TCAF BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TCND BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TCFD BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TSCN BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TSCF BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 INNDBX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 INFD BX2 CPS 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 TENS BX2 LB 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 GR BX2 GAPI 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 CCL BX2 V 1094403 O0 000 O0 0 14 1 1 4 68 0000000000 ** DATA ** DEPT. 11160 000 SIGM. BX2 36.782 TPHI.BX2 48.110 SBHF. BX2 47.442 SBHN. BX2 49 634 SIGC.BX2 2.478 SIBH. BX2 58.786 TRAT. BX2 1.642 SDSI.BX2 0 958 BACK. BX2 257.122 FBAC.BX2 59.442 TCAN. BX2 22674.043 TCAF. BX2 6529 795 TCND.BX2 17080.047 TCFD.BX2 4391.200 TSCN. BX2 2106.674 TSCF. BX2 675 786 INND.BX2 2313.948 INFD.BX2 394.566 TENS.BX2 1435.000 GR.BX2 282 250 CCL.BX2 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 59 DEPT. 10648.500 SIGM. BX2 SBHN. BX2 61.508 SIGC. BX2 SDSI.BX2 0.544 BACK. BX2 TCAF. BX2 11534.740 TCND.BX2 TSCF. BX2 2566.711 INND.BX2 GR.BX2 51.438 CCL.BX2 17.795 TPHI.BX2 0.943 SIBH. BX2 253.519 FBAC. BX2 18630.285 TCFD.BX2 2902.903 INFD. BX2 0.000 26.045 81.855 54.969 6798.414 503.357 SBHF. BX2 TRAT.BX2 TCAN. BX2 TSCN. BX2 TENS.BX2 50.104 1.555 24399.727 5429.430 1355.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 15 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 11183.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH .......... 10626.0 14-SEP-97 CP 44.2 1044 14-SEP-97 11174.0 11170.0 10650.0 11165.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 6O LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS 862 TDIC 816 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 3292.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX 45.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS: BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP 20 CRUDE, LOG BASE PASS 2 PUMP 19 CRUDE, LOG BASE PASS 3 PUMP 185 BORAX PUMP 25 CRUDE, LOG BORAX PASS #1. PUMP 21 CRUDE, LOG BORAX PASS #2. PUMP 20 CRUDE, LOG BORAX PASS #3. LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 61 THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE N-t~B I~JMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 SIGM BX3 CU 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TPHI BX3 PU 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 SBHF BX3 CU 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 SBHN BX3 CU 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 SIGC BX3 CU 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 SIBH BX3 CU 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TRAT BX3 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 SDSI BX3 CU 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 BACK BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 FBAC BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TCANBX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TCAF BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TCND BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TCFD BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TSCN BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TSCF BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE 62 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INND BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 INFD BX3 CPS 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 TENS BX3 LB 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 GR BX3 GAPI 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 CCL BX3 V 1094403 O0 000 O0 0 15 1 1 4 68 0000000000 ** DATA ** DEPT. 11160.000 SIGM. BX3 30.822 TPHI.BX3 47.592 SBHF. BX3 SBHN. BX3 51.935 SIGC.BX3 3.530 SIBH. BX3 64.005 TRAT. BX3 SDSI.BX3 1.275 BACK. BX3 262.950 FBAC.BX3 60.011 TCAN. BX3 TCAF. BX3 6539.647 TCND.BX3 17521.281 TCFD.BX3 4689.328 TSCN. BX3 TSCF. BX3 875.000 INND.BX3 2286.920 INFD.BX3 408.817 TENS.BX3 GR.BX3 107.375 CCL.BX3 0.000 DEPT. 10640.000 SIGM. BX3 11.603 TPHI.BX3 10.597 SBHF. BX3 SBHN. BX3 67.772 SIGC.BX3 0.424 SIBH. BX3 84.043 TRAT. BX3 SDSI.BX3 0.283 BACK. BX3 261.568 FBAC. BX3 60.115 TCAN. BX3 TCAF. BX3 24831.719 TCND.BX3 22785.418 TCFD.BX3 11872.723 TSCN. BX3 TSCF. BX3 5980.842 INND.BX3 2697.507 INFD.BX3 601.984 TENS.BX3 GR.BX3 45.438 CCL.BX3 0.000 42.743 1.712 21449.500 2602.127 1460.000 53.612 1.205 36948.359 8899.193 1355.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 63 FILE HEADER FILE NUMBER 16 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NU~BER: 7 DEPTH INCRIEIWzF2FT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 11182.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 10649.0 14-SEP-97 CP 44.2 1044 14-SEP-97 11174.0 11170.0 10650.0 11165.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS 862 TDIC 816 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 3292.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PF 45.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 64 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) '. BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS: BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP 20 CRUDE, LOG BASE PASS 2 PUMP 19 CRUDE, LOG BASE PASS 3 PUMP 185 BORAX PUMP 25 CRUDE, LOG BORAX PASS #1. PUMP 21 CRUDE, LOG BORAX PASS #2. PUMP 20 CRUDE, LOG BORAX PASS #3. THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 65 ** SET TYPE - CHAN ** N.~IE SERV UNIT SERVICE API API API API FILE I~JMB Nr.~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 SIGM FP1 CU 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TPHI FP1 PU 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 SBHF FP1 CU 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 SBHN FP1 CU 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 SIGC FP1 CU 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 SIBH FP1 CU 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TRAT FP1 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 SDSI FP1 CU 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 BACK FP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 FBAC FP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TCANFP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TCAF FP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TCNDFP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TCFD FP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TSCN FP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TSCF FP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 INNDFP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 INFD FP1 CPS 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 TENS FP1 LB 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 GR FP1 GAPI 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 CCL FP1 V 1094403 O0 000 O0 0 16 1 1 4 68 0000000000 ** DATA ** DEPT. 11160.000 SIGM. FPi 33.140 TPHI.FP1 46.849 SBHF. FP1 SBHN. FP1 48.589 SIGC. FP1 3.254 SIBH. FP1 56.416 TRAT. FP1 SDSI.FP1 1.344 BACK. FP1 38.376 FBAC.FP1 12.641 TCAN. FP1 TCAF. FP1 6004.078 TCND.FP1 17855.801 TCFD.FP1 4704.379 TSCN. FP1 TSCF. FP1 836.116 INND.FP1 2666.489 INFD.FP1 416.928 TENS.FP1 GR.FP1 22.125 CCL.FP1 0.000 DEPT. 10649.000 SIGM. FP1 18.059 TPHI.FP1 19.285 SBHF. FP1 SBHN. FP1 45.594 SIGC. FP1 1.733 SIBH. FP1 48.482 TRAT. FP1 SDSI.FP1 0.462 BACK. FP1 158.445 FBAC. FP1 46.377 TCAN. FP1 TCAF. FP1 13999.051 TCND.FP1 25505.258 TCFD.FP1 9822.221 TSCN. FP1 TSCF. FP1 3493.541 INND.FP1 3514.734 INFD. FP1 769.272 TENS.FP1 GR.FP1 20.641 CCL.FP1 0.000 40. 646 1. 705 19909. 871 2529. 561 1360. 000 36.983 1.471 28839.250 7196.994 1320.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 66 **** FILE TRAILER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .017 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 17 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 8 DEPTH INCREMENT: O. 5000 FILE SUFIMARY VENDOR TOOL CODE START DEPTH ........................... TDTP 11181.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH .......... 10642.0 14 -SEP-97 CP 44.2 1044 14-SEP-97 11174.0 11170.0 10650.0 11165.0 1800.0 TOOL NUMBER ........... CGRS 862 TDIC 816 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 67 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 3292.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PF 45.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS CNL, 7-JAN-88. *************JOB SEQUENCE************* LOGGED FLOWING PASSES #1 & #2. ALL MEASURMENTS: BBLS PUMP 155 CRUDE, LOG BASE PASS 1 PUMP 20 CRUDE, LOG BASE PASS 2 PUMP 19 CRUDE, LOG BASE PASS 3 PUMP 185 BORAX PUMP 25 CRUDE, LOG BORAX PASS #1. PUMP 21 CRUDE, LOG BORAX PASS #2. PUMP 20 CRUDE, LOG BORAX PASS #3. THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 68 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 SIGM FP2 CU 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TPHI FP2 PU 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 SBHF FP2 CU 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 SBHN FP2 CU 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 SIGC FP2 CU 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 SIBH FP2 CU 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TRAT FP2 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 SDSI FP2 CU 1094403 O0 000 O0 0 17 i 1 4 68 0000000000 BACK FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 FBAC FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TCANFP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TCAF FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TCND FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TCFD FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TSCN FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TSCF FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 INND FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 INFD FP2 CPS 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 TENS FP2 LB 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 GR FP2 GAPI 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 CCL FP2 V 1094403 O0 000 O0 0 17 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-DEC-1997 12:08 PAGE: 69 ** DATA ** DEPT. 11160 SBMN. FP2 49 SDSI.FP2 1 TCAF. FP2 6324 TSCF. FP2 839 GR. FP2 104 DEPT. 10641 SBHN. FP2 51 SDSI.FP2 0 TCAF. FP2 28900 TSCF. FP2 7231 GR.FP2 20 000 SIGM. FP2 32.098 TPHI.FP2 965 SIGC. FP2 4.187 SIBH.FP2 048 BACK. FP2 197.368 FBAC.FP2 080 TCND.FP2 16962.871 TCFD.FP2 967 INND.FP2 2738.039 INFD.FP2 313 CCL.FP2 0.000 .000 SIGM. FP2 .753 SIGC.FP2 .268 BACK.FP2 .980 TCND.FP2 .668 INND.FP2 .078 CCL.FP2 12.496 TPHI.FP2 0.669 SIBH. FP2 260.492 FBAC. FP2 30270.801 TCFD.FP2 3190.765 INFD.FP2 0.000 40.032 SBHF. FP2 59.537 TRAT. FP2 65.101 TCAN. FP2 4542.274 TSCN. FP2 402.202 TENS.FP2 9.633 SBHF. FP2 57.723 TRAT. FP2 69.145 TCAN. FP2 15576.467 TSCN. FP2 845.403 TENS.FP2 48.305 1. 572 20006.988 2341.237 1370. 000 41.259 1.197 43947. 813 10996. 719 1385. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .017 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/12/16 ORIGIN : FLIC TAPE NAME : 97510 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 18-17, PRUDHOE BAY, 50-029-21768-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/12/16 ORIGIN : FLIC REEL NAME : 97510 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 18-17, PRUDHOE BAY, 50-029-21768-00 HA L L IBUR TON LOGGING S~R VIC~S, /NC. OA Halliburton Company Oil ,~ 199~ DATE. ,::.:i...,:~.,:~.....,.:..:.,..,..,:,.:..,:..?:;:..::.?....:...::. i:.;':FI'ELD:::.":'" :":'"'.'.' i,;~;' LIS TAPE VERIFICATION LISTING LDWG FORMAT Page 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 93/04/06 --- ANCH --- 847704 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 93/04/06 --- ANCH 0 COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: DS 18-17 API NUMBER: 500292176800 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: HALLIBURTON LOGGING SERVICES TAPE CREATION DATE: 06-APR-93 JOB NUMBER: L84770-4 LOGGING ENGINEER: M. MCCARTER OPERATOR WITNESS: K. MORRIS SURFACE LOCATION SECTION: 24 TOWNSHIP: liN RANGE: 14E FNL: 1242 FSL: FEL: 146 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 48.00 DERRICK FLOOR: 45.50 GROUND LEVEL: 17.00 WELL CASING RECORD OPEN HOLE CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) 1ST STRING 13.375 3292.0 2ND STRING 12.250 9.625 10350.0 3RD STRING 8.500 7.000 11222.0 PRODUCTION STRING 12.250 3.500 10774.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: SGR PBU CURVE CODE: CGR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH TMD 72.00 47.00 29.00 9.30 -EQUIVALENT UNSHIFTED DEPTH .......... 10768.5 10768.0 10834.5 10834.0 10901.0 10900.5 10943.0 10942.5 11005.5 11005.0 11054.5 11054.0 11091.5 11091.0 11108.5 11108.0 11165.5 11165.0 $ REMARKS: TIED INTO CNL DATED 07-JAN-88. $ FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 ----m 0 --m~ 5 --- 93/04/06 --- 1024 --- LO COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH Page 3 TMD 11165.5 10772.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 --EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TMD $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #1. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F FTMD TMD 847704 CPS NTMD TMD 847704 CPS SGFM TMD 847704 CU FSBF TMD 847704 CPS RSBF TMD 847704 RTMD TMD 847704 SGBH TMD 847704 CU SGIN TMD 847704 CU SGFF TMD 847704 CU SIGQ TMD 847704 SGFN TMD 847704 CU NSBF TMD 847704 CPS SIGC TMD 847704 CRNF TMD 847704 PHIT TMD 847704 PU API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 Page 4 GRCH TMD 847704 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 11165.500 FTMD = 1367.499 NTMD = 7360.949 SGFM = 32.065 FSBF = 7.573 RSBF = 1.161 RTMD = 5.383 SGBH = 84.267 SGIN = 33.275 SGFF = 30.013 SIGQ = .982 SGFN = 34.476 NSBF = 55.732 SIGC = .964 CRNF = 4.603 PHIT = 30.584 GRCH = 45.877 DEPT = 11065.500 FTMD = 3114.877 NTMD = 18134.090 SGFM = 18.364 FSBF = 2.390 RSBF = .455 RTMD = 5.822 SGBH = 68.316 SGIN = 16.544 SGFF = 18.405 SIGQ = .994 SGFN = 21.666 NSBF = 33.817 SIGC = 1.110 CRNF = 5.076 PHIT = 33.808 GRCH = 15.507 DEPT = 10965.500 FTMD = 3017.988 NTMD = 17837.750 SGFM = 15.595 FSBF = 3.036 RSBF = .502 RTMD = 5.910 SGBH = 62.106 SGIN = 13.248 SGFF = 17.119 SIGQ = .989 SGFN = 19.038 NSBF = 45.640 SIGC = 1.177 CRNF = 5.172 PHIT = 33.922 GRCH = 13.850 DEPT = 10865.500 FTMD = 4942.682 NTMD = 22317.520 SGFM = 11.516 FSBF = 4.272 RSBF = .477 RTMD = 4.515 SGBH = 66.106 SGIN = 8.637 SGFF = 11.500 SIGQ = .989 SGFN = 16.111 NSBF = 59.380 SIGC = 1.333 CRNF = 3.672 PHIT = 15.409 GRCH = 8.287 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 ~ 0 --- 93/04/06 --- 1024 --- LO --- COMCEN.002 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.002 ~-- 0 --- 93/04/06 --- 1024 --- LO Page 5 OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 11165.5 10770.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD THIS FILE CONTAINS EDITED DATA FOR PASS #2. NO PASS TO PASS DEPTH SHIFTS REQUIRED. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: Page 6 MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 FTMD TMD 847704 CPS 00000000 0 4 1 68 NTMD TMD 847704 CPS 00000000 0 4 1 68 SGFM TMD 847704 CU 00000000 0 4 1 68 FSBF TMD 847704 CPS 00000000 0 4 1 68 RSBF TMD 847704 00000000 0 4 1 68 RTMD TMD 847704 00000000 0 4 1 68 SGBH TMD 847704 CU 00000000 0 4 1 68 SGIN TMD 847704 CU 00000000 0 4 1 68 SGFF TMD 847704 CU 00000000 0 4 1 68 SIGQ TMD 847704 00000000 0 4 1 68 SGFN TMD 847704 CU 00000000 0 4 1 68 NSBF TMD 847704 CPS 00000000 0 4 1 68 SIGC TMD 847704 00000000 0 4 1 68 CRNF TMD 847704 00000000 0 4 1 68 PHIT TMD 847704 PU 00000000 0 4 1 68 GRCH TMD 847704 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 11165.500 FTMD = 1294.328 NTMD = 7076.027 SGFM = 32.247 FSBF = 18.980 RSBF = 1.122 RTMD = 5.467 SGBH = 85.985 SGIN = 33.076 SGFF = 30.382 SIGQ = .987 SGFN = 34.644 NSBF = 129.758 SIGC = .975 CRNF = 4.694 PHIT = 32.220 GRCH = 117.423 DEPT = 11065.500 FTMD = 2895.164 NTMD = 16776.670 SGFM = 18.176 FSBF = 9.011 RSBF = .466 RTMD = 5.795 SGBH = 64.495 SGIN = 16.320 SGFF = 19.154 SIGQ = .986 SGFN = 21.488 NSBF = 88.961 SIGC = 1.114 CRNF = 5.047 PHIT = 32.542 GRCH = 31.926 DEPT = 10965.500 FTMD =' 3024.253 NTMD = 17625.340 SGFM = 16.166 FSBF = 8.808 RSBF = .506 RTMD = 5.828 SGBH = 64.853 SGIN = 13.927 SGFF = 16.880 SIGQ = .989 SGFN = 19.581 NSBF = 95.903 SIGC = 1.161 CRNF = 5.083 PHIT = 33.158 GRCH = 28.738 DEPT = 10865.500 FTMD = 4717.379 NTMD = 21486.350 SGFM = 11.922 FSBF = 9.529 RSBF = .525 RTMD = 4.555 SGBH = 61.843 SGIN = 8.941 SGFF = 12.433 SIGQ = .983 SGFN = 15.863 NSBF = 102.001 SIGC = 1.333 CRNF = 3.713 PHIT = 14.999 GRCH = 24.726 FILE TRAILER RECORD TYPE 129 FILE NAME --- COMCEN.002 Page 7 SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME ------0 --- 93/04/06 --- 1024 --- LO --- COMCEN.003 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 --- 93/04/06 --- 1024 --- LO --- COMCEN.002 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 11165.0 10768.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TMD 10768.0 10768.0 10834.0 10834.0 10900.5 10900.5 10942.5 10942.5 11005.0 11005.0 11054.0 11054.0 11091.0 11091.5 11108.0 11108.5 11164.5 11165.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #3. $ Page 8 LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 FTMD TMD 847704 CPS 00000000 0 4 1 68 NTMD TMD 847704 CPS 00000000 0 4 1 68 SGFM TMD 847704 CU 00000000 0 4 1 68 FSBF TMD 847704 CPS 00000000 0 4 1 68 RSBF TMD 847704 00000000 0 4 1 68 RTMD TMD 847704 00000000 0 4 1 68 SGBH TMD 847704 CU 00000000 0 4 1 68 SGIN TMD 847704 CU 00000000 0 4 1 68 SGFF TMD 847704 CU 00000000 0 4 1 68 SIGQ TMD 847704 00000000 0 4 1 68 SGFN TMD 847704 CU 00000000 0 4 1 68 NSBF TMD 847704 CPS 00000000 0 4 1 68 SIGC TMD 847704 00000000 0 4 1 68 CRNF TMD 847704 00000000 0 4 1 68 PHIT TMD 847704 PU 00000000 0 4 1 68 GRCH TMD 847704 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 11165.000 FTMD = 1356.698 NTMD = 7576.477 SGFM = 33.071 FSBF = 22.333 RSBF = .994 RTMD = 5.584 SGBH = 87.462 SGIN = 33.643 SGFF = 31.290 SIGQ = .989 SGFN = 35.409 NSBF = 155.854 SIGC = .983 CRNF = 4.821 PHIT = 34.345 GRCH = 119.062 DEPT = 11065.000 FTMD = 3185.551 NTMD = 18658.020 SGFM = 18.144 FSBF = 10.085 RSBF = .495 Page 9 RTMD = 5.857 SGBH = 65.029 SGIN = 16.283 SGFF = 18.654 SIGQ = .988 SGFN = 21.458 NSBF = 118.458 SIGC = 1.114 CRNF = 5.115 PHIT = 33.671 GRCH = 46.277 DEPT = 10965.000 FTMD = 3133.259 NTMD = 18323.850 SGFM = 15.634 FSBF = 10.526 RSBF = .603 RTMD = 5.848 SGBH = 62.215 SGIN = 13.294 SGFF = 17.185 SIGQ = .984 SGFN = 19.075 NSBF = 115.069 SIGC = 1.176 CRNF = 5.105 PHIT = 32.920 GRCH = 38.528 DEPT = 10865.000 FTMD = 5001.378 NTMD = 22755.000 SGFM = 12.366 FSBF = 11.132 RSBF = .467 RTMD = 4.550 SGBH = 67.074 SGIN = 9.404 SGFF = 12.686 SIGQ = .990 SGFN = 16.443 NSBF = 122.159 SIGC = 1.315 CRNF = 3.708 PHIT = 16.004 GRCH = 32.575 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 ~m~ 0 --- 93/04/06 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 --- 93/04/06 --- 1024 --- LO --- COMCEN.003 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 Page 10 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS TMD 01,02,03 $ REMARKS: GRCH, NSBF AND FSBF ARE TAKEN FROM PASS #1 DATA. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F FTMD PNAV 847704 CPS NTMD PNAV 847704 CPS SGFM PNAV 847704 CU FSBF PNAV 847704 CPS RSBF PNAV 847704 RTMD PNAV 847704 SGBH PNAV 847704 CU SGIN PNAV 847704 CU SGFF PNAV 847704 CU SIGQ PNAV 847704 SGFN PNAV 847704 CU NSBF PNAV 847704 CPS SIGC PNAV 847704 CRNF PNAV 847704 PHIT PNAV 847704 PU GRCH PNAV 847704 GAPI API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4' 1 68 DATA RECORD TYPE 0 DEPT = 11165.000 FTMD = 1340.023 NTMD = 7340.189 Page 11 SGFM = 32.556 FSBF = 7.646 RSBF = 1.079 RTMD = 5.477 SGBH = 86.207 SGIN = 33.363 SGFF = 30.622 SIGQ = .985 SGFN = 34.932 NSBF = 55.175 SIGC = .976 CRNF = 4.705 PHIT = 32.440 GRCH = 45.877 DEPT = 11065.000 FTMD = 3056.707 NTMD = 17893.460 SGFM = 18.248 FSBF = 2.468 RSBF = .466 RTMD = 5.853 SGBH = 66.017 SGIN = 16.406 SGFF = 18.776 SIGQ = .989 SGFN = 21.556 NSBF = 33.714 SIGC = 1.112 CRNF = 5.111 PHIT = 33.826 GRCH = 16.449 DEPT = 10965.000 FTMD = 3043.799 NTMD = 17832.060 SGFM = 15.900 FSBF = 3.093 RSBF = .540 RTMD = 5.859 SGBH = 63.145 SGIN = 13.611 SGFF = 17.022 SIGQ = .987 SGFN = 19.329 NSBF = 45.543 SIGC = 1.168 CRNF = 5.116 PHIT = 33.294 GRCH = 15.589 DEPT = 10865.000 FTMD = 4881.724 NTMD = 22202.080 SGFM = 11.952 FSBF = 4.358 RSBF = .489 RTMD = 4.548 SGBH = 64.743 SGIN = 9.007 SGFF = 12.217 SIGQ = .987 SGFN = 16.146 NSBF = 59.957 SIGC = 1.327 CRNF = 3.706 PHIT = 15.512 GRCH = 7.801 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 t~ 0 --- 93/04/06 --- 1024 --- LO --- COMCEN.005 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 ~m 0 --- 93/04/06 --- 1024 --- LO --- COMCEN.004 COMMENT RECORD TYPE 232 Page 12 FILE HEADER FILE NUMBER: 05 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 11187.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 10772.0 17-AUG-92 PLS-II 2.23 0952 17-AUG-92 11158.0 11173.0 10780.0 11165.0 1200.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY TMD PULSED NEUTRON $ 106312 106315 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 11222.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DEAD CRUDE 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 11000.0 BASE NORMALIZING WINDOW (FT): 11040.0 Page 13 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #1. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 80 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F ABTN TMD 847704 FTMD TMD 847704 CNTS NTMD TMD 847704 CNTS SGFM TMD 847704 CU FSBF TMD 847704 CNTS G4ER TMD 847704 RSBF TMD 847704 RTMD TMD 847704 SGBH TMD 847704 CU SGIN TMD 847704 CU SGFF TMD 847704 CU SIGQ TMD 847704 SGFN TMD 847704 CU NSBF TMD 847704 CNTS SIGC TMD 847704 CRNF TMD 847704 PHIT TMD 847704 DECI GR TMD 847704 GAPI CCL TMD 847704 MV AP1 CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 Page 14 DATA RECORD TYPE 0 DEPT = 11187.000 ABTN = 28048.600 FTMD = 1395.796 NTMD = 7322.484 SGFM = 28.549 FSBF = 5.404 G4ER = -.011 RSBF = 1.141 RTMD = 5.246 SGBH = 86.711 SGIN = 28.598 SGFF = 23.639 SIGQ = .986 SGFN = 34.739 NSBF = 40.631 $IGC = .998 CRNF = 4.455 PHIT = .292 GR = 17.156 CCL = 5401.000 DEPT = 11137.000 ABTN = 27785.610 FTMD = 2603.363 NTMD = 14286.070 SGFM = 17.486 FSBF = 2.301 G4ER = .011 RSBF = .898 RTMD = 5.488 SGBH = 71.759 SGIN = 15.499 SGFF = 18.118 SIGQ = .981 SGFN = 20.835 NSBF = 23.954 SIGC = 1.128 CRNF = 4.716 PHIT = .293 GR = 33.700 CCL = 10923.000 DEPT = 11087.000 ABTN = 30293.140 FTMD = 1680.923 NTMD = 9606.545 SGFM = 22.657 FSBF = 2.617 G4ER = .011 RSBF = 1.451 RTMD = 5.715 SGBH = 66.274 SGIN = 21.655 SGFF = 22.039 SIGQ = .951 SGFN = 25.705 NSBF = 31.806 SIGC = 1.046 CRNF = 4.961 PHIT = .317 GR = 43.114 CCL = 5401.000 DEPT = 11037.000 ABTN = 20725.670 FTMD = 3371.682 NTMD = 19447.430 SGFM = 15.685 FSBF = 2.503 G4ER = .015 RSBF = .491 RTMD = 5.768 SGBH = 63.483 SGIN = 13.354 SGFF = 16.744 SIGQ = .984 SGFN = 19.123 NSBF = 37.021 SIGC = 1.175 CRNF = 5.018 PHIT = .319 GR = 13.365 CCL = 5448.000 DEPT = 10987.000 ABTN = 19420.910 FTMD = 3310.339 NTMD = 18938.590 SGFM = 16.505 FSBF = 3.112 G4ER = .004 RSBF = .459 RTMD = 5.721 SGBH = 65.736 SGIN = 14.331 SGFF = 16.902 SIGQ = .987 SGFN = 19.904 NSBF = 42.673 SIGC = 1.152 CRNF = 4.968 PHIT = .316 GR = 12.670 CCL = 5457.000 DEPT = 10937.000 ABTN = 20493.540 FTMD = 4271.970 NTMD = 21014.570 SGFM = 13.722 FSBF = 3.081 G4ER = .015 RSBF = .461 RTMD = 4.919 SGBH = 64.493 SGIN = 11.017 SGFF = 14.512 SIGQ = .987 SGFN = 17.268 NSBF = 49.182 SIGC = 1.245 CRNF = 4.103 PHIT = .200 GR = 10.544 CCL = 5460.000 Page 15 DEPT = 10887.000 ABTN = 21725.070 FTMD = 4098.346 NTMD = 20436.600 SGFM = 13.717 FSBF = 3.774 G4ER = -.002 RSBF = .504 RTMD = 4.987 SGBH = 63.500 SGIN = 11.012 SGFF = 13.727 SIGQ = .989 SGFN = 17.245 NSBF = 54.912 SIGC = 1.246 CRNF = 4.176 PHIT = .206 GR = 11.349 CCL = 5475.000 DEPT = 10837.000 ABTN = 22984.770 FTMD = 4838.957 NTMD = 21743.790 SGFM = 12.196 FSBF = 4.732 G4ER = .022 RSBF = .512 RTMD = 4.493 SGBH = 64.582 SGIN = 9.201 SGFF = 12.218 SIGQ = .987 SGFN = 16.607 NSBF = 62.725 SIGC = 1.326 CRNF = 3.650 PHIT = .148 GR = 9.523 CCL = 5457.000 DEPT = 10787.000 ABTN = 26651.790 FTMD = 6109.946 NTMD = 23896.970 SGFM = 11.150 FSBF = 5.265 G4ER = .017 RSBF = .549 RTMD = 3.911 SGBH = 63.073 SGIN = 8.363 SGFF = 12.187 SIGQ = .989 SGFN = 16.072 NSBF = 67.491 SIGC = 1.333 CRNF = 3.049 PHIT = .084 GR = 10.107 CCL = 5504.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 93/04/06 --- 1024 --- LO --- COMCEN.006 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --m~ 0 --- 93/04/06 --- 1024 --- LO --- COMCEN.005 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 RAW CURVES Curves and log header data for each pass in separate files; Page 16 raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 11187.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 10769.5 17-AUG-92 PLS-II 2.23 0952 17-AUG-92 11158.0 11173.0 10780.0 11165.0 1200.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY TMD PULSED NEUTRON $ 106312 106315 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.50O 11222.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DEAD CRUDE 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 11000.0 BASE NORMALIZING WINDOW (FT): 11040.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5500 Page 17 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #2. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 80 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 ABTN TMD 847704 00000000 0 4 1 68 FTMD TMD 847704 CNTS 00000000 0 4 1 68 NTMD TMD 847704 CNTS 00000000 0 4 1 68 SGFM TMD 847704 CU 00000000 0 4 1 68 FSBF TMD 847704 CNTS 00000000 0 4 1 68 G4ER TMD 847704 00000000 0 4 1 68 RSBF TMD 847704 00000000 0 4 1 68 RTMD TMD 847704 00000000 0 4 1 68 SGBH TMD 847704 CU 00000000 0 4 1 68 SGIN TMD 847704 CU 00000000 0 4 1 68 SGFF TMD 847704 CU 00000000 0 4 1 68 SIGQ TMD 847704 00000000 0 4 1 68 SGFN TMD 847704 CU 00000000 0 4 1 68 NSBF TMD 847704 CNTS 00000000 0 4 1 68 SIGC TMD 847704 00000000 0 4 1 68 CRNF TMD 847704 00000000 0 4 1 68 PHIT TMD 847704 DECI 00000000 0 4 1 68 GR TMD 847704 GAPI 00000000 0 4 1 68 CCL TMD 847704 MV 00000000 0 4 1 68 DATA RECORD TYPE 0 Page 18 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 11187.000 7159.295 .003 98.590 .979 1.321 90.168 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 22124.860 35.992 .759 35.992 38.759 5.252 5395.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 1236.771 20.016 5.789 32.684 141.609 .390 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 11137.000 13717.800 .017 71.430 .985 1.126 78.773 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 26533.660 17.571 .867 15.600 20.916 4.713 10923.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 2500.868 9.919 5.485 17.838 89.553 .292 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 11087.000 9438.857 .010 68.741 .959 1.041 66.540 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 28733.200 23.158 1.373 22.252 26.176 5.087 5407.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 1618.579 9.551 5.832 22.787 89.880 .341 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 11037.000 18133.730 .018 62.718 .985 1.174 30.866 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 19330.800 15.691 .494 13.361 19.129 5.071 5448.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 3117.354 8.575 5.817 17.208 92.679 .325 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 10987.000 18138.550 .008 67.528 .987 1.159 24.835 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 18912.340 16.230 .471 14.004 19.643 4.867 5455.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 3223.125 7.440 5.628 16.528 94.797 .306 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 10937.000 20875.570 .004 67.165 .993 1.240 22.295 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 19580.660 13.847 .434 11.167 17.451 4.080 5467.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 4261.828 8.500 4.898 13.509 98.744 .203 DEPT = NTMD = G4ER = SGBH = 10887.000 20110.370 .014 71.398 ABTN = SGFM = RSBF = SGIN = 20292.520 14.390 .467 11.813 FTMD = FSBF = RTMD = SGFF = 4086.212 7.761 4.922 13.949 Page 19 SIGQ = .986 SGFN = 17.964 NSBF = 102.579 SIGC = 1.218 CRNF = 4.105 PHIT = .214 GR = 21.644 CCL = 5472.000 DEPT = 10837.000 ABTN = 22042.430 FTMD = 4804.533 NTMD = 21443.770 SGFM = 12.197 FSBF = 9.171 G4ER = .019 RSBF = .493 RTMD = 4.463 SGBH = 64.630 SGIN = 9.201 SGFF = 12.382 SIGQ = .986 SGFN = 16.579 NSBF = 101.183 SIGC = 1.326 CRNF = 3.618 PHIT = .145 GR = 26.285 CCL = 5459.000 DEPT = 10787.000 ABTN = 23839.700 FTMD = 5685.411 NTMD = 22572.530 SGFM = 11.542 FSBF = 9.614 G4ER = .011 RSBF = .511 RTMD = 3.970 SGBH = 62.536 SGIN = 8.656 SGFF = 12.585 SIGQ = .987 SGFN = 16.297 NSBF = 107.136 SIGC = 1.333 CRNF = 3.110 PHIT = .089 GR = 23.035 CCL = 5460.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 t--~ 0 --- 93/04/06 --- 1024 --- LO --- COMCEN.007 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 ~ 0 --- 93/04/06 --- 1024 --- LO --- COMCEN.006 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 Page 20 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD LOG HEADER DATA 11187.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 10768.0 17-AUG-92 PLS-II 2.23 0952 17-AUG-92 11158.0 11173.0 10780.0 11165.0 1200.0 NO TOOL NUMBER GR GAMMA RAY TMD PULSED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 106312 106315 8.500 11222.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DEAD CRUDE 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 11000.0 BASE NORMALIZING WINDOW (FT): 11040.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): 0.0 Page 21 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #3. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 80 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 ABTN TMD 847704 00000000 0 4 1 68 FTMD TMD 847704 CNTS 00000000 0 4 1 68 NTMD TMD 847704 CNTS 00000000 0 4 1 68 SGFM TMD 847704 CU 00000000 0 4 1 68 FSBF TMD 847704 CNTS 00000000 0 4 1 68 G4ER TMD 847704 00000000 0 4 1 68 RSBF TMD 847704 00000000 0 4 1 68 RTMD TMD 847704 00000000 0 4 1 68 SGBH TMD 847704 CU 00000000 0 4 1 68 SGIN TMD 847704 CU 00000000 0 4 1 68 SGFF TMD 847704 CU 00000000 0 4 1 68 SIGQ TMD 847704 00000000 0 4 1 68 SGFN TMD 847704 CU 00000000 0 4 1 68 NSBF TMD 847704 CNTS 00000000 0 4 1 68 SIGC TMD 847704 00000000 0 4 1 68 CRNF TMD 847704 00000000 0 4 1 68 PHIT TMD 847704 DECI 00000000 0 4 1 68 GR TMD 847704 GAPI 00000000 0 4 1 68 CCL TMD 847704 MV 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 11187.000 ABTN = 24826.200 FTMD = 1175.493 NTMD = 6498.534 SGFM = 31.877 FSBF = 26.420 G4ER = .018 RSBF = 1.186 RTMD = 5.528 SGBH = 83.378 SGIN = 33.245 SGFF = 28.962 Page 22 SIGQ = SIGC = GR = .984 .959 59.084 SGFN = CRNF = CCL = 34.301 4.760 5419.000 NSBF = PHIT = 146.713 .325 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 11137.000 14246.260 .010 72.038 .983 1.131 101.348 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 29991.230 17.373 .968 15.364 20.727 4.875 5407.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 2528.221 13.245 5.635 18.415 117.523 .317 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 11087.000 10395.430 .008 70.599 .969 1.036 74.184 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 27596.750 23.573 1.060 22.746 26.563 4.880 5407.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 1843.409 11.410 5.639 22.531 118.227 .314 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 11037.000 19754.890 .011 70.376 .985 1.151 42.578 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 19790.480 16.515 .446 14.342 19.913 5.106 5448.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 3377.523 11.751 5.849 16.709 119.243 .347 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 10987.000 19467.960 .009 71.268 .990 1.145 31.527 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 18793.250 16.779 .421 14.657 20.164 4.995 5453.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 3388.025 12.340 5.746 16.643 121.244 .332 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 10937.000 21931.800 .014 64.918 .986 1.250 28.579 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 20848.850 13.624 .447 10.901 17.250 4.090 5457.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 4469.458 11.595 4.907 13.443 121.465 .199 DEPT = NTMD = G4ER = SGBH = SIGQ = SIGC = GR = 10887.000 21382.020 .017 66.631 .985 1.235 32.748 ABTN = SGFM = RSBF = SGIN = SGFN = CRNF = CCL = 22805.980 13.958 .509 11.298 17.478 4.187 5464.000 FTMD = FSBF = RTMD = SGFF = NSBF = PHIT = 4278.864 11.331 4.997 13.877 120.276 .214 Page 23 DEPT = 10837.000 ABTN = 24047.750 FTMD = 5049.730 NTMD = 22430.790 SGFM = 12.265 FSBF = 11.016 G4ER = .010 RSBF = .520 RTMD = 4.442 SGBH = 64.515 SGIN = 9.283 SGFF = 12.732 SIGQ = .984 SGFN = 16.459 NSBF = 124.170 SIGC = 1.321 CRNF = 3.596 PHIT = .143 GR = 33.432 CCL = 5466.000 DEPT = 10787.000 ABTN = 26413.720 FTMD = 6063.990 NTMD = 23947.040 SGFM = 11.189 FSBF = 11.708 G4ER = .009 RSBF = .538 RTMD = 3.949 SGBH = 65.284 SGIN = 8.392 SGFF = 12.233 SIGQ = .984 SGFN = 16.276 NSBF = 130.005 SIGC = 1.333 CRNF = 3.088 PHIT = .092 GR = 32.237 CCL = 5478.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 --- 93/04/06 --- 1024 LO TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: --- COMCEN --- 93/04/06 --- ANCH REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 93/04/06 --- ANCH --- 847704 END OF TAPE ENCOUNTERED Page 24 coe'i' R.~L:Uh:.L)-F'"FF'E I ::::;' REEL HEADER ........................ F'..ECnR r:: LEi".i 3-FH = ' ...... ' ..... .L .,'-~ ~. 5 RL...~ F:NM Y R....."'M C ...... r':,~ F'.. £ Fi_ Li"...~i','! E R. C: F' P....-ET~, F'N,'"! .................................l~-1t'-~m-.~ :S: I SFD c. iL CNF! -FI-IFI~ USFiF:' :_;FD TFiQ~ F:L F.':;EF';T Tn c: ]: T , "'" "- -"-' ."- -=t,.. ~ r ~,~, ~ .:,'-' L:",_. C LF'IG E:-' i -':'!. iq R S; A ::, ,, F-.ECCF. D T'",'"F'E 2:i',2 COHPIEN-FS .......................... ..... ~ ": P ....... A P.. C: C A L F:~ S i.'::.A 'r N C. L. U: ~, ,:-e..t '~ I"4~-'P'iFi. ~, .~.,! E L L. NAH E ' :]. 8- 2. 7 F i ELD ,~PFUDHOE BAY t... U,JN7 ~ = N 0 R"F' H S L 0 F' Fi C C LINT R"f = Ij SA R Z G = Ft. OHF~N .l,f,. 41 R. EC:OF.'.D TY?E 1:30 TAF'E HEADEF'. REC:ORC, LENGTH = 132 ,::-"', i 1y .... i . _ ' ,.:. h'.. ..... ...t ,i~'-, 'Y' R ...'h"! q ./Dca F:. L L -"- B 8 8," 0 2 ,'"' r-~ 9 F::"~Mh'iEN'TS,. ................... i SF'D & 1 Ct",if~ "TF~Qt I I'.SVD ,, SFD TOOL. CLOSES'7 ..... ..... r'n B'('T' , t::;',EPE~:%"!'' .:,"-'~-.. ...... .. LC'G [::: 14 H P,S ,~:% E:: ,: F.' i L..N.~%H, N UM HAP(P, L l~, , ~ ~', ~ _ ~. ~-. L L '-- ~, 0 !'i "., l 0 2 4 C:OHHEiNTS ,~ DF'.. i:'~'L~...~.L.' .:,"~"C)T :[ ON~:: .......... i-.,!.,..:' t-i';F[:, "!' :i qt E:, F P 3" F'.. ~ L - ~:; 0 Ii t-~ !I 0 N r', ...... 8 8, ROP ..q:.L.L.-E~ 80 Iii 0 O00 8 0 0 0 0 01 iii R.~ R I.._ L..- 8 0 t'.! t'3 0 Ii! l.-J i-I I-I I.-.l I"l 8 Iii !"I '] 0 4 0 0 ii ! [:, G R E; R L L.- 8 0 0 0 F~ 8 0 0 0 0 0 r) 0 n i fi "~ FI 0 R '~ F) G F:. C: R L L -- B ~-~. ....... n n n n 0 n ,_.n n_ "",..., 0 0 ~"~ ........ 1 0 4 0 n n 'i D E 14 F', Ft L L - 8 080 Cl 000 0 ~'~ n r-! Ct r-~ 1 0 4 0 002 D r2NFO RLL.-E'. 0000000 0 0 0 O 0 0 4 000 % D C:N F 1 R L L-.. 8 0000000 0 0 0 0 0 0 ! 0 4 n 0 ]i :L L, r4",lO RL.L-E; 0000000 0 0 0 0 O 01 ri 4 0001 D E:NNi F:.L L-.B 8000000 0 n 0 0 0 Ol 04 0801 D C:N P S R L. L.-B 0008000 0 0 8 O 8 01 O 4 00 O ! [:'- D E F'T fR. 0 F' G RA G R E: G R C: EI.4 R 10 2 E; 2,00 ..... 999,2:5 .... :2993,25 ...... 999,2:5 ...... 39'_:.) ,~. 25 .... 99'3,2:5 . ~ ~ ,~.~ ~..-, ...... ~ .., ._..... ~ , ! F! :: ~.'.'-: ;2' 0 r'~ :33 ¢:; 78 ,::, o 13 ':." ~'~ 85 .'7. ,s' q e 2 22 5 :q .=:= l']._ ri_ !:5 2 7 ,8. Fi_ ~.:..."' ._, =' ,_, = ,:.:'"" ~ F~ Fi 2. :3 6 0 ,, 0 O 6 5 ~ 8 0 l 0 4 6 :?., 0 0 9:3, '3 2 4 8,6 6 4 6 ~ 7:3 4, 7,7 0 1 2:3.8 l 99',:."' ~ 28 958~ O 7 35" 19,49 3459,0 2 P. 6 ,, 88 '~ .... 0._=; ,_.,": ,.'-':' ..... Fi F~ I n i ::...~- =.:, ! Iii 8 , :3 F', o,_, ~,.. , 7 2 ':~..., 8., Fi. ~.--,.. 2 7 , O. P '~ "-'"" '; ',52 'l :347 0 n 4200.64 ':',':q?q 36 16,90 ,.. ,,,".~ .,.,.i ,"/.,,;, ~ .... . ...... .. ,_ ,.. ,~ . I F~ 6 6 2 r'~ 0 er, ::: 0 ¢-i. ':-'.~5 68 'R'"' ,, ,, _ ................. :..t. O0 28:34 les 2.4 ..... .:, .J ._, ~ 8 3 i 3 0 4.8 9 4 3 2 9.6 7 3 9',7'6.0 0 ! 'E'. 4 4 ! r'j 7 E: 22,0 0 6 9,0 1 I 5,4 2 1 8, :i':': 0 ".l.. 6.8 6 8 2 g. :'3 9 1363, O0 '].395, O0 45'20, O0 4 I04., O0 i 3,38 10 8652.00 245,4:3 1:3,24 "i 4,9:3 14,0 S 386, ::-', ?, 887., 00 8 ::39,00 3720,00 3 '70 4.00 2_' 5,8 ?a :!. 0 962'.-.: ,, 00 197, :'a 5 23,81 ].. 9, '.2'.'_--.~ 20, r.! 5 26 F. , 50 ¢:~F, 1 21 ;:' 8 ..... 2 7, "" = 01" 79 396'7,59 :36:30 eR ! 3:. 0 62,00 90, '18 4:3,5'2: 38,72 41,12 20 ~ .57 849,77 8,45,24 3268 ,, 4 ! 30 71,75 2'.8,48 · 'i ':: '~, - '" !. i .,. ~:,,:.., 0 r~ z: ,, :3 :=J :34-= 22: 40,60 :37, ,"4.1 48,22 i 0 25 '~ 4. ;'* =''- 4 . ,,, ,. :37 T"',:.s c..~ fl "~" 5':_:.'3 .... :: ..... :~ ,, 36:., 00 5 '~ -¢ ....... ¢... ,.' , R E C 0 F:. E:' -FY F' E i 29 F I L E T RA .'[ L E R ....................... MAX F:. L. N EX'T' F LNAH E 10 ;24 F:. E r": C F:. D TY F' E 128 F' I L_ E l'."t EF'.':~D E F: P.. L L..- !-] ,, 00:2 :L F; 24 L. LI ~,. I E N T '.E; ~ :':; F D ,~:. CA L T p DATA F' !--I F'.. [." P, L [:, '.:_; E iS:, ~ '- -',- r;,. i-) T'",'"F'E ,64 DATA FCIRi".IA-f- '.=;F'~-C: i F I ,_.~, ]] F:.EC:OF:.F.;, LENGTH = :L4SI--,-' ........,, c_..:,-' T'Y' P E :_--; _T. Z E C: 0 £:, E D E S C: R ";' F'T ! 0 N 4 "~ E', U F',..'" D Ol,..iN F L A G = - 1 23 _i F'_, F~_ LI-F F'I_IT D E PT H c-~, ,_~ ..... G = F~_ 1.4 4 A UN ": T '.:_; r't F ,_.. E v t ~ ! N DATA R E F: 0 F', E:, '.3 = F T :]..?'~ i E: REF' CODE FOR F~UTF'UT DEPTH = [:, 0 0 E: T E F:.i'.'I ! NA']' 0 R [:,ATA SF'EC T F i CAT l ON BLOF:I-'::.f:; NAPtE '._:;RVCNi"i F~R. DEF',NUI"i i_li'.,l'rT LCIGT C:R.k.;T CR.k?C AF'Z!'"I F.T.I_NL.IPI SiZE F'LL,,(L. D £ F-'T F. _ L.- c, 0 0 i"10 !-I El i"i i'-I T iq [3 Fl F1 FI 2 I"f 4 I'I 0 FI :L SDF'S RLL-B 0000000 0 0 0 0 0 02 04 0C01 C:ALI RLL-D 0000000 0 0 3 0 ] 02 04 f::O01 D E P-F S D F' F-; C:A L. Z 10 ;:::' 62,00 .... .399 ,, ;::;.-':.'.='i- 999.25 10 :_-.-:62.00 2. 4., (57' I. 2:, 46 ..,_"~ 0 ,'"~ E; 2 ,, 00 ;=-' w. ........ ......... ql ,...,':' = 1. Cl 5 ¢~ '.':, ' , 0 [1 ?, I':l . 3 el l~l , 6 3 10662, O0 .'-~0. "k2 8.99 1 F~ 7cF., 2 ~.'. ~] '::' =; 27 L:.: '::' ''~ '~ 0 R E':,:' 00 .'! 9 f'l -':.~ D '"" :1. 0 9 6 2., ~]~ 0 2 5. F', 2 9, :1. :3 .....'~ I 0 G 2,0 0 I ¢; ,, :--: 0 8, .:Cb'-'" 11162,00 ]. 6;, ~ 7' ,9, G 2 R. EC:OF.'.D 'f'YPE 1;:.:"_--.~ FILE TRAIL. ER F.'.ECOF',D L. ENG'TH = 62 F .,"(. LNAM ,, N LIM PlAX F.'. L ..... -b ii F/ 02' 4 N E:x:"l'" F LNAM E ELbr,..L., TYPE 128 F']LE HEAE:'ER F(E'.F:OF:'.D LENGTH = F I Lh.~-~N N LIM hlAX R L F.',L.L..--B .00 3 i 024 C OhlM ENT S; REPEAT SECTION N,," SFD TOOL., F' REV F LNAPIE RECORD ]""~'"PE 64 E:,A-FA FOF:.MAT SPEC]:F:'iCAT]:CJi"....t .......... F', E F: .... '"', R ..... r', L FN GT H = 4,,. G F:.. E:YT E S T"FPE STZE CODE !;;:'ESC:R ~ PTI ON 4 1 B I iF:'.." C, 0 N N ~- "" c. ...... t- L_r'-t,.~ = -- ].. 1:3 :~ ' ' ..... ' " ..,- B OdtPUF DEPTH F'LAG = 0 14 4 A UNZTS C!F DEPTFi .'(N DATA F',EC;CIF'..DS = F'T 15 2. i:3 F:.E'F' CODE F'OR OU'FF'LIT F.:,E:P'FH = L':' 0 0 E', 'T E F;.'.M I h.iA'r 0 R DATA SF'EC: NAhiE._,'::-r~'~- ~p.~,.m,.~, ......., .,, ORDERNUM i il,.ll'T' ........ LF'~F:';-F CF',UT CRL..~C ~.....~.,'- :(I"t F"[ L.r,.f. Ui'., SIZ. E r ~, C: 4. C~ 4 i}]i.-.i 7:. F:. L L- E: 'a L] A FI A A Ii', t-; L-I Ft 0 i-~ P, :3 C: 4 i-': :".4 L-~ 4 04 C.N F' :-'2; F', L L.-E', 0 0 0 0 L] 0 0 A 0 0 Ci I.-_! 0:7:; D E PT RAT CN iF I F~ P; 4 8 50 :--~ --::3::3q '-':' ':'~gq :25 .... :-.~,.-':l.~c-~ '-,,= .-c.~q9 ":'.=i 1. Fj ~S 4 L--[= 5 fl IL 2 E:, 7--" I.-.I ]. '?, G 5 2 Fj , '.~ 0 1 O 72. 7 F, :l. Fi 117 O 0 :'-': 9 9 ~'."-',, :2, E', ":' '~ o .-'~ 00 ]. 0748.50 ._=.. :16, IL7 ].. 5 2 3,, '~ ~"~ ',:: 4. ::: 5 O i iL '-' :::~.=, I '--''~ , 8 2 'L F~ 2. 'I. 866 60 834 60 391¢:, s, 9 '-'==-'* 86 ,~ ~ -- . , -- .2} ,..! ...I f . . 1. r~. 94 ::::: .5 834.7!, 7 7" '? 0 ,, 14 :B 73 E',: ]. 3 33'9'9 ,. 8 :.]... i :L i"[ 4 :::',, 50 I :st Fi 2'9 29 =-- ='- ":' }'.' .4 ~:-~ 92 iB, 9 9 8 ;24,38 3 8 40, '9 :..3 3 4 8 7~ :::39 2. i I. 4 E: F; A '-'1", = .... , ..... .-:3~ 31] '.2, 9 ..... ,:L 4 3 48 ':'-'"' 8 3 9 00 _ c, ,, .~., 0 0 , 3 7 3 6,0 0 3 5'? 6,0 n GRC Ci".4 P S --999,2:5 .... 999.25 ]. q .-, 2 2,7 6 :L3 ~ 03 28,3E; 3O ,12 2:E:, 50 2 6 ,~ 3 2. "'" 5A 27' REC:ORD TYF'E 12'2~ FIL. E -FRAI[..ER ......................... , , RECOR. D LENGTH = 62 F ~' L. NAM N I"" . , . ,"~ MAX P, L F:. L. L.- 8 .00 3 2. O 24 R E C: 0 F.'. [) T'Y F' E 12 S F I L E Fi E A D E F'. P. ECORD L. ENGTH ;= 62 F I LNAM ,, NUN MAXRL P..L.L-B ,00 4 2. 0 24 COMMENTS: SFD~:-C:ALIB DATA FqF'. '"~' .... ' ~ .. ¢..~:.I-EA'T SEC, P REV F L.NAM E 13 L-! !31 0 F! 0 'l 9 t3 O 'i i3 l} Ct 'I RE:-_:ORD '"I-"FPE 64 DATF", Fi-JRMPFF SPECiFiCATION RECORD L..ENG-FH = ].48 BYTES T Y P E S I Z E C. 0 D E ~...~', ,......, ,_.:, =' ':' ''~' ~'::' ,.'r p"T .i: 0 N 4 I., E: UFY'DONN FLAG = .... 2. :L3 ]. F; OUTPUT DEF'TH FLAG = ] iL "l. 4 A UN .i T S Ct F D E F"T H i t'"4 DATA R E C: 0 R D'.E; = FT 25 E E: REP (:.'ODE FOR OLJTPU'¥ DEF'TH = D 8 0 S TERM t NATOR !-':A L i F:. L L-E', t'] i-i Fi 0 ri Ill 0 iii :] Ci Fi Fi F~ 4 FEC-R.[:, T'Y'F'E '].2I_--.t FiLE TR. AiLEP, ...................... F:. E C 0 R. F:, L E[''4 fat H = 62 F t Li"-,IAM .-. N LIP1 ?'IAX Fi. L F..LL--'.- 004 :Ln24 h.,~ E >'-:.T F LI"..,~AM E R. EC:CF:D TYPE 128 FiLE HEADER. RECOP..D LENGTH = 62 F' '( L. NAM ~ N UI'-'I MAi:,-.':; R L P..LL.-B .,005 L024 COhIHENTS: DF:.ILL. ED SECT'.-.tON F,i,.," CNO TOOL, F' FL E V F' L. N A M E ,'-_l 4 0003. F.'.EC(]P..[) TYPE (:;4 DATA FORMAT SPEC IFiC'ATiEIN F.'.EC:OR.D L. Et'..iGTH = 468 BYTES 'TYF'E SIZE CODE DESCR. ]: PTi ON 4 :l. B UP.,'"DOI,.,,tN FLAG = .... :'L:3 :i. B OUTPUT OEP'TH FLAG = O Z a 4. A UN .T T S IiIF [:,E PT FI t' N DA'FA F,c_ .... R. [:~_. = F"F :1.5 "L [3 REF' CODE FOR OUTPU'T DEPTH = .D 0 0 B 'T E Rid i NAT 0 F.'. E:,ATA SPEC':! Fi CAT ! 3N BLOCKS NAi".!E SF'.'...,'CNPI ORDERI'4LiM UNiT LOGT CRVT C:RL.~C APiM F iLNUPI SIZE PL.~,,L D E PT P, L. L-E: 0 0 0 0 0 0 0 0 T 0 n n 0 F 5 O 4 n r~ 0 '~' ._ - t ' , . .... =' 0 s 0 C 0 2 R Fi p F .....L- E, 0 0 0 0 0 I'i L] R ~"~ O 0 Fi 0 ..... GRA RLL-E~ 0000000 0 0 0 0 0 05 04 O03Z G F.', E: P-. L L -. B 0 0 0 0 0 0 0 0 0 0 0 0 0 5 0 4 8 i] 0 '! :.:~ ..... ~-,..' C R.L.. L -- B 000 ::.) 000 n ..... n n 0 n.,., n ...... ~ n 4 000 :i E:N P, F.: L. L -B 0 0 0 0 r~ 0 0 0 0 0 0 0 0 5 0 4. 0 0 0 :l. ..... ,-., F' 0 P.. L L - B 0 0 9l l.] ":? '2 C' 0 0 0 O ~"'f_ 0 5 O 4 u 0 f'~ .... 'i C:[`,i F 3. R. L L- B r'j 0 0 r:~ 0 0 0 0 n 0 n C 0 5 0 4 0 0 0 'I C:NN 0 P, L L.-. iS: 0 0 0 0 0 0 0 0 0 0 O 0 0 5 0 4 0 0 } '! C:i",l F' 0 C:N F 2. C:NN 0 r":N N' i C:f'..t F' S __ ,7~ ,:;~ ,...m ~ ~ ...... i 'M '-i '..-., ~ _ ,7.:~ C~. '--i ~ ~, -- ,'-~ ,ri ,7- '-' ~= ..... I'-t '-i '--' ~ ._~ _.._. _, _, _. _.. ....... ,-". I _. _, ._. ,~.....,~ · ' A_ :.?, 2 _..q, R_ I-!. 4 q_.: .:,'-' ~"' F, .... 2 - ',:; 7 ;-'; 6 ,, 4 '_-3 ._':--'; 4 , ::_:; F_", Z 71 , 7 :-3 507, i 5 503: ;2 ,:£ :;' ,:--';'! 7 = '.:J' :3 2 G 17. '3 :_--: 5'3,2 S :'],'.. A 42 '-~ R A 2 ~:-S 7 4 a ¢g"i ~:-$ :':', ~-~ ::: '--"' ::' ~:--; R :':', 't 2 F! L:...~ ':'~ .-:'-' E: 4 S.'~ ,, 0:3 ::_--: 37., 3 S :--': :36 i: l ;2 ::: :':: ,;:; 2,' . :]_ ;2:---: !] , ~:-'"; 2 t Ti Fi,'-2'-3 ."-] F, :':t ;2 i :; ...... .::'~ F, = '-, ',:', S': .5, 2 . ,4 '-,.--' ".~35 'I R 2 77 =; ;:: F; 'l 7' 24 ,:X 2 48 i--'~ 2. "~ = '"' ':' '--'~ ''~ "~ ':'-~ ..... ,- .... _, ., .... 2'" 42 '~ '- ~-C :;' ':.~ q ? =- L:', ;d :::, 6', 6; W H, ::: ::: ....... ; ~ i___ , .=i_ Fi_ _. ~ :: ...... 2 F,, .'_:I 7' 4- '~. ;:', 'l [I iL l-I '] 't ...... I' 4 ':t :_q g-, 1~ i-I ',-ZI 4 :?, ~'::-;'~-; !]i i~i ~- 2 ~ '] -- . --.' '--' .,' m _- - ~ ~ = .m _ "' F1 T- ? ,ri F, I-1 ~' ''~ : ,-' ,:2,. ',7' '? ":; = '-' '---"rS ;--.. ;.5 , ._~ ..~ :---' 1-I . , ,-, '-' '--' ."~ 'E."' 5'?' ,, [! 0 '"i. 0 27 ,, 00 ::; ir 2 III , 0 ii 3 l.':' 2: FI , 0 FO Fj ::: = 'l 2 2. 0 82 b3 % II 't .~ 2' ,:.~ ,a 2 Fi ~ ':~ ':'"~ :34 '-' =' ':-" -" ........... . ............ ,--.,, :3 F, '-3 .5, 4 . -- --.',' ---- z 7 :-3 :::, 00 7' g 7: CI fi :3464 ,, 0 fi :34 E, ,4.. ;;l 0 :--', 2,06 :]~ 0 E~, 2 '3,50 ..... 'l 7 A._,._':' .~ ....... 'I ':.~. ,, ",_' :3 :;' fl : 24 :Z _.':'~, 69 ;2 ._,"" ~:I. .. '-'~ :.::_." - 7" 3 '? ,, 7 ~': 770 , (] 2 34 ',:: 7, :]. 0 34 E', 7,2. 0 :R 2 ,., 0 & 'I. 1 I-I ';":.~ 5n 1 ',:32 '-"-' :'-]:--: 41 :.:::.-_: ................ ¢.._, ..... ....... ~-.._-, . - - : = '::.'--"; _ qi :: '-' = Zt i t-1 ~ F:':.~, _._ , ...... 1 ':~. -':--'~,.- ,..., ,, 4 8 :352;2,2.1 35::.!:2, i i 2,5, ,.': 1 .. m_- 'Z, ~. - - 3.. i '1 '-2':~ 5 F! 3 4._, 9 q':3 '-' =' - '-':-~ q':~ ~=._, --'.,..~'-4'3 2 F, ...... '2:5 .......... .-. ......~: ..., .......... _ ,-] ,--~ cj R E C 0 F', [) T'"¢" F' E i 29 F ! L. E T F.'.A I L E R ....................... F:.ECE i:;: [:, LENG]'"H = 6;2 F' :f. L!'..~.AI"'I, N Llht f'.tAX R. L. [", ~_ L.- ~::, K! R R :t. ri ;24 N E>('F F' LNAI"t E RECORD-F"fF'F '32:3 F~LE HE~.~.E)~.R F;.'.E' Z: fi R D L EN G'T' H = 62 F I Lt'...tAM. NUN MAXRL RL.L-S ,006: i,,024 E: 0MPI ENT S: -" i","' C.:, "-'". 't' - h.,::, F£~-..~ ~ '.:; E' r':T T CtN M./ CN 0 T 0 f'i L, R. EF':r'ip. ....... C' T'fF'E 64 DATA FOR. t"'IA'T c'PEC....., I F i CAT !7 U,-~'~,., ,, ,, ,, ,, ,, ,, , , ,, , RECORD LENG'FH = 46;8 BYTES TYPE S i ZE CODE: DESCR I F.'T I ON 4 2. B UP,'"DOMN FLAG = .'13 i S OUTPUT DEPTH FL. AG = 0 14 4 A UNITS OF [:,EPTH i1'.4 DA'I-A REE:OF:.D'S' = F"'F 25 i I:3 REP CODE FOR OUTPUT' DEP"FH = 0 0 B 'TERPI! NATOR DA"f"A 3F'E Z:i F ! CATE ON BL. OCKS NAME SR.L..~C:NM C. IRDEP, t'-iLih! UNiT L. 0G'F CRt.)'T C:RL.JC AF'!PI F't'L. NUN SiTE E:, E F:'T R L. L-B 0000 ['J 00 0 T 0 0 0 0 06; 04 RATE F.'.L L-B 0000Fj00 i":' ' r-, - I'! _~ F, c:, i< L. L -B 0 0 0 0 0 ~.'.! 0 . 0 _ 0 0 0 6; 0 4 G F.T. R L L.'--E, 0 0 0 0 0 0 0 0 0 0 0 0 O 6 0 4 EN P, F< L L.- E: A 0 r~ 0 ~"'.~ 0 0 0 0 (] 0 0 0 6 0 4. F'L. VL 0 0 01 000 ".t_ 0 0 0 i r2 0 fl '1 0 0 0 i 0 0 f"~ :l C:N F' ] R L L-E= '..]f 0 3 ~':," (.S 0 r.) 0 0 0 0 0 0 6 0 4 S ;'~ 0 :.]'... D R. EC:SRD 'FYF'E !29 FiLE TRA!LE:P, ...................... RECORD F'I LNAH, RLL-B RECORD LENGTH = 62 N (.IH PiAX R L N EX'T F' L..NAM E 006 1024 TY F:' E :i 31 T A P E m R.A i L E R ........... ............. RECOF'..D LENGTH = 132 S RU CNH ]'"R ,"H 0/" DA TA F' ENAPI E R 13 NXTTA F'NM F::. L L -- E: 3 8..'""' C 2 ./0 9 :i...,/:ii. 01 COHhIEN-i"'S: I SFD ,(: '~ C:NO TOCIL. "-'-' ... . ........... L.,.::,E.E:, SFC, 'FOOL... F':L n°.:;F'-'.::::T 'T0 E:iT , REF'EAT S::C ~..': ,,..,'-':-',.: D .~4 HR.S AD. rs:. E Ii:C) P.. D "FY F' E 1:3:3 R E EiL T F:.A I L E R ....................... P:.ECORD LENG"FH = i:32 S R~. .~ CF.iPi Y R.,.'"H Ill..,' DA R E E LNAH E F:. C .~..,.,,,, R E,_I-41-, RL_L-B 8:=:/0 2.../0 ~ 87-12---24 Ol C:n['dMENTS*, .......... i '::;FD,=..¢'-i F.'NFI ......... TOOL t i'.SED "";:.F L T00L. F'.~.PO.CRT_....,,_.., ":'F:_ 8':'r. ,. , , REPEAT SEC: ':,"IG, E:' ::)..4 HRS AD, RECEIVED JUN 2 ~' ]990 Alaska Oil & Gas Cons. Commission Anchorage * BOROI,,IG}~~ : NORTH S'[.~OPE STATE API N[j~BgR : 50-029-21,768 REFERENCE ~C~ : 73890 I$ Ta~e Verification List i, nc~ ch.lUmberger AlasKa Compt]tir~q Center 12:30 **** PEEL HE~OEE **** SERVICE ~,~E : EDIT L ~, TE: : 90/06/20 O~I~IN : ~LIC R~EL ~A~¢E : 73BqO CONTINUATIOI~ g : COM~ENT : A~C[) A[.~SKA, !LC., PRLI[)Hf]E bAY, D.S. 18-17, AP1 ~50-029-21768 SEP¥ICE~ ~A,~F7 : EDIT DATE' : 90106/20 ORIG] i'~ : FblC TAPF NA~E : 7389o PRE-;VIOI]S TAPE : COM~ENT : ARCO AT.ASK.A, iNC., PRU[)t~OE'..~.>AY, D.S. 1~-17, AP1 ~50-029-21768 **** FILE HE;Al)ER **** FILE N,~ IqE SE~v!cE : FbIC VERSION ,, 0 0 l ,~{'.)4 .DATE : 90t06/~0 ~AX ~EC SiZE : 1024 F I I..,E~ TYPE L~ST FILE PAGE: ********************************************************************************* ******************************************************************************* ** ** SCHLIt~,BERGE,R ~EI,,L SERVICES ** ** ** ** ******************************************************************************* ******************************************************************************** CO~,,~iPANY NA"~!E;: ~RCO ilLASKA, INC, .~! E.t,b: D.S, 1.. 8-17 FIE;L[): 'PRUDH{:,~E E~AY BOROUGH~ i'~l[]~T~ SLOPF STATE: A,LASKA AP1. NLI~BER: 50'0~9'21768 L[!CATI('...1N: 1.242' F~.iL & i, 46' F'EiL $ E C T l'. 0 :r~: 24 T 0 W I,~.! S i.~ I P: 11 N RAN(;B:: PER~.~NENT DATUM: ~'~Sb ELEVATION lis Ta~e Yerlf..lcatJon l.,J, st. jnq ehlUm[,er(~er AlasKa C. on'.p~ut:i, nq Center 1.2:.t0 FI, EV~TION$ Ki3: 4~ DF: 45.5 GL: 17 P~-T[~: I,OGGED: DRILLER: I,t)GGER: CASING 23-~IAY-1990 ONE: 11176 11176 518" 47 LI~ @ DN!L,[,ER DI~PT'H f)F O TO 1,0350 ?g Lb (a O~II, LER DEPTH (.iF ~0118 TO 112~2 112" 9,3 Lr~ r,.~ DRI. LI,E~,' PF]PTH OF 0 TO 10774 BIT SIZE 1: 1.2 1/4" BlT SIZE 2: 8 1./2" TYPE FLUID IN HOL, E: FRE',,DUCEiD FLUiPS TIP, E bOG(;RR ON BOT?O~,~: 15:57 23-MAY LOGGING D, IST~:iCT: I.,O(;G ! NC E~,iG I i"~ EER: w I TNESS: CAL-dB 3al. CNT-D 101 AT~',~- A ~ 283 PORTER A, TC-.C[~ i 163 NSR-[,A 3039 CORREI~.ATE;D TO CNL E!F 07-JAN,-88. OPEN PERFS.. .11040-50~, 1,1070',,'84,, 1. I098""111.06,, 1!.1.1,4'1-,~2~ 1.11.3¢t".158~ 1,1162,,170, bOG(lING PASS #.."1., DID NOT REPEAT '~HICH C()U[,,I) RE DUE Ti] Fbi!IL.) STILL, BEI~iG PUMPED WHICH COt,,l[,[) ~iA. VE CAUSE][) GAS Ti] BE IN THE WEI',,~I, BORE [:IR IN THE; FC,)P,,I~ATIO,~',I', GA5 'L'~AS F'RO~, I:)RI'GIt'~At~ DATE JOB STAR'rED: 19-JuN-g0 JOB RF, FF, R~NC'E: P,~,r,): 73890 [.,DPt~N~: K. OHRI!',.tG PAGE: IS Tape veri~icati, on l,istino chlumberoer Alaska Comuutinq Cer~ter 2()-dON-199~. 12:30 DATA !i,:C. LUDED- TOOT, ~:XTENS TON T[]f~L TYP£ USEr~ NA~: 11174' TO 10252' 11174' TO 10228' 11174' TO 10163' 11174' TO 10240' 11174' TO 10240' pAGE: TABLE TYPE : CONS TU~iI VALU DEFI CN ARCO AbASKA' I~C' Company Na~e F~ PR~DH[:tE BAY Field ~ame WN [') S 18-17 ~ell ~ame a~I~; 56-629-2176~ API Serial. Number FL 1242' ~'~NL & !46' FEL Field Location S~CT 24 Section TOWN 1 ~ N Tow'~ship RA~!G 14~ Ranoe C C ~,.! ~ ~ O ~ T ['i ;3 L [) P E C o u h t y $~,~T ,AI,,A$~A State or Province NATI USA ~ation WIT~ ~EIMTS/~OR~IS witness' Name SO~ 391148 Service Srder Number PDAT ~SI,., Permanent datum EPD FT L~F ~i~.,~:ii hog ~easured Fro~ APD FT EFiB FT 48, EDF FT 45,5 EGL FT 17 BLI FT 1,1173. Bottom I:,o~ I,terval TLI FT 10250. Top boq Interval TLAB 15957 23-~h¥' Time boq~er ~t Bottom IS ]laDe Verliication L, istlr~<,] ChlUmherger AlasKa Computinh Center 20-jUN-199o 12:30 TABLE TYPE : CURV DEF! D~PT cth n m NP~ Neutron Porosity NPHI ~etltron Porosity T~:~a CalibrateO Thermal >.~eutron Ratio RCNT RAW NEAR CNI COLI~:TS RCFT RAW FAR CNT COUNTS CS:TC Corrected ~,}ear Thermal Counts CFTC Corrected Far Thermal Counts G~ Gamma Ray TEt~S Tenslon CCI., CC5 a~Dlitude ~PHI ~eutron Porosity Th~ Calibrated Thermal ,',Ieutron Natlo PCNT RAW NEAR CMT COU~TS RCFT RAW FA~ CNT COUNTS Cb~TC Corrected f~:ear Thermal Counts CFTC Corrected Far Thermal Counts GP Gamma Ray TENS Tension CCI, CCI., Amplitude NPH! Neutron Porosity TNRA Calibrated Thermal Neutron Ratio ~CNT RAW NEAR CNT CO[~NTS RCFT RAW FA~ CNT COUNTS CNTC Corrected ~,~ear Ther(~al Counts CFTC Corrected Far Thermal Counts GR Gamma ~ay TINS Tens.ion CCL CCL ~mplit~]de N P }'"} I Neutron Porosity TNRA Calibrated Thermal Neutron Patio ~CNT RAW ~E~R CNT COONTS RCFT RAW FAR C~,~T COU~TS CNTC Corrected ~,lear Thermal Counts CFTC Corrected Far Thermal Counts G~ Gamma Ray T E', N S 't e n s I o n CCL CCL gmplitu, de PAGE: ** F.~AT/~ FO~AT SPECiF'ICATION RECOI:::D ** IS Ta.~>e Verification l,istin(~ chlU,,herqer AlasKa Comuutir, q Center 2()-Jt,~--1990 12:30 ** SE 'NA~;E RV UN'I ID l) E P T F T N P F! .T. HLA PU NPHI .,PSi PU TNR~, PS1 l?,C N T PSi CPS RCFT PS1 CPS CNTC PSi CPS CFTC PSI CPS GR PS! GAPI TE~S PS1 LB CCL PS1 ~ NPHI PS2 PU T~.~ PS2 RCNT PS2 CPS RCFT PS2 CPS CNTC PS2 CPS CFTC PS2 CPS GR PS2 GAPI TENS PS2 LB CCI., PS2 V NPHI PS3 PU TNR~ PS3 R C N ~,7" PS.3 CPS RCFT P83 CPS CNTC P83 CPS CFTC PS 3 CPS GR PS3 GAP! TE~QS P,83 b8 C C:6 PS 3 V NPHI PS4 PU 4 66 5 66 6 73 7 65 ~ 68 0.5 9 65 11 66 6 12 68 13 66 0 14 65 FT 15 66 6e 16 66 1 0 66 0 T 'rYP~: - CHAN ** ORDER ~ LO(; TYPE CLASS M 9 8 O. 000 O0 39114~ O0 000 O0 391.1,48 42 890 391,.148 42 420 O1 39.1148 .42 420 01 391.148 42 420 O1 391,148 42 4~0 O1 391.148 4.2 420 O1 391:148 42 310 O1 391148 42 635 21 3911,4,8 42 150 O1 391148 42 890 O0 391145 42 420 01 391148 .42 420 O1 391148 42 42() 01 391148 42 420 O1 391148 42 420 01 391148 42 310 O1 391. :1.45 42 635 21 39 1148 42 1,. 50 0 39 l, 14. 8 4:2 B 90 00 39!,1.48 42 420 O1 39!.1.48 42 420 01. 391148 42 4.20 01 39114.8 42 420 0! 391148 42 420 O! 391148 42 310 O1 3'91148 42 6:]5 21. 391148 ,42 150 O1 391.148 4,2 890 00 3911.48 42 4.20 O1 I F! E MB NUMB I E REPR ROCESS OD NUMB SANiP EbEM CODE (HEX) ''''''''''''''''''''''''''''''''''''''''I 1 68 0 00000 0 1, 1 1 4 68 0000000000 0 1 1.,, 1 4 68 0000000000 0 i 1 1 4 68 o000000000 0 1 1, 1, q 68 0000000000 0 1 '1. i 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 I 1 4 68 0000000000 0 1, 1 1 4 68 0000000000 0 1. t I 4 68 0000000000 0 i 1. :1, 4 68 0000000000 0 !, 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 I 1. I 4 68 0000000000 0 1 I 1 4 68 0000000000 0 1. ! I 4 68 0000000000 0 1 .1 1 4 68 0000000000 () 1 1 :1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1, I 4 68 0000000000 0 1 t 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 i 1 :1 4 68 0000000000 () I 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 0 i 1 1., 4 68 0000000000 0 i ! 1 4 68 0000000000 0 1 1 1. 4 68 0000000000 IS ~aDe ~erifJcatJ, o~ Llsti~q chlumberoer Alaska Co~,~putJnn Center 20-JLiN-1990 !2:~0 PAGe] E~RDE~ RCFT PS4 CPS ]91148 CNTC PS4 CPS 39114~ CFTC PS4 CPS 391148 GR P$4 G~PI 391145 TENS P$4 CCL PS4 ¥ 39114~ ~ I.,0¢; TYPE Cl.,ASS ~;CD at;~B SA~P ELE~ CODE (HEX) 42 2(i) 01 1 t 68 0 000000 42 42C O1 0 1 1 1 4 68 0000000000 42 420 01 0 ] 1 1 4 68 0000000000 42 420 O1 0 1 1 1 4 68 0000000000 42 310 01 0 i 1 1 4 68 0000000000 42 635 21 0 1 1 1 4 68 0000000000 42 150 01 0 t 1 1 4 68 0000000000 DFP~' 11209.500 RCNT'[PS1 3573.201 GP.PS1 59.31.3 TNRA PS2 -999.250 CF~C:PS2 -999,250 NPH~.P$3 -999,250 CNTC,PS] -999,250 CCI..PS3 -999,250 RCFT.PS4 -999.250 TENS PS4 -99a 250 NPHI.HLA -999.250 NPHI.DS! 30.647 TN~A.PS1 RCFT.PSl 734.491 CNTC.P$1 3715.647 CFTC.PS1 'rE~s.P$! 1020.000 CCL,PSI 0 000 NPHI.PS2 RCNT P$2 -999.250 RCFT.PS2 -999:250 CNTC,P62 ' 'P62 -999.250 TENS.PS2 -999:250 CCL.PS2 GR'ps3 999.250 RCNT.PS3 999 250 R, CFT.P$3 TNRA. ' - CFTC,PS3 -999.250 GR,P83 -999 250 TENS,PS3 NPh!.' PS4 -999. 250 TNRA.PS4 -999~250 RCNT.PS4 CNTC,P$4 ~999 250 CFTC,PS4 -999~250 GR.PS4 CCL,P$4 -999:250 D E P T, ! 1200.000 N P H I. F! b/~. RCNT.PS1 3527.777 RCFT,PS1 ¢;~.PSl 59,313 TENS PS1 TNR~,PS2 -999 250 RCNT' CFTC,PS2 -9gq' ' ,P82 ...... .250 GR. PS2 '¢ ~ 250 T;:.~RA PS3 NPH !, PS ] .)99, CNTC'PS3 '999,250 CFTC:PS3 CC[.~, PS3 -999,250 RCFT,PS4 -999,250 CNTC.PS4 TENS, PS4 '999,250 CCL. PS4 'T l ! ! 00 000 DEF'.., . 626 RCNT,PS1, 2626~ GR, PS 1 23,67:2 TNRA, PS2 5,203 NPHI' PS2 532,854 . PS 3 32,279 CNTC, PS3 2689.781 C C L, P S .3 0.000 RCFT. PS4 5,44. 544 T E NS. PS 4, 1. 325,0 0 0 11000.000 PSI 3870.207 PS1 21,859 PS2 5,875 PS2 525,524 ,PS3 36,51.0 D E P ? R C ~.~ T T N R n CFTC N P H I: -999 250 740 496 1320 000 -999 25O -999 250 -999 -999 ~ 0 -999 250 -999 250 -999 250 31 250 577 154 1800 000 2565 130 21 5.317 516,94:0 30,204 269~,968 0,000 36.475 974,460 1770.000 3043,043 14,21.9 5.~()6 NPRI,PSI CNTC,PSI (:c!~~, PS 1 RCF',PS2 TENS,PS2 NT PS3 RCGR,ps,] TNRA,PS4 CFTC,PS4 NPHI,PSI CNTC,P$1 CCS,PS1 RCFT,PS2 TENS,PS2 RCNT.PS,3 GR.PS3 TNRA,PS4 CFTC,PS4 29 637 3664 341 0 00o -999 250 -999 250 -999 2.50 -999 250 -999 250 -999 250 29 694 28.1,0' ,979 0.000 576.577 1390.0(.)0 2575,757 2~,094 ,069 532,86.3 22.472 3970,091 0.000 539 326 1365:000 ~ 0~' 29.0 675 TNRA,PS1 CFTC NPH! PS2 CNTC PS2 CCh PS2 RCFT P$3 TENSPS3 RCNT,PS4 GR,PS4 TNRA,PS1 (]FTC.PSi NPHI,PS2 CNTC.PS2 CCh PS2 RCFT:PS3 'TEN~.PS3 ~CN ,PS4 GR,PS4 CFTC.PS1 " '' PS2 CNTC,PS2 CCL,PS2 R'" PS3 5 122 725 365 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 5 000 735 794 -999 250 -999 2:50 -999 250 -999 250 -999 250 -999250 -999 250 5,007 557,765 3t,320 2726,355 0,000 540,019 .1355,000 2661',322 23,938 4,085 988,889 37,122 303~,539 ,000 493,732 IS ?ave Verif. icstion Li chlumbercer ^].aska Comp Clv TC. PS3 3048. 435 CCI:, P$3 0. [~CF~'. P$4 555,669 TENS. PS4 1330.00() DFPT, 1090o, 00o ~C~.T, PSi 3803,53b GE,PS1 31. ,328 TN~ , PS2 4.651 C~TC.PS2 796.256 IiPH] .PS3 23.965 CMTC, PS3 3864,450 CCL. PS3 o, O00 RCFT, PS4 833.5o 4 TEMS,PS4 ] 300.000 ..D.~TpT. 10800. 000 RC~.~T, PS 1 53!2,377 GF.,P$1 13.336 T~RA.PS2 2 7..64 CFTC, PS2 2137 ~ 609 NPHI, PS3 13i 522 C~TC, PS3 5962,276 CCL, PS3 O, 000 ~CFT. PS4 2084,1,68 TENS' PS4 1300,000 DEPT, 1,0700. 000 RCNT, PS1 5708,775 GR, PS1 14.281 TNR;~,, PS2 2,903 CFTC, PS2 1952,392 NPMI, PS3 1, ~, 472 CNTC, PS3 53!5,773 CCI,~.PS3 0,000 P,,, 4 20~ O. 215 .,,C~ U, , . TE'''~N~.,~, PS4', 1280,000 stinq UtlinQ Center CF'TC. PS 3 .,'~ p H I. PS 4 C~iTC. P$4 CCL. p$4 ~CFT.PS1 TEdS. PS 1 RCaT, PS2 CF;', , PS2 T.~:RA .PS3 CFTC,PS3 NPHI.PS4 CaTC.PS4 CCh,PS4 20-jUi'~-J990 12130 516.496 GR.PS3 35,8U9 TNRA.PS4 3071.904 CFTC,PS4 0.000 24,951 NPHI,PSI 091,150 CNTC.P81 1605.000 CCL.PS1 3464,7OO RCFT,PS2 26.875 TEiNS.PS2 4.283 RCNT,PS3 838,510 GR,PS3 24.517 T~IRA,PS4 3691.270 CFTC,PS4 0,000 1.3,135 NPhI.PS1 1793.510 CFTC.PSt 1,595.000 CCL,PS1 5733 733 RCF'f, P$2 16]266 TENS,PS2 2 876 RCNT PS3 2(, 69,585 GR'PS3.. 13.207 THRA,P84 6060'080 CFTC.PS4 0,000 13 3'79 2144 648 1425 000 4445 353 15 766 3 005 1,.930 ~ 108 11,769 4809,221 0,000 13,g86 2121, 08 1370,000 5850,~68 15.1,56 2,812 2149,895 13,069 6088,056 0.00() 1, 8 . 3 !, .tl. 1..650,2 1 ,i 10,0 0 5133.333 73,:125 3,532 ~J P f~ I, PS 1 CN,q?'C. PS l COb. PS1 [1CFT, PS2 ,'£ E', N ~, ,.~82 {.~C}~.t , 83 15,180 5.736 528.979 25.581 3879.322 0.000 800 801 1360~000 3677,800 26 219 4~355 844,108 15 012 5602i339 0 000 2173.646 1345 000 58321208 13.086 2,833 2113,853 043 1~ 696 592 0 000 1795 918 1340 000 4752 169 16 031 2 636 20.27 314 12 987 5885 824 0 000 21.89 990 11320 000 5783 89O 15 547 2 814 2164 084 16,706 5351,667 0.000 J,,5~2 605 13 5249,509 TENS.PS3 i~ChT.PS4 GR,PS4 TNRA.PSI CFTC.PS! NPHI.PS2 CNTC.P82 CCh. PS2 RCFT,PS3 TE~S.P83 RC~'Y PS4 GR:PS4 TNRI.PS1 CFTC,PS1 ~P~I,PS2 CNTC,PS2 CCh,PS2 ~CFT,PS3 TENS,PS3 RCNT,PS4 GR,PS4 TNRA,,PS1 CFTC,PS1 ~JPHI.PS2 CNTC,PS2 CCt..P$2 RCFT.PS3 TE~.$,PS3 RCS~'T"P'S4 G~'PS4 TMRA.PS! CFTC,PSi CN C,PS2 CCh,PS2 RCFT,PS3 TENS PS3 RC~T PS4 GR PS4 TNRA,PS1 CFTC'PS! NPFfI.PS2 CNTC,PS2 CCL,PS2 RCF'T,PS3 PAGE: 1330 000 29711429 17,797 4.493 955,863 26 821 37~1 273 0 000 83] 977 1320 000 3527 054 25 500 3 079 18151628 12.703 6005,205 0,000 074.656 ~355,000 5785,495 16,141 2 810 2095 472 13 720 5198.488 0 000 1774 349 1325 000 4228 228 16 2 803 2096 181 1 205 610~ 531 0 000 2206 365 131.5 000 5844 897 15 563 3 309 165 906 I~ 715 5325 750 0 000 ~541 790 IS Tame Yerificatio. Listlna ch]u~heroer AlasKa Co,:putinq Center C~}TC.PS] 537 ]~..bl8 CFTC.PS3 CCL. P$3 0.0o0 ~IPHi, PS4 RCFT'. PS4 ! 585.29 ! C.uTC. PS4. TENS. PS4 1255. 000 CCL. PS4 DFPT. i 040 O, OOO i{PH.[. RCNT.PS1 4306,483 RCFT.PSI GP,PS1 76,~25 TENS.PS1 TP~A,PS2 3,~05 RCNT.PS2 CFTC.PS2 1201,622 GR,PS2 NP~].PS3 21.229 TNRA,PS3 Ck. TC. PS3 4490.712 CFTC.PS3 RCF~. PS.4 ~25~{.427 CNTC.PSI TF~S. PS4 12~5. 000 CC'I,. PS4 DEPT. 10300,000 P. PHI.HLA RCbT.PS1 3206,2~7 RCFT.PS1 GR ' ? P,,1 31. 109 TE~S. P51. TNR~PS2 4.742 RC~"iT. PS 2 CFTC. PS2 725,689 GR. PS2 NPHI,PS3 28,960 TNRA.PS3 C~9TC. PS3 3500,;)72 CFTC,PS3 CCL,PS3 () 000 F)PHI, PS4 RCFT.PS4 734369.4 CNTC,PS4 TE~:;:S' PS4 1230, OOO CC!,, PS4 D .F; p T, 1 (.) 200,000 N P H I. }4 L A RCNT,PS! -999,250 RCFT,PS1 (,,[~.PS1 -999.25f) TENS.PSI T~.~, PS2 4,4:13 RCNT, PS2 CFTC,PS2 756. 725 GR.PS2 ~'PHI.PS3 -999'250 TN'Ri.PS3 CNT(i,PS3 -999.250 CFTC.PS3 CCI~,''~ PS 3 - 999,250 ~t P}.l I PS 4 RCFT,PS4 -9q9.250 .... CNTC', Po,ge TgNS, PS4 -999,250 CCh. PS4 10163,00(t ,NPHiI MLA DEPT'Ps1 '999,250 C ~ ' R C N'I:, R ,,,F t, PS 1 (;P, PS 1 -999.250 ,,,, ~ ~,, e,,,. r. ,.~ ,>. PSI TNRA.Po2 4.662 CFTC PS2 724 31. I GR,P~,2 ~,t P t',~ I': P S 3 - 999 250 T N R A, P $ 3 C~TC'P83 -999 250 Cv~,r' P83 CCI, PS3 -999 250 NPHI. P5,4 RCFT,PS4 -999'250 CNTC,P84: TESS, PS4 -999' 250 CCL,, PS4 ** END OF DATA ** 20-JI..,N-1990 1.2:1t0 1532.249 GR.PS3 17.866 TNRA,PS4 5323.410 CFTC.PS4 0.000 20.557 NPHI.PS1. 1.142,857 C~iTC.P$1 1345.000 CCL.PS1 4300.000 RCFT,PS2 81.31,3 TKNS,PS2 3.917 RC~'~,PS3 1150.129 GR.PS3 20.261 TNRA.PS4 4383.422 CF~:C,PS4 0.000 27,7~3 NP~i,PS1 691.552 C~ITC.P$1 1340.000 CCh,PS1 31~094 4,917 R C N '.r, P S 3 709,528 GR, PS 3 27,208 TNRA,PS4 3454.674 CFTC,pS4 0.000 i 999,250 NPtiI,PS1 999,250 CNTC,P$1 999,250 CCD,PS1 3200,000 R'. CFT,.,.S2P' '999,250 Re T,PS3 -999o 250 GR, PS3 P $ ,4 -999.250 TNRA,PS4 -999.250 CFTC, -999,250 -999, -999, '999, 3.333. 39 -999 -999 '999 -999, -999,  50 NPHI,PS1 .50 CNTC,PSI 250 CCb. PSl 333 RCFT,PS2 594 TENS,PS2 250 RCNT,PS3 250 GR.,PS3 250 TNRA,PS4 250 CFTC,PS4 25O 80.063 3.468 1548.952 22.5'18 4387.277 0.000 1233.333 1310.000 4306,48.3 78,43~ 3.788 1204,831 27 306 3366 435 0 000 "102 758 1325 000 3426 326 37 1,25 4 700 726 131 -999 250 -999 250 -999 250 783 333 13!,0 000 -999 250 -999 250 -999 250 -999 250 999.250 :g99.250 -999 250 733 333 1295 000 -999 250 -999 250 -999 250 -999,250 TENS.PS3 RCMT,PS4 GR,PS4 TNPA.P$1 CFTC,PS1 NPHI.PS2 CNTC,PS2 CCL,PS2 RCFT.PS3 TE~$.PS3 RCNT.PS4 GR.PS4 TNRA. PS 1 CFTC.PS1 NPHI ,P$2 CNTC.PS2 CCh,PS2 RCFT,PS3 TENS,PS3 RCNT.PS4 GR,PS4 TNRA.P$1 CFTC,PS1 NPHI.PS2 CNTC,PS2 CCh.PS2 TghS,PS3 RCNT.PS4 GR,PS4 TNRA.PS~ CFTC.PS1 NPHI.PS2 CNTC,PS2 CCI,, PS2 RCFT PS3 TENS PS3 RCNT PS4 GR,PS4 PAGE: 1310,000 5099,080 80.750 4.099 1085.121 20,387 4442.942 0,000 1194.499 1290.000 4114.286 87.000 4.712 724,683 27,545 3454,680 675,835 1280'000 3366,701 39,656 .-999 250 -999 250 24 960 3350 93~ 0 000 :-999 250 -999 250 -999,250 -999.250 :~99,250 99,250 26 909 3374 052 0 000 :-999 250 -999 250 -999 250 -999 250 IS Tape verificat.~.on List.ins cblumberqer AlasKa Computir~q Center 20-jb,~!-i 99o 12:30 PAGE: **** FILE: FIL, F I',:A~.<E : EDIT ,o01 SERVICE : FLIC VERSIO~,~ : OnlA04 DATF ~X REC SlZ. g : lO24 FILE TYPE : LAST FILE : **** TAPE TRAI LE, R SFRV].Ck: ~AME : EDIT DATF' : 90/06/20 ORIGIN : FLIC TAPE: N.A~.'. : 73890 COt'~TINI,3ATI[3N $ : 1 PREVIOUS TAPE : CO~ENT : .ARC[] A!..,ASKA, INC., PRUDBOE BAY, D.S. 18-17, API ~50-029-2~768 **** RS:E [,, TRAIbER **** S~;RV ICE NA~g : DATF : 90/06/20 ORIGIN : FLIC REEL., NA~E : 73~90 CONTINUATIO~ ~ : PREVIOUS REEL LVP 010,H02 VERIFICATION LISTING PAGE ** 'REEL HEADER SERVICE NAME :EDIT DATE :88/01/18 RIGIN ~EEL NA~E ~72564 CONTINUATION # PREVIOUS REEL COMMENTS :EDIT LIS,ARCO PRUDHOE BAY' DS 1B-17,AP! 50-029-2176B '** TAPE HEADER *~ SERVICE NAME :EDIT DATE :8B/01/18 ORIGIN :7256 TAPE NAME : CONTINUATION # :01 PREVIOUS TAPE : COMMENTS ~EDIT LIS,ARCO PRUDHOE BAY DS 1B-17,API 50-029-2176B ** FTbB HEADER ** ~ILg NAME ~ED.IT ,OOi S~RVICE ' · NAME , YEBSlON # : TYPE PREVIOUS FIDE INFORMATION RECORDS ~N { ARCO ALASKA,, INC~ WN · ~ D.S' 1B-l'7 P,RUDHOE BAY RANG 14E TO~N{ lin ~4 COUN: NORTH ShOPE S?AT: ALASKA CT~Y{ USA UNIT TYPE CATE SIZE CODE O00 010 OOO 000 0::65 000 000 06:5 000 000 00' ooo ooo oooooo 000000~04 UNIT TYPE CATE ,sIZB CODE PR,'~S: g O00 000 00t 065 *.,, CON~ENTS 1,1 LVP 010,HO2 VERIFICATION LISTING PAGE * SCHLUMOERGER * ALASKA COMPUTING CENTER ************************************************************************************ COMPANY -' ARCO ALASKA, INC WELL ZELD = PRUDHOE BAY COUNTY = NORTH SLOPE BOROUGH STATE = ~LASKA JOB NUMBER AT AKCC: 72564 RUN Mi DATE bOGGED: O?-JAN-88 LDP,, R~CK KRUWELb CASING CASING TYPE FLUID SALINITY MACL 9,625" SURf'ACE TO 10350~ - BIT SiZE = 12~25"5 TO t0350" 7.000" 10123' TO 11222' ' BIT SIZE = 8, TO 11224' 'BRINE 9.0 LB/G 50,0 PPM NOTE~ TH£RE WERE PROBLEMS GETTING TOOL STRING DOWN TO TD~ OPEN HOLE bOGS DUAL INDUCT ~ DATA THRT IS PRESENTED ON GAMMA RA THRU CASIN Bht,IE~INE, LVP OlO.H02 ¥~iRIFICATIOI.4 LISTING PAGE MATRIX SANDSTONE ***** THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS * SCHLUMBERGER hOGS INCLUDED WITH THIS MAGNETIC TAPE: * DUAb INDUCTION SPIJERICA[JBY FOCUSED BOG (DIb OPEN HOLE)* * DATA AVAIhABhE~ 10162' TO 10345' , COMPENSATE[) NEUTRON LOG (CNT CASED HOLE) * DATA AVAIBABbE~ ~118~' TO 10055' . .ATUR~ ~A~.A TO0~ (~GT CASED .O[,E) * DATA AVAILABbE= 1117i' TO 10055' * GA~A RAY IN CASING (GR.CSG) , DATA AYAILABbE~ ~0315' TO 3200' ** DATA FORMAT RECORD ** F~NTR¥ BLOCKS TYPE SIZE NEPR CODE ENTRY LVP OlO,H02 VERIFICATiO!g bISTING PAGE 4 2 ! 66 0 4 ! 66 ~ 8 4 ?~ 60 9 4 65 ,lI~ 16 $ 66 ! 0 1 66 0 DATUm, SPECIFICATION flbOCK$ MNE'M SERVICE SERVICE UNIT API AP1 APl APl FIbE SiZE SPL REPR PROCE$~ ORDER # hOG TYPE Ch,SS ,OD ,0. CODE DEPT FT O0 000 O0 0 0 4 I 68 00000000,000000 , ~ ~, oooooooooooooo ~.~ ~ ~ OD ~~,o ~ ~ o.~ oo ~ o o ~ ~ ~0 oooooooooooooo ~ oooooooooooooo oooooooooooooo bD DI~ IP OIL TENS C, NT TN~A CNT CFT T RCNT CFTC tNT CNTC CNT ~PH'I CN? ~GR CN? SGR NGT CG'~ ~$~G NGT W4:NG NGT W$NG NGT WI~G NG:T NGT P:OTA NGT TENS' egg GR CSG o.~. OD OHMM O0 120 46 0 0 4 MV O0 010 01 0 0 LB O0 635 21 0 0 4 O0 420 O1 0 0 4 O0 000 O0 0 0 4 CPS O0 000 O0 0 0 4 CPS O0 000 O0 0 0 4 CPS O0 000 O0 0 0 4 CPS O0 000 O0 0 0 4 PU O0 890 O0 0 0 4 GAPI O0 310 01 0 0 4 bB O0 635 21 0 0 4 ~ PI O0 ])0 01 0 0 IP! O0 ~ 0 01 0 0 4 1 ~ 68 00000000000000 I 68 00000000000000 1 68 00000000000000 , 68 00000000000000 ~, ooooo~o:ooo,oo , ., oooooooo,oooooo ~, oooooooooooooo i ~. oooooooooooooo 68 000000000000'00 68 0000000000'0000 68 0000,000000000:0 ~ 00000000000000 00000,000000000 I ~:I ooooooooo, oooo.o 000000::0:00,:0'0000 i ~ ~oo ,oooo ,o,oo I ~ ~oooo,o,,.oooooo~oo 00:O0000000:0'00 DATA R:TNR SGR: ~3'NG .999,2500 -999~2500 -99:9.~2500 CGR W2NG ~999,2500 DEPT R ? CN~C SGI~ 200,0000 TENS ~999~2:500 2,9552 RCFT 4,4, 2'? 5 ~. P t.t t 59,0704 CGR -.999,2:500 SFbl. J ~i -,,,9,~::~,:,~.:so,o ~.s '-,::, CN~ ~'99962500 $:GR -999,2500 W5NG -9:99: W4NG -9,99,2500 WiNG '999 ?HOR -999,2500 TENS -999 ;,500 TE 2:64:0:'0000 613,!918 RC:NT 1737.4795 CFTC 25,]32~ 59,0704 42.5197 W5NG B,5262 W4NG tO31 ~'000 6541 LVP OlO,H02 VERIFICATION LIST.lNG PAGE 5 ~3NG [1RAN DEPT RTNR CNTC DEPT RTNR CNTC ~3NG DEPT RT~R CNTC ~3.NG URAN RTaR C~TC ~3NG U R :R N D~PT I bD 26,7960 W2NG 2,0912 POTA 11100.0000 TENS :2,oo 154~:4192 HPHI 2 5331 CGR TENS SP RCFT NPH! 110000000 -999 2500 3 0169 3634 CGR 125261 ~2NG t 337~ POTA 10900.0000 TENS -999.2500 SP 2,8088 RCFT 16~,5212 NPH! ,8969 CGR 1~,5392 W2NG ;6179 POTA 10800,0000 TENS -99~,2500 2,3:523 RCFT i900,4087 NPH.! ' 13',5088 CGR ~ ~2NG 0.,.3I POTA 107'00'0000 TENS -999,2500 SP 2'0855 RCFT 20~7.21267;2:384 C!.RNPH! 9.~4044 POTA I0600'?000 TENS -:999,25'00 SP 1936,8101 NP:HI 20,5862 CG:R W2NG POTA 10500,0000 TENS .-.9'99,2500 SP 3;t562 R'CFT 694275 WING 0:7866 TENS -999 2500 SF[,U -999 2500 TENS 545 0687 RCNT 2~ 0140 SGR 1 4491 WSNG 458811 W1NG 0 2729 TENS -999 2500 SFLU -999'2500 TENS 596:i225 RCNT , ~87 SGR ~, 13 W5NG . 8 TENS :999.2500 SFbU 999,2500 TENS 661,0869 RCNT ~6149 WiNGTENS ~999, :5'00 SFLU · 999., :500 NS l?,O~ll $',R I1.9012 18"8088 WiNG 0;'1914 TENS -99'9,2500 SF~U -999,2500 TENS 103t.0254 RCNT 13,.i220 SGR 12,78!6 ~SNG 27'1682 W1NG 0,'2878 -999,'2:5'00 -999,2500 16,t536 1=8'9098 W'SNG :.~5648 31~..25:48 TENS srbu 999~2500 TENS 662,5870 RCNT 198,5184 THOR '999,2500 GR '999,2500 I5~ ~074,0000 TNRA 1670.4517 CFTC 2~.5331 TENS ,'0000 W4NG 67.7789 THOR '999.2500 GR -999 2500 ILN 30140000 TNR~ 2~ 0874 TENS 7 W4NG 69 9374 THOR -999 2S00 GR -999,2500 Ih~ 954 0000 TNRA 30.8969 TENS 4,1797 W4NG 9~,9540 THOR '99 '2500 GR -999.2500 2930,0000 TNRA 1989'5828 CFTC '13,5088 TENS · 0.0000 W4NG . 36,5726 THOR 999,2500 GR -999,2500 3010'0000 TNRA 2147;0332 CFTC 1.7, TENS CFTC 2 TENS ~4NG .3933 I~OR -999,250:0 ILN 288'0,00~00RA t8~6. 28 ~T'C 7,1697 -999,2500 -99~,2500 2,7748 551,2050 3074,0000 2565 .999i 1694 2500 9,2500 '992,7805 56~,9104 3011,0000 ,{315 .99~ '9786 ,2500 -999,2500 2954,0000 i,0449 3,9160 "999',25'00 -999,2500 ~ ~0,.0 O0 -999 ~00 -.' ,25'00 2.86.~. ~0 .-99~. )0 -99'9,2500 LVP OlO,H02 VERIFICATION i,,ISTING PAGE CNTC 1663,914b MPHI SGR 104,2614 CGR NG 34.9099 ~2NG RAN 9.3618 POTA D'EPT 10400,0000 TENS bD -999,2500 TNR 3,1455 RCFT CNTC 131~,2358 NPHI SGR ' 9 ,1290 CGR W3NG 45,9770 W2NG UR~N 5,5,453 POTA lbo 999,2500 SP URAN ' 3 POTA 00,0000 TENS OEPTibD 112'9~.88009,2500 SPRcFT ~TNRNTC 0~t,8484 SGR . ,1520 CGR W~NG ,8427 W2~G U~N :~.6891 ~OT~ D£PT 10100.0000 TENS 2500 -999, RCF? SGR.. 9:6, CGR ~:~,:O 999;2500 -99:9~25:00 R'~'FT Wi.~G ,999,2500 W. 2NG U:R:A N "999' 2:50:0 POT A DEPT TENS ILO SP RCFT W3NG W2NG URkN POTA DBPT 9800,0000 TENS 146,3964 0,6204 999.~500 999. 500 397,9106 29.80~ 92. 4748 -999 2500 -999 2500 209 4066 52 6367 42 32t6 6 4 1 -999 2500 -999 ~500 209 8'75 57 ~848 60 060 100 ~000 1 I52 ~iNG TENS SFLU TENS RCNT WiNG TENS TENS RCNT WSNG W1NG TENS SFbU TENS RCNT SGR WSNG W~NG TENS :999,2500 SFLU 999.2500 TENS 242,2286 RCNT 48,4015 $ R 53~2196 W~G 123,45:68 ~ING i;gi'6S TENS -999.2500 S[bU -999,~$00 RCNI '99'9,2500 SG:R -99'9~:2:500 WSNG '9:99,2500 SFbU '999.,2500 TENS '999,250:0 -999,.~500 -999'25oo -999,25oo WlNG -9991,2500 TENS -999.2500 SFbU 104,~b14 4, 045 '999. 0 -9992500 9 4 0000 28.~ 1766 -99 2500 -999 2500 2874 0000 997 2439 49 0120 ] 3746 ,8560 [,oooo '999,2500 ~00 0000 2500 2834, 0000 10i3,2372 600:8; 0000 "9'99, ~5:00 '99:9 "999 -g ;00 -99'9 0 '99' 500 ;00 00 0000 -999' ~500 TENS W4NG THOR GR IbM TNRA CFTC TENS W4NG THOR GR IbM TNRA CFTC TENS W4NG FTC TENS W4NG  HOR R TNRA CFTC' TENS THOR GR TNRA CFTC TENS W4NG THOR: TN,RA THOR 2880,0000 7568 .999i 7928 2500 -99g,2500 3,0374 428,2969 291 ,0000 ' ~,4044 . 6, 098 999,~$00 -99~,2500 4994 '999~2500 2800,0000 4.4944 9,37 4,,0:577 -9! I$00 -9' iO.O -9! ~;0 LVP OlO,H02 YEI~IFICATIO[~ LISTING PAGE 7 ILD -999.2500 SF RTNR -999,2500 RCFT CNT¢ -999,2500 NPHI SGR -999.2500 CGR 3NG -999,2500 W2NG RAN' -999,2500 POTA  EPT 9700 bO "9'9~  TNR -99 NTC -999 SGR -999 RAN 0000 ,PENS 25.00 2500 RCFT 2500 NPH! 2500 2500 W2NG 2500 POTA DEPT RTNR CNTC ~3NG ~600,0000 .999,2500 999.2500 ~999,2500 .999'25o0 .999,2500 999,2500 TENS 8P RCFT NPHX CGR W2NG POTA EPT CNTC w ~ URAN 9500.0000 .999.;.2500 -999,2500 -999.2500 -99'9.2500 -999,2500 "999,2500 TENS SP RCFT NPHI CGR W2NG POTA DE. PT -99'9,2500 9400,.0000 "9:~9,'25:00 CN::T:C -' 0 ., oo W3NG '9~ .00 UR,AN -9! ~00 NPH! CGR POTA 9: 0,000 "9! -9! "9 ..00 ',,' ;00 TENS NPH! CGR w2NG POTA DEPT CNTC SGR ~ 3,:N G 50.0 °o SP RCFT NPHI CGR -999 2500 -999 2500 -999 2500 -999 2500 9~ 2500 25oo -999,2500 -999, -9'99.2500 -999.2500 .~;25oo '999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -.999,2500 -999,2500 m999, 0 "999,2500 "999,2500 ~999,2500 -,999. soo 999'250 "999,'2500 '999~2500 -999,2500 "999;2500 -99'9,2500 -9:9'9;:2500 2500 -' ~,~,o0 !~00 "999 )0 -9!199 "999 iO0 ~999 TENS RCNT WSNG WiNG TENS SFLU ZEN$ RCN'T SGR W5NG W1NG TENS TENS RCNT WSNG WiNG TENS SFbU TENS RCNT S R WiNG TENS SFbU T~N$ RCNT WSNG WiNG TENS '999,2500 '999,2500 '999,)500 '999. 500 "999,~500 6088. 000 -999 2500 "999 -999 2500 6012 0000 -999 2500 -999 2500 -999 2500 -999 O0 -,9, -999 2500 5648 0000 -999 2500 -9992500 "999 2500 -9 9 2500 '9~9 ~SO0 TNRA CFTC TENS THOR GR TNRA CFTC TENS W4NG THOR GR TNRA CFTC TENS w4NG NRA FTC TENS W4NG THOR -99:9,.2500 -99,9,2,500 TNRA "999.25:00 CFTC W4NG SFbU -999,2500 IbM RCNT CFTC S. R W4NG W~NG TENS 2500 TENS 5400 0000 GE SFLU -9~ IbM CNT "' CFTC SGR '9~ T~NS H5NG "' W4NG WING -' THOR TENS 5! GR -999, 0 -999,2500 -999,2500 -999,. 2'500 72,2500 .,999,2500 .,999,~500 -999,2500 -9, 9, ~ O0 ., ,.Iloo -999,2500 74.3125 -999,2500 -999,2500 -999,2500 ,,,999, ~$00 :999,2500 999,2500 8t,8750 -999,.2500 ',,99.9 "":tL°°o -999l ~: 0 "9.99 ~'500 · '! }:0 -9 )0 ~'0 LVP 010,H02 V£RIFICATION LISTING PAGE CNTC W3NG [.TRAN DEPT RTNR C~TC ~3~G UR,~N DEPT CNTC W3NG URAN D~PT R?NR CNTC W 3NS DEPT IbP' c ?:c 'W ' "' ' ~ RTNR CNTC DEPT RTNR CNTC S:~,~ 9100,0000 TENS .2 2,2soo -~u~,2500 RCFT -999,2500 -999.2500 CGR 2500 POTA 9000 0000 -999 2500 -999 2500 - 2500 '999 2500 '999 2500 8900 0000 '999 2500 "999 2500 '999 2500 '999 2500 O0 '999 0 B800,O000 -w~, O0 2.500 -.999~2~00 ' 9' 25'00 870'0 0000 '99! "99 '99' 86"00~0000 ~00 ~00 '9' 0 "99~ ~,~00 - 00 8500,0000 - 999,2500 999,2500 - 9;2500 TENS SP RCFT NPHI CGR W2NG POTA TENS SP RCFT NPH! CGR W2NG POTA TENS RCFT CGR W:2NG POTA TENS SP RCFT NP~I TENS S~ RCF? N:P,,HI W2NG POTA TENS RCFT NPMI -999 2500 -999 0 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 -999,2500 -999.)500 -999. ~00 -999,) O0 -999, 500 -999 2500 -999 2500 -999 2500 -999 2500 ~999 2500 -999 0 -99'9.2500 -999.,2500 -999,2500 -999,~500 -999,2500 ~999,25'00 999'250'0 '9'99.2500 -999,:2500 -99,'00 '999,25'00' -9:,,,. '0'0 ~999'2500 -:999,2500 ,'9:99~,2500 -999,2500 999,2:500 '999~2'500 '999',2500 "9919,25,00 "999'2900 SFbU TENS RCNT WSNG SFbU TENS RCNT SGR WSNG WING TENS SFLU TENS RCNT SGR W5NG WiNG TENS TENS RCNT SR WXNG TENS SFbU TENS ~NG W lNG TENS SFhU ~ENS RC'NT WSNG ~ iN(; TENS SFbU RCNT SGR 2999.2500 IbM .999,2500 TNRA .999.2500 CFTC -999. W4NG -999, ' THOR 5332,00'00 GR -999 2500 -999 O0 -999 2500 -999 2500 -999 2500 5564 0000 -999 2500 -~99 2500 - 99 2500 -999 2500 -999 2500 ~999 1BO ~500 000 '999.2500 -999,2500 -999~2500 -999~2'500 "999.2'S00 5240'0000 -' ~500 -' 1500 -9' ~500 '999 5452' '999, !50:0 -9! O0 O0 O0 TNRA CFTC TENS W4NG THOR GR IbM TNRA CFTC TENS W4NG THOR GR TNRA CFTC TENS W4NG CFTC TENS W 4 'rHoR -999 2500 '999 -9~9 50 "999.2500 -999'2500 -999.2500 '999,2500 -999,2500 62'8750 -999,2500 '999. -99~,2500 -999; ~999~2500 '999~2'50Q -999,2500 -999,.~5.00 '-' )0 -9! T~RA TC TENS H 4NG NRA FTC W4NG LVP 010,H02 VERIFICATION [,IST~N(; PAGE 9 DEPT ORAN DEPT RTNR CNTC SGR WSNG URAN DEPT CNTC ~3NG URRN DEP? RT,NR CNTC S:GR ~SN:G URAN' CNTC WSNG DE~.T CNTC W: 3:,NG UR:A~ DE,PT 'I~D '999~.2500 -9 .2500 8400.0000 -999,22500 -999, 500 -999,~500 '999. 500 '999.22~00 "999. O0 8300 0000 '999 2500 -999 2500 -999 2500 -999 2500 '999 2500 '999 250"0 .200.0000 999,2500 ~'999,2500 .'999,2500 -999,2500 -9'99,2500 '999,2500 8 ! O0,000,0 99, 2500 '99:9', 2500 - O0 "~99'. '~:~.:00 -99:9,2500 ,'9"99:~ 2~00 800 0 ~00 "999 .00 .'! 0 . 7900 0000 -9 ! : 500 ,,,, F:500 -999 -99:9 -9! ',:500 " 2500 W2NG POTA TENS RCFT NPHI CGR H2NG POTA TENS RCFT NPHI CGR W2NG PO?A TENS SP RCFT NPHI CGR W2NG POTA TENS RCFT NPH! CG~ W2. NG POT~ TENS N, PHX CGR W'2NG P:O:TA ~ENS SP N,PH! · , ~ ~2NG POTA TENS '999,~500 '999. 500 -999 2500 -999 0 -999 0 -999 2500 -999 2500 WiNG TENS TENS RCNT S ~ W~JNG TIENG -999.2500 SFbU -99 2500 RCNT -999,2500 SGR -99~i~500 WS:NG -99 500 W~NG -99 500 TENS -999,2500 SFLU 500 TENS "999'~500 RCNT -999, -999,1100 SGR -999, 00 WSNG -99~., O0 W1NG -999, O0 TENS '999,2500 '999.,2500 TENS . 9 .2 oo :999:;2500 .999.;2500 WiNG 999;2500 -9:99,.2500 SF~U :99?'2500 TENS -999,,~2:5.00 -.9'9'9,2 500 -999,2500 WING -999~ 2500 " i.O0 T~N,S ' 0 ,RC:NT 2 0 ~, '99:' LS:00 ~IN:G '99' TENS SFb,U TENS RCNT '999.2500 THOR 5148,0000 GR -999 2500 ILM -999:2500 TNRA -999.2500 CFTC 99,2500 TEN~ 99,2500 W4N 99,2500 THOR 4900,0000 GR -999.2500 -999.2500 -999..2500 '999,2500 -999.2500 -999.2500 5028,0000 -999 2500 -999~2500 '999.2500 '999,2500 '999,2500 "999,2500 5140'0000 -999.'2500 '999~2500 '999";2500 -99,.50 999,2500 4'524,0000 -999 '99:9 '9! IbM TNRA CFTC TENS W4NG THOR GR IbM TNRA CFTC TENS W4NG THOR GR TNRA CFTC TENS THOR GR N A W4NG THOR T N,R A CFTC TENS W4N:G -999 500 '999.2500 '999'~i00 -99~, O0 -999, O0 -999, O0 66, 5 -999 2500 -999 2500 -999 2500 9~9:500 ~500 .999 500 65 625 :999, 5oo 999,2500 '999;250'0 -999,2500 -999,2:5'00 ~999..2500 64,.8::750 '99.9~ O0 -' O0 '9:' 0,0 -91 0 [,VD 010.N02 VERIFICATION LISTING C~TC -999,2500 NPHI SGR -999,2500 CGR w3NG -999.2500 W2NG URAN -999.2500 POTA RTNR CNTC SGR 7700.0000 -999,2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 25'00 DEPT 7600,0000 D '999,2500 TNR -999.2500 CNTC -999,2500 SGR -999,2500 ~]NG -999,2500 U RRN '999,2500 DEFT 7500.0000 ISD -999, 500 RTNR -999;~500 CNTC -999~, 2500 SGR ~999,2500 W3NG -999,2500 R ~ N ' 999; 2500 D~PT 7400,0000 I~D ,~999,2500 RTNR ,99:9:~ 2500 C N T C - 9 9 9, 5.0 0 SGR -999' 25:00 ~3~G ~999;2500 U ~999,25 O0 RTNR ~999 ~:TNR CNTC s~, DEPT 7200 ,00'00 ""9~ 500 iO0 0 -999:2,5'00 "999 2:5:00 7 ! 00,0 O0:0 TENS RCFT NPHI CGR ~2NG POTA TENS SP RCFT NPH! CGR W2NG POTA TENS RCFT NPHI CGR W2NG POTA TENS RCFT NPHi p~TG TENS W2NG POTA RCFT N2NG POTA TENS -999,2500 -999,2500 -999,2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 -999 500 -999 2500 -999 ~00 -999 500 '999 2500 ~999 2500 '999 O0 -999 -999 "999.2500 "999,2500 -999,2500 -999,2500 -999,2'500 -999,,~50 -999;250u :999'2500 .999*25,00 "999;250'0 :999.2500 . 999,,2500 '999'2500 -999,,2500 '999,250'0 '999~2:::500 '9,99'~2500 .999,2500 999*25'00 "999,2500 SFLU TENS RCNT SGR WSNG WING TENS TENS RCNT SGR WING TENS TENS RCNT WSNG Wl. NG TENS SFLU SGR W. 1NG TENS TENS W lNG TENS CNT ~SNG SFPU - 99 2500 -999,2500 46~0.0000 -999.2500 -999,2500 -999. .999,~ 500 5OO '999,2500 '999'2500 4748'0000 '999 2500 '999 -99~ 250O -99 2500 -999 2500 4360 0000 -999,2500 -999~2500 '999',2500 -999,2500 :999.2500 999,2500 4212':00'00 '99'9,2S00 -999,..2~@9 "9'99~25:00 -999',:2500 :999'2:500 4,4,68:~,0000 -9'9'9 i:O0 -99 2,500 4:: 00.0.0 .9'992500 '99:9 -'! ~,0:0 -~ ~,00 '9 ,,2500 4: 0000 ~999,2500 TENS W4NG THOR GR N~A TENS W4NG THOR GR Ib~ NRA TENS W4NG GR TNRA CFTC TENS W4NG THOR NRA :FTC ~4NG THOR GR ,F:T,C 4 G THOR GR TNRA CFTC W4NG THOR: -999, O0 '999,~500 35, 938 -999 2500 -999;2,$00 4,0,6563 -999,2500 -999,2500 -999,25,00 -999'2500 -999,2500 -999,2500 -9,99,2500 -99:9:,2,:500 '9:9' 2500 - ~'0 ": :: -9 )0 )0 ~0 LVP 010,~02 VERIFIC&TI(.)t~ LISTING PAGE .l. bD RTNI~ CNTC W3NG URkN DEPT Iht> RTNR CNTC SGR 3NG ~RAN DEPT TNR NTC SGR DEPT I bD RTNR SGR URAN D~PT W U R'A N DE:PT CNT,C CNTC :999,2500 SP 999,2500 RCFT -999,2500 NPHI '999,2500 CGR :999,2500 W2NG 999,2500 POTA 7000 0000 TENS -999 2500 SP -999 2500 RCFT -999 250'0 NPH! -999 2500 CGR :999,2500 W2NG 999,2500 POTA 6900 0000 TENS -999,2500 SP -999,2500 RC'FT -999,2500 NPHI -9'99.2500 CGR -999.2500 W2NG -999,2500 POTA ~800,0000 TENS 999,.2500 ~999,.2500 RCFT -999,2500 NPHI "999,2500 CGR -999,2500 W2NG -999;2500 POTA ?oo,oooo "999,2500 -999',2:500 RCFT CGR -9:99',2:500 W2NG ':99912500 POTA 6600,0000 TENS ~9,99.2500 999,2500 NPHI WZNG 999,2500 PDTA 65,'0o,,~00o TENS -999,2500 P -999'2500 ~CFT "999,2500 NPH~ W2NG POTA -999 2500 TENS -999 2500 RCNT -999 2500 SGR =999 2500 WSNG -999 2500 WING -999 2500 TENS -999.2500 SFhU -999,2500 TENS -999,2500 RCNT -99~.I~00 SGR -99 , O0 W5NG -999,2500 WING -999,2500 TENS -999 2500 -999 2500 TENS -999 2500 RCNT O0 SGR -999 -999 -999 . 500 WING -999 {500 TENS "999,2500 SFbU -999,2500 TENS -999,2500 RCNT "999,2500 S R -999.2500 W~NG -999,2500 WING -9994:2500 TENS ~999,2500 SFLU 999,2500 TENS ~999;2500 ECNT ~999,2500 SGR a~,ZSO0 W~NG '999,2500 TENS -99,9.2500 SFbU -999,25,00 TENS :999::,~500 RCN? 999.,25.00 SGR -999,2500 SFb:U 2500 T:~:N~ '"999,2500 RCN ~ ~N'G -999,2500 TNRA -999,2500 CFTC -999,2500 TENS -999,2500 W4NG 500 THOR · '999.2500 IbM -999..2500 TNRA '999.2500 CFTC -999,!500 TEN$ "999, 500 W4NG -999, 500 THOR 4144,0000 GE -999 2500 IbM -999 2500 TNRA -999 2'500 CFTC -999 2500 TENS -999 2500 W4NG -999 2500 THOR 4112 0000 GE 1999,2500 IbM 999'2500 TNRA '999'2500 CFTC -~9.2500 W4NG -999.2500 THOR 4000i0000 G:R "999 CFTC -99 TENS W4:NG "~ 00 THOR 3'?~ 000 GR, -~99 25,00 ~bM T:NRA CFTC' TENS -' ,2500 TH,O~ OOO0 GR W:4:NG -999 2500 -Egg 25OO -999 2500 -999 1500 -999 ,500 36 438 :9'99.2500 999,2500 -999,2500 -99'9,2500 -999'.2500 -999.2500 43,1675 "999,2'50'0 -999,.2500 · .999. 2500 · '999 ,'25'00 -999,2500 "999,2500 -9:99,2500 '),:7; 2'6 t'3 -9! 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CGR W2NG POTA TENS SP RCFT NPHI CGR w2NG POTA RCF~ N, PHI CGR W2NG POTA TENS RCFT NPHI CGR W2NG TENS RCFT NPHI CGR -999. 50O -999.1500 -999~2500 -999;~500 '999, 500 '999.2500 '999'~500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -9992500 -999.2500 · 999, O0 .999,~ 5 5OO -999' :999,2:500 999,2500 '999,2'500 '999,2500 '9'99'2500 0 '999 -999,2500 -999,2500 -999,25:00 -999,2500 '999,2500 '999,2500 "999'2500 =999,2500 '999:,2500 '999' 25:00 '" 999 ,:, 25 O0 '999,2500 TENS RCNT SGR W5NG WING TENS SFL, U TENS RCNT WSNG WING TENS SFLU TENS RCNT SGR WLNG W1NG TENS TENS RCNT WS,NG WiNG TENS S'FLU TENS RCNT W'LNG WiNG TENS TENS RCNT SGR WSNG $:FLU TENS RC~T SGR WLNG -99'9 2500 -999 2500 -999 2500 - 2500 ,0000 -999,2500 -999 O0 -999.2500 -999.2500 , 000 -999,2500 '999,~500 '999, 500 '999. O0 '999,~00 "999. 500 3694.~000 :999,2500 .999,2500 9'99~2500 :999,2.500 .9'9912500 999,2500 3:6:44,.00:00 "99'9'.2500 ~999~2500 ~9'99:'2'500 -999:~2500 .-999~:250:0 64~0:000 -999,2500 -! :2500 "' .25.00 -9:9 0 -:9! ;0'0 IbM TNRA CFTC TENS W4NG THOR GR IbM TNRA CFTC TENS W4NG THOR GR IbM TNRA CFTC TENS W4NG THOR TNRA CFTC TENS W4NG THOR GR TNRA CFTC TENS W4NG T~OR G~ T,NRA CFTC THOR · GR TNRA CFTC W4N~ '999.2500 '999,2500 -999,2500 -99'9, 0 -999 2500 .,,, -999 -999 25,00 -999 2500 '999 25'00 '999 2500 '999 ~500 = :oo 4063 -999,,2500 -9:9, 0'0 ':' i:O0 - 9 iO::O -9 9:! ,, 9 ~0 '999, }:00 LVP 010,H02 V,E~IFICATION blSTING PAGE k3NG -999 2500 W2NG URAN -999~2500 POTA DEPT 5700,0000 TENS bD -999,2500 TNR -999.2500 RCFT NTC -99~,2500 NPHI ~GR -99 .2500 CGR ~NG '999.2500 ~2NG AN -999.2500 POTA DEPT 1600.0000 bD 999.2500 TNR -999.2500 CNTC -999;2500 SGR -999,2500 W3NG -999.2500 URAN -999.2500 5500 0000 -999 O0 -999 2500 -99'9 2500 -999 2500 -999 2500 DEPT 54'00,0000 IbD -999,2.500 RTNR -999',25"0'0 CNTC -9'9.9,2500 -999.,2500 ~999;2500 530( )000 RTNR CNTC W3NG U~AN' CN~,C S DEPT 5200 0,0:00 -999 CNTC -~ :5:00 SGR 0 N3,NG - 500 . 5100 000o -,9! TENS RCFT NPH! CGR W2NG POTA TENS RCFT NPHI CGR POTA TENS SP RCFT NPHi C~R W, 2NG POTA T~NS N,PHI CGR' POTA, TENS RCFT NPHI ~2:NG POTA -999 2500 W!NG -999:2500 TE~S =999 2500 SFLU -999'2500 TENS -999:2500 RCNT -999,2500 SGR -999..2500 WSNG ~999,2500 WING -999.2500 TENS -999 -999 -999 -999 -999 -999 -999 2500 SFbU 0 RCNT 500 SGR 500 NSNG 2500 N~NG 2500 TENS -999 -999 -999 -999 -999 -999 -999 2500 SFbU 2500 T NB 2500 R~NT 2500 SGR 2500 WSNG 500 W N :999.250:0 SF~U .999'2500 TENS .999,2500 RCNT 999,:2500 -999,2500 W1NG -999;:.2500 TENS "999,2'500 "999,2500 SGR -~9!~..2S0.0 W'S~G "99'9,2500 WiNG '9'99'2500 TENS "9'99,2:500 SFLU "999,2500 TEgS '999.~25.00 .2500 WING 2500 TENS ', 999,., 25:00 S,F b U -9'99,~500 TENS. "999e2500 RCNT -99~,2500 3284.0000 -999 2500 -999 O0 -999 ,2 O0 -999 2}0O -.999 2500 3584 0000 '999,2500 '999.2500 "999 2500 '999:'2500 '999.2500 '999.2500 ]240,0000 -999.2500 "999'i500 "999, 5'00 "999, 500 "999,~500 '999. 3484',00 '999'2500 -99.9, 500 '999, 500 "999,2500 "999:,:250:0 "99" ' ,0 THOR GR TNRA CFTC TENS W4NG ?C W4NG THOR GR IbM TNR~ CFTC TENS W4NG THOR IbM TNRA CFTC TENS W4NG THOR GR IbM TNRA CFTC TE.::NS TENS -999,2500 40,6250 -999,2500 -999,2500 -99'9; 2500 - 99 ~, 2500 -99~,2500 -99~, 250,0 46 ~ 't 250 -999 2500 .,,, -999 0 -,999 0 "999 2500 2 03 "II° ,,,999, ~$00 ,~999,2500 .999,2500 999,2500 -99'9' 2500 '999,15~0 2~, 5 1. 999,2500 ~999,250:0 ::9:99,.250:0 ° ' 999,,2500 49 ~:5e:25 i'50o .: :' Z, bt4 ,,,: TNR. A CFTC LVP OlO.H02 VERIFICATION LISTING PAGE 1.4 DEPT ~C TNR NTC URAN CNTC -999.~00 NPHI SG~ -999. O0 CGR ~3NG -999,2500 W2NG [.RAN -999.2500 POTA 5000 0000 '999 0 ' 9 '0 0 '9 2 -9 2500 EPT 4900.0000 ~bD -99 2500 RCFT NTC .9 N H! 2500 500 POTA .N DEPT ~800.0000 TENS ~bD 999,2500 RTNR ~9.99,2500 RCFT CN'TC -999,2500 NPHI SGR '999:,.'~500 CGR WSNG -999, '~0 PO?A URAN '999, 0 W2NG I~D 999,;~'50u SP ETNE -999~2:500 RCFT CNTC -999:,2500 N:PHI '999,2'50'0 CGR - 9, ~00 :UR'~ TA DE,PT 460:0 0:000 T~NS CN:TC -., C, ~ 3,NG -:99 O0 WiNG N 2 5.00 P'O~A TENS SP RCFT NPH[ CGR POTA DE:PT TENS W3NG W2NG POTA 4.400,0000 TENS -999 2500 -999.2500 -999.2500 -999,2500 · .999, 0 '999, O0 '999. O0 '999,2500 "999,2500 '999 2500 '999 2500 '999 2500 '999 2500 '999 2500 '999 2500 '999 2500 '999,2500 '"999 ' 999 2' 500 ""999. 2500 ; 2,500 '999. 2500 ',999'2500 "999,, 2'500 99,: O0 .9999.1~00 4999,2:500 "99'9,2500 ,..999 500 "99 '999 O0 '999 O0 999,2500 -:999,2500 ':999, 0 99:9:;2::~00 "999'2:500 SGR W5NG WiNG TENS SFE, U TENS RCNT TENS TENS RCNT W5NG WlNG TENS SFLU TENS RCNT SGR WSNG TENS TENS SG:R ~ING TENS SF~U TENS RCNT WSNG WiNG R:CNT TENS $ F b U :999.2500 999.2500 3100. 0 -999 2500 -999 -999 .999 2 'oo 0000 '999,2500 '999,2500 -9 ,,2500 -~99,2500 - 99,2500 3250,0000 999,2500 99'2500 "~99,2500 '999,2500 '999'2500 ,0000 '99:9~2500 "999,2500 '999'25'00 - :9,50 -999,.2,:$00 2980,0000 -' 2500 iO:O -999,2500 TENS W4~G THOR I~ TNRA CFtC TENS W4NG THOR ?NRA CFTC TENS W4NG THOR GR TNRA CFTC TENS W4NG T. NRA TENS W4NG IHOR R INRA FTC W:4,NG THOR 999,~ - , .~00 -999, 500 '9~9t.2500 ,9062 -999,2500 ,_2500 ',2500 "994), 2500 ,5938 -999,2500 -999,2500 -999':2500 -,999,~ -99__ ,25oo 2~,0'938 ~999,2500 999, ,,99~; 2.500 .-999,25.00 999..$ ,,,99~ iO0 -9~ <,0.0 -9, ~0'0 )0 . ,.9 -9'99 i 0 5:i: ,,.! !0 -.::9;9:9:, 2'500 LVP 010,H02 VERIFICATI[)I~ LISTING PAGE 15 -999 2500 -999 2500 0 -999 -999 25OO =999 2500 4300 0000 -999 25O0 -'999 2500 ~1999 2500 -999 250O -999 250O -999 2500 4200.0000 -9,99m2500 .999,2500 -999'25'00 -99'9'2500 4100,0000 -999,,,2500 9,~9,~2500 :999,2500 9~9~2,500 4~0,0 0000 iO 0 ,~, oooo - i,O 0 RCFT NPHI CGR W2NG POTA SP RCFT NPHI CGR W2NG POTA TENS RC'FT NPH! CGR W2NG POTA TENS RCFT NPHI CR ~:~NG RC'FT NPH! W2':NG POTA R:CFT W~NG TENS R.CFT NPH I CGR W2, NG P:O:TA -~99 2500 - 99 2500 -999 2500 -999 2500 -999 2500 ~999 2500 :999,2500 ~999,!500 999, 500 ~999e.$00 '999,2500 -999, :999 2500 O0 -999 0 -999 0 0 -99,9,~$00 -~99,~500 .999'~500 -999,2500 '999'25'00 -999'2500 -99 ~'99912500 ,sOo -9 ! $ 00 -' !:50'0 "99' '999, 0:0 O0 O0 -:91 O0 · -,' 0:0 TENS SGR W5NG WiNG TENS SFLU TENS RCNT SGR W5NG WING TENS SFbU TENS RCNT W5NG WiNG TENS srbu TEN RCN~ 8GR WSNG WiNG TENS 8Fb,U l~N 8GR WSNG WING TENS SFLU TENS RCN:T W ~:N:G W 1 NG TEN8 S:F bU TENS RCNT W N ~999,2500 TNRA ,00 TENS O0 THOR 2864,0000 GR -999 2500 IbM ~999 TENS =999~2500 WCNG -999,2500 THOR 2780,0000 GE -999 2500 IbM -9'99;250u CFTC ,2500 W4NG "999,2500 THOR 2790~0000 GR "999,2500 "999,2500 TNRA -999,2500 CFXC -999 -999~2500 2B6o;oooo OR' '.999: iO0 l'bN NRA ::FTC TENS w4,NG T:HOR GR TNR:,A TENS W4NG TN:RA W4NG -999,2500 -999;2500 -9~,~$oo -999,2)00 -99~,~$00 3'5,6250 -999,2500 -9 9,'5 0 -999,250'0 -999.~500 LVP 010,HO2 VERIFICATION bISTING PAGE DEPT RTNR CNTC URA~ DEPT ILO RTNR CNTC 3NG URAN DEPT R~NR CNTC URAN DEPT ~TNR C,NTC DE:PT 'R?LR c ,Tc CNTC 3700 0000 TENS -999 250o SP -999 2500 RCFT '''9 9 0 CG'R -999 2500 W2NG -999 2500 POTA 3600,0000 TENS -999,2500 SP -999;2500 RCFT -999,2500 NPH! -999,2500 CGR -999,2500 W2NG -999.2500 POTA 3500 0000 TENS '''999 2500 SP '''''999 2500 RCFT 00 N,PHI 999 2 0 CGR '999 2~00 W2NG '999 2 O0 POTA 3400'0000 TENS -99~,25:00 SP -99 ,2500 RCFT *999;2500 CGR -999,2500 ~2NG -:9:99;:3500 POTA 33'00 0000 TENS '" SP "~ RCFT '~ NPH! -~ CGR -:I ~2N'G POTA TENS S~ RC:FT N,PHI CGR' -999.~250~ ~2HG ~999',25:00 PO?A 3189 0000 TENS ":~ RCFT '''9'99 0 NPHI -999 2500 SFLU -999:.~500 TENS -999,2500 RCNT -~9~,~00 SGR ' 9 ,'00 WSNG '999.~00 W1NG '999. O0 TENS -999 -999 -999 -999 -999 -999 -999 2500 SFbU 0 RCNT 50o 8GR 0 W5NG 2500 WING 2500 TENS -999 2500 SFI.,U -999 2500 TENS -999 2500 RCNT -999 2500 SGR -999 2500 W5NG '"999 ~5()0 WING '999 500 TENS "'9'99,2500 SFbU '999.,2500 TEN -999,2500 RCN~ '999,2500 SG.R '999.2500 W5NG -999,2500 W1NG -9'99., 2500 TENS :999.2500 SrbU 999 2500 TENS "999.2500 RCNT "999:,2500 SG'R -999,25.00 WSNG .,9'99., 2500 W1NG '"999,2500 TENS -999,2500 SFLU - 999 ;. 25 O0 TICN:S 9 2:5:0:0 RC'N'T -999, ',2:5 O0 W 5 " 99,: O0 ,2500 SFLU '999', O0 TENS -999,,2500 SGR -999;; 2500 ~SNG -999 2500 -999 ~00 TNRA '999 O0 CFTC '999 ~00 TENS -999 O0 W4NG 540 0 GR -999.2500 IbM -9.~9,2500 TNRA "9 9,2500 CFTC '999,2500 TENS -999,2500 H4NG -999,2500 THOR 2484,0000 GR '999,2500 "999', CFTC "999,2500 TENS -999,1500 W4NG -999, 500 THOR 2340, 000 GR -999,2500 ~bM -999 TNRA -999;.2500 TENS -999.2500 W4NG THOR ,2500 .,oooo -999 o 'zb -9 )0 TNRA '9 ~0 CFTC '9! )0 TENS '" )0 ~4'NG -i iO0 -,999:,,2500 ~,NRA '99:9::.2500 CFTC mgl :500 TEN& '9! ):50 O: W 4 NG -:91 ;00 THOR 2'5~ ~0;0 G:R TNRA CFTC TE S i!99.2500 99.2500 99'2500 9 ,200 '999,2500 oo :II : ,oo '?19 .999 2500 -999 25.00 -999 250,0 -999~2500 49,6563 ,.9'99,2500 .,999.25.00 ,,,999' 2:$'00 .- 9,. : 0 ,. 999,2500 5,:~ ;:O:3, t 3 '" ! ~0 "' :00 .99:9 -9," ~0 ,- ~0 - 1500 ,,,9.99 [.VP Ol.O.H. 02 VER'[FICATION LISTING W3NG ,,Egg.2500 W2NG :999,2500 WiNG -999.~.500 THOR -,999.2500 URAN -999,2500 POTA 999.2500 TENS -999. 500 GR 999,2500 ** FILE TRAILER ** FILE NAME :EDIT ,00! SvERVICF., NAM~ : ERSION # DATE : ~hX.,IMU~ bEN~ S 1024 FI[~ TYPE ~TH NEXT F~LE NAME : EOF ** TAPE TRAILER ** SERVIC~ NAME :EDIT DATE :88/01/18 ORiG)N :7256 TAPE_NAME CONTI~IUATION # NEXT,TAPE NAME COMMENTS :EDIT LI$~ARCO PRUDHOE BAY DS 18~17~AP.! ~R:~ICE NAME :EDIT A,'TE ,E~.~AME ,72'564 # REEL N'AMENTS {EDIT i!S,ARCO PRUDHOE ,BAY DS 18-17,~PI 50-029-21768 ********** EOF ********** EOF