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Home My WebLink About192-156 ‘qt-k5, Cook Inlet Energy_ RECEIVED JAN 2 9 2015 January 27, 2015 AOGCC Mr. Edward Kowalski UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency(OCE-082) 1200 Sixth Avenue, Suite 900 Seattle,WA 98101 SCANNED i (A i) 4 Re: Cook Inlet Energy(CIE) Class I Wells Quarterly Report Dear Mr. Kowalski: Please find the injection reports for CIE's Class I disposal wells WMRU 4D and RU D1 for the fourth quarter of 2014 required by Condition El of Part II of EPA Permit No. AK-1I007-A. Copies of EPA Form 7520-8 are attached for either well, as well as graphs of the daily injection pressures and rates. All maxima and minima presented on the form are calculated from daily values. Please find attached a CD containing electronic records of daily injection pressures and rates. Fluids injected into WMRU 4D this quarter were exempt and/or non-hazardous. Primarily this was produced waters from the West McArthur River Unit(WMRU),but also consisted of small quantities of produced water from the West Foreland Gas Field,rainwater from secondary containment areas. Solids processed through a grind and inject facility are occasionally injected into WMRU 4D. Solids are slurried with bentonite and water prior to injection. The water is either fresh water from a nearby lake or produced water from WMRU. All solids are exempt wastes: drilling muds and cuttings and tank bottoms from crude oil production tankage. The density of the injected slurry is in the range of 8.3 — 8.7 lb/gal. Solid percentages are in the 5 — 15%range and may not exceed 20%. Fluids injected into RU D1 were greywater, deck drainage,produced water, and boiler blowdown. Flash point and TCLP testing for volatiles, semivolatiles and metals has confirmed that Osprey platform deck drainage and greywater are non-hazardous. TCLP testing for metals has confirmed that boiler blowdown is non-hazardous. Solids processed through a grind and inject facility are also occasionally injected into RU Dl. As at WMRU, the solids were slurried with bentonite and produced water prior to injection. All solids have been exempt wastes: drilling muds and cuttings. The density of the injected slurry is in the range of 9.6— 11.3 lb/gal. Solid percentages are in the 12— 17% range and may not exceed 20%. Neither well underwent mechanical testing during the last quarter. 601 W 5th Ave.,Suite 310,Anchorage,AK 99501 "I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that,based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fines and imprisonment". Sincerely, (ateA/( 6/OA-- Karen Brown Environment Manager Cc: Mr. Thor Cutler(OCE-127) Mr. Jim Regg Mr. Marc Bentley Walter Wilcox, CIE President Attachments OSPREY RU #D1 ONB No.2040.0042 Approval Expires 4130!07 United States Environmental Protection Agency EF,,, Washington,DC 20460 Injection Well Monitoring Report Yer . 2.614 Month Month Month Injection Pressure(PSI) October s. ; November December 1. Mnlmum 3,623 3,450 3511 2. Average 3,760 3,721 ....... .. ... ..,.,. .3,700__,.n," . - 3. Maximum 3,951 " ' 3,995 ' ""'" , 3,900 Injection Rate(GallMln) :_M,._.__ October November December 1. Mnlmum 52.6 24.7 31.9 -._ 2. Average '4170--- 82.3 .w. .70.2,... ,,..._.• . 3. Maximum ......136.3 :, . . . . , .1'52:0 . . 11 :� . , ,.,• Annular Pressure(PSI) October ' ` November ," ""DeoembieI , 1. Minimum 16 j - 15 14 2. Average 19. . .. ... 17 _ , . ."_ ..... .15_ . . ., 3. Maximum 24 19 18 Injection Volume(Gal) October November "'December 1. Monthly Total 4,103,754 3,553,734 1,819,480 2. Yearly Cumulative • 25,947,651 29,501,385 31,320,865 Temperature(F') 1. Mnlmum 2. Average 3. Maximum . pH 1. Mnimum 2. Average 3. Maximum - Other Name and Address of PermitteePermit Number ' Cook Inlet Energy,LLC,601 W.5th Ave.,Suite 310,Anchorage AK 9 01 : AK4I007-A Name andOficial Title (Please type or print) Signature Date Signed Walter Wilcox,President (/t7 / s EPA Form 7520-8(Rev.8-01) \ WMRU #4D ORB No.2040-0042 Approval Expires 4130/07 United States Environmental Protection Agency TEPAWashington,DC 20460 Injection Well Monitoring Report Year r 2014 Month Month Month October ' _ November December -- - Injection Pressure(PSI) 1. Minimum 2,905 2,394 3,126 2. Average • w. u 3,179 W._ + 3,143 ., 3,363 3, Maximum 3,396 " 3,356 3;514 Injection Rate(Gal/Min) ; .. ,.09.,1Nr:..,. ..:. .,,,.,..... ,, December 1. Minimum 359 15.9 41.1 2. Average , -,.. . 68.7. ..,... 55.4 .-_,,....,- ..,. ----77.1 . ----.-„, 3. Maximum 84.5... . _ . .84.9.,, 97.0 Annular Pressure(PSI) October November F December 1. Mnlmum0,0 0,0 ....... .. 0.0 2. Average .. 1,.0 . .. 0.0 i 0.0 3. Maximum 19.0 0.0 0.0 Injection Volume(Gal) October . - November December ... 1. Monthly Total • 3,068,058 . .! 2,393,118 3_443,580 , . 2. Yearly Cumulative • 16,$09,94 19,203,072 22,646,552. . ...... • Temperature(F') 4 1. Mnlmum 2. Average 3. Maximum " , ' pH ,, , .. ; 1. Minimum 2. Average . 3. Maximum . Other ' Name and Address 4f PermittseI Permit Number . ., Cook Inlet Energy,LLC,601 W.5th Ave.,Suite 310,Anchorage AK 99 1 AK1I007-A Name and Official Title (Phase type or print) Signatur / Date Signed Walter Wilcox,President ‘..1.9.q.../..1.5".... EPA Form 7520-8(Rev.601) . • (Aep/m) auanion uo! pa(ui o0 0 0 0 0 0 o 0 o O o CO to Ni. M N ,- O f f46/4Z/Z6 ww} 1 s . 4 4 • _46/L6/? 4 • 4 • 4 • 4 • 4 • 4 4 A « _46/0626 4 4 • 4 • 4 • 4 • 4 •4 • 46/£/Z6 y 4 • 4 • C N 4 0 4 • 'U 4 • 0 • C • .46/9Z/66 — 4 • 4- • 0 • - 4 • D N 4 • 4 • I 4 • _46/66/66 4 • C w• 0 w • • 4 • t0 4 • a CD w • _4626/66 Cr) '_ 4 • C _ 4 • • r 4 7 0 4 • 0 I • wCL•• _46/9/66 IX 1 4 • 4 4 4 • 4 • • -46/6Z/0I. 4 • 4 • 4 • 4 • 4 • 4 • • -46/ZZ/06 4 • 4 • 4 • 4 • 4 • 4 •• _4 6/9 6/0 I. 4 • 4 • t • 41 • 4 • A • • _46/8/06 4 t • t • 4 • 4 • i • 4 4 46/6/06 0 0 0 0 0 0 0 0 o O to O to O to O to O Uf) 7 N) C') N N (e!sd) aanssa,Jd uogoeful • 4 • bL/LE/ZL 4 • 4 . 4 4 • i • 4 41 • _17L/17Z/ZL 4 • 4 • A • 4 • i • 4 A •• _171/LL/Z1 4 • 4 • A • 4 • 4 • 4 • 4 • _VIA L/ZL 4 • 4 • 4 • 4 • 4 • i i • (.7)i • 171/E/Z1, d i4 4 � c i • H • 0 bl/9Z/LL NI- 3 i 4 D i . I . 4 0 7 . • U) i .4 • i s • _bL/6L/LL I 1 4 4 C 1 s i 4 4 O 4 • i 4 CD4 •t _171/Z 1/11 2 .—1 i I .o C 4 • c 4 4 o 0 4 o • N d' 4 • C �_/ 4 i 4 _bL /9/LL 0 — LL 4 • i 2 . • D t • 4 4 4 4 b 1/6Z/0 L 4 e • 4 4 4 4 i 4 4 4 4 • 4 • _171/ZZ/O I- 4 4 • i • 4 4 4 • • i • • 17119E/OL 4 • 4 • 4 • 4 • 4 • • _b 1/8/0 L • • 4 • I 4, i 4 4 • • bL/1/01 oo o 0 0 0 0 0 0 0 o to o to o ul o to d' M M N N (eisd) aanssead uog3e ui Is (fepjigq) euanion uoipe ui Im~'-,. Project Well History File Cov,"-'~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing ~o~.:~ RESCAN Color items: [] Grayscale items: Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~~I~/INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation ~ x 30 = (~'(~) OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OV~J~ D (Non-Scannable) ~ Logs of various kinds Other BY: BEVERLY ROBIN VINCENT SHERYL~~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES Stage 2 IF NO IN STAGE t, PAGE(S) DISCREPANCIES WERE FOUND: BY: BEVERI(~INCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) NO YES ,~ NO III IIIIIIIIIII II RESCANNEDB¥; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY · General Notes or Comments about this file: DATE: IS/ Quality Checked ~....:.,:: 12/10102Rev3NOTScanned.wpd / 72 - /5'~ ~ ~ @ FOREST OIL CORPORATION S10 d7Cc;?høø¿-. 6l:dW 700 ~~J Q9fÍ~ .9.9501 (907) 258-86'00 . (907) 258-86'01 (øax) May 9, 2003 Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. ih Avenue Suite 100 Anchorage, Alaska 99501 Re: West McArthur River Unit #01 Plug and Abandon Mr. Maunder, Steve Davies contacted Rob Stinson recently asking about pictures of the wellhead cut-off. Attached are two pictures. The first shows the cut casing with the marker and the second shows the marker up close. The foreman on the job did not notify AOGCC directly of the cut-off operation. The correspondence between yourself and I was assumed to be notification of our schedule and activities. Although the pictures don't show it, cement was found in the outer annulus 8 ft below the cutoff. This was filled up to the cutoff with new cement. If there are any questions, please contact me at 907-258-8600. -,~ Paul D. White Drilling Manager - Alaska Division Forest Oil Corporation RECEIVED MAY 0 9 2003 Alaska Oil & Gas Cons. Commission Anchorage Attachments: Pictures of Wellhead and Marker Plate Date Modified: 5/9/03 Date Prepared: 5/9/03 rds M:\WMRU #D1\Rig P&A\WMRU #D1 Followup.doc Forest Oil Corporation Alaska Division 3] 0 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL Date: August 18, 2003 To: Lisa Weepie/Howard Oakland AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 !Phone: (907) 279-1433 From: Linda M. Starr Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Phone: (907) 868 - 2162 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION: Well West McArthur River#D1, AP1#50-133-20446-00 1 Blackline 4/8/2003 Perf Record 5" 1,369 1,367 1 Film 4/8/2003 Perf Record 5" 1,369 1,367 1 Color 4/9/2003 Perf Record 5" 201.1 199.1 1 Film 4/9/2003 Perf Record 5" 201.1 199.1 Please sign below to acknowledge receipt. IReceived By: Date: Date Modified:8/18/2003 Date Prepared: 12/6/00, bk RE: Abandonment WMcRU #D1 Subject: RE: Abandonment WMcRU #D1 Date: Fri, 9 May 2003 15:51:32 -0600 From: Paul White <PDWhite@forestoil.com> To: 'Tom Maunder' <tom_maunder@admin.state.ak.us> CC: Rob Stinson <RDStinson@forestoil.com>, Osprey Company Man <ospreycm@starband.net> Tom, Thanks for your note. I realized too late that the Forman had assumed that we had done the communication. I will not let this happen again. Thanks for your patience. Paul White Forest Oil Corp. Drilling Manager 907 868 2134 Cell 907 242 3305 ..... Original Message ..... From: Tom Maunder [mailto:tom maunder~admin.state.ak, us] Sent: Friday, May 09, 2003 1:39 PM To: Paul White; Rob Stinson; Steve Davies Cc: AOGCC North Slope Office; Jim Regg Subject: Abandonment WMcRU #D1 Paul, I have received your letter with photos attached of the marker plate and "working hole" after the casings had been cut off on the subject well. We had earlier received the 10-407 which formally communicated the information regarding the abandonment of the well. It appears that an Inspector did not "view" the final cut off prior to the marker plate being welded on. In your letter you state that by virtue of our conversations and messages on the changes necessary in the plan that proper notice regarding the work was given. I do have an email from you date April 8 regarding the difficulties encountered attempting to circulate outside the 7" casing and proposing to change the abandonment program. I believe we did talk on the circulation difficulties and I responded with an email giving approval of the change. I did understand from the message and our conversation that the work was in progress, however the responsibility of coordinating with the Inspectors for the opportunity to witness an operations (plug setting, cut off, BOP test, etc.) is that of the Company Representative performing the job. There are a host of possibilities out there when well work is being performed and the person on the job should have the best sense of timing as well as what travel logistics are possible. For future activities, please have the responsible foreman/supervisor take the lead for contacting the Inspector. In most cases, this will put the 2 people that will be present when the work is accomplished in contact with no "middle men". As you are aware, the Inspector's voice line is 659-2714 and their pager is 659-3607. With few exceptions (Thanksgiving, Christmas and New Years), someone is available at those numbers 24/7/365. Please call me if you have any questions. Tom Maunder, PE AOGCC : g o RES T O I L C O R P O R A T I O N May 5, 2003 Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: West McArthur River Unit #D1 Plug and Abandon Ms. Palin, West McArthur River Unit #D1, a class II disposal well was permanently plugged and abandoned. This well was abandoned due to a mechanical integrity problem. A P&A attempt, without a rig failed in the Summer of 2002. The abandonment just completed was performed with a service rig. If there are any questions, please contact me at 907-258-8600. Paul D. White Drilling Manager-Alaska Division Forest Oil Corporation Attachments: 10-407 Well Completion Report and Log Completion Schematic- April 2003 Operations Log RECEIVED MAY 0 6 2003 Alaska Oil & Gas Cons. Commission Anchorage \V~NCFLSI~ANC_Drilling\WMRU #Dl\Rig P&A\WMRU #D1 Cover 407.doc ' ORIGINAL ~CANNED "JUL 1 8 20113 Date Modified: 5/5/03 Date Prepared: 5/5/03 rds STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number Forest Oil Corporation 303-069 ! 9~-/5 ~ 3. Address 310 K Street, Suite 700 8. APl Number Anchorage, Alaska 99501 50-133-20446-00 4. Location of well at surface .... :.;7/., ~%;;.-..~-'~, 9. Unit or Lease Name ' ~..J~),' L ,... ~t,~;~' ~ 2776' FSL, 1446' FWL, Section 16, T08N, R14W, SM ~,(~-;~ [ West Mc, Arthur River Unit At Top Producing Interval ,*' ~, 10. Well Number ~Zi~ ~::' West Mc, Arthur River Unit #D1 At Total Depth i ___~,.~_i 11 . Field and Pool 2776' FSL, 1446' FWL, Section 16, T08N, R14W, SM Wes McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 163 RKB n/a 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions I 04/12/2003 n/a feet MSLI n/a 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 4,500'/4,500' SurfaceI Yes: No: XI n/a n/a 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 72# N-80 Surf. 131' n/a n/a None 9 5/8" 43.5# L-80 Surf. 1,364' 12 1/4" Surface None 7" 29# N-80 Surf. 4,500' 8 1/2" TOC 1,380' None 24. Perforations open to Production (MD+-I-VD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2 7/8" 4,197' 4,197' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) n/a I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD --> Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => ~) E/~ r" It Ir' I'~ 28. CORE DATA ! ,% L_ ~ L__ I V L_ ~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submi~o'~ chips. ~o.~-,-k-o% ~. ~t,~~&~':)M AY 0 6 2 0 0 3 ,~',~'~,,.,.,'-~\ ~ ~ Alaska 0il & Gas Cons. Commission ~%..~r.:_~%, ~~~6,/~ AnchoraDe Form 10-407 ~' Rev. 7-1-80 CONTINUED OORI~G1ENAL Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS _ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH SSTVD GOR, and time of each phase. 31. LIST OF A'I-I'ACHMENTS Daily Operations Summary 32. I hereby c~f~at the foregoing is true and correct to the best of my knowledge Signed~"~~ \_~'~' ~,/~ Title~DrillingManager 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 space 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 productin 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 We~cArthur River Unit #D1 3/8" NS0 72 # Welded 131' MD L 80 LTC 1,364' MD 7rr TIW Packer retrievable 4,197' Tubing tall to 4,203' Pel'fs · 12 spf (4,289' to 4,351') N-80 LTC 4,500' MD West McArthur River Unit #D1 P&A- April 2003 Operations Log April 04~ 2003 06:00 to 00:00 Rig up on WMRU # D-1 00:00 to 05:00 Assemble BOP stack in cellar area for quick application. 05:00 to 06:00 Remove tree from well # D-1. April 05~ 2003 06:00 to 14:00 Weld threaded connection to tubing hanger. Remove cement in tubing hanger and into first joint. 14:00 to 22:00 Nipple up BOP. 22:00 to 02:00 Test BOP. 02:00 to 06:00 Rig up free point hanger. Shoot off tubing below hanger. Pull on tubing hanger. Hanger not free. April 06~ 2003 06:00 to 12:30 Unable to jar tubing hanger free after jet cutting below hanger. 12:30 to 14:00 Jar tubing hanger free. Lay down tools. 14:00 to 20:30 Pick up rotary drive, kelly, swivel, and wash pipe. 20:30 to 22:30 Fish short cut offpiece of tubing from top of string. 22:30 to 06:00 Wash over cemented in string from 18' to 38'. April 07~ 2003 06:00 to 18:00 18:00 to 20:00 20:00 to 23:00 23:00 to 02:00 02:00 to 03:00 03:00 to 06:00 Wash over cemented pipe to 180'. Free after 125'. Lay down kelly and swivel. Stand back wash pipe. P/U kelly. Dress overshot. Mill top fish at 24'. Engage fish. Attempt blind back off. Twisted rig rotary drive shaft off. Repair rotary drive shaft. Blind back off with intentions of recovering 2000' of pipe. Back off successful. Lay down kelly. Pull out of hole with 2 7/8" tubing. April 08~ 2003 06:00 to 13:30 13:30 to 14:30 14:30 to 21:30 21:30 to 22:30 22:30 to 00:30 00:30 to 02:30 02:30 to 06:00 Lay down 132 joints of 2 7/8" tubing. Lay down fishing tools and wash pipe. Pick up 3.5" D.P. 7" scraper, 6" mill and drill collars. RIH to 1635'. Cut drilling line Circulate at 1635' POH. Lay down drill collars. Perforate with Schlumberger 1367' to 1369'. 2' perforated, 6 shots/ft, 13shots, 360 deg phasing. April 0% 2003 After scraping the 7" casing to 1635', Schlumberger perforated just below the 9 5/8" shoe at 1367' to 1369'. A bridge plug was set at 1325' and after stabbing in with the stinger, several attempts to circulate the annulus were made in both directions with no success. The 7" casing above the bridge plus held a good test at 1500 psi. BJ Services squeezed 7 barrels of cement through the plug and out the perforations at 500 psi. 7.5 barrels of cement was left on top of the bridge plus making 202 ft of height. A second bridge plug was set at 210' and this morning Schlumberger will shoot squeeze perforations above it so that cement can be circulated into the 9 5/8" by 7" annulus. April 10~ 2003 A Baker Oil Tool bridge plug was set at 210' and squeeze perforations were shot just above it at 200'. With pressure on the 7" casing we were unable to circulate the 9 5/8" by 7" annulus working with 500 psi and losing fluid into the formation. Another attempt to reverse into the annulus failed with the pressure jumping up to 1500 psi and holding rock solid. The perforations drank a little fluid until we pumped in 5.5 barrels of cement on top of the retainer. Shortly thereafter the well stopped taking fluid. The BOP and well head were removed and cement was tagging inside the 7" at 50' rkb. This remaining area was then filled with cement. Probing the annulus it was found to be solid at 8' below the cut off. After determining that this was impassable the annulus was also filled with cement. The remainder of the night was spent cleaning the mud pits, rigging down the cement unit, drying up the pumps, organizing rental tools and rigging down fluid and gas monitoring equipment. April 11~ 2003 Cleaning mud pits, rigging down the cement unit, drying up the pumps, organizing rental tools and rigging down fluid and gas monitoring equipment. Clean contaminated cement from cutting tank. Lower rig floor, lower and lay down derrick, remove dog houses from rig floor. Aprill2~ 2003 Rid down, load out rig, clean / organize location, palletize rental BOPE and tools, clean and roll up liner and felt, (palletize for production use). Haul loads and stage at barge ramp. Dig out old cellar culvert, break up cement and excavate cellar bottom dirt. Dig down 8' below present ground level and prep. To cut off casings 6' below present ground level = 3' below original ground level. RE: U-1 al3an(:lonmen~ Subject: RE: D-1 abandonment Date: Tue, 8 Apr 2003 19:13:36-0600 From: Paul White <PDWhite@forestoil.com> To: 'Tom Maunder' <tom_maunder@admin.state.ak.us> Yes Tom it has been tested to 1,500 psi. We had that pressure on it when we were attempting to circulate around and it held fine. Paul White Forest Oil Corp. Drilling Manager 907 868 2134 Cell 907 242 3305 ..... Original Message ..... From: Tom Maunder [mailto:tom maunder~,admin.state.ak, us] Sent: Tuesday, April 08, 2003 5:07 PM To: Paul White Subject: Re: D-1 abandonment Paul, Thanks for the information regarding the change in plans. Your revised plans are acceptable. You have approval to proceed as planned. Only other question I have is, has the 7" casing been pressure tested?? Given that the plans are changing, having a test of the 7" above the retainer presently in the hole might be a good bit of information to get. Tom Maunder, PE AOGCC Paul White wrote: > Tom, > We have been unable to circulate the 7" by 9 5/8" annulus on D-1 in order to > cement between these strings. We have perforated 2' w/6spf at 1,367' to > 1,369' and set retainer at 1,325'. The shoe of the 9 5/8" is at 1,364: I > would like to squeeze cement through the retainer and perfs @ 1,369' and > place cement on top of retainer at 1,325'. We would then set a retainer at > 200' and shoot squeeze perfs above that and attempt to circulate cement to > fill the 7" X 9 5/8" annulus. If we were unable to circulate this annulus we > would fill the 7" to the surface and make the cut off. At this point we > would run small pipe down in the 7" X 9 5/8" annulus as deep as possible and > do a top cement job before welding abandonment plate on well. > Paul White > Forest Oil Corp. > Drilling Manager > 907 868 2134 > Cell 907 242 3305 1 of 1 4/9/2003 8:25 AM file:lllUntitled 2 of 2 ,-,. __ __ -,~ , . :,,-> t,~, ,---,% 3/6/2003 10:56 AM FOR E ST OIL C O R P O R A T I O N March 4, 2003 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 Anchorage, Alaska 99501 Attn: Mr. Tom Maunder Re: West Mc, Arthur River Unit #D1 - Plug and Abandon Mr. Maunder, We request to Plug and Abandon the West McArthur River Unit #D1 Class II disposal well, with a service rig. Please find attached the Application for Sundry Approvals. The well was unsuccessfully plugged last summer. If there are any questions, please contact me at 907-258-8600. Paul D. White Drilling Manager- Alaska Division Forest Oil Corporation Attachments: 10-403 Application for Sundry Approvals Outline Summary Current Well Schematic WMRU #D1 Wellhead and BOP configuration M:\WMRU #D1Rig P&A\WMRU #D1 Rig P&A Cover 403.doc Date Modified: 3/4/03 Date Prepared: 3/4/03 rds ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X "'"' Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Forest Oil Corporation Development: 163' MSL 3. Address Exploratory: 7. Unit or Property name 310 K Street, Suite 700 Stratigraphic: West Mc, Arthur River Unit Anchorage, Alaska 99501/. ~ J Service: X 4. Location of well at surface ,,~ 8. Well number 2776' FSL, 1446' FWL, Sec. 16, T8N, R14W, SM West McArthur River Unit #D1 At top of productive interval 9. Permit nu~mb~ 92-156 v. At effective depth 10. APl number 2776' FSL, 1446' FWL, Sec. 16, T8N, R14W, SM 50-133-20446-00 At total depth 11. Field/Pool 2776' FSL, 1446' FWL, Sec. 16, T8N, R14W, SM West McArthur River Field 12. Present well condition summary Total depth: measured 4,500'~f~'" Plugs (measured) 2 7/8" Tubing plugged at surface true vertical 4,500' Effective depth: measured 4,407' Junk (measured) Fill and fish in 2 7/8" tubing at -3,700' true vertical 4,407' Casing Length Size Cemented Measured depth True vertical depth Structural N/A N/A N/A N/A N/A Conductor 131' 13 3~8" Driven 131' 131' Surface 1,364' 9 5~8" Surface 1,364' 1,364' Intermediate 4,500' 7" TOC 1,400' 4,500' 4,500' Production (Liner) Liner Perforation depth: measured 4,289' to 4,351' 12 spf "' true vertical 4,289' to 4,351' 12 spf , ,,,", :~"~, ': ,~, Tubing (size, grade, and measured depth) 2 7/8" N-80 at 4,203' '. Packers and SSSV (type and measured depth) TIW Retreivable at 4,197' ... ';'.:-....::','... ' ....... 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for comme[~'~ng operation 15. Status of well classification as: 01-Apr-03 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of a.,~r~ver Date approved Service: Class II Disposal 17' I hereby t~ng is true and c°rrect t° the best °f mY kn°wledge'I~" Signed: \ ~,~l,/V~~ Title: Drilling Manager, Forest Oil Corporation Date: FOR COMMISSION USE ONLY . Conditions of approval: Noti, i~ Commission so representativex may witness,~~lAppr°val No. Plug integrity /~. BOP Test Location clearanc.e /~, 3~..~ Mechanical lntegrity Test Subsequent form required l0- ~-O'~ 'T'~'~ ~0~ E" '~ Approved by order of the Commissioner ..-, Commissioner Date Form 10-403 Rev 06115188 ! SUBMIT IN TRIPLICATE 2.) 3.) 4.) 5.) 6.) 7.) 8.) 9.) 10.) 13.) WMRU #D1 Proposed P&A Procedure Move in and dg up workover rig. Set BPV Nipple-down 11" 5M Injection Tree Nipple-up and Test 11" 5M BOPE. Test to 3,000 psi. Pull 2 7/8" tybing and clean out cement down to 1,400'. Note: estimated bottom of cement in tul~ing and annulus to be at 160'. Perforate 7" long string at 1,380'. Set bridge plug at 1,360' Sting into bridge plug and circulate 40 bbl of cement through perforations and back up the 7"x 9 5/8" annulus. This goal is to bring cement back to surface. Un-sting and spot 10 bbl of cement on top of bridge plug. This is the drillpipe volume from surface to the bridge plug. Set bridge plug at 200', Spot 8 bbl of cement on top of bridge plug. Nipple-down BOPE Remove well head and cellar, cut and pull casings from at least 3' below original ground level - not rig grade. Weld on steel plate with required data as per 20 AAC 25.120 WELL ABANDONMENT MARKER. Fill and compact excavation, grade area as appropriate. M:\WMRU #Dl~Rig P&A\WMRU #D1 Rig P&A. doc Date Modified: 3/4/03 Date Prepared: 2/10/03 rds West ~lcArthur River Unit #DI Tubing and tubing annulus have cement down to an estimated 160' ~13 3/8" NS0 72 # Welded 131' MD 9 5/8" L 8O 43 5 ¢¢ LTC 1,364' MD 2 7/8"6 5# L-SO 8rd EUE tubing 3706' to 4058' 7" FIWP;lcker retrievable4,19? Tubing tail to 4203' Perrs - 12 spf {4,289' to 4,351 ') 29 # LTC 4,500' MD West McArthur River Unit #D1 BOP Layout 11" x 5M Annular BOP 11" x 5M Gate (blinds) 11"x 5MGate (pipe) 7 1/16" 3M x 11" 5M XO 11" 3M x 7 1/16" 3M Tubing Head 9 5/8" Weld-on x 11" 3M Casing Head 11" 5M x 11" 5M Mud Cross w/two 4" 5M outlets --- Choke side: 4" 5M manual, 4" 5M HCR, 4" 5M x 3 1/8" 5M DSA Kill side: 4" 5M x 2 1/16" 5M DSA, 2 1/16" 5M manual, 2 1/16" 5M manual, 2 1/16" 5M check Disposal Injection Order No. 7 http:llwww.state.ak.usllocallakpageslADMINIogcloindexldioldio7.htm ¢¢ 'I' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: The REQUEST OF STEWART ) PETROLEUM COMPANY to dispose ) of Class II oil field fluids by ) underground injection in the West ) McArthur River D-1 well. ) Disposal Injection Order No. 7 West McArthur River D-1 well April 19, 1993 IT APPEARING THAT: 1. Stewart Petroleum Company by correspondence dated March 3, 1993 made application to the Alaska Oil and Gas Conservation Commission (AOGCC) for authorization to inject Class II waste fluids into the West McArthur River D-I well. 2. Notice of an opportunity for public hearing was published in the Anchorage Daily News on March 5, 1993. 3. No protest or request for a public hearing was timely filed. FINDINGS: 1. No wells penetrate the proposed injection zone within a one-quarter mile radius of the West McArthur River D-I well (WMR D-I). 2. Cook Inlet Region, Inc., State of Alaska, Salamatof Native Association, Inc., and Phillips Petroleum Company are offset operators and surface owners within a one-quarter mile radius of the WMR D-I and have been duly notified of the proposed plans. 3. CIRI has designated Stewart Petroleum as operator of the WMR D-I. 4. The WMR D-I was drilled to the subsurface estate of Cook Inlet Region, Inc. (CIRI) to a total depth of 4502 feet measured depth. 5. The Tyonek Formation consisting of Lower Tertiary aged, massively bedded, fluvial deposits is present within the WMR D-I from approximately 3000 feet measured depth to total depth. 6. A highly porous and permeable sandstone with calculated porosity and permeability of 32 percent and 1600 millidarcies respectively is present from 4283 to 4351 feet measured depth (4120 to 4188 feet subsea). 7. Formation water with total dissolved solid (TDS) content of at least 11,800 parts per million (ppm), as determined by EPA method 160.1, is present in the sandstone occurring from 4283 to 4351 feet measured depth. 8. An impermeable confining zone composed of shale, coal and minor discontinuous sands and siltstones is present in WMR D-I from 4184 to 4282 feet measured depth. 9. Openhole wireline log analyses and EPA-approved laboratory analyses of formation water samples indicate underground sources of drinking water (USDWs) are present (TDS < 10,000 ppm) to 4184 feet measured depth (4021 feet subsea) in WMR D-I. 10. Openhole wi~~ alyse~~dicate the deepest non-exemptable aquifer (TDS < 3000 ppm)occurs at a measured depth I~335 feet~/..~.--~ 11. Nine and 5/8-incl%'satfac~'~a~ing string is set at 1361 feet me'a~ured depth, cemented to the surface and tested to 2500 psi. 12. Seven-inch casing is set at 4500 feet measured depth and ce~...r~ted to at least 2000 feet above, its base. 13. Two and 7/8-inch tubing with packer is installed, with the packer set at 4197 feet measured depth. 1 of 3 3/6/2003 4:26 PM Disposal Injection Order No. 7 http:llwww.state.ak.usllocal/akpageslADMINIogc/oindexldioldio7.htrn 14. With tubing and packer in place, the 7-inch casing was pressure tested to 1000 psi. 15. Cement evaluation tools run in WMR D-I indicate good to excellent cement bond over most of the cemented interval of the 7-inch casing string. 16. The operator estimates that the injection rate will not exceed 6000 bbl/day. ~,~.~:,~--.'~ ~--~3~--~ 17. The estimated average operating pressure will be 800 to 1000 psi and the maximum anticipated surface injection pressure will be 1115 psi. 18. A three-dimensional hydraulic fracture simulator run at rates and pressures exceeding those planned in the WMR D-I, due to wellhead and equipment limitations, indicates induced fractures will not propagate through the overlying confining zone. 19. A mechanical integrity test has not been performed on WMR D-I. 20. The operator plans to monitor the 7-inch casing by 2 7/8-inch tubing annulus pressure and report the results on the Monthly Injection Report. 21. Prior to commencing injection operations in WMR D-I, the operator plans to perform a step rate test in order to determine the formation fracture gradient and optimum injection rate. CONCLUSIONS: 1. The approval of disposal injection operations at WMR D-I will not jeopardize correlative rights. 2. Permeable strata which reasonably can be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata are present in the interval from 4283 to 4351 feet_measured c,;Lepth in WMR D-I. 3. The interval from 4283 to 4351 feet measured depth in WMR D-I does not qualify as a USDW. 4. An impermeable confining zone is present in WMR D-I from 4184 to 4282 feet measured depth. 5. Disposal fluids injected at WMR D-I will consist exclusively of Class II waste generated from drilling, completion and production operations. 6. WMR D-I is constructed in conformance with the requirements of 20 AAC 25.412. 7. Well integrity must be demonstrated in accordance with 20 AAC 25.412 prior to initiation of disposal operations in WMR D-I. 8. Operational parameters will be monitored routinely at the WMR D-I for disclosure of possible abnormalities in operating conditions. ~-~'. No application for a freshwater aquifer exemption is required in conjunction with the proposed disposal injection[ ~ project in WMR D-I because TDS content exceeds 10,000 ppm for the formation fluids within the proposed disposal zone, 10. Disposal injection operations in the WMR D-I will be conducted routinely at pressures less than disposal zone parting pressure. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Injection Strata for Disposal. Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for the purpose of disposal into the Tyonek Formation interval from 4283 to 4351 feet measured depth in WMR D-I. Rule 2 Demonstration of Tubing/Casing Annulus Mechanical Integrity Prior to initiating injection and at least once every four years thereafter the tubing/casing annulus must be tested 2 of 3 3/6/2003 4:26 PM Disposal Injection Order No. 7 (. for mechanical integrity in accordance with 20 AAC 25.412. Rule 3 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 4 Step Rate Test Prior to sustained injection the operator shall perform a step rate test to determine a formation fracture gradient and optimum injection pressure. Rule 5 Administrative Action Upon request, the Commission may administratively revise and reissue this order upon proper showing that any changes are based on sound engineering practices and will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated April 19, 1993. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission Russell A. Douglass, Commission Alaska Oil and Gas Conservation Commission Dispose Injection Order Index http:llwww.state.ak;usllocallakpageslADMINIogcloindex/dioldio7.htm 3 of 3 3/6/2003 4:26 PM Summary by Month: Individual Well Injection / Disposal Well Name: W MCARTHUR RIV UNIT D1 APl: 50-133-20446-00-00 Permit to Drill: 1921560 Operator: FOREST OIL CORP Field/Pool: W MCARTHUR R1V, WDSP UNDEFIN Sales Cd: 93 Acer Grp: 1 Final Status: 1WINJ Current Status: WDSPL 1993 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Days Wtr Gas 1993 Invalid Meth. Invalid Meth. Invalid Meth. Invalid Meth. Invalid Mcth. Invalid Meth. Invalid Meth. Disposal Disposal 0 0 0 0 0 0 0 12 30 0 0 0 0 0 0 0 19,377 50,582 0 0 0 0 0 0 0 0 0 Totals: Water 159,673 Gas 0 Cum Wtr 159,673 1994 Jan Feb Mar Apr May Jun Jul Aug Sep Disposal Disposal Invalid Meth. 25 20 31 34,892 21,792 33,030 0 0 0 Cum Gas 0 Oct Nov Dec Meth Days Wtr Gas 1994 Disposal Disposal Disposal Disposal Dispos~ Disposal Dispos~ Dispos~ Dispos~ 31 28 30 30 31 30 31 31 30 47,596 49,777 46,950 60,924 44,860 51,178 15,823 43,228 43,519 0 0 0 0 0 0 0 0 0 Totals: Water 537,262 Gas 0 CumWtr 696,935 Disposal Disposal Disposal 31 28 31 45,179 36,065 52,163 0 0 0 Cum Gas 0 1995 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Days Wtr Gas 1995 Disposal Disposal Disposal Disposal Disposal Disposal Disposal Disposal Disposal 31 28 31 30 31 30 31 31 30 55,421 49,639 57,576 80,245 83,840 73,536 98,443 86,649 78,201 0 0 0 0 0 0 0 0 0 Totals: Water 833,280 Gas 0 Cum Wtr 1,530,215 Disposal Disposal Disposal 31 30 24 67,566 52,684 49,480 0 0 0 Cum Gas 0 1996 Meth Days Wtr Gas 1996 Jan Feb Mar Apr May Jun Jul Aug Sep Disposal Disposal Disposal Disposal Disposal Disposal Disposal Disposal Disposal 31 29 31 30 31 30 31 31 30 56,120 51,748 60,012 74,235 71,221 74,133 81,834 81,457 82,762 0 0 0 0 0 0 0 0 0 Totals: Water 885,817 Gas 0 Cum Wtr 2,416,032 Oct Nov Dec Disposal Disposal Disposal 31 30 31 83,595 83,195 85,505 0 0 0 Cum Gas 0 1997 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Days Wtr Gas 1997 Dispos~ Dispos~ Dispos~ Dispos~ Dispos~ Dispos~ Dispos~ Dispos~ Disposal 31 28 31 30 31 30 31 30 30 83,925 76,073 96,017 93,468 94,753 82,199 113,400 116,842 113,808 0 0 0 0 0 0 0 0 0 Totals: Water 1,112,174 Gas 0 Cum Wtr 3,528,206 Disposal Disposal Disposal 31 30 31 102,191 67,270 72,228 0 0 0 Cum Gas 0 Thursday, March 06, 2003 Page 1 Summary by Month: 1998 Jan Feb Mar Apr Meth Disposal Days 31 Wtr 93,784 Gas 0 1998 Totals: Disposal Disposal 28 31 88,439 99,741 0 0 Water 1,207,881 Individual Well Injection / Disposal May Jun Jul Aug Sep Oct Nov Disposal Disposal 30 31 99,875 98,541 0 0 Gas 0 1999 Jan Feb Mar Apr May Disposal Disposal Disposal Disposal 29 31 31 30 97,135 106,536 105,601 97,479 0 0 0 0 CumWtr 4,736,087 Dec Disposal Disposal Disposal 31 30 31 107,733 105,625 107,392 0 0 0 Cum Gas 0 Jun Jul Aug Sep Oct Nov Dec Meth Disposal Days 31 Wtr 105,235 Gas 0 1999 Totals: Disposal Disposal 28 31 99,740 110,666 0 0 Water 683,347 Disposal Disposal 30 31 106,058 113,304 0 0 Gas 0 2000. Jan Feb Mar Apr May Disposal Disposal Shut-In Shut-In 30 31 0 0 114,556 33,788 0 0 0 0 0 0 Cum Wtr 5,419,434 Shut-In Shut-In Shut-In 0 0 0 ~. 0 0 0 0 0 0 Cum Gas 0 Jun Jul Aug Sep Oct Nov Dec Meth Shut-In Days 0 Wtr 0 Gas 0 2000 Totals: Shut-In Shut-In Shut-In Shut-in 0 0 0 0 0 0 0 0 0 0 0 0 Water 0 Gas 0 2001 Jan Feb Mar Apr May Shut-In Shut-In Shut-in Shut-in 0 0 0 0 0 0 0 0 0 0 0 0 Cum Wtr 5,419,434 Shut-In Shut-In Shut-In 0 0 0 0 0 0 0 0 0 Cum Gas 0 Jun Jul Aug Sep Oct Nov Dec Meth Shut-in Days 0 Wtr 0 Gas 0 2001 Totals: Shut-in Shut-In Shut-In Shut-In 0 0 0 0 0 0 0 0 0 0 0 0 Water 0 Gas 0 2002 Jan Feb Mar Apr May Shut-In Shut-In Shut-In Shut-In 0 0 0 0 0 0 0 0 0 0 0 0 Cum Wtr 5,419,434 Shut-in Shut-In Shut-In 0 0 0 0 0 0 0 0 0 Cum Gas 0 Jun Jul Aug Sep Oct Nov Dec Meth Shut-In Days 0 Wtr 0 Gas 0 2002 Totals: Shut-In Shut-In Shut-In Shut-In 0 0 0 0 0 0 0 0 0 0 0 0 Water 0 Gas 0 Shut-In Shut-In Shut-In Shut-in 0 0 0 0 0 0 0 0 0 0 0 0 Cum Wtr 5,419,434 Shut-In Shut-In Shut-In 0 0 0 0 0 0 0 0 0 Cum Gas 0 Thursday, March 06, 2003 Page 2 2003 Jan Summary by Month: Individual Well Injection / Disposal Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut-In Days 0 Wtr 0 Gas 0 2003 Totals: Water 0 Gas 0 Cum Wtr 5,419,434 Cum Gas 0 Thursday, March 06, 2003 Page 3 W McRU D-1 (192-156) (302-189) Subject: W McRU D-1 (192-156) (302-189) Date: Wed, 03 Jul 2002 16:05:06 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Rob Stinson <RDSfinson~forestoil.com> CC: Paul White <pdwhite@forestoil.com> BCC: Chuck Scheve <chuck_scheve~ladmin.state.ak.us> Rob, This note acknowledges our conversation on Monday and your fax regarding the attempted plugging operations. Due to fill, you were not able to perforate the tubing as deep as you intended. Then, your attempt to reverse circulate cement via the perfs at -3706 was short circuited by a tubing leak estimated to be at 150'. Chuck Scheve and I have reviewed the information you have provided and the accomplished work is not sufficient to consider the well abandoned according to the regulations. Further work will be necessary to properly abandon the well, in particular the injection interval must be sealed with cement. We look forward to receiving your new work plan. Tom Maunder, PE AOGCC Tom Maunder <tom maunder~admin.state.ak.us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission lofl SCANNED JUL 3 :t 21 1 2 7/3/2002 5:27 PM 07/01/2002 07:36 FAX 907 258 8601 FOREST OIL ALASKA FOREST OIL CORPORATION 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 - Office (907) 258-8601 - Fax 001 TO: FAX NUMBER: DATE: FROM: · i PHONE NUMBER: TIME: Total Number of Pages Including Cover Sheet: COMMENTS: RECEIVED JUL, 1 2002 A~ i SCANNED JUL :3 1 2002 07/01/2002 07:37 FAX 907 258 8601 tl IIII FOREST 0IL ALASKA ~002 I I II 131' RKB ( 100' SOL ) 384' RKB ~333' SOL ) ,f ! 4500' RKB ( 4469' BGL ) 13 3/8" conductor, drilled and driven I~ 9 5/8' surface, cemented lo surface i · 7/8", 6.5#, Tub rig. 2 N-80o SR, EUE TIM Retrievable Packer Set @ 4197' Tubing Tall (~ 4203.35 Perforations 12HPF 4289' - 4551' 7" 29# P-110, S-95, N-80, combination string cemented to 1400 ff. FIGURE 6-1 WEST WcARTHUR RIVER WELL D- 1 SCHEMATIC DIAGRAM I I I I II 6-2 SCANNED JUL 3 1 2002 07/01/2002 07:37 FAX 907 258 8601 FOREST OIL ALASKA ~003 Well D-J P&A 27-iun-02 1300 - Arrive WMRU -Steve Howarth Pollard Operator - Well D-1 tubing pressure 650psi, annulus 550psi - Rig down 3' flanged line of tubing side with check valve (injection line). - Locate 2-9116 x 5000 psi R-27 flange for Pollard lubricator. Unflange from D-4. 1630 - Flange up on D-1 - Forest Oil crane out of service with blown motor - Attempt to set lubricator with loader and stinger. Did not work. - Wait on Conam crane 1800 - RIH with 2.30 OD gauge ring -"sticky" work line with T/t 100-ft tight. (Material building up under ring). - POH with 2.30 gauge ring - RIH with 2.25 gauge ring, T/4148 WLM. POH. - RIH w 2.00 Tbg stop, set (~ collar ~ 4058 WLM - Attempt to release tbg stop, no jar action. Material (scale) fallen around jars (top) work line. Open 1" valve on tbg side and bleed while working line. Did not work. Tbgl annulus bled to zero in 10 minutes (perfs plugged). 2400 - Shut down - Line up line cutter, stop, sinker bar for Pollard 28-iun-2002 O63O - Fly tools (Pollard) - Kenai Aviation - Drop 5-ff Godevil 1-112: OD (base for cutters) - Drop 3-ft cutter bar 1-112" OD - no cut - Drop 5-ft cutter bar 1-114" OD - no cut - Drop 1.73 blind box-base - Drop 3-ff cutter 1.50 OD - no cut - Drop Kinely snipper 1.50 OD - no cut 1300 23-ft. - Fly Pollard tools - Kenai Aviation (2nd trip). Orginbal tool string length = - Drop 5-ft x 1.55" OD blind box - Drop 5-ft x 1.75" cutter- no cut 1500 - Drop 6-ft x 1" OD cutter- successful cuff - Bait to retreive tools x 2 trips T/3923. Dry runs. - Run impression block- no marks 07/01/2002 07:37 FAX 907 258 8601 FOREST OIL ALASKA I~1004 - Bailer run - tag at 3918-ff- Lost 8-ft in 2-hrs - Run 2.25 gauge runs x 2 - sharpen BTM of gauge to scrape T / 3140. No good, material getting sticky around gauge. 29-iun-2002 0200 - 0600 - 0900 - Shut down, POH laydown lubricator rig down Conam crane. They needed it back. Shut down, Waiting on Veco crane. Veco crane on location. Rig up to wire brush tbg. Get estimate for coiled tbg unit.. 1030 - Crane starter out. Crane inop. - Attempt to locate crane. - Make up 2.40 scratcher - Veco mechanic repaired crane. 1100 - RIH wi 2.40 scratcher. Work 3816 to 3850. - Trip scratcher to bottom 2 times. - RIH with F-stop set down i~ 3731. No set. ' - RIH with slip stop T/3724. No set. - Rerun and set ~ 3724. (material falling in every trip, losing ground) - RIH tbg punch. Press back side to 130 psi. - Punch hole ~ 3722 (punch spaced out 2-ft above bottom of tool. - POH - Redress - Punch hole i~ 3721 - Redress - Punch hole @ 3706 (fill falling in 3721 - 3706). - RIH w/slip stop pulling tool. Tagged @ 3710 (Fill) leave slip stop in hole - POH - Rig down. 2320 00:20 - - BJ services test lines t/3,000 psi. Marshall Brown - Rev circ 5 bbl h2o. rate t/4.3 bpm 284 psi. - Pump 15.8 ppg (reverse circ) ~ 3-4 bpm 845 psi. - Swap returns from 72 bbl Forest oil slop tank t/WMRU # 2 cellar. Notice cement returns to surface i~ 75 bbls away. Change over from backside t/tubing. Bull head 1.75 bbls down tubing. Pres t/2,500 psi. shut in well, wash up. While draining lines, discovered cement in 72 bbl tank. After gauging the Tank it is questionable exactly how much cement actually is in the 7" Annulus. Best guess is about 5 bbls, or about ,160' of cement. 1.75 bbls Of cement bull headed into the 2 7/8 "tbg is about 300' of cement. 6~30 Pressure tested 9 518 x 7" t/1,000 psi..50 bbl pumped bled off t/545 Page 2 of 3 - 07/01/2002 07:37 FAX 907 258 8601 FOREST OIL ALASKA ~005 in 10 minutes. Note: 72-bbl tank being used to catch returns while cementing had approximately 10" slop oil, solids etc already in the tank. With the returns from the cement job coming into the tank from the bottom, the returns were masked by the slop oil pad. Mike Mello Page 3 of 3 ~IUL ~ .[ £uu£ WMRU #D1 P&A ., Subject: WMRU #D1 P&A Date: Tue, 18 Jun 2002 13:10:55 -0600 From: Rob Stinson <RDStinson@forestoil.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> CC: Paul White <PDWhita~forestoil.com> Tom, As per our phone conversation this morning, replace the submitted P&A procedure for WMRU #D1 with the following: 1 .) Conduct a pump-in test to establish rates and pressures. 2.) Perforate tubing with a JET cutter at ~ 4150', just above the TIW packer @ 4197'. 3.) Reverse circulate 866 cf (volume of 7" 29#, not accounting for tubing) of cement to the holes, taking returns out the tubing, when the cement reaches the surface, close the annulus and tubing. Hold 650 psi of back-pressure on tubing during this displacement. 4.) Bullhead an additional 54 cf (volume of 7" 29~ casing between tubing cut and PBTD) down the tubing. Do not exceed 2500 psi surface pressure. Shut in all surface valves and wait on cement. ._' 5.) Pressure test the 9 5/8" x 7" annulus to 1,000 psi. If no fluid is pushed away, attempt to place cement in the very top of the annulus and \ proceed to step ~. If the fluid is pushed away, attempt to bullhead the equivalent of 150' of cement away (22.6 cf). 6.) Remove well heads and cellar, cut and pull casings from at least 3' below original ground level - not rig grade. Weld on steel plate with required data as per 20 AAC 25.120 WELL ABANDONMENT MARKER. Fill and compact excavation, grade area as appropriate. Thank You, Rob Stinson SCANNED"JUt 1 20DZ I of 1 6118/2002 11:37 AM RES i. T O I L C O R P O R A T · ;" C~.~7~ 2'f;'(,~ I 0 N June 17, 2002 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 Anchorage, Alaska 99501 Attn: Mr. Tom Maunder Re: West McArthur River Unit #D1 - Plug and Abandon Mr. Maunder We request to Plug and Abandon the West Mc, Arthur River Unit #D1 Class II disposal well at this time. Please find attached the Application for Sundry Approvals. The well currently has 625 psi of tubing and annulus pressure. Bleed-off tests indicate a lack of tubing integrity. We request to perform the outlined P&A without a rig. If there are any questions, please contact me at 907-258-8600. RECEIVED JUN 1 7 2002 Paul D. White Alaska 0/I & Gas Cons. C0mmms~o[, Drilling Manager- Alaska Division Anchorage Forest Oil Corporation M:\WMRU #DI\WMRU #D1 P&A Cover 403.doc Date Modified: 2/19102 Date Prepared: 2/12/02 rds SCANNED'JUN 2 I 200Z ORIGINAL . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Forest Oil Corporation Development: 163' MSL 3. Address Exploratory: 7. Unit or Property name 310 K Street, Suite 700 Stratigraphic: West Mc, Arthur River Unit Anchorage, Alaska 99501 c . Service: X 4. Location of well at surface v/ v' 'v" 8. Well number 2776' FSL, 1446' FWL, Sec. 16, T8N, R14W, SM West Mc, Arthur River Unit #D1 At top of productive interval 9. Permit numjber 92-156 At effective depth 10. APl number 2776' FSL, 1446' FWL, Sec. 16, T8N, R14W, SM 50-133-20446-00 At total depth 11. Field/Pool 2776' FSL, 1446' FWL, Sec. 16, T8N, R14W, SM West McArthur River Field 12. Present well condition summary Total depth: measured 4,500' Plugs (measured) true vertical 4,500' / Effective depth: measured 4,407' Junk (measured) true vertical 4,407' Casing Length Size Cemented Measured depth True vertical depth Structural N/A N/A N/A N/A N/A Conductor 131' 13 3/8" Driven 131' 131' Surface 1,364' 9 5/8" Surface 1,364' 1,364' Intermediate 4,500' 7" TOC 1,400' 4,500' 4,500' Production (Liner) Liner Perforation depth: measured 4,289' to 4,351' 12 spfRECEIVED true vertical 4,289' to 4,351' 12 spf · JUN 1 7 2002 Tubing (size, grade, and measured depth) 2 7~8" N-80 at 4,203' . Alaska 0J! & Gas Cons, Packers and SSSV (type and measured depth) TIW Retreivable at 4,197' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 01-Jul-02 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of a.~e~er Date approved Service: Class II Disposal 17. I hereby ([ertify/t~at the foregoing is true and correct to the best of my knowledge. Signed: '~ ~ ~V%~,~ Title: Drilling Manager, Forest Oil Corporation Date: co .ss,o. Conditions of approval: No~f~ Commission so representative may witness ' IAppr°va'l No.o~ Plug integrity _~. BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- t'~l,.~ ~'~ Cammy Oechsli Taylor Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 ORiGiNAL SUBMIT IN TRIPLICATE FOREST OIL CORPORATION . West McArthur River Unit #D1 ~,';~ii~,~. Scope of Work - Plug and Abandon 2. t t ker @ 4197'. 3. Reverse circulate 866-c~' ~'vGoo~g ;3of(~"%29~, ~ot~ac~nting for tubing) of cement to the holes, taking returns out the tubing, when the cement~r~aches the surface, close the annulus and tubing. Hold 650 psi of back-pressure on tubin.~g~during this displacement. / 4. Bullhead an additional 54 cf (volume of 7"~9~ casing between tubing cut and PBTD) down the tubing. Do not exceed 2500 psi su~ce pressure. Shut in all surface valves and wait on 5. Remove well heads and cel~, cut and pull casings from at least 3' below original ground level- not rig grade. W~ld' on steel plate with required data as per 20 AAC 25.120 WELL ABANDONMENT M~;{KER. Fill and compact excavation, grade area as appropriate. 06/17/02 Page I of I SCANNED JUN [ 1 ZOOZ RES T O ! L CO R PO R AT I .~'-/o o2~,."c5~,~.~/· c.Y,.,w,, zoo o N June 5, 2001 Ms. Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 W. 7~ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Shut-In Well Status Report Dear Madam Chair: kFCff v Eu Alaska Oil & ~-- .. Anchorage Pursuant to 20 AAC 25.115 Forest Oil Corporation ("Forest") hereby submits this status report of wells that have been previously reported as shut-in. A. West McArthur River Unih D-1 Well ~ ~~~s~..!,:~ Early in 1999 Forcene~gy Inc ("Fomc~c~gy"), predcccsso~ i~ ~tcrest to ~orest, recognized that the water injection well, D-l, then being utilized at the West McAnhur River Unit ("W~U"), would not be sufficient to meet all of the produced water ~sposal needs of the A second weB, 4-D, was ~llcd to be a producer but instead ended up as a ~y hole. It was then convcacd for water disposal service as a back up to D-1. Since thc 4-D well had mom sand pay open than thc D-1 weB, thc decision was made to place thc 4-D well in service as thc primly water ~sposal well and use the D-1 well as ~c st~y well. 1. Shut-in Date & Circumstances The 4-D well was placed in service On July 8th, 1999. At the same time that the 4-D well was put into service, the D-1 well was shut-in for the reasons stated above. 2. Mechanical Condition 'Since the D-1 well was taken out of service due to a management decision and not due to a mechanical problem, the mechanical condition of the tubulars in the D-1 well remain sound. 3. Analysis of Future Utility The D-1 well has considerable utility as a back up disposal well for the West McAurther River Unit. If there were to be a mechanical failure in 4-D well, Forest could AOGCC Page I of 3 Shut-in Well Report \\ANCHFLSBJDARLINGTON$\Working Land Files~Permits~s~OGCC Shut-in Well Status Report 2001_FINAL.doc June 5, 2001 place the D-1 well back in service while repairs are made on the 4-D well with minimal lost production time. Forest is also in the process of placing another producing well, 7-A, in service. Depending on the amount of water produced by the 7-A well, or if water breakthrough occurs in any of the other WMRU producing wells, the D-1 well may need to be placed back in service. B. West Foreland Field, WF #1 Gas Well The West Foreland Field is defined by a discovery gas well, the West Foreland gl CWF gl"), that was drilled on federal lease A-035017 in Section 21, Township 8 North, Range 14 West, Seward Meridian, Cook Inlet Basin and completed on March 29, 1962' by Pan American Petroleum Corporation. The WF gl was drilled to a total depth of 13,500' MD & TVD. During the completion, several zones were tested and two productive sands were found in the well in the lower tertiary; one at 9502'-9527' and one at 9336'-9352'. At completion, the lower sand tested an AOF potential of 5.6 MMCFD and the upper sand had an AOF of 16.5 MMCFD. The lower zone was plugged back and currently only the upper zone is open in the wellbore. 1. Shut-in Date & Circumstances Following its completion, the WF gl was shut-in on March 29, 1962 following the completion of pressure testing just prior to running the "A-2" subsurface' safety valve (SSSV) located at 9234 feet. The WF gl remained in a shut-in status due to the lack of a natural gas market, high cost of pipeline installation and low product price until April 26, 2001 when it was brought on line to supply fuel gas to the West McArthur River Unit production facility. 2. Mechanical Condition Shortly after Forest Oil Corporation's predecessor in interest, Forcenergy Inc, acquired the federal lease and WF gl well from Phillips Petroleum Company in September 1998, Forcenergy conducted a mechanical/casing integrity test which maintained a tubing annulus pressure of 1,500 psig and tubing pressure on the wellhead of 3,380 psig while venting for forty minutes. After the installation of production facilities at the WF gl well pad and a 6" gas gathering pipeline, connecting that facility with the WMRU production facility, on November 21, 2000 Forcenergy conducted a flow test that measured a flow rate of 7222.0 mscf/day. Forcenergy removed the SSSV on November 22, 2000 resulting in an open well bore from the surface to the completed reservoir intervals. Forest considers the mechanical integrity of the WF gl gas well to be completely sound. 3. Analysis of Future Utility The WF gl well is the only well in the West Foreland Field. The West Foreland Field gas reserves are contained within the following two oil and gas leases: Federal Lease A-035017 State of Alaska Lease ADL-359112 AOGCC Page 2 of 3 Shut-in Well Report \La. NCHFLS lklDARLINGTON$\Working Land Files~Permits~AOGCC Shut-in Well Status Report 2001_FINAL. doc June 5, 2001 ADL-359112 is presently one of two State of Alaska leases committed to the West McArthur River Unit ("WMRU") while federal lease A-035017 is not committed to any state or federal unit. Subject to AOGCC Conservation Order 450, as amended and supplemented, the WF #! well was placed on production April 26, 2001 and will provide fuel gas to the WMRU and potentially to both the Trading Bay Unit and the Redoubt Unit. Consequently, the WF gl well is no longer in a shut-in status. During the next two years production data will be accumulated on the WF gl well pursuant to a Compensatory Royalty Agreement ("CRA") executed between the Department of the Interior, the State of Alaska, Department of Natural Resources, and Forest Oil Corporation. After the data accumulation period, all parties to the CRA will agree to allocate production volume from the WF #1 well among the two leases. There are no additional wells planned to be drilled in the West Foreland Field at this time. Should you have any questions, or require additional information, regarding this report, please do not hesitate to contact the undersigned at the address and phone number listed in the this letterhead. Sincerely, FOREST OIL CORPORATION Kenneth W. Griffin Planning Manager AOGCC Page 3 of 3 Shut-in Well Report \\ANCHFLS l klDARLINGTON$\Working Land FileskPermits~AOGCC Shut-in Well Status Report 2001_FINAL.doc June 5, 2001 Re: West McArthur River Unit D-I and 4 Subject: Re: West McArthur River Ucit D-1 and 4 Date: Tue, 17 Oct 2000 12:37:57-0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Berg, William" <WBerg@ensr. com> Mr. Berg, I have researched our files for the subject wells and provide the following information. W. McRU D-1 (PTD 192-156). This well was completed as a disposal well on 5/24~93. The well was formally determined in compliance with cementing operations and bond requirements (MIT II) on 6/23/95. Annular pressure tests (MIT I) were successfully conducted on 4/19/93 and 7/21/97. Next pressure test due summer 2001. Disposal of fluids into this well are authorized by Disposal Injection Order (DIO) #7 issued 4/19/93. W. McRU 4 D (PTD 197-234). This well was completed as a disposal well on 4/6/99. The well was formally determined in compliance with cementing operations and bond requirements (MIT II) on 7/23~98. The initial annular pressure test (MIT I) was successfully conducted on 10/1/98. Next pressure test due summer 2002. Disposal of fluids into this well are authorized by Disposal Injection Order (DIO) #16 issued 9/3/98. There is one other injection authorization in place for the Unit. Area Injection Order (AIO) 15, revering enhanced recovery injection was issued 7/24/96. I am not aware of any outstanding issues with regard to either ~ell, DIO or AIO. I hope this information will suit your needs. If you need anything further, please feel free to call. Thomas E. Maunder Petroleum Engineer UIC Program Manager Alaska Oil and Gas Conservation Commission "Berg, William" wrote: As we discussed this morning, I am conducting a Phase I environmental due diligence of the West McArther River Unit (WMRU). I am looking for compliance information concerning 2 disposal injection wells (D1 and #4) associated with the facility located in Section 16, TSN R14W, Seward Meridian. The information contained in this communication is confidential and privileged proprietary information intended only for the individual or entity to whom it is addressed. Any unauthorized use, distribution, copying or disclosure of this communication is prohibited. If you have received this communication in error, please contact the sender immediately. It is our policy that e-mails are intended for and should be used for business purposes only. 1 of 2 10/17/00 12:39 PM TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 8, 1998 Paul White Drilling Manager FORCENERGY Inc. 310 K Street, Suite 700 Anchorage, AK 99501 Re: Request for approval to inject sanitary waste in WMRU .D-1. Dear Mr. White: This letter is in response to your July 1, 1998 letter requesting approval for disposal of sanitary wastewater into West McArthur River Unit disposal well D-1. Treated sanitary wastewater is not authorized for Class II disposal. The Commission may approve injection into a Class II enhanced recovery well upon showing that the treated sanitary wastewater is compatible with formation fluids and that it will not impair the mechanical integrity of a well. Please feel free to contact the Commission if you need further clarification. · . David W. ~'0 ston Chairman il/10/97 MON 10:17 FAX 907 255 $$01 Forcenergy £.a FORCENERGY ALASKA Krlsa Wegemer FORCENERGY INC. 310 K St., 6ult® 700 Anchorage, AK ~950t To: Blair Wondzell Fax: 276-7542 From: Kriss Wegemer Date: 11/10/97 I~001 · ., ~;'t. ; .Itt'.';',' ',.'$ ",*,~;: 't · m;;,,. · ,t};~.,nl.l,...,~:.~,r.- , ,~.....,.t.. .J. ;. -- Re: Pages: 5 Including this cover Hello' Mr, Wondzell, This is the fax lhat I promised regarding my question on the West Mc, Arthur River disposal injeclton well (WMR D-1 ). The issue that we dJs~ Oll Friday (11/7) is as follows: Fomenergy has planned and permitted a new well to be drilled from .~e West McArlhur River Fell ~n. The bottom hole Iocatim of this well wil be outside of the West McArlhur River'l. JniF. Is there an Issue wilh disposing of~luids ganerat~ from the dtlling and production of this well in the disposal well at the location? I have read Ihe inject]on order and round no language Ihat suggested a problem. I also reed the applk~tion that Stewart Petroleum submilted and did note that ENSR (Ese consullant who assembled the applicaaon) stated that the wastes would be generated at Ihe West Mc/Vlhur River"Unit". Fomenergy has eveq~ing in place to proceed wi~ the drilling of this well. A spud date of December' 15 is planned, I wil altach a copy of ~ Injection order and the page of the applicat~n showing the statement that I referred to above. · ff them is anything else that you may require, please let me know, Thanks, Kriss Wegemer/~____--~, U D C .~ I rev 05110/90) TEST: lnltll! 4-]Iree, r~_~ Ikrkavff~ _ Exislila AeOCC WI TIERS S tiXTT'Jli£ ..... J ~ .~/97 MON 07:52 FAX 907 258 8601 FORCENERGY ALASKA ( Forcenergy Inc 310 K Street, Suite 700 Anchorage, Alaska 99501 {907) 258-8600 258-8601:FAX FAX TRANSMITTAL SHEET TO: DATE: ~001 FAX: ~2_ ? Ia ~ 7 _~'~_~.~_- Phone: CONfiDENTIALITY NOTEr The infonneltion in this facsimile transmlttal is legall~ I~rlvil~d and eenfldentlal infarmatlonl inte,,nd.ed on,ly foe the use of the indiv{duel or entity named above, If the reader you are. hereby notified that any dissemination, disblbuEon or copy of the tmnsmittM is strictly preheated. If you rem~ive this[ trall~mR~al in elTo~, please Immediately notifi/us by telepharm, and tatum the otlglrml transmlttei to us et dm shove addrels ~ via the United $tate~ Postal Sewiee, Thank yea. VAXAI, A. DOC 2/! I~? MESSAGE: ' ~aS~ ~Jl.& Gas .Cons. PERMIT DATA AOGCC Individual Well Gs~ ~ ogical Materials Inventory.. T DATA_PLUS Page: 1 Date: 01/04/95 RUN DATE_RECVD 92-156 5518 92-156 DRY DITCH 92-156 DWOP 92-156 CEMENT ADVISOR 92-156 407 92-156 PIL/SFL/GR 92-156 T 1295-4552 S 150-4500 SS#866 R 01/11-01/29/93 R 01/25/93 R COMP DATE:01/29/93 L 130-4492 MUD(FORMATION L) L 129-4500 92-156 CET L 1250-4402 92-156 CBT 92-156 BHC/SL/CAL L 1250-4402 L 130-4468 2 03/01/93 02/23/93 02/23/93 02/23/93 02/23/93 1-2 02/23/93 1 02/23/93 3 02/23/93 3 02/23/93 1-2 02/23/93 Are dry ditch samples required? yes (no~ And received? (yes') no Was the well cored? yes /n~Analysis & description received? Are well tests required?~,...yes ~ Received? yes ~ Well is in compliance/~-~ Initial AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST check off or list data as it is received?list received date for 407, if not rel luired list as NR drillinQ historv survey well tests core descri cored intervals core ditch intervals itai data i LOG ,'TYPE RUN INTERVALS SCALE ...... NO. (to the nearest foot) [inchllO0'] 1) , ,, ..... ,,~.,,..L. (~'o,.,,.~}.~. k..ofl / I.:.q---~s~o .., ~ 6] - iiiij ~ i i i i i ii 8) i 9) .,io) , . i i i 11] ~] , ,i ,, i i i i i i i i i ii j 13] . .... i i .- , iii i i i 1,,8j ................. i May 25, 1993 ,?' ENSR Consulting and Engineering 4640 Business Park Blvd. Building D Anchorage, AK 99503 (907) 561-5700 FAX (907) 273-4555 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Commissioner David Johnston, Chairman Re: Stewart Petroleum Company, West McArthur River Well D-1 (AOGCC Permit Number 92-156) Request for Change in Well Status from Temporary Operations Shutdown to Service (Disposal Injection) Dear Mr. Johnston: On January 28, 1993, following the drilling, and evaluation of West McArthur River Well D-l, I requested a Temporary Operations Shutdown status for the above well on behalf of Stewart Petroleum Company, pending the approval of a Disposal Injection Order. This request was in the form of a letter to Commissioner Russell Douglass and an accompanying Form 10- 403, (copies attached). The Disposal Injection Order (DIO No. 7) was issued on April 19, 1993 and the well is currently being utilized for the disposal of Class II drilling wastes. In order that the AOGCC well file reflect the correct classification for the well, we hereby request that the well status be changed to "Service - Disposal Injection". I have attached three originals of AOGCC Sundry Notice Form 10-403 which references this application. Please contact me 'at anytime if you have any questions concerning this request. Regional Program Manager Oil and Gas Services (Agent for Stewart Petroleum Company) RCG/law RECEIVED cc: W.R. Stewart, Stewart Petroleum. Company Attachments MAY 2 5 1993 Alaska 0il & Gas Coris..(;0ti~;.ss~t," Anchorage '~ STATE OF ALASKA COMM!i" IN ~' (.A OIL AND GAS CONSERVATION REPORF OF SUNDRY WELL OPEmATIO I. Opera[,ons pe~.~rmeo. ODe,al.on shutdown_.. St,mula~e .._. 2, N~e o; Stewart Petroleum Corn 3. ~ares; 25~0 DeneZ~ Street, Suite 1~00 AK 9950~ 4. ~at~on of ~1 al sunoco 1446 ft ~L, 2776 ft ~L, Sec ~ to~ of ~o0uct~ve in[orval N e~tive Oept~ ~me as surface [ocatton (stretght ho[e) Al tol~ deDlh Same as surface 12. Ptetenl weft Cono~bOn summary To[al Oep[h: measure0 4500 feet true ~¢~ 4500 lee[ Eflec!ive deplh: measured 4406 feet true vertical 4406 f~ Reoa~r w~ll ... Ome~ ~ statu~ 5 Ty~e o~ We~: & Datum e~at~on (DF O~oomenl ~ 163 ~' St~ll,graDmc ~ 7. U~I Or P~o~y ~t Se~ce ~ Wes,t HcArthur ~ver 8. We,I numar D-1 9. Permit numberlappr~ number 92-156 10. APl number 50-- 133-20446 11. Fiel~lPool ~ ~oZ or fteZd destRnat~ 4406 - aS00 ' Plugs (measured) dunk (measured) None Cas, no Length Size Slruclural Conduclor 131 ' 13-3/8 Sudace 1361 ' 9-5/8 Intermediate 4500 ' 7" Production Liner Perlorat~ondeplh: measured 12 HPF 4289'-4351' (62) true vertic, a 428g '-4351 ' Cemented Measured depth ~uev~nic& aep~ Driven 131' 1~1' To Surface 1361' 1361' 4500'-1600' 4500~ 4500~ RECEIVED Tubing (size, grade, and measured depth) MAY 2 6 199 2-7/8" 6.5~ N-80~ EUE 8R~ 4196~ to surface Alaska 0il & Gas Cons. C0rnmiss%o~ Packers and SSSV (type an0 measured depth) T:[W HM-1 RetrtevabZe ~ 4196' 'Anchorage 13, sLimulation or cement squeeze summary ' ~/A- 'Z'h~.s 10-404 ~.s. subm~.tted to z'etlect a Intem, aJslreated(measurecl) change in well status only Treatment descr,plion incluO~ng volumes used and final pre,ute 14. R_~e~resental~ve Oa,ly Averaqe Pro0uc. t~on or Injection Dar,-. O~1.801 Gas. Mcr Waler. Bl~ Casing Pressure Tu~ng Pre,ute Prior to w~ll opera,on t ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Dave Johnsto~/ DATE: 4-19-93 Commission~ Through: Blair E Wondzell P. I. Supervisor FROM: o~uu Gdmaldi Petr Inspector SUBJE~ MONDAY 4-19-93 1 witnessed the initial Mechanical Integrity test on Stewart Petroleum's disposal well, West McArthur River #D~. The well was not on injection during the test. A thirty minute pressure test of the annulus showed a frye psi pressure loss over the length of the test and the well was passed for injection. SUMMARY; I witnessed the successful, initial Mechanical Integrity test on Stewart Petroleum's West McArthur River #D~ well. Attachment: MIT test report. ALASKA OIL AND GA8 CONSERVATION COMMI8810N Mechanical Integrity Test OPERATOR: STEWART PETROLEUM FIELD / UNIT / PAD: WEST Mc, ARTHUR RIVER DATE: 4/.19/93 · ."~..i : '.;T.~PE;';":...PACKER. ~.,. ,,;. :i'!;.,, :.;;;.,,:!. ,';.':::..::.:!;"!:~:..;'~ , .... ...;.,.REQ.i :':, :....'T G.:: ,.:.,':~:':'-lL'lMl~!!~i'-'.:';i:~lblE .':'"~'TIME..": :':'~ '~ ;:,i'WEL;E':::~':~' 'i; ~:.i:i..:,,: , .. .: .......:..,., ,.,, .... ,..,..:..:.: .........,: .... .:,....T .:,...T...: .... ..::..... .. ".S 'ANNULUS.: ::.' :t3/D- I' . ;.,..'.,.. !' :,;.,,.: ,..CASINB ~;.';, ::-. :.. ;:,,,..,.: a~: :..TES .:.' ...; ,.CS~.',.., · ;~:!: !T:BI~ '.:i:; ' ;: :iTBIB:' :i ~:. TBG... ': STAR"!' ":P ~1 F. ::;. :.' .:NAME.':.'.; i.: :~ .:';:~LUiD:;,i.:: i l!i ;;HD'ii;:' :: :~!{;:.ii:;"~I;ZE.."t!W.3';.;/:6RADE'i::i '}:.,... ~:~S. IZE: :P. RES.'{~:," ~!::.':.PRES.S;:i;"; i:?..~:C~{~!!;:.;:' '?' ;I::SG :.: "i "IESG.'.':' ,TIMEi · ':!' li!:i:.."; :::..~i::; ':i..:.!,:::} '; '.~':~ ::;i"?i;!i' ;':i .' %_;:_!:_ ;il/i: !~ ,,.:.,~;i~.;i .;;:~..!;, ,;,: ;! i:_.::,!;;i::_!i ,"i"" ::! _:.?';'.; !!'.:.,:?i:!!;i. i:.:' i'" ',.. _:i.{;i ;;i~ i:_: !,"': !.: ;! ,! ~:'"_'":.!ii: _.:'!. i:, !_!: ,,:PRESS"'! 'PRESS___ PRESS'! _." '_" :_;I." '"! _'_' · D-~ P~,N -WATER 4,210 7" L-e0 29# 2 7~,e 1,500 500 500 500 I 500 a45 P 4,21,0 5 1,625 1,620I' 1,620 . 'COMMENTS: PTD 92-156 COMMENTS: COMMENTS: COMMENTS: -. COMMENTS: =TUBING INJECTION FLUID: ANNULAR FLUID'~ GRADIENT: WELL TEST: P = PRODUCED WATER INJ. DIE GEL I nitial X $ = SALTWATERINJ GLYCOL 4- Year M - MISCIBLE INJ. SALT WATER Workover I = INJECTION D R I LU N G M U D 0 ther N = NOT INJECTING OTHER WATER 8.3 OTHER Distribution: orig - Well File c- C~erator c- Da~base c-Trip Rpt File c- Ir~spector AOGCC REP SIGNATURE LOUIS R GRIMALDI OPERATOR REP SIGNATURE PAUL WHITE STWRTMIT.XLT Rev. 12/93 TWRTMIT.;x.. February 26, 1993 ENSR Consulting and Engineering 750 West Second Avenue Suite 100 Anchorage, AK 99501 (907) 276-4302 (907) 272-7851 (FAX) Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Larry Grant Re: Digital data and washed and dried samples for the Stewart Petroleum Company West McArthur River No. D-1 Well (AOGCC Permit No. 92-156) Dear Mr. Grant: Please find the enclosed open hole log digital data and washed and dried cuttings samples from the West McArthur River No. D-1 Well. It is our understanding that this additional submittal will satisfy the Completion Report requirements for the referenced well. If you have any questions or require additional information, please contact the undersigned at 561-5700. Sincerely, Ro~ner Regional Program Manager Oil and Gas Services (Agent for Stewart Petroleum Company) Attachments cc: W.R. Stewart, Stewart Petroleum Company Stewar P .. oleum ompany Denali _T~ow~rs North, Sui~ 1300 2550 Denali l~t~eet, Anchorage, Al, aska 99503 (9.,~07) 2~ February 1, 1993 Re: West McArthur River Unit Area and all wells drilled within this Unit Area or in the vicinity of the Unit Area. Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: Mr. Robert P. Crandall Senior Petroleum Geologist Gentlemen: The purpose of this letter is to confirm that Mr.'Robert C. Gardner, individually, and ENSR Consulting and Engineering have been designated agents of Stewart Petroleum Company and are authorized to represent Stewart Petroleum Company in all matters before the Commission with respect to the captioned area. This authorization includes, but is not limited to, execution and filing of any and all required reports and appearances before the Commission as necessary. These authorizations shall remain in full force and effect until revoked or modified in writing by Stewart Petroleum Company. Thank you for your cooperation in this matter. WRS:nl cc: R. C. Gardner (ENSR) Sincerely, W. R. Stewart President February 23, 1993 ENSR Consuhing and Engineering 4640 Business Park Blvd. Building.D Anchorage, AK 99503 (907) 561-5700 FAX (907) 273-4555 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN: Robert P. Crandall, Senior Petroleum Geologist SUBJECT: Completion Report and Well Records Stewart Petroleum Company, West McArthur River Well No. D-1 (AOGCC Permit No. 92-156) Dear Mr. Crandall: Please find enclosed the following materials for your files on the above-referenced well: i 2. 3. 4. . . 7. 8. 9. Completion Report (Form 10-407), 2 originals; Deviation survey summary, 2 each; Copies of Daily Well Operations Reports, 2 sets; Phasor induction SFL - Gamma Ray Log, 2" and 5" scaler,, runs one and two composited, 2 each blue lines and 1 each sepia; Borehole compensated sonic - Caliper Log, 2" and 5" scaler, .runs one and two composited, 2 each blue lines and 1 each sepia; Lithologic (mud) Log, .2 each blue lines and 1 each sepia; Cement Bond Tool Log, 2' each blue lines and 1 each sepia; Cement Evaluation Tool Log, 2 each blue lines and 1 each sepia; and Cement Advisor Report (Schlumberger), 2 copies. The washed and dried drill cutting samples from this well are being submitted under separate cover.' It is understood that all of this material, with the exception of the locatiOn, total depth, and supporting information required in the public review of our Application for a Disposal Injection Order, will be kept confidential for 24 months under AS 31.05.035. RECEIV' D FEB ~ ;~ 199~ Alaska Oil & Gas Cons, Comm..issi.Ol Anchorage Robert P. Crandall February 22, 1993 Page 2 Please contact the undersigned if you have any questions. Sincerely, Robert C. Gardner Regional Program Manager Oil and Gas Services (Agent for Stewart Petroleum Company) Enclosures cc: W. R. Stewart, Stewart Petroleum Company RECEIVED FEB 2 3 199,~ Alaska Oil &. Gas Cons. Comrnisslo~ Anchorage STATE OF ALASKA /~ ALASKA OIL AND GAS CONSERVATION COMMISSIOI~/~!_ WELL COMPLETION OR RECOMPLETION REPORT'AI 1. St.ms of we, AS OF DATE OF COMPLETION REPORT, WELL IS IN OPERATIONS Cla-.ifi~tion of SHUTDOWN STATUS PENDING APPROVAL OF DISPOSAL INJECTION OR~~..,,,_,...,..~,,~.,~,~,,,., // OIL I~ GAS I-I SUSPENDED I-1 ABANDONED I-1 SERVICE 1.~e~_,~,,-.,-. w ~ ~. Name of Operator_~"/~,t ! v' ~;~' { 7. Permit Number STEWART PETROLEUM COMPANY ~ 92-156 ~. Address .~.,~ B. APl Number 2550 DENAL! ST. SUITE 1~00. ANCHORAGE, AK qqs~3~ , 50- 1-~-~_?0~ ! C~/~.PLET[ON; g. Unit or Le~ Lotion ~11 It 1,446 ft ~L, 2,776 ft NSL, Sec 1~, T8N, E14~, ~//~-~7~~/"~ ~EST NcAR~UR RZVER At T~ Pr~ucing Inte~al ~ ~ 10. Well Number ~EST HcAR~UR At Total D~th S~E AS SURFACE L~ATZON (STRAZGHT HO 11. Field a~ Pool ~EST NcAR~UR RZVER FZELD 5. El~ation in f~t {indicate KB, DF, etc.) I 6. L~sl Dm{gnat{on and 5~ial No. NO POOL DESZGNATED 16D ftI CO~ ZNLET REGZON~ ZNC~ 12. Data Seudd~ 13. D,tn T.D. Re~h~ 14. Data Com~., Su~. or A~nd. i 15. Water D~th, if =ffmore 116. No. of Completions JAN 11, 1993 JAN 21, 1993 JAN 27, 1993! N/A f~t MSL 17. Total D~th {MD+TVDI 18. Plug Beak D~thIM~WD) 19. Dir~tional Surwy ~ 20. D~lh where SSSV set ~ 21. Thicknm of Permafrost 4,500 ft ND & T~ 4,406 ft ND & T~ YES ~ NO ~X~ N0 ~SV f~tMD~ N0 PE~AFR~T PRESENT 22. Type El~tri¢ or Other Logs Run ~ASOR INDUCTION SFL - G~A RAY, BOREHOLE C~PENSATED SONIC-CALIPER, CBT/CET ~. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER FT. GRADE TOP aO~OM 'HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 72.0~ NT80CHYE SURFACE 131 ' 13.3/8" DRIVEN O 9-5/8 4~.5~ L-80 SURFACE 1,~61' 12-1/4" 801 CU FT CLASS G BLEND' 0 7" 2~.0~ N-80 SHRFACE 4.500~ .8-1/2' 510 CH FT CLASS G BLEND 0 . . . ~'.... , 24. Perforations o~en to Pr~uction (MD+TVD of To~ and Bottom and 25. TUBING RECORD {marvel, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 6.5~ 4,196' 4,196' . 12 HPF 4,289'--4,351' MD & ~ (62' of PERFS) 26. ACID, FRACTURE. CEMENT SQUEEZE, ETC. DEPTH INTERVALIMD) AMOUNT & KIND OF MATERIAL USED NONE 27. PRODUCTION TEST Date First Pr~uclmn ~ Meth~ of O~eratmn (Flow,ag, ~ hfl. etc.) I (N0 TESTS RUN) (DISP~AL WELL) Date of Test Hours Tes~ PRODUCTION FOR OI L.BBL GA$.MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ ; OIL.BBL GAS.MCF WATER.BBL OIL GRAVITY-APl (tort) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief d~ri~on of lilhol~y, porosity, fracture, a~arent d~t anO ~re~nce ot mi. ~ or water. Subm~ core RECEIVED NO OORE8 TAKEN ~ncho~e Form 10-407 Rev. 7-1,80 CONTINUED ON REVERSE SIDE Submit in dul~licate ~. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include internal testa<t. I~res~re data. all fluids recovered ancl gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, ariel time of each phase. TYONEK 3,300 3,300 FORMAT[ON WATER RECOVERED FROM ZONE AT 4,288' -- 4,352' TESTED 11,800 mg/1 TOTAL DISSOLVED SOLIDS. RECEIVED FEB Alaska 0ii & Gas Cons. c0mm~SSm~- Anchorage 31. LIST OF ATTACHMENTS 32. I heret3V certify that the foregoing is true ancl correct to the I~e~t of my knowledge R. C. GARDNER AGENT, STEWART 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 supplv 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 an¥ attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so stat~ 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 separateI¥ 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- .. lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 DEVIATION SURVEY SUMMARY STEWART PETROLEUM COMPANY WEST MAcARTHUR RIVER - WELL D-'I · ··Depth'·· ' 'MD. &....TVD · ' 493' ""-'"-'.Length".':...Driff.Angle:':i~:.'' .:.:Average"Angle.: '.Deviati0nC°Urse ... I 1,002' ~ 509' 0° I 1,350' I 348' I 1,859'I 509' 2,359' 2,850' 3,350' 500' 491' 500' 0 0 0 0 0.75o 0.375° 1.0° 0.875° 0.875° 0.625° 0.75° O.S° , , · Accumulated Course 'Deviation. · (worst case) , , 0' 0' 3.3' 3.3' 7.6' 10.9' i 7.5' 5.5' 18.4' 23.9' 3,858' 508' 0.5° 0.5° 4.4' 28.3' 4,240' 382' 1.0°: 0.75°- 3.8' 32.1' 4,500' , 260' 1.75° 1.375° ! 6.2' 38.3' I ' ' · ...." ':"'::":" ·" : .... "· '~' '." i. :..'. .':' ". i" ..... : .. · Makes-!'worst-ca'se." assumption that.: all:thei course, deviation' is in'the same' plane (direbti0n). . · . · R'EEEIVED' FEB 2 199, Alaska 0il & Gas Cons, G0mmlssl0n Anchorage Stew; CEMENT ADVISOR Company: STEWART PETROLEUM COMPANY Field: West McArthur River Well: West McArthur River No. D-1 Logging Date: January 25, 1993 January 25, 1993 Dear Sir: I believe you will find this report and enclosed color logs useful in evaluating the cement in this well. The interpretation contained in this report is the result of my application of the known tool responses for the Cement Bond Tool (CBT) and the Cement Evaluation Tool (CET) to your well. I have included a copy of the log in the back cover, as well as, a header for use with the log sections in the report. The color log contained within the report is new and deserves a brief description. The Variable Density Log (VDL) is much like the field VDL, but the amplitude of the . received signal is now presented in color. Dark green and white represent a wave of high amplitude; the white representing the trough, and the green the peak. As the amplitude decreases, the green becomes blue, and the white becomes orange. Violet represents an amplitude of zero. The attenuations, Near and Discriminated, are identical to those on the CBT log. The.color CET map is very different from the map presented in the field. Six different colors are used to represent specific acoustic impedance bands. These bands cover the ' following: Red: Yellow: Blue: Green: Brown: Black: Free gas behind pipe. Typically gas cut cement. Water or drilling mud behind pipe. Mud contaminated cement. Cement slurry, no compressive strength. 500 psi compressive strength cement. Again, I believe you will find this report useful. Should you require further explanation on any detail, feel free to contact me or another Schlumberger representative. Brian Schwanitz Schlumberger Well Services CEMENT EVALUATION SUMMARY CHANNELS: The only continuous channel in the 7" cement job is from 1,426'- 1,510'. This channel appears to cover 40% of the casing, but is sealed at the top (at the base of the 9 5/8" casing) and at the bottom of the channel. GAS CUT CEMENT: liner job. No gas cut cement or free gas is present in the LINER CEMENT QUALITY:The overall quality of the liner cement is excellent. Aside from the one channel (noted above),there are a few voids in the sheath between 2,090' - 2,500'. The average compressive strength is 3,700 psi. LINE LAP CEMENT QUALITY: The liner lap has poor cement. It appears to be either contaminated or still green with the consistency of a heavy drilling mud. DETAILED INTERPRETATION 7" 29# LINER NOTE: These logs were run with 1,000 psi surface pressure. 3,400' - 4,400' EXCELLENT CEMENT The only defect in the cement sheath is at the shoe which looks slightly wet on the CET from 4,380'- 4,400'. Compressive strengths range from high peaks of 6,000 psi to low peaks of 1,000 psi, with an average strength of 3,700 psi. DETAILED INTERPRETATION 7" 29# LINER (Cont.) 2,400' - 3,400' EXCELLENT CEMENT Two voids exist: a large one from 2,454' - 2,490', and a small one at 2,560'. The large one looks like mud cut cement due to poor displacement. However, the hydraulic seal is intact- no fluids will communicate. DETAILED INTERPRETATION 7" 29# LINER (Cont.) 1,400' - 2,400' GOOD CEMENT The major defect in this cement job is a channel from 1,426' - 1,510. It covers about 40% of the pipe based in the CET image, but is sealed both at the top, from 1,384'- 1,404' and at the bottom. The CBT confirms the channel with a strong casing signal, showing casing collar ring, and yet, giving a formation signal, indicating good bond on one side of the pipe. DALLY PROGREIili REPORT OPERATOR ~r,~A'~- WELL NAME - NO. LI.~~ DRILLING CONTRACTOR DATE DAYS RIG NO. I/ JAN 1~9.3 TIME SUMMARY. HRS. - SEE REMARKS ~ ,A,~~ '~E.J~ _A~-,Lr'FI~, DEPTH TODAY l DRILLING ,,,~, ~ TRIPS OTWER H~ U~ ~H~ ~, O / 24 HR. F~TAGE ~1 ~" .3,/4' (~ o~ .t, BiT. NO.~ SiZE j TYPE i ,m I UUl [ F'FO. I HRS. I NOZ I T ' B I G BIT WT. A V"AJLAI~II..~' 'Th Hl,~lbi) RPM ~=~0--(~::~ 'r'~ /o-' ;a.,,~oo PUMP DATA MFG. MODEL LINER STROKE BPM GPM PRESSURE SURVEY DATA GJ~b. · mo1~ 5. ! ~,,te ~)~s. DEPTH DEVIATION DIRE..CTION .TVD .. SECTION ,LATITUDE I DE,PARTURE :.. DRILu~G FLUID TIME WEIGHT VIS WL CAKE PV YP SOLIDS Ss 0,/,/_5-' 8.~,+8~.,s~_ ~,~s ~~ ,~:~.~.$~,~ NaCi Ca Oel~ PH ~ RE~RK8 S~O~ ~0~ , ..... .... ~/~. _ ~ ~o~ ~~~ ~o,P ,~ ~~~ REMARKS--. FORMATION DRILLED C o,,~, ,.., ,..,,,=_ ~,_~c,.,,.,,. ~p, A'~"='"r' .'p_,,- ~ OD_c,,. ,-m,$ /_1 -J,~'~ ,l~l'J~-~I - ~-- A~.~,~, ~~v,~. ~.O., ~~,~~ .. . -. .: LITHOLOGY: .. INTERVALS: E~I'. E4 HOUR COGT ES"I'. CUMULATIVE AVERAGE DAILY COST: AVERAGE COST/Fr. DRILLED BEDS ~;L'''P' NO. PEOPLE .-<4 WIND DAILY PROGRESS REPORT WELL NAME - NO. ~.~ M~ =~,T'PIp~."'"~F_I~ '*~-~e' I DRILLING CONTACTSR ~~/~ ~Bt~ TiME SUMMARY, HRS.- SEE "E~RKS DATE ~ DAYS mG NO. -- __ DEPTH TODAY DEPTH YESTERDAY ~4 H~. FOOT^~ _BIT WT. · - ..... I~UMP DATA ' __ MFG. MODEL LINER STR,OKE SPM, GPM . PRF_~$URE NO. ~ -- .. ~ . ~U~EY DATA ~' ~ ~o~ ~. I ~ ~. .. o._Z~ ,~u.~. ;=,,~=. ~'r'= . IN. J OUT I.FTG. HRS. ! NOZ .. T ! B ! G' I /z~~c../,sa~ c_ o ./,v-_ .--' a-/~, ~-'f -,-- J i - DEPTH DEVIATION j DIRECTioNI TVD !, SECTION LATITUDE DEPARTURE DRILUNG FLUID .. TIME .J WEIGHT.,· VIS WL CAKE PV Y,P SO.L, ID8 Ss o o ~ o , 9.5 ./,,o --- --_ /R . ~ ¥ 6 , ~'",~, _ ..... NaCi Ca _, Oel~ PH REMARKS ..... iiii _l i i~ ' i--i . . ii LITHOLOG?: INTERVALB; EST. 24 HOUR E~. OUMULAT~ P~)6T AVERAGE DAILY AVERAGE CO6T/I=T. DRIllED NO. BEDS q~_'~ Nfl p;.npL= ._';~_o)_ w,~,n r~ ~ TEUP ~ ,..m,, ,.,~, ~~ ..,, ,.,. "" PREPARED BY , STE'WART PETFIOL. EUM COMPAI~ 31, C STREEt · SUrTE 400 · N~CHORAGE. Al. ASK, ~ DALLY PROGRES~ REPORT O.R~O. S~'~"~-~='~ --P~' ~;~ ~o. .... WELL NAME-NO..._~_ ~_~P_~,I'HplZ,'~.. t/~"~, --I~'4~' ! DRILLING CONTRACTOR L~'~.~,~F__- '"~1~1 ~ ~-~,. TIME SUMMARY, HRS.- SEE REMARKS OTHER_.] '~9-~ ~11,.t~W_.~ 3.5'"~"'~'~14a'D-.l I, ~""d..t'~lP./~,.'~, ~'""'L~ 24 HR. FOOTAGE DATE 1:5 DAYS RIG NO. DEPTH TODAY DEPTH YESTERDAY BITNO. J. SIZE I TYPE [ IN OUT FTG. HRS. NOZ T Bi G -i ! , ~. _~ ~'rc/a ~ c_ i ~ _ ~ ~ so. ,~ ~;o~- a . , . ~ I. BIT WT. I0 ' ~,0 ~ RPM q C) · PUMP DATA MFG. MODEL LINER STROKE ~ GPM PRESSURE NO. 1 /E~t,4~,C.~ !=- I'~mC~ ~.~'"" I~t." ~ -- ,o.~ ~~ ~-,~ ~.~" '~" ~ -- 4~ ..-/o~ DEPTH DEVIATION - I DIRECTION TVD ~EOTION ... LATITUDE I DEPA.R..TURE 13 ~-o o' . -.- / ~ .s2::) --. ""-" ,--- ._ DRILUNG FLUID TIME WEIGHT VIS WL CAKE PV YP SOLIDS I Ss ¢0~ ..... ~.¢ ~. 9,~ ~ ~ ~_ " ~ 'I /.o.4 NaCI Ca C~Is PH REMARKS ,/~o I.,oo ~/~_4. 8.s- ,_. DRILLING ASSEMBLY ~1~'. '~rT ~IPlB=_'~},C,.; ,..~'r-~'~kI "2- ~),~_,. JA1L.~ _J(~: HI,,OT)P 'BNA 293,~.~ '. Hk/Z)P 29.~,~,_"~ ' TG: INTERVALS: __ · · EST, ~14 HOUR co~r EST. CUMULATIVE AVERAge DALLY AVERAGE COb'T/FT. DRILLED NO. PEOPLE ~ 7' WIND TEMP /8'...'VISIBILITY CEILING STEWART PETROLEUM COMPANY (;o7) sr,~.~zo · ;4x (;07) DALLY PROGRESS REPORT OPERATOR ~-C~J~a'~"TT,. "~~ ~- ~--"-~/~f ~O, __ DATE WELL NAME - NO. ~~ H~~=~ ~V~=. ~= I DAYS DRILLING CONTRACTOR 31A. Ag_E._ -J[~13.1u.~. t~ .' RIGNO._ TIME SUMMARY, HRS.-. SEE REMARKS DEPTH TODAY DRILLING i.0 TRIPS ~,0 . __ DEP~YESTERDAY PUMP DATA .L!NER STROKE SPM. __ GPM . PRESSURE (,,. s'" ,~" - '-- ,,., ~,, ~"' ,2;' 4,~ ,/~S"' J o ~",,. SURVEY DATA NO. 1 -- NO. 2 MFG. MODEL DEPTH ! . DEVIATION ·DIRECTION TVD SECTION LATITUDE DEPARTURE · , .. i i i i ii .... i .. . DRILUNG FLUID TIME WEIGHT VIS WL CAKE PV YP SOLIDS Ss NaCl Ca Gels PH REMARKS ii i il i ,/oa [ ./oo 8J,;..?,.. ~. ~'"' _~ · · i · .... LrTHOLOGY: _ _ BG: TG: iNTERVALS: EST. 24 HOUR CO~1' EST. CUMULATIVE ~ AVERAGE DALLY CO~T: AVERAGE COST/FT. DRILLED NO. BEDS ~ NO. PEOPLE ~WIND ~/I ~ TEMP ~VISIBILITY odeate~- CEILING PREPARED BY .:£- ~AFIT PrrROL. ffi. IM COMPAI,, . 3~11 C STREET · SUITE 400 · ANCI. IOI~G£, A~bSKA FJS03 E~I) .~,~0 · FAX ~07) S~,.:tila4 DAILY PROGRESS RE~ORT OPERATOR '~"l'~z,D,a.l~"l' '--~~.~~ ~_,O, WELL NAME --NO. ~,,,~~ IL"JP_.AI~.'T3'II, YlZ. DRILLING CONTRACTOR ~_.~'I2,,A,CF_.- "~1~ TIME SUMMARY, HRS.- SEE REMARKS DRILLING (~ TRIPS OTHER I ~ fz,.. DATE - DAYS RIG NO. DE~H TODAY DEPTH YESTERDAY 24 HR, F~TAGE -b_-~ ? BI__TNO.,[ SIZE [ .TYPE . I IN_ I OUT. I FTG. I HR6. NOZ i! T J El ! O I i1 --- - · BIT WT. RPM ..... PUMP'bATA ' " MFG. MODEL LINER STRO. K_E_ SPM ,. GPM PRESSURE NO. ~ NO. 2 SURVEY DATA DEPTH I O.E_.V.!ATION DIRECTION I . TVO _SECTION LATITUDE ..D.,EPARTURE I · ·. ·,, · · DRILUNG FLUID TIME WEIGHT VIS WL CAKE I PV YP SOLIDS Ss NaCl Ca ~ PH REMARKS i , _ iiin DRILLING ASSEMElLY /~ / ~ . _ ' i -- , m _ i ,lira · REMARK$ -- FORMATION DRILLED __L~ r C~s,,,~. c~ ~/~ ~C~w I$~/' _ . __ ~- -- CIRC CLERk, /~qo* ~oo Mt~ ~ otsP~c~ '30~ ~ ~ ~. ~Cl ~ I~ PPG, CmT,_~ SuRgAcE m~ ~o sX ~ I~G.. OISPL~c~ - .~&m. OeCD Po~ ~! o~ c~ oFF /,~e $ 9~ ~~.o~ c~E '. I ' J --- ~ w "" ~ " -- -- LITHOL~Y: _ EST. ~ ~UR COST __ BO: ........ ~T. OUMU~TIV~ ~T INTERVALS: __ AVENGE ~~. ORI~D 1 NO. BEDS q~,~' NO. PEOPLE WIND C.~/_~ TEMPI ~ o PREPARED BY, '"'~O L , VJSJBJLrrY C4F__A~ CEILING OPERATOR $'F'P~',' ~j~r- WELL NAME - NO. [J.~~ DRILLING CONTRACTOR, TIME SUMMARY, HRS.- SEE REMARKS DRILLING __ (~) TRIPS BI._.T__NO. SIZ. E ~ TYPE IN .O,U,T FTG. HRS. NOZ ITI BI G, BIT wT. RRM NO. 1 RUMP DATA MFG. MODEL LINER STROKE ~.~ s ~ ~= - i'~c,o G, S"' ! ~." SPM GPM PRESSURE SURVEY DATA ~..~. -. DEPTH DEVIATION I DIRECTION TVD SECTION I LATITUDE DEPARTURE DRII. UNG FLUID . TIME WEIGHT VIS ,, WL CAKE PV YP I SOLIDS I SS .;,/oo~, / 4,~. t~.-- ~ . ;~, ---~-t '. I ...... ! ' NaCI Ca Gelt,PH REMARKS .'.Oo0 40 4-1¢ ~ .~ ~Puo muo -- , DRILLING ASSEMBLY REMARKS--FORMATION DRILLED __L.~.~t- ~.~,l~-s~.~ ~ 6-"/8 ~"~',~T" o~oo- 0~oo 13Gl' LITHOLOGY: BG: TG: INTERVALS: NO. BEOS t'~,.~J~ NO. PEOPI.~ EST. 24 HOUR COST EST, CUMULATIVE CO~T AVERAGE DALLY COST: AVERAGE COST/FT. DRILLED -. WIND ~lc.v~ TEMP ~..C)e VISIBILITY i i i , CEILING PREPARED aY ~,q.,U L [/0 ~.1~ 'r-~.. STEWAFIT PETROLEUM COMl,'~d~f ~ D~ Sus~, $L~e 1300 DAILY PROGRESS REPORT WELL NAME - NO, DRILLING CONTRACTOR TIME SUMMARY, HRS. - SEE REMARKS DRILLING ~.O TRIPS OTHER DATE DAYS RIG NO. DEPTH TODAY DEPTH YESTERDAY 24 HR. FOOTAGE !'1 "7 I~,o ~ool 13 ~,'7 BIT NO. I SIZE TYPE IN OUT FTG_._.I HRS. NOZ T I B J G I I I J BIT VVT. 2 ~"'" RPM ilo PUMP DATA MFG. MODEL LINER STROKE SPM GPM PRESSURE NO. ~ ~SCO F- 1300 I, , ~' 1,7.. -'/ E' 3'8'7 ..... !'-I00 ~IRVEY DATA DEPTH DEVIATION DIRECTION TVD SECTION LATITUDE DEPARTURE = __ DRILLING FLUID' TIME J WEIGHT VIS WL CAKE PV YP SOLIDS Ss oo30j ~ , .~ 4.0 / ~ . 7 I Iq ~ -1 . --. NaCI Ca- ~ PH REMARKS · REMARKS -- FORMATION DRILLED JO00 ' 1~00 Tg s ~ C~ ~ o ~oe Psi //~oo- 0/~oo D~Jc~. TO ADO/' Ar' 01,,oo 5o£dr,..y hr 185"1 LITHOLOGY: BG: TG: INTERVALS: EST. 24 HOUR COST Esr. CUMULATIVE ~ AVERAGE DALLY COST: AVERAGE COST/FT. DRILLED NO. BEDS ~_~=.~ NO, PEOPLE WIND ~4~1L,.1~. TEMP ~ 3 · VISIBILITY CEILING · LIE..qT SNOuJ PREPARED BY_ '---)')~O L ~W~ l"F_ STEWART PETROLEUM COMPANY WELL NAME - NO. DRILLING CONTRACTOR TIME SUMMARY. HRS.- SEE REMARKS DRILLING 16 OTHER I 2~- DAILY PROGRESS REPORT TRIPS OAT'= ,-,~-P- ~ DAYS R~ NO. DEPTH TODAY DEPTH YESTERDAY 24 HR. FOOTAGE BITNO.! SIZE ,, TYPE I IN OUT FTG. HFI~. NOZ T !, B G ,3 !8'I,socH ~.~e~ ~a~,./. Io~ .3-~.. 3 i~ '/e BIT WT. ~ ReM ! O -. PUMP DATA MFG. MODEL .LINER STROKE SPM ,m NO, 2 F__. ~SCO F-13oO ~.~' GPM PRESSURE SURVEY DATA DEPTH I- DEVIATION ' DIRECTION TVD SECTION LATITUDE DEPARTURE lin · · lei i - · ~ m DRILUNG FLUID TIME WEIGHT VIS WL CAKE PV YP SOLIDS Sm ,.~qoo 9.E' 49. 'JI. 4 fl.. ' ;'7 -7 ,.' ~ NaCI Ca Gels PH REMARKS m ~ m , ,.~co 40 I-t~ , ~,~ .... DRILLING ASSEMBLY OUT" ,qS L41PF. dt TRIP. TOOL. S- LITHOLOGY: BG: TG: INTERVALS: EST. 24 HOUR COST EST. CUMULATIVE 00~1' AVERAGE DALLY COST: AVERAGE COST/FT. DRILLED NO. BEDS ~t.~,. NO. PEOPLE WIND ~TEMP ~0 · VI&IBILITY ~ ~'m; CEILING PREPARED BY -~1-- ~'~ · ,-w. i -1--1 -, sa- WELL NAME - NO. D l ~ ~ ~ ~ ~ ~ ~ vi ii~iIl il VVi i i i ii iv , ~1 I -- i · - I - · TIME SUMMARY, HRS. - SEE RE~RKS DRILLING ~ ~ TRIPS DALLY PROGREU REPORT DI RPU. I Io PUMP DATA MODEL LINER ~ROKE S~ GPM PRESSURE . NO. 2 SURVEY DATA DEPTH ! DEVIATION DIRECTION TVD SECTION LATITUDE DEPARTURE -i ,. . · _ _ , DRII. UNG Ft, UID TIME I WEIGHT ViS WL CAKE I PV I YP I SOLIDS DRILLING ASSEMBLY REMARKS- FORMATION DRILLED 14 3o - IG3o !L 30 - 0~30 - o 5 ~o ~330- OCoOe ~o00 LITHOLOGY: TS: INTERVAL~: EST. 24 HOUR COST . EST, CUMULATI%~. COST AVERAGE DALLY COST: AVERAGE COST/FT. DRILLED NO, BEDS NO. PEOPLE · WIND ~ TEMP O * VISIBILITY CEILING PREPARED BY STEWART PETROLEUM COMPANY WELL NAME - NO. DRILLING CONTRACTOR OTHER DAILY PROGRESS REPORT DATE DAYS R,a NO. DEPTH TODAY DEPTH YEB'rERDAY 24 HR, F~TAeE ~o BFy_NOd SlZE I TYPE .~'iN ....... OUT FTG. HR8. NOZ T __B! G 2RR I ~'/2 ~;TC ~OG ~1 E G~' 3- I'Z .,m wT, ~o ..~ //-~' ...... __ PUMP DATA MFG. MODEL LINER STROKE SPM GPM PRESSURE NO.~ E'. ~ S C O ~'-13 0 0 ~, ~ 12 '70 $~0 15'5~ SURVEY DATA DEPTH [ DEVIATION ! DIRECTION TVD SECTION LATITUDE DEPARTURE .i · ! ! I · · DRILLING PLUID TIME I WEIGHT VIS WL CAKE PV YP SOLIDS Ss _~. .~op. ! 9,8 4/,, /I;7 ~ ~o I~, ., / ~.~' NaCI Ca Oel~ PH REMARKS DRILLING ASSEMBLY ~1~-- ~1 r $ ~1/~ -. ~ .~ C ~ -- '$7'~ - ~ ~) C'$ - N i~/~ l0 " -- REMARKS -- FORMATION DRILLED 0~oo - OgJ_~O Dp.i~ · ~'F__~,m /~0' To DoTI~w~ 7 - LITHOLOGY: BG: TG: INTERVALS: EST. E4 HOUR COST EST. CUMULATIVE COST AVERAGE DALLY COST: AVERAGE COST/F'r, DRILLED NO. BEDS <:~ ii i NO. PeOPL~ £~ WIND ~.~- w~ TEMP "'" VISIBILITY U,9 LTD CEILING .___C L ~ ~ PREPARED BY ..TAhl P_i '93 06:0~.RH SP,- *~,C RRTHUR RIVER STEWART PETROLEUM COMPANY I~) P. ILI_t kl G DALLY PROGRESS REPORT WELL NAME - NO, DRILLING CONTRACTOR Di TIME SUMMARY, HRS.- SEE REMARKS ~.,~,.~ Iq './~ OTHER DATE DAYS .~ No. DEPTH TODAY DEPTH YESTERDAY BIT WT. Z 0 RPM / I ~" ___ PUMP DATA MFG. MODEL LINER STROKE SPM GPM PRESSURE NO, 2 .. SURVEY DATA DEPTH DEVIATION DIRECTION 'I'VD SECTION LATITUDE DEPARTURE 3G4C ...... ) ° .. i , . · __ DI~LUNG FLUID TIME WEIGHT VIS WI, CAKE PV YP SOLIDS Ss , 2,.Io o ':1. ~1 5~ lc A ,,q o H- ~1 NaCI Ca Gels PH REMARKS i 300 .~o t~[,~t ? ...... DRILLING ASSEMBLY REMARKS -- FORMATION DRILLED O/,,cc- /~oo IBcp- 0~o 033o_- O~c.o.._ NE.~ .t..~LF_ Pt/LL .F-.0 LITHOLOGY: BG: TG: INTERVALS: EST. 24 HOUR COST EST. CUMULATIVE COaT AVERAGE DALLY COST: AVERAGE COST/F'r. DRILLED "0. BEDS 4-0- _ _no. PEOPLE ~7,. ____.._VISIBILITY CEILING PREPARED BY _ _ o'~-%a,,n'~j,~ - t__O~C~,,~ ~.Z~t. DAILY PROGRESS REPORT __ - - DRILLING CONTRACTOR ~~./~: .~1 [ ~_ ~,~&_ , DATE ,,,J_/:~AJ ,~__.2. ? I qg~,~ DAYS , ., I~ R~G NO. I/.,,. 0 TIME SUMMARY, HRS. - SEE REMARKS C~~ DEPTH TODAY .~ DRILLING I,~L __ . TRIP,S (~ .. DEPTH YESTERDAY OTHER I Sl.)_'D.V'--~-'~ t- -''~- ~ ~.~I~..'~___M,I~. ~ "~,1~1~,,,~'" 24 HR. FOOTAGE BIT. NO.I S!?l=. I TYPE IN l__. OUT FT..G. ~ HRS. NOZ I .T, B I G ._.J _ .. · m ! m, . J I . · I I _B!TwT. ,,'q,,,~,o . RPM .,/,/O-/a~,.~) . . -- . .. ~UMP DATA ' MFG. MOD. EL LINER STROKE Slam ,. GPM __ PRESSURE.._ NO. ]=-,ac, o. 4,.s"' .. NO. 2 ._~'~__1~$/*_,';'_) '~'- I'~O0 ~.'~:* I~t." ~ --'-' ,,. __ SURVEY DATA DEPTH DEVIATION I DIRECTION T'VD . .. SECTION LATITU_DE DEPARTURE -- · , III .- DRILUNG FLUID TIME WEIGHT VIS WL CAKE PV YP SOLIDS Ss , m, w ~ J ~CI Ca G~; PH REMARKS _. oo , ....... · -~.1, · REMARKS--.-- FORMATION DRILLED l_.a~,r' _~__A,.~m a,.~_,. ~ "~' " ._~~' I~J _' o,:~ - I ~"~. "Z:m-.?,, ~ _-r~_, o,~' ~,~"~ ' _, - ~o~ - ..~_OL--'x'~. ,oj.~,,_., Ho~_=r e,r~'__~.,~,__ ~HO~T' -I'xZ~4· -- qO~ UTHOLOGY: BG: TG: INTERVALS: EST. 24 HOUR COST EST. CUMULATIVE COST AVERAGE DALLY COST: AVERAGE COST/FT. DRILLED NO. BEDS t'tl~..?e' NO. PEOPLE '~ WIND _.~f~,m.~TEMP "'-~-~ ~=eViSlBIUTY UldUI,,IIT" CEILING PREPARED BY~ ' b'TEWART PETROLEUM COMPAh, 3111 C STREET ° SUITE 400 · ANC~E. ALASKA (~ Sll~ . FAX I~?) -rib',la04 O'Pe~.A'noN: 'Eu,~,~,,~ ,~, ')' C,es,u~ DALLY PROGRESS REPORT OPERATOR ~'~'T'~_.~ A.'J~'-~ WEL~.^~E-.O. ~-.'~~.-n.,,.,=-_*-~,,,,='=. -b"*=') DRILLING CONTRACTOR DAYS RIG NO. TIME SUMMARY, HRS.- SEE REMARKS DRILLING ~ TRIPS DEPTH TODAY DEPTH YESTERDAY 24 HR. FOOTAGE ¢/~"oo 'r;b. i · . i I --- i BIT WT. RPM PUMP DATA MFG. MOD.EL LINER STROKE .8._P_M . ,GPM_ . . PRESSU,.,RE · NO. ~ E.J~,~ .¢.0 r=- la~,o ~,~" I~," --- -.-- ----- SURVEY DATA DEPTH I DEVIATION DIRECTION TVD SECTION LATITUDE DEPARTURE Omi. UN(] FLUID TIME I WEIGHT VIS WL CAKE PV YP SOLIDS Ss . .... ... ! . _ NaCI ~ Ca O~ PH REM~K$ ~oo i 4o ~~ ~~ ~ " ' . _. .. DRILLING ASSEMBLY ~Ot..t_~t~..~ '"~ .t ~--~I~4~ .... · . . · _ · . . REMARKS -- FORMATION DRILLED EST. 24 HOUR COST. [N.T. ERVALS: EST. CUMULATIVE COST AVERAGE DALLY COST: AVERAGE COST/FT. ORIL.LE NO. BEDS ~ NO. PEOPLE ~WIND ,A/,/L,.. TEMP --/(i~L VISIBILITY UMu k~EILING / 3111 C STREET · SUITE 44)0 · ANCHORAGE. ALASKA (~; ~. F~ (~ ~-~ DAILY PROGRESS REPORT OPERATOR $.l.-~..~ A.'l~---r' '".'~~ ~~ ___ DRtLLING CONTRACTOR TIME SUMMARY, HRS.- SEE REMARKS DRILLING '--'"' DAYS RiG NO. DEPTH TODAY DEPTH YESTERDAY ~ rOD _ __ 24 HR. FOOTAGE BI__TNO.; SI21= i . TYPE IN i ._OUT FTC. I HRS. . NOZ I T B J G i,._1 - i i. · . ., i BIT W'I'. RPM NO. I PUMP DATA MFG. MODEL LINER STROKE SPM GPM PRESS_U_RE ~-~$~ ~=- ~o G,S" I~." "-- '-- - SURVEY DATA Q,,P,A. ~1~ 5. II,,b r,~,.~. .. DEPTH I DEVIATION DIRECTION I TVD SECTION LATITUDE DEPARTURE I DIal. UNO FLUID .... TIME ! WEIGHT VIS.. ! WL CAKE PV ....YP SOLIDS Ss a,,~ J ,~. 9 ~ /o.o / /4., 7 ... / ! ..~, _Y, NaCI Ca ~ PH REMARKS iii ,/oo .,/,:) ...... DRILLING ASSEMBLY .. LITHOLOGY: BG: TG: INTERVALS: EST. 24 HOUR ~ EST. CUMULATIVE CO~T AVERAGE DAILY CO~T: AVERAGE COST/FT. DRILLE[ NO. BEDS /'~),_'P' NO. PEOPLE ir?. ~ WINO /4,~ I..- PREPARED BY i---' Il----1 TEMP '-' fie VI$1BII. IT~~Jm CEILING i i DALLY PROGRESS REPORT DATE DAYS RIG NO. DEPTH TODAY TIME SUMMARY, HRS.- SEE REMARKS DRILLING DEPTH YESTERDAY OTHER ~IJ~l,~, ~- 1~-3~) .LA~.'~,]), ' }3; '~0~'~ '~a~ 24 HR. FOOTAGE -0- BIT NO.[ S,?; TYPE I IN . I OUT F~..G. I MRS. N.O.Z. I .T I B I G ; BIT WT. RPM PUMP DATA ....... ' MFG._ .MO. DEL LINER ___S_TI~_ OKE SPM GPM NO. 1 _~---~t~,~__~ ~'- I'~l~ G,~" !~" --..: ....... ~ SURVEY DATA PRESSURE · DEPTH DEVIATION DIRECTION TVD SECTION LATITUDE DEPARTURE I Ill i I Ii I .... , i I I I · · . ! ! i .~ .! . · DlqlLUNG FLUID TIME I WEIGHT ViS WL ! CAKE PV YP SOLIDS I Ss , i ,i, --- · NaCl Ca Oeli PH RE~S ,., OD qo DRILLING ASSEMBLY LITHOLOGY: - BG: TS: INTERVALS; EST. 24 HOUR C,08T EST. CUMULATIVE COST AVERAGE ONLY CObT: AVERAGE COST/FT. DRILLED NO. BEDS ~NO. PEOPLE ~.~J WIND TEMP ~,, pi _ VISIBILITY ~OEILING ~1-. 3111 C ,.,%TREET · SUITE 400 · AHCHORAGE. ALASKA 99503 (007) M3,.aS30. F,~C (GOT) N2.3804 DALLY PROGRESS REPORT OPFRATOR ~7'~'t.~,a."~'-'~ '-"'~l'g:~ L.r__4~.e.q WELL NAME- NO. [.a~~ ~"~_g~ g>...-r~ lp~..'-'~J..~- '~. DRILLING CONTRACTOR _ __ ~.~ g-E_. ~ 1~. I ~ ~ ~ TRIPS 11~, O TIME SUMMARY, HRS.- SEE REMARKS DRILLING OTHER __~_J~.~ ~ ~bo. ~o0 ... DATE "~_"4~ I DAYS RIG NO. DE~H TODAY DEP~ YESTEROAY _ 24 HR. F~TAGE j i · --- · · i i i i , I i BIT WT. RPM MFG. MODEL NO. 2 PUMP D'ATA ....... LINER __..S. TROKE SPM GPM . -- la I (,,. s'" -- ' q t .,, (,,. ~"', ~" SUKI/EY DATA G~.~. e$OO~2 ,,~. I ~le G..--.S. .. PRESSURE DEPTH DEVIATION J .. DIRECT_ION . 13/0 SECTION ..LATITUDE DEPARTURE..., | DRILUNG FLUID TIME WEIGHT .... VIS WL CAKE PV YP SOLIDS J __Ss .~o,~ . ~.,. q ¥ / ;:=..o ! ;9 7, ; / '_~_ '~', NaCf Ca Gels PH REMARKS .... Il. qoo ~o 3/~/~,~ ~'....~ I .., i. REMARKS -.- FORMATION DRILLED L,~.~t" ~,,S! l~J~C.~ 7" ,S~"~'",,,4.1'- q~;' .OO_._~ .... ?/LP ~. s ~ ~e- ,~c~___A~ p':_~ 0//=- _'o_] H . -"~..A__/.. ~ = ~ ~_/TO~, 'P, , ·~.- ...A~. --- -- -- ti mil. LITHOLOGY: BG: TG: INTERVALS: lB I, EST. ~4 HOUR COST EST. CUMULATIVE AVERAGE ONLY COST: AVERAGE COST;~'T. ,O. BEDS q~L~ NO. PEOPL.E~ PREPARED BY WIND ~TEMP .lO' F VISlBIUTY .~ ~/q/~;_. CEILING ::l'"--- --s_~o,..,~; A..,/~ ! 1, STEWART PETROLEUM COMPAh . 31~I C STREET, 8UrTE 400 · AhCHORAGE. ALASKA e9,10~ lO07) M341~0 · FAX Ig(~7) DALLY PROGRESS REPORT OPERATOR ~C~1'~=_~4~A~:~- '"~__~--'I'I;~~L~,'L4._ ~.~, WELL NAME- NO. Li~~ DRILLING CONTRACTOR ~~ ~ ~ I ~ ~ ~. _ _ TIME SUMMARY, HRS, - SEE REMARKS DATE DAYS .. _ RIG NO. __ DEPTH TODAY DEPTH YESTERDAY _ 24 HR. FOOTAGE /7 B'--~"NO'~SIZE!I TYP'E--,IN .OUT i_Fro. HRS. "OZ JTj B G, · BffW'T. RPM NO. 1 .__ PUMP DATA MFG. MODEL LINER_. STROKE SPM GPM PRESSURE ~t~,iS~ 1=- I:~o __. G, 5"" I~." __ NO,..2 e~,~e~. 'F=o l'~cx3 ~,'3"' l~.*' SURVEY DATA G.P~. ll~O'~i' I~. I(d,,~ GJ'~. ' :: DEPTH DEVIATION DIRECTION TVD SECTION LATITUDE DEPARTURE --'- I il · m · , 11 m iii , m · · mi , DRILLING FLUID TIME, WEIGHT~[,~:~ I L,L~i~M"I=~VIS ,, WL CAKE, PV ,, Y_P SOLIDS 't Ss NaCI Ca Oel~ PH REMARKS n II I I m il i DRILLING ASSEMBLY ... REMARKS-- FORMATION DRILLED 1o oo _-_ /~¥~'-~o~ .. NO, BEDS _ _ NO. PEOPLE ~- WIND TEMP VISIBILITY .> I m; CEILING JAIi 28 '93 06:16AM SPC MC ARTHUR RiVEF. ~ STEWART PETIr~OLBUM COMP~~~- O t'~,~'/-~o~"~: ~ m 1~ t.~'-- ~ DAILY PROGRESS REPORT OPERATOR SI"~j..D,i.1L,-r '""~=-T'I;~T_.t..~H ~__~._ , DRILLING C, ONTFIACTOR OTHER S~ DAYS RIG NO. DEPTH TODAY __ DEPTH YESTERDAY 24 HR. F~TAGE B._ff. NO.I SIZE ! TYPE . IN OUT I '.FTG. I HRS. NOZ I T .I B G '- ) I - - % -- -- il i · _ , BIT wT. RPM PUMP DATA MFG. MODEL LINER STROKE SPM GPM PRESSURE i.. · SURVEY DATA DEPTH i DEVIATIO'N ' I DIRECTION I TVD SECTION LATITU. DE .DEPARTURE · ......... -, __ i . __ .j .-~ , _ J DRILLING FLUID TIME WEIGHT I VIS WL I CAKE PV YP SOLIDS SS . _ NaCI Ca Gels PH REMARKS i, . i ..... i · DRILLING ASSEMBLY REMARKS-- FORMATION DRILLED L.4~,r' ~...ASi 1-~=,. ' ~" __ , -- JO _~b. -. /.S"oo NO. BEDS ~~ NO. PEOPLE ~ / WIND MI ~ ~MP ~ VI~IBIL~ ~ MI CEILING ~~~ -- PREPARED'BY ~~IL ~~f~ ..... STEWART PETROLEUM COMPANY ~__~_ C)~i ~ suile (D/~ oGo I;)F_~i~'rtoN DAILY PROGRE98 REPORT DRILLING CONTRACTOR TIME SUMMARY. HRS. - SEE REMARKS DATE DAYS RIG NO, DEPTH TODAY /9?3, -I J~(::) DRILLING __ TRIPS OTHER ~)~__j3~/~[ ~_ ,~J¢"/'~l 7-0_ WMA__'~£._ DEPTH YESTERDAY 24 HR. FOOTAGE BI,T..NO.I, SIZE TYPE , IN OUT FTG. HRS. NOZ .T . · BIT WT. RPM PUMP DATA MFG. MODEL LINER STROKE SPM GPM PRESSURE NO. I ~-l~5 C(3 F- 13o~ '7 ~' 1~_ , NO. 2 -~" I~-- SURVEY DATA DEPTH ' DEVIATION I DIRECTION TVD SECTION LATITUDE DEPARTURE · i i iii · i i i ,11 11 t ~ I , , ! DRILUNG FLUID TIME WEIGHT VIS WL CAKE PV YP SOLIDS Ss -- .. imam,, ...... NaCl Ca ~ PH REMARKS , ~, · DRILLING ASSEMBLY REMARKS -- FORMATION DRILLED LITHOLOGY.' BE: TG: INTERVALS: -- NO. BEDS "~ ~ NO. PEOPLE ,~ '7 WIND EST. 24 HOUR COST E~r. CUMULATIVE CO~T AVERAGE DALLY COb*r: AVERAGE COST/FT. DRILLED TEMP "/",~' o VISIBILITY CEILING PREPARED BY January 28, 1993' ENSR Ref. No: 6397-003-400 ENSR Doc. No: 930056.RG ENSR Consuhing and Engineering 4640 Business Park Blvd. Building D Anchoragc, AK 99503 (907) 561-5700 FAX (907) 273-4555 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ORI6INAl Attention: Commissioner Russell Douglass Re: Stewart Petroleum Company, West McArthur River Well D-1. (AOGCC Permit Number 92-156) Request for Temporary Operations Shutdown of Well (20 AAC 25.072) Pending.Approval of Disposal Injection Order. Dear Commissioner Douglass: . Stewart Petroleum Company has completed the drilling and evaluation of West McArthur River Well D-I. This well was permitted as a stratigraphic test to 4;500 feet to evaluate subsurface zones for the injection of class II drilling wastes. A suitable zone lying between 4,288 ft. and 4,352 ft. has been identified in this well from open hole 'logs. Seven inch casing was run to total depth (4,500 MD) and cemented back to 1,600' MD. CBT and CET logs were. run to evaluate the cement job. These logs showed an excellent bond, up 'to 1,600 ft. and a fair bond between 1,600 MD and 1,400 ft. The zone was then perforated underbalanced, and formation fluid samples obtained. Stewart Petroleum Company will be filing an application for a Disposal Injection Order within the next few days (as soon as a laboratory analysis of'the formation 'fluid samples are received). When the injection order is issued, the well status will be changed to an injection well for the purpose of' disposing of class II drilling wastes originating from delineation and development drilling within the West McArthur 'River Unit. If this Disposal Injection Order cannOt be obtained within the twelve month period allowed under 20 ACC 25.072, the well will be properly abandoned in accordance with AOGCC regulations.. I have attached three originals of AOGCC Sundry Notice form lO-403 which references this request for temporary operations shutdown. RECEIVED JAN 2 8 199 Alaska Oil & Gas Cons. CommiSsion Anchorage Janua~ 28,1993 Commissioner Russell Douglass Page 2 Please contact me at anytime if you have any questions concerning this request. Sincerely, R.C. Gardner Regional Program Manager Oil and Gas Services (Agent for Stewart Petroleum' Company) RG/Iw cc: W.R. Stewart, Stewart Petroleum Company A~achments RECEIVED ,klaska Ul{ & Gas Cons. Gom~isSio~ Anchorage, STATE OF ALASKA .~KA OIL AND GAS CONSERVATION COMMI JN APPLICATION FOR SUNDRY APPROVALS 1. Type cd RIKlUe~; Abanclcm ... Susc~nd .._ Opefam3n ~utcl~wn ~ Re-ent~ suspencl~l w~l __ ~ caang .._. Re~aif w~l .._ I~ugg, ng ....., nme exten~en __.. Samulam ._.. Change ~ I:~ogra~ ~ Pull ruling _... Variance _._ Perf~ate ~ Ot~ _.... 2. Name cd Operator & Type of Well: Stewart Petroleum Company EXl31Oratow _.... 3, Address 2550 Dena11 Street, Suite 1300 Stra~graonic..&. Anchoraoe. AK 99503 4, I.ocam3ncdwellatsurface 1446 ft EWL, 2776 ft NSL, Sec 16, T8N, R14W, SM; At top cd productive interval N/A At effective depth Same as surface location (straight hole) At total depth Same as surface location 12. Present well condition summary Total depth: measured 4500 true vertical 4500 feet Plugs (measured) feet & Datum elevation (DF or KB) 163 7. Un, t or Property name West McArthur River 8. Well numl3er D-1 9. Permit number 92-156 10. APl number 50-- 13:~-20446 11. Relcl/Pool No pool or field desionate~ · 4406 - 4500 feet Effective depth: measured 4406 true vertical 4406 feet Junk (measured) feet None Casing Length Size Structural Conductor 131 ' ' 13-3/8 Surface 1361" 9-5/8 Intermediate 4500 ' 7" Production Uner Perforation depth: measured 12 HPF 4289 '-4351 ' (62) true vertical Cemented Measurecldepth ~ueverticaldepth Driven 131' 131' To Surface '1~61' 1261' 4500'-1600' 4500' 4500' 4289'-4351' Tubing (size, grade, and measured depm) REEEIVED JAN 2 B 199,9 Alaska 0il & Gas Cons. C0mm'~ssio~ 2-7/8" 6,5, #N-80, EUE 8R, 4196' to surface Anchorage, ., PackemandS&5'V(typeandmeasureddepth) TIW HM-1 RetrievabZe 6 4196' 13. AttaChments Oescriplton summa~ cd proposal _x_ Demiled'oper~ons program .=_ Bop ~ ..=., i i 14, Estimated date for COmmencing Ol~m 1 i5. Satua of well c~aSaficati(~n a= January 30, 1993 I Stratigraphic Test x__ i6. If ~ropoeal w~ verl3aily e~ ' Oil .... Gas .=. Suspended ._. Name of approver Date aporov~ Service , 17, I hereOy ca~ly that the f~.oregoing~ar~l correct to the best cd my knowledge, , E,C, Gardner ,.~~'"' Signed ~~.~..__.._~ Title Agent, Stewart Petr~Zeum Company Date January 27, 1993 " ;- ~ '~ ........ FOR CQMMISSlQN USE QNLY ' ' .... iii i i C°ndi"°ns °"[ 'ppr?val: N°tify C°mmism°n s° repre~ntative may witnasamug integrity __ BOP Tea _ Location c~earance ' ' I Appr°Val N,o· Mechanical Integrity Teat ._ Subeequent form required 1~"- ~Oy .~ ,:':.:':~'~-~ :~ . ~.- ~..; ,":. '~. .. · Approved by order of the Commi~i~er ..... Date Form 10.403 Rev 0~/1~88 ( ~ SUBMIT IN'TRIPLJCATE · MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh Griffi~ date: Commissioner file: January 27, 1993 LOU01151.DOC thru: Blair E Wondzell Sr Petr Engineer from: Lou Grimaldi Petr Inspector subject: BOP Test Grace 160 Stewart Petroleum West McArthur River D-1 PTD 92-156 Friday, January 15, 1993: I traveled to Grace Rig 160 for the initial BOP Test on Stewart Petroleum's West McArthur Well D-I. When I arrived, the casing head was being welded on so I stood by until the following morning. Saturday, January 16, 1993: The test went well with one failure observed, this being the second inside valve on the hydraulic leg of the choke manifold. All other components functioned correctly and held their respective pressure tests. When the failed valve was disassembled it was found to have a bad seat and one would have to be brought from town. The valve was reassembled and shell tested. Repairs are to be completed within three days. The area surrounding the rig was clean and well kept with adequate access provided for emergency equipment. Monday, January 18, 1993: I was contacted by Paul White (drilling foreman) who informed me that the failed valve had been repaired and tested "OK". SUMMARY' I witnessed the initial BOP Test on Grace Rig 16.0 drilling Stewart Petroleum's West McArthur River Well D-l; test time 2 hours - 1 failure. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg ~ Wkvr~ ~ ~ C ~, _ Operator ~'l~J~. ~ ~'- /~' -~'~F~)~' Rep ~ ~ell ~e~~ ~~ ~_ ~ Permit Drlg contrctr ~~~ ~ csg set ~ /~/ /ft Location (general) ~ Housekeeping (general) ~~ Well sign 0 ~(~ Rig. ~K Rsrve pi t MUD SYSTEMS: Visual Audio Trip tank ~:)/) J "-- Pit gauge ~5'3~ J ~~, Flow monitor ~:~ ~/~ J d) N Gas detectors ~ ,J ~/ BOPE STACK: Test Pressure Annular preventer ~ 02,~:~0 Pipe rams ~ J~DO0 (0 Blind rams Choke line valves HCR valve Kill line valves Check valve TEST: Initial Rig# ACCUMULATOR SYSTEN: Full charge pressure Press after closure / Pump incr clos press 200 psig Full charge press attained Controls: Master ~)~ Weekl y,~ Other Rig phone # '~ 7(~ :~"~' 0 Location: Sec/~ T ~ R/y~ MUM psig psig min ~;~' sec rain ~) ~" sec psig ~(~ ~ Remote ~ ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES': Upper Kelly ~ ~0~) Lower Kelly ~ ~ ~ Ball type O~ ~ ~ n, de Chok 'm , fo d .8 Number valves / ~ ~// ~t/. Number flanges ~ Hydraulically opera~ed choke / ~ Test pressure Test pressure Test pressure Test pressure TEST RESULTS: Failures / Test time (~ hrs Repair or replacement of failed equipment to be made within days. Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/92) STATE WITNESS REQUIRED? yes ~ no 24-HR NOTICE GIVEN? yes ~r no Waived by: Witnessed by: ~~ ~, ,~~' AOGCC phone 279-1433 - FAX 276-7542 HAND DELIVERY January 19, 1993 ENSR Ref. No: 6397-003-600 ENSR Doc. No: 930051.RG :,,,a l~:,g,.,,;,;r,,,g 4640 Business Park Bh'd. Building !) Anchorage, AK 99503 (~07) 56~-5700 FAX (~)7) 273-4555 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTENTION: Commissioner Russell A. Douglass RE: AppliCation for Sundry Approvals, (Form 10-403) Stewart Petroleum Company, West McArthur River Well 9-1 ~,~ .. i~,~ Dear Mr. Douglass: I have attached three originals of the above referenced' application. Thank you for your time today and discussing the proposed revised total depth with me. · Sincerely, R.C. Gardner Agent, Stewart Petroleum company RG/Iw Attachments cc: W.R. Stewart, President, Stewart Petroleum Company RECEIVED JAN 1 9 199 Alaska Oil & Gas Cons. (;ommissio~'~ Anchorage ,,.: ALASKA OIL AND (3A~ CONSERVATION COMMISSION APPLI TION FOR SUNDRY APPROVALS ng ~ . ~~ ~ P~ ~ ~me ~e~on ~ S~m~e ~ 2. N~e of O~ator ! [ Type of W~I: · Datum ~ation ~dr~ 2550 Denali Street, Suite 1300 S[r~graon~ Anchnra~. AK ~03 4. Location ~ w~l at sudace 1446 ft EWL, 2776 ft NSL, Sec. 16 T8N, R14W, SM At top of productive interval N/A Al effective depth Same as surface location (straight hole) At total depth Same as surface location 12. Present well condition summary Total depth: measured 3461 feet Plugs (measured) true vertical 3461 feet 163 7. Umt or Property name Wgst McArthur River 8. Well numOer 9. Permit numl:)er 92-156 10. APl number 50-- 133-20446 11. Field/Pool No pool or field d,~iqnated None Effective depth: measured 3461 fee~ Junk (measured) true venicaJ 3461 feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ng~ ~ Cemented · 131' 13-3/8 Driven 1361' 9-5/8 To Surface measured true vertical No Perforations Tubing (aze, grade, and measured depth) No Tubing Packers and SSSV (type and measured depth) No Packers ~ 13. Attachments Description summary o~ proposal ..~ Measured depth 131' 1361 ' True vertical dep~ 131' 1361 ' RECEIVED ,JAN 1 9 199) Alaska 0il & Gas Cons. commission Anchorage Detailed'oper~ons program .=,_ BOP sketch ... ,14. 'Estimated date lot ~3mmer~ngoperalion . i15. OiIStatus ot wetIGasclasafication as: i , January 21, 1993 Stratigraphic Test x ._ __ Susa-haled ._ 16, If proposal wa~verbally approved. "~ 1-19-93 Nameo~apprev~ Eussell A, Douglass Dateapl~'ov~ S~¢e , 17. I hereby certify that the foregoing is true>~;~;rrect to the best of my knowledge, . ¢ondit~om of appro~l: Notify ¢ommi~on ~o mpr~ntati~ m~t ~tn~ .... Plug integrity _. _ BOP Test _.. Location clearance __ lApp,ovalNO, ,~==~.¢:>,/~ Mechanical Intogrity 1~ ._ Sul~quant lorm r~qui~110- ~ n ~ · ~'' ~....., Approved by order of the Commis~ion OrigirlD! ',?i,l~.l~r'l~d' I~V ..', ".'.r.':::.,'L' ':;"';:;":'":'"/'~'--~''j ~'~'~ Form 10-403 Rev 06/15/88 ...... SUBMIT .~ .....~'"' ...... IN TRIPLICATE Janua~ 19,1993 Description of Proposed Operations: West McArthur River Well D-1 This description is attached to and made a part of an Application for Sundry Approvals (Form 10-403) submitted by Stewart Petroleum Company dated January 19, 1993. Well D-1 is currently permitted to a depth of 4,000 ft. Drilling is currently underway and had reached a depth of 3,461 ft. at 0600 hrs, January 19, 1993. Stewart Petroleum Company hereby makes application to amend the permitted depth to 4,500 ft. RKB. This will enable the operator to evaluate two additional zones for future use as Class II injection zones. If this amended 'depth is approved, 7" casin~ will be run and cemented to total depth as per the original program, and cement slurry quantities will be increased to place this top of cement a minimum of 2,500 feet above the casing shoe. All other conditions and procedures defined in the original permit will remain unchanged. Thank you for your consideration of this 'application. ~~rdner Agent, Stewart Petroleum Company RECEIVED JAN 1 9 199, Alaska 0il & Gas Cons. L;0mmissior, Anchorage Memorandum Oil and Gas Conservation Commission To: FILE McArthur River D-1 Date: State of Alaska January 19, 1993 From: R. A. Douglass Subject: BOPE Test Pressure On January 19, 1993, spoke with Bob Gardner of Stewart Petroleum Co. regarding the BOPE test pressure specified on the Permit to Drill. The pressure specified is 5000 psig. Since the well is shallow (<5000'TVD) and the casing head is rated to only 3000 psig the test pressure should not exceed 3000 psig. As discussed with Mr. Gardn~,~r the new specified test pressure for the BOPE installed on th~cArthur River D-1 is 3000 psig. JAN-08-199~ 17:10 FROM ENSR ANCHORAGE ALASKA TO 92?6?542 P.01701 ?~o _T Ta TOTAL P.O1 ALASKA OIL AND GAS / CONSERVATION COHHISSION /' WALTER J. HICKEL, GOVERNOR .. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Janua~ 8,1993 R C Gardner, Agent Stewart Petroleum Co 2550 Denali St Ste 1300 Anchorage. AK 99503 Re: Well # Company Permit # Surf Loc Btmhole Loc West Mr, Arthur River No. D1 Stewart Petroleum Company 92-156 1446'EWL, 2776'NSL, Sec 16, T8N, R14W, SM same Dear Mr Gardner: Enclosed is the approved application for permit to drill the above referenced well. Your request to drill the surface hole without a diverter system is hereby approved. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies., and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness ttte test. Notice may be given by contacting the Commission at 279-1433. Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - wlo encl STATE OF AT.ASKA MEMDRANDt~ ALA~Kik OIL C=AS CONSERVATION COMMISSION To 2 Russell A. Douglasm Commissioner Thru' Leigh Grif f in~ Commissioner From' ~{ichael T ~{inder ,~.~.~', Sr Petr Engineer Date: January ?, 1993 Sub, oct: Diverter ~aiver ~. McArthur River D1 ~ell Stewart Petroleum Company requested a waiver for the diwerter required under 20 AAC 25.035. They presented data supporting their contention that shallow gas would not be encountered while drilling this well. Substantiation was based primarily on information gathered while drilling the ~est ]4cArthur River Unit #1 ~;ell (drilled last year from pro~ D1 l~tion) a~ the Pan Ameri~n ~t Fo~l~d ~2 ~ell (drill~ 985' to the ~outheast in 1966).' No gas was en~unte~d in the interval in which the surface casing of ~ell ~D1 will ~ ~t so the~ is no shallow hydr~r~ns e~ect~ to ~ found in ~D1. ~erefor a diverter i~ not ne~ary. Bob Crandall states that no shallow hydrocarbon zones are expected in the #D1 ~;ell (see Check List For New gell Permits, Additional remarks). Based on this information I recommend that the diverter waiver be granted. The best way to address the variance request is to write it on the Permit To Drill form 10-401, at the bottom, under "Condition~ of approval, Other. "" The written response should say "Request for waiver on diverter is granted." Wt,4RD1C~T :XLS State: Well: Field: State Permit ~ Nc. Ry. II~1 S#al. Te~t Engineer. Work Sheet: Date: Cc=me/# Vo~we 1/4/~3 Ca~ng T ~pe Ca=lng Size -Inches Cas'rog Length - Fee{ Hole Diame~a -Inche~ Cement-Sacks {{1 Cement- ¥,eld 111 Cement- Cubic it111 Cement- Cubic It#1 Cement- Sacks {{2 ~- Yield {{2 Cement- Cubic {l{{2 Cement- Cubic Ii{{2 Cement-Sacks {{3 Cement- Yie{d . {{3 Cement- Cubic Ii{{3 Cement- Cubic Ii{{3 Cement- ~ !1 ! Vo{ Cement- Fill Factor Conductem 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 OLO00 0,000 {191V/O! Surlace 9.625 1,350.000 12.250 0.000 0.000 0.000 465.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 465.000 1.100 L}nel 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Ca~'~ T~e Ca,t, ir~ Size -Inches Ca~ Depth - Fee{ Hole Diamete~ -Inches Cement- Sacks {{1 Cement- Yield {{1 Cement- Cubic ~t {{1 Cement- Cubic It II1 Cement- Sacks {{2 Cana'~ - Yield {{2 Cernent - Cul:~'c ~t {{2 Cement- Cubic it {{2 Cement- Sacks {{3 Cement- Yiekl {{3 Cement- Cubic R {{3 Cement- Cubic ~[ ! Vol Cement-Inte~¥al ft Top o! Cement- Feet Intermediate {{1 0.000 SE000 [~000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 {{DIV~ Inte~me6~e {{2 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 {tDIV/O{ Production 7.000 4.000.000 8.5OO 0.00 0.00 0.00 281.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2,215.97 1184.0 Heasured Depth Printed 1~/'93 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION Ci,...4MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill 83 Redrill !~I lh Type of well. Exploratory ¢1 Stratigraphic Test ~] Development Oil Re-Entry E] DeepenEl Sew}ce ?1 Deveiopement Gas [] Single Zone !~! Multiple Zone 2. Name of Operator Stewart Petroleum Company 3. Address 2550 Denali Street, Suite 1300 Anchorage, AK 99503 4. Location of well at surface 1,446 EWL, 2~776 NSL, Sec. 16, T8N, R14W, Seward Merid'~an (Straight Hole) ' At top of productive interval I~. G-~x./ At total depth /'" S~me as s_urface location 12. Distance to nearest 13. Distance to nearest well property line 500 feet 135 feet 16. To be completed for cleviatecl wells Kickoff depth feet Maximum hole angle Casing program size ~,,"J.~J. Si=dc}floc_lions Hole Casing Coupling; 5. Datum Elevation (DF or K__B) 163 fa~t 6. Property Designation Property Owned by 7. Unit or propqrty I~ame West McArthur River 8. Well nurpberWest McArthu River ~ No. D1 9. Approximate spud date January 4,' 1993 14. Number of acres in property 9,018 Acres CIRI Subsurface Estate} 10. Field and Pool West McArthur River No Pool Designated 11. Type Blanket Bank of 6~lumber America Alaska CD ($200,000) Amount $200,000 15. Proposed depth (MD ~ ~ 4,000 ft. MD and T'v'D feet 17. Anticipatecl pressure (~ ~ ~G ;a. o3a (,~ * M"M~d~ 1,508 M~*~W~a'"'"tn~ 1 968" we DePth TOp Bottom Ouantity of cement MD TVD (include stage data} LTC' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Length Size feet feet feet feet Plugs (measured) Junk (measured) Cemented RECEIVED DEC 19.92 Liner · ,.. --"~easuro'~laska .0ii & 6as Cons. CQla~|ssi0.~ Perforation depth: true vertical Measured depth True Vertical depth Pressures based on 0.492 psi/ft gradient (normal gradient plus 0.27 psi/ft safety factor), and assumed gas gradient of 0.115 psi/ft 20. Attachments Filing fee I~! Property plat ~ BOP Sketch ~1 Diverter Sketch ~] Drilling program ~ ~. Drilling fluid program'~ Time vs depth plot Bi Refraction analysis r"l Seabed report [] .20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of ~y knowledge ~ Signed Commission Use Only Permit Number APl numl3er App~uval date ,_ o iConaitlons of approval Samples requirecl C] Yes No Mud log requi~e~ [] Hydrogen sulfide measures E] Yes ~ No Directional survey required C3 Yes Other'Requirecl working pressure for BOPE 1'12M; ~[. ~3M; ."~/~SM; r'l 1OM; E3 15M ' Original Signed By t~ ~ commissioner Approved by i David W. Johnston Form 10.401 Rev. 12.1-85 ' R, C. A~. 6: (~. Title Agent, Stewart Petroleum Co Date 12 2 cover NO by diner of the commission Submit in triplicate December 30, 1992 ENSR Consulting and Engineering 750 West Second Avenue Suite 100 Anchorage, AK 99501 (907) 276-4302 (907) 272-7851 (FAX) Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill Stewart Petroleum Company West McArthur River No. D1 Gentlemen: Stewart Petroleum Company (Stewart) submits herewith three (3) copies of their Application for Permit to Drill the West McArthur River No. D1 well in the West Foreland area of Cook Inlet Basin. The required $100 filing fee is enclosed. Bond information is included in the Application booklets. Stewart is requesting a waiver for the diverter requirements in 20 AAC 25.035. Information to justify the waiver is provided in the Shallow Gas Sources and Overpressured Strata sections of the permit application. Thank you for your consideration of this application. If you have questions, please contact the undersigned at 561-5700 or Bill Stewart, President, Stewart Petroleum Company at 277-4004. Sincerely, Robert C. Gardner Regional Program Manager Oil and Gas Services REEEIVED RCG/Iw Enclosure cc: Bill Stewart DEC Alaska..Oil .& Gas Cons, ~Bank of America Business Banking Center December 30, 1992 Dave Johnston, Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Johnston: Stewart Petroleum Company has caused to be issued by Bank of America Alaska, in favor of the Alaska Oil and Gas Conservation Commission, two certificates of deposit to secure Stewart Petroleum Company's obligations in connection with a blanket bond under 20 AAC.25.025. The certificates of deposit, which are enclosed, are Certificate of Deposit No. 100025331, in the amount of 8100,000, and Certificate of Deposit No. 100018645, also in the amount of 8100,000, for a total of 8200,000. Bank of America Alaska guarantees the availability to the Alaska Oil and Gas Conservation Commission of the funds represented by these certificates of deposit until the Alaska Oil and Gas Conservation Commission authorized their release to Stewart Petroleum Company. Bank of America Alaska will honor written instructions from the Alaska Oil and Gas Conservation Commission to withdraw or apply funds represented by these certificates of deposit in accordance with the purposes of 20 AAC 25.025 and Stewart Petroleum Company's blanket bond. Sincerely, BANK OF AMERICA ALASKA, N.A. Ralph S. Combs Vice President Bank of America Business Banking Center: AK-0501550 West Seventh Avenue, Suite 1700 Post Office Box 1070071Anchorage, Alaska 99510-7007 Telephone (907) 263-3200 or (907) 266-7480 FAX: (907) 263-3272 SEC. 17 ., 1.446 FT. 2,776 Fl', · SEC. 9 SECTION 1 6, T8N, R1 4W,S.M. COOK INLET BLUFF · SEC. 21 ' SEC. 15 RECEIVED DEC 0 19.92 Alaska Oil & Gas Cons. Commissi, .. age.' 0 1000 2000 SCALE IN FEET ENSR CONSULTING &: ENGINEERING DRAWING: PSBH DRAWN: SR C/SC: 2000.0 DISK: D/5! 5 DATE: 12/05/92 CHECK: J.M. PROPOSED SURFACE & BOTTOM HOLE LOCATION FOR UNIT NO. D1 WELL STEWART PETROLEUM COMPANY WEST McARTHUR RIVER UNIT PROJECT 6597-005-400 RECEIVED FILLUP LINE ~ IIII II II ~1111~' 5,000 PSI WP ANNULAR PREVENTER BX 160 RING GASKET -----I I BX 160 RING GASKET BX 160 RING GASKET ;II I ~3 5/s" 5,000 PS~ X 11" 3,000 PSI DOUBLE STUDDED ADAPTER ENSR CONSULTING 8; ENGINEERING DRAV/ING, 3RAHSTK2 DRA%/N, ABB C/SC, 1,1 DISK, ]3/515 DATE, 1E/09/92 CHECK, JM 3' CHOKE LINE TO 10.000 PSI WP CHOKE MANIFOLD I I ~ g 5/8" ~,oo~o ~s' F~ CSG HEAD r,j~.._~ Bx 16o RING GASKET 11" ,:3,000 PSI FLANGE 9 5/8", 47 ih., N-80, BTC SURFACE CASING WEST McARTHUR RIVER UNIT NO. D'~ 13 5/8" THREE RAM BOP STACK WITH ANNULAR PREVENTER STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 BLOWOUT PREVENTION EQUIPMENT GRACE DRILLING COMPANY RIG 160 3 ea Iea 1 ea Iea Iea Iea 1 lot 13-5/8" x 5000 psi wp ram type preventers (Hydril) 13-5/8' x 5000 psi wp annular preventers (Hydril) 13-5/8' x 5000 psi wp drilling spool with 2 ea 4' side outlets (choke and kill), HCR and manual valves on both choke and kill lines BOP accumulator, V alvcon, 3000 psi w/12 bottles, 180 gallons, and (1) 80-gallon Valvcon accumulator. Accumulator pump, Gardner-Denver Triplex, Model PQ 172, air pump Model G7E. 8 bottles nitrogen backup Valvcon, 6 station, remote control panel Thornhill Craver, automatic choke 3" - 10,000 lb with control choke panel Hydraulic pipe and fittings from manifold to BOP stack RECEIVED DEC 3 0 1992 Alaska Oil & Gas Cons. Commission :Anchorage DIVERTER SYSTEM Stewart Petroleum Company is requesting a waiver for the diverter requirements in 20 AAC 25.035. Information to justify the waiver is provided in the Shallow Gas Sources and Overpressured Strata sections of this permit application. In the event that the AOGCC requires a diverter for the West McArthur River Unit No. D1 well, the following diverter system will be installed. r -. RECEIVED DEC ~ 0 1992 Alaska 0il & Gas Coris, [;orm~ission Anchorage {' FLOWLINE ~ = FILLUP LINE III \\ 15 5/8" 5,000 PSI ANNULAR PREVENTER BX 160 RING GASKET BX 160 RING GASKET DRILLING SPOOL I /~' 5,000 SOW CSG HEAD 1IX' HYDRAULIC VALVE OPENS AUTOMATICALLY WHEN ANNULAR PREVENTER CLOSES J~ TO BULL PLUG NOTE: DIVERTER UNES HAVE DOWNWIND DIRECTIONAL DISCHARGE CAPABILITY J== I ENSR CONSULTING & ENGINEERING I DRA~/INr,, VELLH~/R DRA%/N, A]H~ J J C/SC, I,! 9[SK, 9/5Z5 J JDATE, IE/og/gE CHECK, JM J 15 5/8", 72 lb., N-80 STRUCTURAL CASING RECEIVED WEST McARTHUR RIVER UNIT NO. D1 WELLHEAD DIVERTER SYSTEM D FO 3 0 1992 Alaska. Oil .& L~as Cons..C..o. mmissLo, n I WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 1 O" HYDRAULIC VALVES (VALVE LINKED THROUGH CONTROL UNIT .SO ONE MUST BE OPEN AT ALL TIMES) TO DISCHARGE POINT TO DISCHARGE POINT NOTE: FLUIDS TO BE DIVERTED DOWNWIND, AWAY FROM RIG BY CLOSING APPROPRIATE 1 O" HYDRAULIC VALVE 10" DIVERTER DISCHARGE LINE I'~0" HYDRAULIC VALVES, NORMALLY CLOSED (OPENS AUTOMATICALLY WHEN ANNULAR PREVENTER IS CLOSED) WELLHEAD AND 13 5/8" ANNULAR PREVENTER RECEIVED Alaska .Oil & Gas Cons. Co, mm. jss[o.D ENSR CONSULTING & ENGINEERING DRAWING: ONLINE DRAWN: ABB C/SC: 1.0 DISK: D515 DATE: 12/09/92 CHECK: JM WEST McARTHUR UNIT NO. D1 DIVERTER LINE AND VALVE LAYOUT STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6,397-003-400 STEWART PETROLEUM COMPANY WEST McARTHUR RIVER NO. D1 INJECTION DISPOSAL WELL (Straight Hole) Program Basis . . J . Se Se Hole Sizes, Casing and Casing Points Hole Size. Casing Description Programmed Casing Points (Driven) 13-3/8', 72 lb, N-80, welded 120 ft RKB 12-1/4' 9-5/8', 43.5 lb, L-80, LTC 1,350 ft RKB 8-1/2" 7", 29 lb, N-80, LTC, 4,000 ft RKB Drilling Ria: Grace Drilling Company Rig 160 (National 110 UE) will be used to drill the well. Rig description is attached. The maximum anticipated mud weight is 9.7 ppg at total depth. No overpressured zones are anticipated in this well. Maximum anticipated pressure at TD (4,000 ft MD and TVD) is 1,968 psi based on normal gradient of 0.465 psi/ft plus a 0.027 psi/ft safety factor. Maximum anticipated surface pressure = 1,508 psi based on column of gas to surface from TD and a gas gradient of 0.115 psi/ff. This well will be drilled as a stratigraphic test well to evaluate a potential zone(s) in the Tyonek formation for the disposal of non-hazardous drilling wastes. The anticipated disposal zone 'is a 50 ft thick sand zone located in the Tyonek formation from approximately 3,848 ft to 3,900 ft TVD. Relevant geological and formation data is presented in the Application for Disposal Injection Order which is being submitted to the AOGCC as a separate document. D0wnhole Disposal of Waste Drilling Fluids and Cuttings Assuming that a competent zone(s) is identified, Stewart Petroleum Company (Stewart) plans to dispose of waste drilling fluids and cuffings by subsurface injection down the 2-7/8" tubing string. Prior to any actual injection of drilling fluids, the operator will meet all requirements of 20 AAC 25.252. RECFIV£D DEC 0 1992 Alaska Oil & Gas Cons. CommisS~O[t Anchorage . . Shallow Gas Considerations This well occupies the same surface location as the West McArthur River Unit No. 1 discovery well. No shallow gas was encountered in the discovery well or the Pan American West Foreland No. 2 well (1966) which was drilled from a nearby sudace location approximately 985 ft to the southeast. The proposed well lies directly between these two previously drilled wells. In light of these conditions, Stewart hereby requests that the diverter requirements in 20 AAC 25.035 be waived. Additional information is presented in the Shallow Gas Sources section of this permit application. The attached Plan of Operations (Executive Summary) describes the key elements of the overall project and gives a proposed schedule of activities. RE( EI'VE D . DEC 3 0 1992 Alaska 0ii & Gas Cons. Commission Anchorage GRACE DRILUNG COMPANY WESTERN DIVISION RIG 160 Drswwork$: Iea National Model 110 UE, Lebus grooving drum for 1-3/8' drilling line. 48' double, Parmac Hydromatic brake. Sandline drum with 9/16' sandline. National automatic air-operated catheads, Crown-O-Mafic, and full instrument controls. Powered by (2) G.E. 752 RI traction motors each 750 HP. Enqines and Generators: 4 ea CAT Model D-398 diesel engines, 910 HP each at 1200 RPM, all driving A.C. E.M. electric generators, Model Bemac III, 600 volts, 800 kW 1000 KVA, 60 cycles. Iea Ross Hill, SCR system, with (4) 1201 SCR cubicles 1250 Amps, with Ross Hill Drillers control panel, Model 425. Mast and Substructure: DRECO cantilever mast 1,330,000, G.N.C., 142' x 25' leg spread, 7 sheave crown block, adjustable stabbing board, windwalls around board, ladders, handrailS, 2 derrick booms, catline, and air hoist sheaves, and derrick stand. Mounted on 29' high substructure floor 46' long overall by 28' wide with built-in 400 bbl water storage and 90 bbl trip tank, choke room, BOP dolly for handling BOP stack. Maximum Rated Hook Loads: 8 Unes = 886,000 lbs 10 Unes = 952,000 lbs 12 Unes -- 1,000,000 lbs Wind Capacity: 84 MPH with full rack 100 MPH without pipe on rack Setback Capacity: Table Capacity: 500,000 lbs 800,000 lbs RECEIVED DEC 5 0 1992 Alaska 0il & Gas Cons..~0mm..issi0n ~cltqra!z.e] PUmDS: 2 ea . . Continental Emsco F-1300 triplex mud pumps 7' x 12', 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 G.E. traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum I with 50 HP G.E. AC motor. Mud Tank System (1035 bbls Total Volume): Mud Tank No. 1 (shaker tank) approximately 270 bbls. Three (3) compartments which include desander, desilter suction compartment and cutting trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. -,,. Mud Tank No. 2 (volume tank) approximately 460 bbls. One (1) compartment equipped with desander, desilter, mud cleaner, mud guns, and mud agitators in top skidded section. Mud Tank No. 3 (suction tank) approximately 305 bbls. Three (3) compartments, two of which are pill pits, 1-65 bbls; (1) 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Eo_ui_oment: 1 ea Brandt dual tandem shale shaker Iea Drilco degasser 1 ea Picenco 16 cones desilter 1 ea Pioneer sidewinder mud mixer 4 ea 4 ea 1 ea Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP G.E. Electric Motors Pioneer desander, 2 cones, Model S-2-12 6 ea Dahlory 3" mud guns solids control equipment will be installed by olJ~r~., I~i~l~l:~d) (additional DEC 0 1992 Alaska Oil & Gas Cons. commission Anchorage. Heating Eguipment: 2 ea Williams and Davis 150 HP boilers, Model 777-T, diesel fired 2 ea Tioga air heaters, Type IDF 21-A, rated at 4.2 million BTU each 1 ea Waste heat recovery system, employs engine and boiler exhaust to heat pump room and sub-base 17 ea Steam heaters Air Compressors: 2 ea Sullair Corp., Model 10-30, 30 HP electric motors 2 ea Pure-Air air dryers, Model PAR 100 Rig Winterization and Equipment: 1 ea 1 ea Drillers' doghouse, steel, skidded, cantilever on substructure Derrick floor house, steel, skidded, cantilever off drillers' side of substructure 1 oa Steel house, skidded, behind drawworks with traction motors and drive system inside 3 ea Sectional pump houses, steel, skidded, houses both mud pumps, suction and discharge manifolding and pump parts room 4 ea Sectional engine houses, steel, skidded, houses engines and AC generators. Also, air compressors, air dryers, and BOP accumulator 2 ea Sectional support houses, steel, skidded, houses both boilers, boiler water tank, parts, and tools Iea Sectional SCR house, steel, skidded, houses SCR and electric gear 1 ea Sectional support house, steel, skidded, houses electrical pj~ and(~ E I V E D work area DEC ;~ 0 1992 Alaska Oil & Gas Cons. Commission Anchorage ( Rig Winterization and Equipment: (Cont'd) Iea Rig extension house for skidding rig to new well, steel, skidded, 40' length, houses mud, electrical, and koomey lines between sectional pump house and rig substructure Iea Sectional parts house, steel and skidded 1 ea Sectional welding shop, steel and skidded 3 ea Sectional shop houses, steel, skidded and pinned together into one (1) unit, 51' x 27' x 19' with door 1 ea Lot (40) matting boards 6"x 8' x 40' 1 ea Lot (2) matting boards 6" x 8' x 15' 10 ea Pipe racks Fuel Tanks: 1 ea Diesel tank, 16,500 gal, steel, skidded, and double walled 1 ea Gasoline tank, 500 gal, steel with stand Mobile Eauipment: 2 ea Forklift, CAT 966 with Young logging forks 2 ea Chew 4-wheel drive crew cab pickups Mi$cellsneous: 1 ea Lincoln "400" diesel welder, skid mounted with bottle racks, Model SAE 400-2056 with bedfold GM engine 1 ea Onan 6 kW portable electric generator RECEIVED DEC 0 A. iaska Oil & Was Cons, .C.0.m .~issi0r~ 1 ea Iea Idealarc 250 Lincoln Electric welder, 250 AMP, stationary Nugier hydraulic press 50 ton, Model H50-14 Travelin_o Eaui_oment and Floor Tools: 1 ea Bethlehem traveling block, 6 - 1-3/8 sheaves, 500 ton capacity 1 ea Web Wilson hydra-hook, 350 tons 2 ea Web Wilson elevator, 250 tons 1 ea Gray swivel, Type B44M, 500 tons 1 ea 1 ea Oilwell rotary table, Model A-37-1/2, 37-1/2' with Varco split master bushings, driven by G.E. 752 traction moter with Oilwell 2-speed transmission Varco HDPX double kelly drive bushing for 5-1/4' square kelly 1 ea 2 ea Drilco 5-1/4" square kelly, 54' B.J., Type DB, tongs with head sizes to 13-3/8' 2 ea Wooley, Type 617-101-0101 tongs with head sizes to 8" 1 ea Spinner Hawk, air-powered spinner wrench, Model 629 1 ea Varco spring slips, Model PS-15 1 ea NSCO deadline anchor Iea IngersoI-Rand air hoist, Type AUL, 40' with 9/16' line 1 lot Slips and elevators for contractors 5" drill pipe, 6-1/4' and 8' drill collars RECEIVED DEC 0 19,92 Nasla 0il & Gas Cons. C0mm~SS%O~ ;Anchorage Blowout Prevention Equipment: 3 ea 13-5/8' x 5000 psi wp ram type preventers (Hydril) Iea 13-5/8' x 5000 psi wp annular preventer (Hydril) Iea 13-5/8' x 5000 psi wp drilling spool with 2 ea 4' side outlets (choke and kill), with HCR and manual valves on both choke and kill lines 1 ea Valvcon BOP accumulator, 3000 psi with 12 bottles, 180 gals, and (1) 80 gal Valvcon accumulator. Gardner-Denver Triplex accumulator pump, Model PQ 172, air pump, Model G7E. 8 bottles nitrogen backup 1 ea Valvcon 6-station remote control panel 1 ea Thornhill Craver, automatic choke, 3" - 10,000 lb with control choke panel I lot Hydraulic pipe and fittings from manifold to BOP stack Miscellaneous: 2 ea Hastings oil heaters 1 lot Welding supplies for contractor's equipment 17 ea Ansul, Type A-B-C Purple *K' hand-held fire extinguishers 1 ea Mathey hydraulic wire line transmission (.092) unit, Model "Surveyors" with 3-speed R'ECEIVED ..A/as..ka .0ii & (Jas c0~]s..¢0.[~issi0.n PLAN OF OPERATIONS (EXECUTIVE SUMMARY) Stewart Petroleum Company west McArthur River No. D1 prepared for Stewart Petroleum Company Anchorage, Alaska prepared by ENSR Consulting and Engineering Anchorage, Alaska RECEIVED DEC ~ 0 1992 Alaska Oil & Gas Cons. Commission Anchorage 1.0 STATEMENT OF PURPOSE The project covered by this Plan of Operations (Executive Summary) consists of drilling a stratigraphic test well to evaluate a potential zone(s) in the Tyonek formation that may be suitable for injection disposal of non-hazardous drilling wastes. Assuming that a suitable disposal zone(s) is identified, the well would be used solely for injection disposal of drilling wastes generated at the West McArthur River Unit. This well will be a straight hole drilled from an onshore location. The surface location is on land owned by the Salamatof Native Association and the well will TD in the subsurface estate of Cook Inlet Region Inc. (ClRI). Agreements are in place with Salamatof and ClRI for drilling of the subject well. The well will be operated by Stewart Petroleum Company (Stewart) of Anchorage, Alaska, acting .,. for themselves and partners. Stewart will be the permittee of record. The activities described in the Plan of Operations will be conducted in a manner consistent with the Alaska Coastal Zone Management Program. 2.0 SITE LOCATION AND DESCRIPTION The subject well, "Stewart Petroleum Company West McArthur River No. DI", will be drilled from a surface location in the SW1/4, NWl/4, Section 16, T8N, R14W on land owned by the Salamatof Native Association. The well will be a straight hole and TD in the subsurface estate of Cook Inlet Region, Inc. (ClRI), containing 9,018 acres. The wellsite is approximately 70 miles southwest of Anchorage and 18 miles west of Kenai, Alaska. The drillsite is located on the northeast coast of the West Foreland peninsula and on top of the coastal bluff at an elevation of approximately 130 ft (see Figure 1). This location is situated on the southeast end of an old runway which was used to support the Pan American Petroleum Company West Foreland Unit No. 2 well in 1966. Arrangements have been finalized with both ClRI and malamatof for surface use and subsurface easement. The drillsite is accessible from the Marathon Trading Bay Facility by. a road that is still used by local residents, hunters, and fishermen. This road has been upgraded and maintained'by Stewart since November of 1990. RECEIVED Alaska Oi/& 6as Cons. Commission .Anchorage "" ENSR CONSULTING & ENGINEERING DRAVIN6, ~,/FnRLND DRAWN, SR C/SC, 1,1 DISK, D/E6O DATE~ 01/17/9E CHECK~ JM ':..".!":F. ':';L' .. VEST McARTHUR RIVER UNIT FACILITY LOCATIDN RECEIVED DEC ~ 0 1992 .at nas Cons. 0 1.5 5 SCALE (MILES) FIGURE 1 LOCATION MAP STEWART PETROLEUM PROJECT 6597-001 3.0 PROJECT SCHEDULE It is estimated that drilling and completion of the subject well will require approximately 10 to 14 days, once rig up operations are complete. Rig up is anticipated to be complete by January 1, 1993 and thus, the subject well could be completed by mid-January, 1993 if it is approved for drilling in late December, 1992 or the first week in January 1993. Grace Drilling Rig 160 has undergone significant modifications since drilling the West McArthur River Unit No. I discovery well. These modifications include a new 37" rotary table with an independent drive motor, new 50' kelly, longer kelly hose, and lock down kelly bushings. It is intended that any potential problems with these modifications will be worked out on the subject well prior to spudding the West McArthur River Unit No. 2 well. If any unanticipated operational problems result from these rig modifications, they will be corrected prior to spudding of the West McArthur River Unit No. 2 well. 4.0 DRILLING PROGNOSIS The well will be a straight hole and drilled to a total depth of approximately 4,000 ft. One or more sand zones in the Tyonek formation have been identified from existing geological data to be suitable for disposal of non-hazardous drilling wastes. The subject well will confirm the presence and competence of these potential disposal zones. Hole Sizes and Casing Program Hole Size Depth (MDI Casing Descrk)tion Driven 120 ft Conductor 12-1/4" 1,350 ft Surface 8-1/2" 4,000 TD Production 13-3/8", 72 lb, N-80, welded 9-5/8", 43.5 lb L-80, LTC 7", 29 lb, N-80 LTC 4.1 Wellhead and BOP Equipment Stewart is re'questing that the diverter requirements in 20 AAC 25.035 be waived for the subject well as the West McArthur River Unit No. 1 well was drilled from the same surface location without any shallow gas being encountered. In addition, the Pan American West Foreland No. 2 well was drilled from a surface location approximately 985 ft southeast of the West McArthur River Unit No. I surface location and was drilled without encountering any shallow gas. The subject well lies directly between these two previously drilled wells. RECEIVED DEC 5 0 1992 Alaska 0il & Gas Cons. Commission Anchorage The following wellhead components and associated BOP equipment will be utilized: Csg Size Wellhead Section BOPE Description 13-3/8' Conductor 9-5/8" Surface 7" Production 13-3/8" SOW csg head(l) 9-5/8" SOW csg head 11" x 7" tubing head 13-5/8", 5,000 psi wp diverter (1) 13-5/8", 5,000 psi wp BOP, RSRRA 13-5/8", 5,000 psi wp BOP, RSRRA (1) Equipment to be used if a diverter system is required by the AOGCC. 4.2 Drilling Fluid Program A Iow solids, non-dispersed, water-based drilling fluid system will be used for the entire drilling program. The system will be maintained to provide the required properties to drill the subject well relatively high penetration rates and maintain good hole cleaning ability. At the conclusion of the drilling operation, the drilling fluids will be evaluated for reuse as spud mud on the West McArthur River Unit No. 2 well which will immediately follow completion of the subject well. 4.3 Formation Evaluation A mud logging unit will be employed for cuttings and drilling fluid analysis from surface to TD. Open hole wireline logs will be run at each casing point. The following logging program is preliminary and may be modified to accommodate specific downhole objectives: Run 1: (9-5/8" casing point) Dual Induction - Gamma Ray Long Spaced Sonic Spontaneous Potential Caliper Run 2: (7" casing point) Dual Induction - Gamma Ray Long Spaced Sonic Spontaneous Potential Caliper Cement Evaluation Tool RECEIVED DEC 0 1992 Alaska Oil & Gas Cons. Commission Anchorage 4,4 Logistics and Support Equipment and materials required for the drilling operation will be transported to the site by barge and truck during the project. After spud additional materials and tools, as required, will be delivered to the site in the same manner or by aircraft using the airstrip at the Marathon Trading Bay Production Facility. Drilling crews and service company personnel will be housed at the Stewart camp building at the Trading Bay Production Facility. Rig tour changes will be made via carryall truck. Crew rotation will be via fixed-wing aircraft from Kenai. The Stewart Drilling Foreman and geologist will be housed in temporary quarters at the drillsite due to the necessity of being on-site at all times. Telephone and data fax communication will be available at the drillsite and a radio link will be maintained with the Stewart camp. Daily reports will be transmitted to the Stewart offices in Anchorage. 5.0 CONTINGENCY PLANNING An approved Oil Discharge Prevention and Contingency Plan will be in effect prior to the startup of drilling operations. This plan will address the prevention and detection of oil spills, methods for cleaning up accidental oil discharges, include a description of methods for controlling blowouts, the location and inventories of spill cleanup equipment, identification and location of a suitable drilling rig in the event a relief well is required, and relief well planning particulars'. An inventory of on-site spill containment and cleanup equipment will be maintained on-site and drilling crews will be trained in the use and location of this equipment. No drilling operations will commence or be continued when any of the following conditions exist: le Drilling will not begin until the Stewart Drilling Foreman is satisfied that the rig is properly rigged up to begin operations and all required materials and third party equipment are on location. e When there is an insufficient supply of drilling fluid materials on location required for pressure control, in the event the well kicks. . When sufficient emergency containment and cleanup equipment is not on location or inoperative. [~ E £ E IV F~ D DEC 0 !992 ~las.k~t.0il .& 6as Cons. C0m[nissio~ . . When the manpower required to safely conduct the drilling operation is not available. When any critical equipment needed to assure a normally safe operation is not operative. 5.1 Qualifications of Key Personnel All wellsite operations will be under the direct supervision of the on-site drilling engineer. A wellsite geologist will also be on-site to supervise mud logging, sample collection, and core recovery. Additional operations personnel will be at the wellsite as specific activities dictate. Operator and contractor personnel involved directly in drilling operations will be trained in well control procedures. All supervisory drilling personnel will be MMS certified as operator's representatives. 5.2 Persons in Charge The person in charge of the overall operation is: William R. Stewart, President Stewart Petroleum Company 3111 'C' Street, Suite 400 Anchorage, Alaska 99503 907-277-4004 (Bus) 907-243-6563 (Hm) The person in charge of on-site operations is: R. C. Gardner Regional Program Manager Oil and Gas Services ENSR Consulting and Engineering 750 West Second Avenue, Suite 100 Anchorage, Alaska 99501 907-563-1412 (Bus) 907-243-7554 (Hm) Mr. Gardner will be responsible for providing the AOGCC with a weekly status report on the subject well. He will also prepare and submit all necessary reports and materials as required by 20 AAC 25.070 and 20 AAC 25.071. R E £ E IV E D SUMMARY DRILLING PROGNOSIS . Construct location as per construction specifications. Set 10 ft diameter, 10 ft deep corrugated steel cellar. Drive 13-3/8' conductor to 120' RKB. 2. Move in and rig up Grace Drilling Company Rig 160. . If a diverter is required by Alaska Oil and Gas Conservation Commission (AOGCC), install a weld-on flange on 13-3/8" conductor, and nipple up 13-5/8" 5,000 psi diverter system as per diagram in Operating Procedures manual. Notify AOGCC sufficiently in advance of anticipated spud so AOGCC representative can witness functional test of diverter system, if necessary. .,, -, If the diverter requirement is waived by the AOGCC, weld drilling nipple on 13-3/8" conductor casing. Rig up mud loggers prior to spud. 1 Drill 12-1/4" straight hole to 1,350 ft MD. a) Run all solids control equipment. Control drilling rate so as to not exceed capacity of solids control equipment to handle drilled solids. b) Maintain lowest practicable mud weight as per mud program. c) Maintain optimum hydraulics. 5. Condition hole and run openhole wireline logs as directed. . Run and cement to surface 9-5/8', 43.5 lb, L-80 LTC casing as per detailed program in Operating Procedures manual. ., a) use stab in float collar and float shoe. b) Use 15% gel as extender and calcium chloride (CaCI~ to accelerate cement. Maintain slurry weight at 12.0 ppg until cement returns to surface and follow with 50 sack 15.0 ppg tail slurry. R E ¢ E IV E D DEC 3 0 1992 Alaska Oil & Gas Cons. commission Anchorage If slurry will not circulate to surface after pumping 100 percent excess, do top job as directed. . Drain cement from drilling nipple and WOC as directed. Nipple down diverter system, if present. Cut off 13-3/8" conductor at base of cellar. Install 9-5/8" x 11" 3,000 psi wp SOW casing head, and 11' 3,000 psi wp x 13-5/8" 5000 psi wp double studded adapter. Nipple up RSRRA 5000 psi BOP stack in accordance with Operating Procedures manual. AOGCC representative must witness test of BOPE prior to drill out of 9-5/8" shoe. Pressure test casing to 2000 psi before drilling out float collar. . Drill out float collar and float shoe with 8-1/2" bit, clean out rathole, and drill 10 ft of new hole. Perform formation competency test to 10.5 EMW. 9. Drill 8-1/2" hole to 4,000 ft MD. Beware of drilling breaks in coal stringers. Do not advance'more than 1 ft on drilling break without picking up and reaming. b) Run all solids control equipment. Control drilling rate so as to not exceed capacity of solids control equipment. c) Maintain lowest practicable mud weight as per mud program. d) Maintain optimum hydraulics. 10. Upon reaching 4,000 feet, make wiper trip and condition hole for wireline logs. Log as directed. 11. Run and cement 7" 29 lb, N-80, LTC casing to 4,000 ft as per detailed program in Operating Procedures manual. a) Use top and bottom wiper plugs, float collar, and float shoe. b) Using slurry volumes calculated from caliper log plus 15 percent, place sufficient slurry for a minimum of 2,000 ft fill-up above casing shoe. Maintain 15.0-15.5 ppg slurry weight. RECEIVED DEC 0 1997.. /~las..ka.0il & Gas Cons. C0m$lss|.0.t~ 12. c) Use CaCl~ to accelerate cement and provide 4-hour thickening time. WOC as directed. Land casing in 9-5/8' 3,000 psi x 7-1/16" 3,000 psi tubing head. 13. Run cement evaluation Icg. Squeeze as directed, if necessary. 14. Pressure test casing to 3,500 psi. 15. Perforate casing across selected disposal zone(s) by wireline with 4.5" perforating guns. 16. Run 2-7/8', 6.5 lb, L-80 tubing and set permanent packer above selected disposal zone(s). 17. Install surface valves and wellhead tree. This drilling prognosis is in summary form. A detailed Wellsite Operations manual and Operational Plan will be issued prior to the startup of drilling operations. I 'E'( EIVED DEC 5 0 1992 Alas~.Oil & Gas Cons. Commission Anchorage WIREUNE LOGGING PROGRAM Run 1: (9-5/8' casing point) Dual Induction - Gamma Ray Long Spaced Sonic Spontaneous Potential Caliper Run 2: (7' casing point) Dual Induction - Gamma Ray Long Spaced Sonic Spontaneous Potential Caliper Cement Evaluation This wireline program is subject to modification to fit geological conditions encountered while drilling. RECEIVED DEC ~ 0 1992 Alaska Oil & Gas Cons, Commission ,~nchorage] AflLP iR IJRILLIN(; I:LUIIJ$ A Baker Hughes company Tec~, dcal Information STFTWART PETROLEUM COMPANY West McArthur River Unit No. D I INTERV AL: HOLE SIZE: CAS IN(; SIZE: MUD TYPES: Spud - 1,000' 12-1/4" 9-5/8" Spud Mud MUD PARAMETERS Weight: Viscosity: pH: YP: Fluid Loss: 8.8 - 9.4 ppg 90 - 200 sec/qt 8.~ - 9.5 14- 24 25 - 50 < 30.0 cc/30 min The surface interval will be drilled with the usual bentonite/Ben-Ex surface mud, For purposes of this program, a 500 barrel active system will be used for all calculations. Fill the pits with fresh water, and check both chloride and hardness levels. Treat out excessive hardness with small additions of Soda Ash ( 1/2 - 3/4 ppb) until < 40 ppm hardness remains. Do not overtreat. Prior to spud, mix the surface system to maximum capacity, adding Milgel of sufficient quantity (20 -25 ppb) to yield a viscosity of 90 sec/qt. RECEIVED Page 1 DEC ;~ 0 1992 Alaska Oil & Gas Cons, Commissio~ Anchorage MILPAR DRILLING FLUIDS A Baker Hughes company Tec uical Information STEW ART PETROLEUM COMPANY West McArthur River Unit No. D 1 Interval: 17-1/4" Spud- 1,000' Drill ahead maintaining volume and sufficient yield point for good hole cleaning, Maintain viscosity at 150 - 200 sec/qt throughout any gravel sections. Keep mud weight at desired levels (as low as possible) with water additions and solids control equipment, Keep sand content below 1% to improve quality of mud and reduce wear on pumps, Ben-Ex may be added at a 5: I ratio with Milgel as a bentonite extender and supplementary viscosifier, Run and cement 9-5/8" casing, ANTICIPATED PRODUCT USEAGE -= 12-1/4" Hole Milgel. Bentonite 100 #/sx 350 sx Soda Ash Soda Ash 100 #/sx 6 sx Ben-Ex Acrylic Polymer 2 #/sx 40 sx Mil-Bar Barite 100 #/sx 55 sx Page 2 RECEIVED DEC Alaska 0il & ~as Cons. Commission Anchoraga' A Baker Hughes company Tec (h. ical Information STEWART PETROLEUM COMPANY West McArthur River Unit No. D I INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPES: 1,000' -. 8-1/2" 7' LSND 4,000' MUD PARAMETERS Weight: 8.8 - 9.4 ppg Viscosity: ~0 - 90 sec/qt pH: 8.5 - 9.5 PV: 8- 18 YP: 15 - 25 Fluid Loss: < 12.0 cc/30 min This section will be drilled with a basic low solids, non-dispersed system, mud Before drilling out the cement, the spud mud from the previous interval should be evaluated to determine the percent low gravity solids and active bentonitic days. If the mud is found to be dean, and it should be if proper solids control was followed on the previous section, the 9-5/8" shoe should be drilled with the old mud. As this would eliminate the necessity of building a new mud system from scratch, this would save both time and money. If the low gravity solids are too high and it is determined some dilution is needed, dump and dilute with fresh water to bring the low gravity solids in,o ,n,. RE ¢ E IV E D Page 3 DEC ,3 0 19.92 Alaska 0il & Gas Cons; Commission Anchorage. A Baker Hughes company InFormation STEWART PETROLEUM COMPANY West McArthur River Unit No. D I Interval: 8-1/2" 1,000' - 4,000' The 8-I/2" section will be drilled using virtually the same type mud as the previous interval, Prior to dri!ling formation, obtain the anticipated pump rates, and increase the Yield Point as necessary to ensure good hole cleaning properties. Milpark's on-site engineer will calculate daily the pump rates and mud properties desirable to keep the hole properly cleaned. Since D1 will be a straight hole, particulate settlement and cuttings bed formation will not be a major concern. Undue pump pressures will be avoided by ensuring complete removal of the cuttings. This will be accomplished by running relatively high Yield Points (20-25) in relation to the funnel viscosity. Initial gel strengths in the 6-10 range will help keep any cuttings suspended whenever the pumps are shut down. Rheological properties can be regulated using Sodium Pyrophosphate (SAPP) in very small quantities. This product, unlike organic thinners, does not require Caustic Soda to solubilize or activate it. It is well known increased hydroxyl ion (OH) content exerts a highly dispersive effect on reactive formations. If it is necessary to reduce the fluid loss to the 6'- 8 cc range, either Mll-Pac or Drispac can be used at low concentrations. RECEIVED Page 4 DEC ;~ 0 1992 Alaska Oil & Gas Cons. Commission Anchorag~ MILPAR DRILLING FLUIDS A Baki~r Hughes company Tec h lical Information STEWART PETROLEUM COMPANY West McArthur River Unit No. D I Interval: 8-1/2" 1,000' - 4,000' Keep mud weight at desired Levels (as low as possible)with water additions and solids control equipment. Keeping sand content below 1% will improve overall quality of mud and reduce wear on pumps. Run and cement 7" casing. ANTICIPATED PRODUCT US_RAGE -- 8-1/2" Hole Mil-Bar Barite 100 #/sx 200 sx Milgel Bentonite 100 #/sx 120 sx Soda Ash Soda Ash 100 #/sx 6 sx Bicarb Bicarb of Soda 100 #/sx 12 sx SAPP Sodium Acid I00 #/sx 8 sx Pyrophosphate Mil-Pac Acrylic Polymer 50 #/sx 15 sx Page 5 RECEIVED DEC 3. 0 1992 Alaska 0ii & (~as Cons. (;ommissio~ Anchorage CASING AND CEMENTING PROGRAM - SUMMARY STEWART PETROLEUM WEST McARTHUR RIVER UNIT NO. D1 Hole Casing Casing Depth, Depth @ Float Cement Slurry Size Size Description Shoe (RKB) Top Length Equipment Class Wt. Notes 12-1/4' 9-5/8' 43.5 lb, L-80, LTC 1,350' MD 0 1,350'(1) F.C. G 12.0-12.5 Use stab-in float collar and float (1,350' TVD) F.S. shoe and cement to surface. Use calcium chloride (CaCI2) to accelerate cement and provide a 2.5 hour thickening time. 8-1/2' 7' 29 lb, N-80, LTC 4,000' MD 0 4,000' F.C. G 15.O-15.5 Use top and bottom wiper plugs. (4,000' TVD) F.S. Calculate cement volume plus 15% for 2,000 ft flllup above shoe. Use calcium chloride (CaCI2) to accelerate cement and provide a 4 hour thickening time. (1) Surface casing will be set to a minimum depth of 1,350 It TVD to seal off any fresh water aquifers above this depth. Please see the attached E-Log from the West McArthur River Unit No. I well for setting depth of the 9-5/8 casing shoe relative to potential freshwater aquifers above this depth. PHASOR BIIXICTIGN LOG / eR / 81) CO&~ANY STEWART PETROLEUM COIV~ANY WR i McARTI-ER RIVER UNiT NO. 1 FIR n W. FOfll:l AI~S BOROUGH KENAI STATE ALASKA ~)T 50-1332-0419 Lq ~llllrl~l Ffem KAL Ofirmg liP. Ism'ed F;em ICJ[ Penn. :. Bev.:- ILB.18~O F DJ:. 6.L. Ty[ W in Hole I~ ' IFM- Lee. _8,~,_ ee of __n~mlde Rm · Meee. Tef~. Rmf · ______~__er T_,~I~. RIll eBHT C'~J~9~_ ~: ~H,~,j ~_Ended Id~=_ ReO. Tefnp. i 27-JUN-WG1 ;ONE 2216.0 F 2182.0 F ,'-. 2178.0 F 130.0 F 130.0 F t7 8.40 LB/G 146.0 S I 8.0' MIX) PIT 9.970 ~ 0 06.00EGI:: O lt80 ~ 0 66.0 DEGF ~ , ss 7.107 0flMM O 04.0 I~GI: 1800 11-27-91 SEE LOG 114.0 DEGF 8 z TOOL STRXNG SKETCH II I TCCB SGTL SDT DTTE FIN STANDOFF FIN STANDOFF STANDOFF FXN STAHDOFF FIN STANDOFF FIN STANDOFF FIN STAHDOFF FXN STAHDOFF GR 75,2 la' 72.2 F 71.3 F 66.7 F 31.3 F RECEIVED OEO ,~ 0 1992 Alaska Oil & Gas Cor~s~'C~mn~ssion Anchorage IL0 -1~0.0 8P(MV ) CP 32.4 TOTAL TOOL STRING LENGTH ZS 77.3 ~'. TOTAL TOOL STRZNG I~ZOHT TS 1136. LB IN ........................ : ............ .M/.H.~..O~..M.~ .................................... .20000 2000.C 100.00 .~.0000 2000.C 9FLU{OI"IMM} -so.oo .20000 ~ooo.c ]:m*UT F]:LE(S) 8 / 100' 13 29-JUt]-1991 02:38 DATA AC(~U~I~D 28-JU1~-1991 03= 11 100 200 300 (" 400 I I 500 600 700 800 ~mcho. ra~ 8OO 900 1000 1100 1200 13oo 1100 9-5/8' SHOE 1350' 'I'VD 1400 1500 1600 ii1111 I lllll ~ Ill ,,,,, ,,,,,, ,,,,, II Illl II Illl~-~' III ,,,,,, ,,,,~ ,,, Ill II1~ III II Illl I11111 ' ,.~1 ,III IIIIII IIIIII ~---~1 III ii,.,. ,, ~--..~ ,,, Illl II1~ III III ~llao ~ng~ I II1~~III III ~,1, L IIJl .__LLtJII~- III III Anchorage." OPERATOR: 5/8' SURFACE CASING DESIGN D. ~A STEWART PETROLEUM COMPANY .~-%SE: SEC. 16 WEST McARTHUR RIVER UNIT NO. D1 FIELD: ,mmmmmmmmmmmmmmmmmmmmmmmmmmm TWP. 8N RNG. 14W COUNTY: KENAI DATE: 30-DEC-92 mmmmmwmmmmmmmmmmmmm~ WEST McARTHUR RIVER STATE: ALASKA SURFACE CASING CASING DESIGN DATA DESIGN CODE: CASING STRING DESIGN CODE - i ·OlOle..oo.·....·o..-----oo- -- ***************************** .DESIGN FACTORS: 2 BURST DESIGN FACTOR .................................. 3 COLLAPSE DESIGN FACTOR ............................... 4 TENSION DESIGN FACTOR ................................ 50VERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) = 1.100 = 1.100 = 1.600 = 100000.000 CASING BURST DESIGN DATA: 7 FRACTURE GRADIENT AT THE CASING SHOE + YOUR SAFETY FACTOR (PPG) ···o·········.·.o······--····· 8 GAS GRADIENT (PSI/FT) .·..OlOlO···.··.··o··.··.·---···o ( WEIGHT OF BACKUP FLUID (PPG) .oo·..oo·o.·o.·oeo--·-·''' CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN ..................... (PPG) OF CEMENT (FT) 12 TOP · ·······o.············---·--'o''eec. OF CEMENT 13 WEIGHT ····o····.··.···.·-·····-··''··' COLLAPSE ~ACKU~ (~G) 14 WEIGHT OF FLUID ................. 12.500 ·115 9.000 9.000 .000 12.000 .000 CASING DESIGN DATA: 15 CASING SIZE, 0 D (IN) -- · .·oe..o..ooeoo....oooo.···ooe·--o 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER .......... (IN) = 17 SETTING DEPTH (FT)- - Olll.··ooeooee·.···.·····-··--··''·· 18 MINIMUM SECTION LENGTH (FT)- - 0o0..0.0.·00000·.--00--00-0 9.625 8.500 1350.000 .000 CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR TENSION ............... (0=YES;i=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;i=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION...(0=YES,I=NO) '= 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY..(0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (CAS.BIN) = C:CAS.BIN RECEIVED DEC 0 1992 Alaska.Oil & Gas Cons. Commission Anchorage , OPERATOR: STEWART PETROLEUM COMPANY I..~ASE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: LC. 16 TWP. 8N RNG. 14W. COUNTY: KENAI 9-5/8" SURFACE CASING DESIGN., ( DATE.' 30-DEC-92 WEST McARTHUR RIVER STATE: ALASKA SURFACE CASING CASING DESIGN -- 9.625 DEPTH LENGTH WEIGHT GRADE JOINT PRICE (FT) (FT) (LB/FT) ($/FT) .0 1350.0 43.50 L-80 LTC STRING COST = $ 40865. STRING WEIGHT = ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** ** FORMULA USED: MAXIMUM LOAD THEORY ** 30.27 58725. LBS BURST PIPE BURST DEPTH WEIGHT/GRADE/JOINT LOAD (FT) (PSI) · 0 43.50/L-80 /LTC 721· 1350· 0 43.50/L-80 /LTC 245. PIPE IN TENSION PIPE DESIGN BURST FACTOR (PSI) NOT IN TENSION PIPE DESIGN BURST FACTOR (PSI) 6461. 8.96 6330. 8.78 6300. 25.67 6330. 25.79' COLLAPSE DEPTH (FT) PIPE WEIGHT/GRADE/JOINT · 0 43.50/L-80 /LTC 1350.0 43.50/L-80 /LTC PIPE IN TENSION COLLAPSE PIPE DESIGN LOAD COLLAPSE FACTOR (PSI) (PSI) NOT IN TENSION PIPE DESIGN COLLAPSE FACTOR (PSI) 0. 3726. 3810. 841. 3828. 4.55 3810. 4.53 TENSION DEPTH (FT) PIPE WEIGHT/GRADE/JOINT · 0 43.50/L-80 /LTC 1350.0 43.50/L-80 /LTC TENS ION JOINT/BODY LOAD STRENGTH (1000 LBS) (1000 LBS) TENSION DESIGN FACTOR 48.2 825.0 -10.6 825.0 17.13 -78.07 OPERATOR: 9-5/8" S¥"'CACE CASING BURST PRESSURE t,'~. DEPTH STEWART PETROLEUM COMPANY DATE: 30-DEC-92 LEASE: ~C. 16 WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA SURFACE CASING BURST PRESSURE VS. DEPTH 0 + .... +-*--+ .... + .... + .... + .... + .... + .... + .... + .... + .... + .... +---++ .... + ! * + .' ! * + ! ! * + '. ! * + ! 500 + * + + i . + ,, ! * + ! * + ! * + 1000 + * + + ., , + ., ! , + ,. ., · + : 1500 + + (" , '2000 + + · ! .' : .' ., '. 2500 + + ! : .' : '. ., '. 3000 + + ! !. ! ! : ! ! 35OO + + ! : '. ., ., ., : 4000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + 0 3.000 2000 3000 4000 5000 6000 7000 BURST DESIGN LINE (PSI) * PIPE BURST (PSI) + RECEIVED DEC 0 1992 Alaska Oil & Gas Cons. Commission Anchorage vs. .% OPERATOR: STEWART PETROLEUM COMPANY I?~SE: WEST McARTHUR RIVER UNIT NO. D1 S.:C. 16 TWP. SN RNG. 14W COUNTY: KENAI DATE: 30-DEC-92 FIELD: WEST McARTHUR RIVER STATE: ALASKA SURFACE CASING COLLAPSE PRESSURE VS. DEPTH 0 * .... + .... + .... + .... + .... + .... + .... +-+--+ .... + .... + .... + .... + .... + .... + · + ., !* + .' ! * + .' : · + 500 + * + + : . + : : . + : ! * + : ! * + : 10o0 + * + + ! * + ! ! * + t , + ! · : '. 1500 + + 2000 + + 2500 + + 3000 + + 350O + + 4000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + 0 1000 2000 3000 4000 5000 6000 7000 COLLAPSE DESIGN LINE (PSI) * PIPE COLLAPSE (PSI) + RECEIVED Alaska Oil 8, Bas Cons. Commission Anchorage OPERATOR: 9-5/8" SURFACE CASING TENSION VS. DE~'"H {" STEWART PETROLEUM COMPANY DATE: 30-DEC-92 WEST McARTHUR RIVER STATE: ALASKA SE: WEST McARTHUR RIVER UNIT NO. D1 SEC. 16 TWP. 8N RNG. 14W COUNTY: FIELD: KENAI SURFACE CASING 5O0 1000 1500 ( 2000 2500 3000 3500 TENSION VS. DEPTH 0 + .... * .... + .... + .... + .... + .... + .... + .... ++---+ .... + .... + .... + .... + .... + ! * + , + ! · + ! . + ! , + + . + ! , + ! . + ! , + -,. · + + ,, . + ! , + ! , + ! + ! ! ! + ! ! ! ! + ! ! ! ! + ! ! ! ! + ! ! 4000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + 0 200 400 600 800 1000 1200 1400 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + RECEIVED DE¢ ~ 0 199~ AJas,ka..Oil ,~ u~s (;oas..(;ommissio~ OPERATOR: STEWART PETROLEUM COMPANY DATE: 22-DEC-92 I.~SE: I~ST Mc, ARTHUR RI~ER UNIT NO. D1 FIEI.~: ~ST Mc,~R~ RIVER SEC. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA PRODUCTION CASING CASING DESIGN DATA DESIGN CODE: i CASING STRING DESIGN CODE ............................ ***************************** DESIGN FACTORS: 2 BURST DESIGN FACTOR .................................. 3 COLLAPSE DESIGN FACTOR ............................... 4 TENSION DESIGN FACTOR .......................... , ..... 5 OVERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) CASING BURST DESIGN DATA: 6 SHUTIN BOTTOMHOLE PRESSURE ...................... (PSI) 9 PACKER FLUID WEIGHT (PPG) .......i.........ee..eeeel.l. 10 WEIGHT OF BACKUP FLUID .......................... (PPG) CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN ..................... (PPG) 12 TOP OF CEMENT .................................... (FT) 13 WEIGHT OF CEMENT (PPG) .OOOl....e............o......... 14 WEIGHT OF COLLAPSE BACKUP FLUID ................. (PPG) CASING DESIGN DATA: 15 CASING SIZE, O D (IN) · ........o...........o............ 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER .......... (IN) 17 SETTING DEPTH .................................... (FT) 18 MINIMUM SECTION LENGTH (FT) .eoe&...ooeoeellO....oeo... CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR TENSION ............... (0=YES;i=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;i=NO) = 26 CONSIDER EFFECT'OF BOUYANCY ON TENSION...(0=YES,i=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY..(0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (CAS.BIN) = 5 = 1.000 = 1.000 = 1.600 = 100000.000 2400.000 8.500 8.500 10.000 .000 15.500 .000 7.000 6.000 4000.000 .000 = C: CAS. BIN RECEIVED DEO 0 199[ Alaska Oil & Gas Cons. CommissJor~ Anchorage 7" PRODUCTION CASING DEsIG(~. OPERATOR= STEWART PETROLEUM'COMPANY DATE: 22-DEC-92 LEASE: WEST Mc. ARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER SEC. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA PRODUCTION CASING CASING DESIGN -- 7.000 DEPTH LENGTH WEIGHT GRADE JOINT PRICE (FT) (FT) (LB/FT) ($/FT) .0 4000.0 29.00 N-80' LTC 17.27 .,. STRING COST = $ ** INTERNAL YIELD ** COLLAPSE LOAD 69080. STRING WEIGHT = UPGRADED FOR TENSION ** UPGRADED FOR COMPRESSION ** 116000. LBS ** FORMULA USED: MAXIMUM LOAD THEORY ** BURST PIPE BURST DEPTH WEIGHT/GRADE/JOINT LOAD (FT) (PSI) · 0 29.00/N-80 /LTC 2400. 4000.0 29.00/N-S0 /LTC 2400. PIPE IN TENSION PIPE DESIGN BURST FACTOR (PSI) NOT IN TENSION PIPE DESIGN BURST .FACTOR (PSI) 8595. 3.58 8160. 3.40 8010. 3.34 8160. 3.40 DEPTH (FT) PIPE WEIGHT/GRADE/JOINT COLLAPSE PIPE IN TENSION COLLAPSE PIPE DESIGN LOAD' COLLAPSE FACTOR (PSI) (PSI) NOT IN TENSION PIPE DESIGN COLLAPSE FACTOR (PSI) .0 4000.0 29.00/N-80 /LTC 29.00/N-80 /LTC. 0. 6574. 7020. 3220. 7142. 2.22 7020. TENSION DEPTH (FT) .0 4000.0 PIPE WEIGHT/GRADE/JO INT TENSION JOINT/BODY LOAD STRENGTH (1000 LBS) (1000 LBS) TENSION DESIGN FACTOR 29.00/N-80 /LTC 29.00/N-80 /LTC 88.8 597.0 -27.2 597.0 RECallED 'D' C 0 1992 Alaska Oil & Gas Cons; OPERATOR; STEWART PETROLEUM-COMPANY DATE: 22-DEC-92 LEASE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER SEC. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA PRODUCTION CASING BURST PRESSURE VS. DEPTH 0 + .... + .... +---*+ .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + ! * + ! * + ! * + ! * + 1000 + * + ! * + ! * + ! * + ! * + 2000 + * + ! * + ! * + ! * + ! * + 3000 + * + ! * + ! * '+ ! * + ! * + 4000 + * + ! ! ! ! 50O0 + + ! 6000 + 7000 + + 8000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... +---~+ ....+ .... + .... + 1000 2000 3000 4000 5000 6000 7000 8000 BURST DESIGN LINE PIPE BURST (PSI) * (PSI) + RECEIVED ' DE O 0 1992 Alaska Oil & Gas Cons. Commissior~ Anchorage 7" PROI~i .ITIO. CASING COLLAPSE PRESS~.,E VS. DEPTH OPERATOR: STEWART PETROLEUM COMPANY DATE: 22-DEC-92 LEASE= WEST McARTHUR RIVER UNIT NO. D1 FIELD= WEST McARTHUR RIVER SEC. 16 mmmmmm mmmmmm mmmmmm mmmmmmmmmmmmmmmmmmmm Nmmmmmmm PRODUCTION CASING COLLAPSE PRESSURE VS. DEPTH 0 * .... + .... + .... + .... + .... + .... +-+--+ .... + .... + .... + .... + .... + .... + .... + · + ! !* + ! ! * + ! ! * + ! 1000 + * + + ! * + ! ! * + ! ! * + 2000 + * + + 3000 + * + + ! · + ! ! . + ! ! * + ! * + ! 4000 + * + ! ! ! ! ! !' 5000 + + ! ! ! ! ! 6000 + '+ ! ! ! ! ! ! 7000 + + ! ! ,1 8000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... +----+ .... + .... + 0 2000 4000 6000 8000 10000 12000 14000 COLLAPSE DESIGN LINE (PSI) * PIPE COLLAPSE (PSI) + f ECEIVED. '~'" 'RODUCTION CASING TENSION V~. DEPTH OPERATOR: STEWART PETROLEUM COMPANY DATE: 22-DEC-92 ?.~qSE: WEST M .cARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER SEC. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA PRODUCTION CASING TENSION VS. DEPTH 0 + .... + .... +---*+ .... + .... + .... + .... + .... + .... + .... + .... +---++ .... + .... + ~ * + ! ! * + ! ! * + ! ! * + ! 1000 + * + + ! * + ! ! * + ! ! . + ! ! * + ! 2000.+ * + + ! * + ! ! · + ! ! · + ! ! * + ! 3000 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 4000 + * + +' ! ! ! 1' ! 5000 + + 6000 + 7OO0 + + 8000 + .... + .... + .... + .... + .... + .... + .... + .... + .... + .... +---T+ .... + .... + .... + 0 100 200 300 400 500 600 700 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + RECEIVED' DEC 0 1 92 Alaska Oil & Gas COns, Commission Anchorage 500 1,000 1,500 - 2,000 - ,., 2,500 - ~ 3,000 - 3,500 - 4,:000 - 4,500 - 5,000 - I I 0 2 ENSR CONSULTING & ENGINEERING DRAWING: TIME DRAWN: ABB C/SC: 1.0 DISK: D/515 DATE: 12/I 1/92 CHECK: JM LOG SET 9 5/8" CASING SET 7" CASING COMPLETE WELL I I I I I I I I I I 4 6 8 10 12 DAYS TIME vs. DEPTH PLOT IWEST McARTHUR RIVER UNIT NO. D1 WELL 14 RECEIVED DEC A/ask; flii-~ STEWART' WEST McARTHUR RIVER UNIT PROJECT 6597-005-400 OVERPRESSURED STRATA The potential for encountering overpressured strata in the West McArthur River Unit No. D1 well (subject well) is extremely Iow. The subject well will be a straight hole with a surface location 135 ft southeast of the West McArthur River Unit No. 1 (discovery well) surface location. No overpressured zones were encountered in the discovery well. Both wells will penetrate the same strata within 600 ft or less horizontal displacement to a depth of 2,000 ft. The discovery well was directionally drilled with a kickoff point of 500 ft TVD and the horizontal displacement in the discovery well is approximately 575 ft at a depth of 2,000 ft TVD. The attached plots of the vertical section and plan view for the two wellbores show the horizontal and vertical spacing of the two wells. Survey data for the 0 to 4,000 ft interval in the discovery well are also attached. Mud weights and bottomhole pressures for the 0 to 4,000 ft TVD (5129 ft MD) interval in the discovery well are presented in the attached mud re .c,.ap. The mud weight for this interval ranged from 8.5 to 9.9 ppg. The primary cause of the mud weight rising above 9.0 ppg in this interval was the accumulation of drilled solids in the mud while drilling 26" and 17.5" diameter hole. In addition to the data presented above, the Pan American West Foreland No. 2 well (1966) was drilled from a surface location approximately 985 ft southeast of the discovery well with no overpressured zones encountered. Similar mud weights below 10.0 ppg were maintained in the 0 to 4,000 ft TVD interval for this well. A mud logging unit will be on-site to continually monitor gas in the drilling fluid, collect and describe cuffings samples, and monitor ROP. A radio or intercom system will be availabe for communication between the mud loggers and the drilling floor in the event that abnormal drilling parameters are encountered. REEEIVED DEC ~ 0 1992~ Alas .Ifa Oil .& Gas Cons. Co~m'tss%0a STEW~rtT PETROLEUM C~uMPANy liarker Zden~f~catlon ltd N/S A) KB 0 ON B} TD 4000 0 N WMRU No. D! PLAN VIEW :CLOSURE ..... : 0 ft at Azimuth DECLINATION.: 22.B0 E SCALE ....... : ! inch: 50 feet DRAHN ....... : i2/29/92 0.00 Gceat Land Dieectional Deillin9 i75 i50 i25 75 50 ....... 25 0 25 50 <- NEST: EAST -> Gomm, ir~i.o.p 75 lO0 125 i50 i7§ HPANY WMRU No. D! VERTICAL SECTION Section mt: i35.00 TVD Scole.: ! inch = 6OO feet Dep Scale.: ! inch = 600 feet Oran .... · t2/29/92 VIEN Sreat Land Na~ke~ ~ffen~f~ca~lon ltd ~ SECTN ZNCL.Iq Al KB 0 0 0 0.00 BJ TD 4000 4000 0 O.O0 , , r I t.-',i74~NO 985! TVD RECEIVED DEC ,.,.,z 0 199~ Alaska Oil & 6as Cons. Gomm. JssioP ~Anchoq~ 0 3O0 60O gOO ........ Sect2Dn_ Departure ..... I~.m:~ Icl ~ wt st.3$ ~o: oT AN ~ lBO0 t,500 :l, GOO -..-::::-:_-.-.._ Iqagc..Or.bar/.:E_NC_p._._ A D['esser/Ha].:labur'ton Company STEWART PETROLEUM NEST MC ARTHUR RTVER -t/,~ DRZLLZN6 FLU'IDS RECAP OECE~BER J. 99 J. REEEiVED Opera,or : STENART PETROLEUM Field/APea : COOK INLET · DescPiption : SEC t6 TBN t4~ SM ~ ~ ~~ r~~~ Location : 51t Co~tPac~oP : GRACE CASING PROGRAM ~ PRESSURE SI~ ~ (~t] 9 iO ii ~ i7 fin] fin{ ao.ooo ~ L ~.ooo n~. -° .., I, tt~ i) I"/'r,,,L ii il O I I I r e.eoo ~: ~ ~. ,, Operator = STEWAR~ PETROLEUM Contra~or= G~ Description= SEC 16 T8N 14W SM Page= 1 Well N~o~ W MC ~ ~ Jl Field/~eaz C~K I~ Location= 511 Well: A3558 *Date 06/23/91 06/24/91 06/25/91 06/26/91 06/27/91 06/28/91 06/29/91 06/30/91 07/01/91 *~pth -ft 0 336 S00 ~2 ~853 22~S 2215 684 1355 *Da~s Sin~e Spud 1 2 3 4 5 6 7 8 9 *IUIEOLOGICAL PROPERTIES Mud Weight -ppg 8.5 9.8 8.9 9.1 9.4 9.4 9.6 9.5 9.4 Plastic ViBC -CpS 0 40 21 18 9 12 18 21 22 Yield Point -lb/100ft2 0 20 25 25 24 13 16 32 34 Zero Gel -lb/lOOft2 0 0 0 0 0 0 0 0 0 n-factor *** 0.7370 0.5425 0.50~5 0.3479 0.5656 0.6130 0.4815 0.4780 X -lb/100ft2-rpm^n *** 0.8966 2.0838 2.4201 4.5359 0.9929 1.0305 3.3999 3.6644 *FLOW DATA Flow~ate -gpm 0 527 611 529 529 529 529 594 594 Mis Flow Rate -gpm *** **. *** *** *** *** ... *** *** Max Flow Rate -gpm ''* *** 2339 2342 2436 1416 1574 5586 5873 Pump Presaure -psi 0 1100 1300 1500 1500 1500 1500 650 870 .; Ptunp -hhp *** 338 463 463 463 463 463 225 .302 *PRESSUAE LOSSES Drill String -psi *** *** 210 309 287 412 483 *** *** Bit -psi *** 720 1510 1150 1190 1190 1220 Annulus -pst *** *** 1 2 5 2 2 *** *** ·otal System -psi *** *** 1721 1461 1402 1604 '1705 *** *** · BIT HYDRAULICS Nozzles -1/32 inch / / 16/16/16 14/14/14 14/14/14 14/14/14 14/14/14 14/14/14 / / / / Hozzlos -1/32 inch / / / / / / / / / / / / / / / / / / Bit Pressure % *** 66 116 77 79 79 81 *** *** Bit -hhp *** 222 536 356 368 368 375 *** .*** Bit HSI (Index) *** 0.90 2.20 1.50 1.S0 1.S0 1.60 *** *** Jet Velocity -fps *** 28? 435 376 376 376 376 lmpa~ Force -lbs *** 767 1223 937 968 968 989 *** *** *DRILL COLLARSANNULUS Velocity -fpm *** *** 62 54 54 54 54 24 24 Critical Vel -fps *** *** 237 237 247 143 159 224 235 *DP, ILL PIPE ANNULUS Velocity -fpm *** *** 17 15 15 15 15 17 '17 Critical Vel -fpm *** *** 165 171 201 98 104 202 212 *HOLE CZ,Fd~NZNG Slip Velocity -fpm *** *** 38 36 28 65 52 26 Rising Velocity -fpm *** *** -21 -21 -13 -50 -38 -9 L:Lfting Capacity -t *** *** *** *** *** *** *** *** C~ttings Cone -% *** *** *** *** *** **. *** ... Penetration Rate -fph *** *** *** *** *** *** *** *** · *CASING SHOE PRESSURES ...................... ECD -PPg *** *** 8.9 9.1 9.4 9.4 9.6 9.5 BC~W~uttings -ppg *** *** *** *** *** *** *** *** *TOTAL DEPtH PRESSURES .................... ECD -ppg *** *** 8.9 9.1 9.5 9.4 9.6 9.5 ReD+Cuttings -ppg *** *** *** *** ... *** *** *** *M~DVOLUM~S 9.4 Drill string -bbl *** *** 5 11 22 28 28 11 13 ·otal Hole -bbl *** *** 200 373 585 ~~L ] ~"~ 927 883 M-I Drilling Fluids Co DRILLING FLUIDS Dm HANAGEHBF~ mT~a ...... ~2,o2/,3 .................................................................................. ............. .... Alaska Oil & Gas Cons. ~cliora~. Opezator : S~dAR~ PR~ROLEUH Contractor: GRACE Desc~£ption: SEC 16 TSN 14W ~ Pago~ 2 ~ell H~e: W HC ~~ ~1 Field/~ea: C~ ~ Loca~ion~ 511 Well~ A3558 *Da~e 07/02/91 07/03/92 07/04/91 07/05/91 07/06/91 07/07/91 07/08/91 07/09/91 07/10/91 *~h -~ 157~ 2036 2178 2215 2215 22~5 2215 2890 34~0 *Da~s S~nce Spud 10 1~ 12 13 ~4 15 16 17 18 *R.H~OLOGZCJZ,~RO~ZES .'qud #eight -PPg' 9.5 9.5 9.5 9.5 9.3 9.2 9.2 9.4 9.5 Plastic Viac -C~B 23 19 18 15 15 12 6 9 8 Y£eldPoint -lb/100ft2 39 24 28 18 9 2 12 12 23 Ze~o Gel -].b/100f~2 0 0 0 0 0 0 0 8 4 n-fac~co= 0.4552 0.5279 0.4764 0.5406 0.7004 0.8931 0.4150 0.7590 0.3744 · -lb/100ft2-z~m^n 4.6219 2.1170 3.0378 1.5117 0.4417 0.0859 1.6872 0.1713 3.1911 *FLOW DA2A ~1o~ Rate -gpm 594 594 653 594 0 0 0 582 582 Y,.in ~lo~Rate -g~:m *** *** **- *** *** *** 9-* 224 710 Hax Flow Rate -gpm 6513 4398 5142 3564 *** *** *** 1873 2500 Punp P=easu=e -psi 945 1000 1130 1300 0 0 0 1735 2000 Pump -hhp 327 347 431 451 *** *** *** 589 679 *PRBSSOR~ ~OSSES Dzill St=lng -psi *** *** *** *** *** *** *** 583 426 Bit -psi *** *** *** *** *** *** *** 1760 1650 Annulus -psi *** *** *** *** *** *** *** 7 0 TOt&l System -psi *** *** *** *** *** *** *** 2350 2084 *BZT HYDRA~LZCS Sozzles -1/32 inch / / / / / / / / / / / / / / 10/12/12 12/12/12 Eozzles -1/32 inch / / / / / / / / / / / / / / 12/ / 11/ / HAt P~OBBU~O % *** *** 9** *** *** *** *** 102 82 BAt -hhp w,, *** *** *** ,,, *** *** 598 559 Bit HS! (Xndex) *** *** *** *** *** *** *** 2.50 2.30 Jet Velocity -fps *** *** *** *** *** *** *** 458 440 Zmpa~tYo=ce -lbs *** *** *** *** *** *** *** 1296 .1260 *DRZLL COLLARS ANNULUS Velocity -fpm 24 24 26 24 *** *** *** 59 59 C=itic&l Vel -fpm 261 176 206 143 *** *** *** 189 253 *DR~LL PZPE Velocity -fpm 17 17 18 17 *** *** *** 16 16 C=itical Vel -fpm 237 157 186 126 *** *** *** 179 219 *HOT-WCLBAHXNG slip Velocity -fpm 20 37 30 48 *** *** *** 0 14 R~sing Velocity -f~m -3 -20 -11 -32 *** *** *** 16 2 Lifting Capacity -t *** *** *** **' *** *** *** 100 12 C~ttingB Conc -% *** *** *** *** *** *** *** 1.54 11.29 ?enetzation hte -fph *** 40.0 *** *** *** *** *** 43.0 38.0 *CASXEG SHOW PR~SSORRS ECO -ppg 9.5 9.5 9.5 9.5 *** *** *** 9.4 9.5 ECD+Cuttings -ppg *** *** *** *** *** *** *** 9.6 10.8 *~AL DEPTH PR~SSORBS BCD -ppg 9.5 9.5 9.5 9.5 *** *** *** 9.4 9.6 EC~Cutt£ng8 -p~g *** *** *** *** ,,, ,,, v., 9.6 10.8 *HODVOL~HRS D=£1Z St=Lng -bbl 17 25 28 28 28 28 28 40 49 Annulus -bbl 1010 1301 1391 1414 1414 1414 1414 2043 2185 Total Hole -bbl 1027 1326 1419 1442 1442 ~/- ~f~ ~ F~2003 2234 l'~ I--- ti"-/ %1 B""' I J M-Z D=tlling Fluids Co DRZLLXHG FLUZDS DATA HAHAGRHE~T S¥STEH 12/02/91 ................................................................................. ,~,~,-~,,,,~,,,~J~ ............ .. .... A~J~ 0ii & 6a$ Cons., ~m~|ss~ (. Opo~&~o~ z S~*WAR~ PETROLEUM Con~&c~o~z GRACX Desc~p~onz S~C 16 ~ON 14W SN P~got 3 *Da~e 07/11/91 07/32/9X 07/13/9~ 07/14/91 07/15/9~ 07/~6/9~ 07/17/91 07/38/92 07/19/91 *~h -~ 3750 4457 4794 5074 5559 5875 6029 6203 6203 *Da~s SSnce Spud l0 20 2~ 22 23 24 25 26 27 *RH~OLOG2CAL PROPBR~TBS )iud We£ght -ppg 9.5 9.5 9.9 9.6 9.7 9.7 9.6 9.6 9.7 Pl&st£c V4sc -cpa 11 11 14 14 8 6 7 10 7 Y4eld Po£nt -Zb/100ft2 9 8 12 16 19 18 18 20 17 Se~o Gel -1~/100~ct2 2 2 4 2 2 I I 2 1 n- f &c't.o.~ 0.6891 0.';199 0.7105 0.5850 0.4005 0.3344 0.3692 0.4406 0.3833 K -lb/100 ft2-gl=m'"n 0.3555 0.2800 0.3823 0.9957 2.5454 3.4145 2.9213 2.2689 2.5833 *FT.,OR' DATA Flow irate -gpm 582 559 559 529 529 529 529 529 0 N~n Flow RAte -gpm *** *** *** *** ... ... *** *** *** )tax YlowRAte -gL:m 1282 1211 1595 1764 2115 2082 2049 2142 *** Pump P=ezau=e -psi 1885 2350 2300 2275 2300 2300 2200 2300 0 Pump -hhp 640 766 750 733 710 710 710 710 *PRBSSURR LOSSHS D~£1l St~£ng -ps£ 647 661 B£t -pix 1650 1520 Annulus -ps£ 3 4 Total System -ps£ 2300 2185 *BXT HYDRAULICS 743 613 464 405 445 539 1580 1380 1390 1390 1380 1380 8 6 10 11 10 12 *** 2331 1999 1864 1806 1835 1931 *** Nozzles -1/32 inch 12/12/12 12/12/12 Nozzles -1/32 inch 11/ / 11/ / Bit P~ezsu~o % 87 65 Bit -hhp 559 496 Bit HZ! (Xndex) 2.30 2.10 ~et Velocity -fps 440 423 Zmp&ot Fosse -lbs 1260 1162 *DRILL COLLARSANNULUS 12/12/12 12/12/12 12/12/12 12/12/12 12/12/12 12/12/12 12/12/12 111 / 111 / 111 / 111 I 111 / 111 I 111 I' 69 58 60 60 60 60 *** 517 424 429 429 424 424 *** 2.20 1.80 1.80 1.80 1.80 1.80 423 400 400 400 400 400 *** 1211 1052 1063 1063 1052 1052 *** Velocity -fpm 59 57 C~itioal Vel -fpln 130 122 *DR/LLPZPE AHFdX,U~ .... 57 54 54 54 54 54 *** 161 178 214 211 207 217 Velocity -fpm 16 16 C~itical Vel -fpm 108 103 *HOX~CT, RA~ZNG 16 15 15 15 15 15 *** 239 140 179 178 172 177 slip Velocity -fpm 64 64 R/sing Velocity -fpm -48 -48 T-4fting Capacity -t **- *** Cuttings Cone -% *** *** 9ene~zation hte -£ph 19.0 39.0 *CASXNG SHOBPRBSSURBS 45 .45 31 35 38 32 *** -29 -30 -17 -20 -23 -17 *** *** *** *** *** *** *** *** *** *** 20.0 20.0 15o0 10.0 *** BCD -ppg 9.5 9 · 5 ECD+Cu~:t:ings -ppg *** *** · I~_AL DBPTH PRESSURES ........ BCD -~ 9.5 9.5 D~ill St~ing -bbl 55 68 74 79 87 93 96 99 99 JUmu~uz -i:d:)l 2278 2471 2563 2640 2772 2859 2902 2948 2948 Tot&l Hole -bbl 2333 2539 2637 2719 2859~..~ ~2E I V9~--~.[~' 3o47 3047 #-x D~illing Fluids co DRZLLZNG FLUZDS DATA ~ SYSTBIq 12/02/91 ............................................................................. J £n. JLL 2 .............. . .... Al ka 0il & Gas Cons. C0mmissi0a SHALLOW GAS SOURCES The potential for shallow gas in the West McArthur River Unit No. D1 well is considered to be extremely Iow. Much of the discussion in the previous section on Overpressured Strata is applicable to the absence of shallow gas in the Beluga and Tyonek formations which will be penetrated by this well. The attached mud log for the West McArthur River Unit No. 1 well shows that minimal gas was encountered in the 0 to 2,000 ft TVD interval. No ditch (total) gas was evident until 1,230 ft MD (1,220 ft TVD). The maximum ditch gas readings over the 0 to 2,000 ft TVD depth interval was 30 units (100 units = 2% CH4 in air) and these readings can be attributed to the presence of coal in the strata. The Pan American West Foreland No. 2 well (1966) was drilled from a surface location approximately 985 feet southeast of the West McArthur River Unit No. 1 well. Again, this well did not encounter any shallow gas conditions in the Beluga or Tyonek formations. RECEIVED o EC 3 0 1992 Alaska Oil & Gas Cons. Commission Anchorage~ Bakersfield. CA (805) 397-7472 Ventura. CA (805) 658-7708 Anchoraae. AK WELL LOGGING, INC. (.0~) 561-2474 ABBREVIATIONS MB NEWBIT MW MUD WEIGHT RRB ~aUNS/T VIS FUN,VEL v=cosm, CB ~e/r PV ;~s;= v=c~/~ W~ W/PER nAS CL ~PM CHLO~NE ~N CG CONNE~N e~s Rm MUO WOB WE~H~ ON B~ Rmf ;/~;~;; RPM ~TA~ R~/MIN ~T LO;eED 4~ER PP ~MP ~URE ~ffi LO~OEfl AFTER ;UWEW SPM S7~S/MIN NR ~ PR POOR RETURNS LC LOST C/Re CO ClRCULATEOUT DML Presentation Formation Log Drilling Dynamics Log COMPANY: STEWART PETROLEUM WEll... W.McArthur Riv. U. #1 FIELD: Wildcat REGION: West Forelands COORDINA~: 1861' EWL & 2871' NSL, Sec 16, TSN, R14W, SM ELEVATION: 163' K.B., 133.6' G.L. All depths are from K.B. · tate/Conntry: Upper Cook Inlet, AK. APl Index: Sped Date: 6-23-1991 Co.tra=tor: Grace Drilling Total Depth: 11,500' Rig/Type: #160 Logging Unit#: 8 Geologists: Mike Broderick Vaughan Williams EngJneer~: Mike Broderick Bill Gilmour Add. Pef~ons: Chris Roussell Scott Carney . r":'-i SAND ~ CLAYSTONE I'~ LIMESTONE ~ COAL I---I I~ SANDSTONE I---I CLAY ~ DOLOSTONE I-~ METAMORPHICS I---I ~ SHALE ~ CHERT E~ SILTSTONE [~ CONGLOMERATE ~-~ INTRUSIVES EPOCH WELL LOGGING, INC. Company: Stewmt_Peuoleom Well: W.M.R.U._#1 Location: West_FMelands Date: 6-23-1991 Page No.: 1 PENETRATION UTHOLO{]Y OIL TOTAL {]AS CHROMATO{]RAPHY REMARKS , O <1o khan® 100K) 200 ROP 0> E ~J'l'rIB~S S <0 Ditch ~,0> ¢10 ldmne 100K> ~ DEBCRI~ON H (ft41r) f PERCBi"rAeE O <10 Prouine 100K> MUD REPORT T (O.100) W c..O ............ ._.C~t. :roMe_ ....... 2=0? c10 Burma# IOOK> ' ~JRVEY DATA ;..10_0. .... _W..O_B ...... .0._> N s (%ME in Air) < 10 I)eatm,# IOOK> OTHER INFORMATION (Mbs) (ppm) .... i....i....i.....i.....i....i....i.....i....i .... ....... i.....i.....i.....i.....i.....i.....i...-.i.....i .... ....... ! ¥ I) .. .... ~....~....i.....~.....i....i....~.....~.....~ .... ::::::::::::::::::::::::::::::::::::::::::::..i..i..~ ........ ~.....i.....+.....~.....~.....i.....~.....~.....i ......... .....i....i....i.....i.....F...-."'....¥.i.....i ............. .:-: ................... : ......... !..i..i ........ i.....!.....i.....i.....i.....¥.i.....i.....i .... !..i.i.ii~....!..!.!!!~ ....... i..!!!i~.....i..!.!~ [~ ,~ n Alaska.Oil .& Gas. 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':" :'":' ii! ................................. .................................... :., !...i: i i-"";' 'T".""!"I ..... i'""i"'"~'""..:'""!'""i'""'..'"'"~'""~ D~ ................................ : iii, i i i i ; i ; ! i L!'-:-~"~ .~.0.~ :::::::::::::::::::::::::::::::::::::::::::::::::: ....... i'""F'"T'"'T'"'i'""F'"T"'"F'"~ ~"T"t"i h...F..~.....i.....i....i i i i 'A!~h,:~':-~ .... !': ......... · · : : : : : : BLK; SL SPONGY TO OOC BFfll.; DULL TO SB-- MAT~ _ LSTR; FISOROUS 'lEX; OCC GRDS FROM PEAT TO COAL; OCC FN SANDY. SURVE:Y O 64,5', 3.5 DEG, 50.0 AZI SAND = DOM CLR ,4- CLOUOY. COM GRY, DCC GRN; FN TO ¥ CR$ UP, GRDS TO CONGL; DO~ FRE:SH 8ROKE:N ~0 1~ SB~iO iDO~ ~ + F'SI~; C~'-'RSD BUT COM VARiaBLE IGRY META GRS; COld I~OTI~ -i. I-I~D IINCLS; {)CC CHLORI~ ALTS; TR EPIDOTE I1R CHTo DOLOST, IGN S~ ~ 706', 5.:3 DEG. ~2.~ AZI CLAY = ~l. INC$ IN BLUSH ~ CLY; OCC A~ CT'G~; SOFT; FN S~NDY; LO COH SOLUBI.[; NONCN,.C; TUFFACEOUS; NON $1LTSI'0Nr' = F1R~ OCCUR~E3qC.~ BI. UE ~rr; ST1CKY; V ARGIL; SML ~RND, MASS N~C; OCC IrNLY CARBONACIrOu~ TIJFF- SAND = INCSNGLY DK DUE: TO INCSD UTHIC FI~I~S; MED--DK GRY. BLK, Fq.--DK GRN, WHT, (::LR~ PL OR0; MED-INCSNGI.Y V CR~ UPPER; COM GRNDO TO 0RANUL~ CONGI4 ANG TO OCC Wi. RND; MOD SI=HE:R; CR$ IrRACllON B~ RNDD; ¥ PRt.Y SR1~; UNCONSL; OCC LT BLUSH GRY CLAY MATRX COATIN0~; E:Qt.tN. LITHIC~ AND QTZ 4- IrspR; DCRSD M~NrlC INCL~ OF' BIOTITE; ~NDT ld~TA CHT, GRN METASEDS; COM CHLORI'ZD; DCR~ £PIDOT~ AND QTZT. SURVEY O 855', 9.7 DEG, 5:3.5 CONGLOM~RAT~ =, DON DK GRY TO BIJ~, INC~ GRN, LESSE:R CLT 4- WHT; 2--$ MM; BIMOD~N. W/CRSR FRACTION E:XHEITINO INC~D ROUND- EDNES$ dc UTHIC COIdPOPte~T; F'NR FRACTN DISPLAYS $~ANGLRITY OF MORE QI'ZT~ COMP;, LO SPHE:R; COM e;MOOTH POLI~HE:D TEX; UN- CONSL; COM BLUSH, QRNSH GRY I't~rFACEOt, I$ CLAY MTRX; iNCSD GRN ME:TASE:D UTHICS BELOW 570', DDM N:q.4N~mc IdLTA DCRSD SIUC PLUTONIC RX$; DOR~D BLOT; RR HRNBLND. SURVEY ~ 917', 11.4. DEG 54.,9 AZI LIGNIT; =~ DK BRN BLK TO BI.K; MOD FIRM; PITHY TO BRITT; SML TO ME'D S2:D TO FLAKY OTGS; OCC ARGIL,; DUU. MAI'rE LSTR; F1BOROUS TO OCO SBOONCH TEX; TO CARBONACEOUS pDII~T. SURVEY ~ 94,7', 12.1 DL"G, 55.7 AZI TVD ~4,3.75', 27.92'N, 35.5:3'E CLAY = BECOMING 'ri.lICKER '4. GRAYER; MEO TO MEO OK ORY;, THK, 511FF LUMPY ODNSIS , ¥ PR SOLU; GD COHESION 4- ADHESION; POOR SOLUBIU'TY; ¥ FN SNDY 4- SILLY; DRY, OE- HYORATED TEX; NONCALC~ NONE:XPANOABI. E; OCC Y LT GRY TUFFACEOUS. ASHY NODUI.[S; INLY CARBONACEOUS. SURVEY ~ IOOB', 12.7 D~'G, 52.8 AZI SILTSTONE ,= 8FINSH GRY.' SOFT; SML SBRND TO SBFLKY CTGS; ¥ A/~GIL GRDNG TO SLTY MUDST; INLY SDY; OCC LAMS OF CARB ,MT'RL; DULL EARTNY f,.STR; F' GRITTY 'TEX; MOD SOL EASILY DISSOL,~flNG INTO MUD SYSTD4; NON-- Cad.GN~EOUS. CLAY ,,, Mr'D TO DARK ORYSN BRN; SFT; SU ~-IICK CONSISTENCY; MOO SOLUBIUTY; GO(X) COHF..SION .l- ADHESION; NONEXPANSIVE ~ff,IL='N RE:HYDRATE:D; SMOOTH TEX; WELL HYDRA'TED; DI~ilVE:D F'/DISINT 4- I,h'DR'TD MU~CKS; SU SILTY; NONCALC. SAND ~ LSE: IN SPLS, POSS ~ ABOVE: OR FROM SANDY MUDRX; DISSAGGRE:GATED; WHT, CLR, GRN, DK GRY. OOC LT ORY, BL.K; LOW MED TO ¥ CRS, DOM L.DW CR$; Y PRLY SRTO; SBII~NG TO ~ RNDD; DOM UIHICS W/INCR PORTION 01-Z OR QI'Zn'E, OCC F'SPR; TR LSE MICA; OCC CARB WOOD FRAGS. SURVL=Y ~ 112~,', 15.5 DE:O, 50 AZI LIGNITE: ,- GEN TR AMT~ IN EACH SPL; LOW-- GRAD~ GRDS TO CARB WOOD; BRNSH BLK TO VIT L.STR; SBBLKY TO SPUNTERY CTGS; DOC LAMS; TR V FNCY PYRITIC. SURVEY ~ 1159'. 16.2 DE(:], 50 AZI MW 9.1 VIS 70 PV 18 YP 2.5 GE]. 7/15 :e t~,. 17.~,., ~._~Tq'....i....~,,. SEC SS,,.~,SC, J4 ~... 'i ..... ..... ~ ..... . .:~..~~'..'-i~ :....i.. i.... ~" °'. ~..L... .......... 2,.:-_.'. ......... i .... GPM ............ '.. i.-...i .... _ "~?, '~. ........................... ,,J;.. 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[] .......... ;'"':'":"":'":""=' "~"i"~"i ..... i'""i ........ !'""i'""f'"'.!"'"i'""i ......... i" ' · ....... ...'- ...i ..... .-' .... ?:::'"=.'":.~.~!i!i:...:..~.~. ~ ~ ~: ~ ~:::i :~:: :~,~: -! i'!' ~.....i.....i .!. i., i.....~.....i...-.i ..... g..-'..-. -....~-....!..i~i..-. : ::::::::::::::::::::::::::::"T'['i ........~i'" i""T'"'[ .......... i'"'T'"T""! .......... i ..... +' ':"~'"i"~..-::'-' :ii:ii .............. ..:...:.~.~:...:. iii ~t~ i i i .. .. .................. ..=....=.....r. - '....:...L.L.! ....... i.....-'... ~ · eD',.: ~ ~ ~ :. .......... --....i.. ,,:::::::::::::::::::::::::::::::- '""'""".-i..i..i ........ i ......... ~.....i .......... i.....! .......... i .........:i..-.:;- .... - ...... ..~- ~l~ffi .......... ?". :'":" ili i ~ i ! i i i i~ i.' · !l-'"':::"t'i"~ ........ t"'"!' 't'"'!'""i"'"i'"".?'i'"~' "~" .. ' ':1 !' '" .... ....... ..... !DIll --- ' ..... : .... ! :--~ !I~:Z:::::'"'~'::"~:'"'~::':~::''''',!I .......... l....[.....!~.'..-.t .......... i.....i...J~ I i...~...j.. I.- _.'. · :'i. ' ~, .......... ._.-...s....-....-....::....:.. :....-."..i..i.. ;....i.....i....¢....~.....i.....i.....~.....~.....~ .... :. : . . ..... ...... ": ...... ......... !" ": : ' ,,.:.s. LSTR; CHALKY TED( IN PLACES; COM SBPI..NR SURVEY ~ 11gO', 17 DEG. 51 4, SILTSTON[ =: TR AMO4.JNTS; ME:D GRYSH BRN, YEI. SI.4 BRN F~CHS; SFT' TO fIRM; POORLY CONSOL.IDA'fED )AJSHY CTGS: -ql. Pt. ATY; DULL TO EARTHY; GEN MASSIVE, 0CC: DK GRY TO BLK W&¥Y LAMS; SLJ S~ND~, TIq MICA. SURV~"Y · 1220', 18,2 DEG, ..~2.'q AZI NOTE -- PERSISTE3~I' LRG CHUNKS OF WOODY ~ONACEOUS MA'TERkN. 4. I. OIN--GRD UGN. NOTE -- INCR COM GRN ~ASIVELY CHLOR-- ITIC CLAY, SILTST, .4- MUDST, COM CHI. OR . FLAKt:'q; INCR TR .dddT MUDSTON£. SURVEY · 127ff** 1g.4 DEG, -54..6 AZI SAND =: SALT .&' PEPfJER, GRAINS ARE WHf1E, O~NG--RED, YEL, BRN; LOW' CRS TO GRAN COld PBLS; SBANG TO WELL RND, OCC UNCONSOL; DOM UTHICS, ESP META--AROIL OCC: OTHER M£TA RX, .4~JO PLUTONICSo ML:"rA RX BETTER RNDD 4. COld POLISHED, 1R HARD SED RX, RR JASPER; TR MICA. SURVEY · 1.3OB', 20.'7 DEG, 52.fl AZI CARBIDE ~ 1B.O MIN · 1286°, 15 UMTS SFId 1~1.4-2=9Z, g2~ TH£OR,14 MIN DURAl'iON NOTE; CARBIDE INC)JCA'T~S MUD CHANNELING WHILE SLIDING ~ MUO MOTOR. SURVEY · 13~', Zl.g DF.G, ..~2.2 AZI TVD 131fq79', 94..3g'N) 121.AB'E CLAY :m M£D GRY; SOFT TO FIRM; S'11CKY, PAS'rYo LUMPY CONSIS; GD COHE:S 4. ADHE:S; POORLY SOLU; SANDY, SILTY; COM PROB 11.JFF; NONCALC; SL E:XPANI:M~LE; COM CARB MTRL; DOM DERIVED FROM SOFT, SOLUBLE SLTST 4. CLYST, SAND = CLR, WHT, pi GRN, LT GRY, BI.K; UP F TO V CRS UP GRDNG TO GRANULAR CONG BIMOI:Md** F FRACTN DOM Q'IZ 4- FSI=R, SBANG TO SBRND, GRdd~ FRACTN DOM RND TO SBRND UTHICS; PRLY SRTD; UNCONSL; ASSDO W/ LT M£D GRY CLY MTRX; ABND CARBNZ WOOD FRAb"$ 4. LIGNITE; 65X QTZ 4- FSPR, 35~ LITHICS OF META ARQILT, CHT 4. 10N; SURVEY · 14.5~', 24,1 DEG, E)1.4 AZI LIGNITE m DK BRNSH BLK TO BLK; SOFT' PITHY' TO FIRM 4- SL BRn'F; OCC MUSHY Flq SOY IN PA,qT'; DULL. Id~TT£ L.STR; FLKY, FIBOROUS 1KX; DOM CARB WOODY MTRL OC::C GRDNG TO LO GRADE UGHITE. SURVEY' · 14,B?', 2S.4 DF.G, 51,4. AZ! 1VO 14S5.54', 131.lB'N, 168.77'£ SAND = CLR, CLOUDY, WHT, OCC Pt. ORN, RDSH ORG 4. BI.K; DCRSD OR SZ 4. U'rHIC COMPONENT; FN TO LO CRS, DM UP ME:D; Si~id~G; FNR SRI'D; ENTIRELY UNCONSL; DCRSD CLY M'rx; IMMd~TUR£; DOM QTZ 4- FSPR iOCC CHLORTC AL.TS; $CT'/RD RDSH IGN GRS .OCC BLK META AROLT; FIRST SIG.CLR AUTH MICA; ~D UONITE~, IN)SS SLOUGH; TR MOD YELSH BRN · SIL'TSTON£ m L'r MED ORY TO BRNSH GRY; V SOFT TO SL RRM; V AJ:IGIL; FI't SDY; GRDS COM FR CARB MTRI.; OCC LNdD; DUU. LSTR; FN GRITTY TEX; NO OIL .INDICATORS. SURVEY · 1578', 27..3 DEG. 5.3.9 AZI I~D 1537.1S', 155.4-5'N, 11.JFFACEOus CLAYSTON£ u~ LT G'Y TO LT BL).J-- SH GRY; BOblNQ SL FRId TO DOId SOFT; SBRND STRUCTURE:].E:$S CTOS; DLJLL £RTHY TO SL SBRESINOUS LSTR; OCC SE~"~ILE:; SIL'rY GRDNG TO AROIL SL'tS'I'; NONCdN. C; SL ~XP~J~)Aat,~; POSS MIGtaC.,q OCC MIGRO C,A~B. SURVEY · 164(3', 20,4 DE:G, -54.;2. AZI TVD 1.501.73'. 172.75'N, 224..05'E: CLAY. = MED Gl[Y; SOFT; MOD THICK EVEN CONSIS; FAIR DOHES 4- ADHES; INCSD SOLU; SANDY; V SILTY; Di:'RNED FRObl SOLU SLTST CLAYST; NCX~IGAd.C; NONEXFAd~ISIVE; ScA'r'r. CARBONACEOUS Id~T£RIAL MW 9,3 VlS 6-5 SURYEY · 1700% 31..q DEG, 52.5 AZI SURVEY · 17.31 ', 32.4 DEG, -5.3.2 AZI LIGNITE m GRADES W/CARBONIZED WOO0; DK 8RN TO BRNSH BI.K; F1RM; BR'/L,; Fq, ATY TO IRR£G 4- SPUN'rElY CTGS; DULL TO GRF-ASY SURFACES, OCC W/FN"r ORNG 0XIDA'llON; 'TR 'SUBVITREOUS W/SUBCONCH011::)AL FRACTURE:. WOI~ 2l~-30KIbl ~ "P 1600 .GPM_ 520 : Note: ROP ~/r uurf~e ~ v./ · . . · · . · "i'- i.~ Mu<~'~,r · PP 17-2000 i i ...... · · · . ~ . : .. · ...... .o · 'OOO o.6 1'.2 1~:6 O.d, 0,8 1,2 I P: ,..[ .... Ditch..Ga..gn..l~......i.....~ ..... 0.4 0.8 1.2 1~6 ..... .w. 9 3pu ....... ...~.:..i~....:.-.~.i.~ · "!'..." ~'"'J":':."i ....... · 'T!i~'"T'~'i'~':-" ....... ....... · ........ :: ::::1 ..... ....... ....... :: :::1: · "i'fi~ ......... · :: ....... :: ::::: ....... :: :::1: ....... ....... ....... ~ ~ L.'[:: :: . =: ::..:: ..... [: ......... ......... i'!'.-' i'i::-.' ....... ::: : 'il.":: · .... :: : .. ... i.ii'.: :: .. .. [. · .lOOKt !iii[', S~EOUS W/SU~ONCHOID~ ~TURE. SU~ ~ 17~', ~3.1 ~ 16~.73', 211.OS'N, 275.33~ ~L~[ - v ~E~ ~DS w~ M~; W~ ~ LT ~; RRM; ~; ~N M~, ~ ~N ~ W~ C~; ~ ~ ~; ~N BLK ~ ~. ~ K ~, SU B~ ~; MU~ ~ ~ ~ ~ ~ ~LY M~ ~T OR~--BRN 0~ R~N~; SU~ e 18~', 3S.g ~D~ ~ 26.B MIN · 1B3B', I? U~ S~ ~1+2~g2, 71~ THE~,11 MIN ~ -- ~D ~HMN~ SU~ ~ 18~', 3~g DEG, 52.8 SU~ M 191~', 36.6 ~ND ~ S~P ~ G~, CLR, MNR ~, ~ V CRS, ~ FN -- PO5~ ~E R~ THRU MIN~ ~; INCR ~ L~I~; ~ M~, PROB F~ ~L~ S~T U~, ~ ~RK~ ~ ~ A C~~ ~ ~D~ ~ OIL IN~R5. 5U~ I 1947', 37.2 SU~ I le78', 37.5 MW 9.~ ~S 4~ ~ g ~ 24 ~L 5/15 18 pH 8.0 Cl 2~ CH~ U~ C~, ~, ~ ~, ~, ET G~ ~ R~, Y~= UP ~S THRU SHK~; ~ S~ND; ~ ~ ~ SIL~NE m LT ~ ~ ~D ~H ~N~ V ~N D~; ~O WA~R ~ ~M TUFF- ~C THIN ~RB CLR SU~ ~ ~1'. ~.6 D~. S~.2 ~ND = WH, M~ ~ DK ~. ~ ~ ~ ~N.' RED~ ~G. ~N; ~D ~ V ~ ~R, ~ ~ ~ 3 MM; RN~ g~ ~N. S~; ~SR L~, SB~ ~ EN~ FRLY MTRX ~RL; H~LY ENCED ~ SD C~N~ O~ + ~PR ~ L~CS COMP~5~ L~E = DK B~SH B~ P~Y ~ ~ RRM ~ ~ ~; H~Y TO C~T~GS OF ~ ~ TO TR ~ G~ SU~ ~ N~ -- ~ E--~5. OPEN H~ TO 2~". RUN 20" C~ ~ 221~'. N~ - A~D ~ENT ~M~ ~. ~, ~E C~--~ M~. ~D = WH, M~ ~ DK BEN) ~E ~; R~ ~ V G~ ~R, S~, C~ ~ GREAT LAND DIRECTIONAL DRILLING, INC. · 'REPORT OF SUB-SURFACE DIRECTIONAL SURVEY mmmm~mm~~mmmmmmmmmm~mm~--~~- STEWART PETROLEUM COMPANY COMPANY WEST MCARTHUR RIVER UNIT #1 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm WELL NAME '" WEST MCARTHUR RIVER UNIT f...,"' .~%~ ,mmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmm -~','~"' LOCATION , ... '~. AL691D29 MWD 11/22/91 mmmmmmmmmmmmmmmmmm JOB NUMBER TYPE SURVEY DATE DIRECTIONAL _ ,,~ , GARY PAUL SUPERVISOR .~_w3~.~.~~r~,~'"/~f"'-'w.~. ................................... · -~= ~.i'-~-?-~_~~- - NAME TITLE SIGNATURE RE'EEIVED DEC 5 0 199 Alaska Oil & ~as Cons. Comm'~ss~O~ Anchorage ' 314 FT. 13672 FT. DEPTH INTERVAL FROM TO 06/2 /91 11/17/91 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULU YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT ~AND DIRECTIONAL DRILLING, client .... : Field ..... : Well ...... : Section at: Engineer..: STEWART PETROLEUM CO. WEST MCARTHUR N,60.83,E GARY PAUL INC. · RECORD OF SURVEY Computation...: Survey Date...: RKB Elevation.: Reference ..... : Magnetic Dcln.: , 11/21/91 RADIUS OF CURVATURE 11/17/91 163.00 ft 24.00 E S MEAS INCLN C DEPTH ANGLE i 314 0.25 1 487 0.25 3 496 0.10 3 527 0.50 3 557 1.00 VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 314.0 151.0 487.0 324.0 496.0 333.0 527.0 364.0 557.0 394.0 3 587 1.60 587.0 424.0 3 615 2.40 615.'0 452.0 3 645 3.50 644.9 481.9 3 676 4.30 675.9 512.9 3 706 5.30 705.8 542.8 -o.4 N -o.4 N -0.4 N 56.70 -0.2 N 26.80 0.1 N 50.40 0.-8 N 47.90 E 1.8 N 51.10 E 3.3 N 50.00 E 5.4 N 53.50 E 7.9 N 52.80 E RELATIVE-COORDINATES FROM-WELL-HEAD 0.3N 0.6W 0.9N 0.gw 0.9N 0.gw 1.1N 0.gw 1.4N 0.6W 1.8N 0.1W 2.5N 0.7E 3.4N 1.8E 4.7N 3.5E 6.3N 5.5E CLOSURE DL DISTNCE BEARING / 100 0.7 N 66.00 W 0.08 1.3 N 45.85 W 0.00 1.3 N 44.81 W 1.67 1.4 N 38.36 W 1.29 1.5 N 23.76 W 1.67 1.8 N 2.91 W 2.00 2.5 N 14.81 E 2.86 3.9 N 28.17 E 3.67 5.9 N 36.40 E 2.58 8.3 N 41.38 E 3.33 3 736 6.20 735.6 572.6 3 766 7.20 765.4 602.4 3 796 8.00 795.1 632.1 3 826 9.00 824.8 661.8 3 855 9.70 853.4 690.4 10.8 N 52.10 E 14.3 N 52.10 E 18.2 N 53.20 E 22.6 N 52.50 E 27.3 N 53.50 E 8.1N 7.9 E 10.2 N 10.7 E 12.6 N 13.8 E 15.3 N 17.3 E 18.2 N 21.1 E 11.3 N 44.31 E 3.00~_, 14.8 N 46.15 E 3.31 18.7 N 47.52 E 2.67 23.1 N 48.54 E 3.33 27.8 N 49.30 E 2.42 3 886 10.50 883.9 720.9 3 917 11.40 914.4 751.4 3 947 12.10 943.7 780.7 3 977 12.30 973.1 810.1 3 1008 12.70 1003.3 840.3 32.7 N 56.00 E 3.8.5 N 54.90 E- 44.6 N 56.70 E 50.9 N 54.90 E 57.6 N 52.80 E 21.3 N 25.5 E 24.6 N 30.4 E 28.1 N 35.4 E 31.6 N 40.7 E 35.6 N 46.1 E 33.3 N 50.19 E 2.59 39.1 N 50.98 E 2.91 45.2 N 51.63 E 2.35 51.5 N 52.14 E 0.72 58.2 N 52.34 E 1.33 3 1038 13.30 1032.6 869.6 64.3 N 51.80 E 39.7 N 51.4 E 65.0 N 52.33 E 2.01 ^Survey Codes: 1/SINGLE SHOT 3/MWD (WMRU1D BI. 24.) #1 S MEAS INCLN C DEPTH ANGLE 3 1067 14.20 3 1098 14.80 3 1128 15.50 3 1159- 16.20 3 1190 17.00 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY Page 2 11/21/91 SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 , 1060.7 897.7 71.1 N 50.70 E 44.0 N 56.8 E 71.9 N 52.23 E 3.11 1090.7 927.7 78.7 N 50.70 E 48.9 N 62.8 E 79.6 N 52.08 E 1.9~-~- 1119.7 956.7 86.4 N 50.00 E 53.9 N 68.9 E 87.5 N 51.93 E 2.34 1149.5 986.5 94.7 N 50.00 E 59.4 N 75.3 E 95.9 N 51.76 E 2.26 1179.2 1016.2 103~5 N 51.40 E 65.0 N 82.2 E 104.8 N 51.67 E 2.61 3 1220 18.20 1207.8 104.4.8 112.4 N 52.50 E 70.6 N 89.3 E 113.9 N 51.69 E 4.02 3 1250 19.30 1236.2 1073.2 122.0 N 53.50 E 76.4 N 97.0 E 123.5 N 51.79 E 3.68 3 1278 19.40 1262.6 1099.6 131.2 N 54.60 E 81.8 N 104.6 E 132.8 N 51.95 E 0.56 3 1308 20.70 1290.8 1127.8 141.4 N 52.80 E 87.9 N 112.8 E 143.1 N 52.08 E 4.40 3 1338 21.90 1318.8 1155.8 152.2 N 51.80 E 94.6 N 121.5 E 154.0 N 52.09 E 4.03 3 1367 22.50 1345.6 1182.6 '163.D N 51.80 E 101.4 N 130.1 E 164.9 N 52.07 E 2.07 3 1396 23.10 1372.4 1209.4 174.1 N 51.10 E 108.4 N 138.9 E 176.1 N 52.03 E 2.10 3 1425 23.40 1399.0 1236.0 185.4 N 51.40 E 115.5 N 147.8 E 187.6 N 51.98 E 1.05 3 1455 24.10 1426.5 1263.5 197.3 N 51.40 E 123.1 N 157.2 E 199.7 N 51.95 E 2.33 3 1487 25.40 1455.5 1292.5- 210.5 N 51.40 E 131.4 N 167.7 E 213.1 N 51.91 E 4.06 3 1518 25.80 1483.5 1320.5 223.7 N 52.50 E 139.7 N 178.3 E 226.5 N 51.92 E 1.45 3 1548 26.60 1510.4 1347.4 236.9 N 53.50 E 147.7 N 188.8 E 239.7 N 51.98 E 2.7~~-' 3 1578 27.30 1537.1 1374.1 250.3 N 53.90 E 155.7 N 199.8 E 253.3 N 52.07 E 2.35 3 1609 28.30 1564.6 1401.6 264.7 N 53.90 E 164.2 N 211.5 E 267.8 N 52.17 E 3.23 3 1640 29.40 1591.7 1428.7 279.5 N 54.20 E' 173.0 N 223.6 E 282.7 N 52.27 E 3.56 16~0 30.20 1617.8 1454.8 294.3 N 53.50 E 181.8 N 235.6 E 297.6 N 52.35 E 2.73 1700 31.50 1643.5 1480.5 309.6 N 52.50 E 191.1 N 247.9 E 313.0 N 52.38 E 4.43 · 1731 32.40 1669.8 1506.8 325.8 N 53.20 E 201.0 N 261.0 E 329.4 N 52.40 E 2.97 1763 33.10 1696.7 1533.7 343.0 N 53.50 E 211.3 N 274.9 E 346.7 N 52.45 E 2.21 1791 34.00 1720.1 1557.1 358.3 N 52.80 E 220.6 N 287.3 E 362.2 N 52.48 E 3.31 3 1824 34.40 1747.4 1584.4 376.7 N 53.20 E 231.7 N 302.1 E 380.7 N 52.50 E 1.27 ^Survey Codes: 3/MWD S MEAS INCLN C DEPTH ANGLE 3 1855 35.20 3 1885 35.90 3 1916 36.60 3 1947 37.20 3 1978 37.90 3 2009 38.40 3 2040 38.80 3 2071 39.60 3 2102 40.60 3 2165 42.80 3 2239 45.00 3 2302 45.40 3 2363 45.80 3 2429 46.20 3 2517 46.50 3 2610 46.70 3 2702 47.10 I 2849 48.00 3 3041 49.80 3 3132 50.00 3 3195 49.70 3 3286 49.7O 3 3379 49.60 3 3473 49.60 3 3565 49.30 3 3657 49 ^Survey Codes VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 1772.8 1609.8 394.2 1797.2 1634.2 411.5 1822.2 1659.2 429.7 1.847.0 1684.0 448.2 1871.6 1708.6 466.9 1896.0 1733.0 485.9 1920.2 1757.2 505.1 1944.2 1781.2 524.6 1967.9 1804.9 544.4 2015.0 1852.0 586.1 2068.3 1905.3 637.,2 2112.7 1949.7 681.7 2155.3 1992.3 725.1 2201.2 2038.2 772.4 2261.9 2098.9 835.8 2325.8 2162.8 903.1 2388.7 2225.7 970.1 2487.'9 2324.9 1078.2 2614.1 2451.1 1222.3 2672.7 2509.7 1291.7 2713.4' 2550.4 1339.7 2772.2 2609.2 1408.8 2832.4 2669.4 1479.5 2893.4 2730.4 1550.8 2953.2 2790.2 1620.5 .00 3013.3 2850.3 RECORD OF SURVEY : 1/SINGLE SHOT 3/MWD 1690.0 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 53.50 E 242.3 N 316.3 E N 52.80' E 252.8 N 330.2 E N 53 . 50 E 263.8 N 344.9 E N 53.90 E 274.8 N 359.9 E N 53.50 E 286.0 N 375.1 E N 53.90 E 297.3 N 390.5 E N 54.20 E 308.7 N 406.2 E N 54.20 E 320.1 N 422 . 1 E N 54.60 E 331.7 N 438.3 E N 55.30 E 355.8 N 472.6 E N 54.90 E 385.2 N 514.7 E N 55.60 E 410.6 N 551.4 E N 55.60 E 435.3 N 587.4 E N 56.00 E 461.9 N 626.7 E N 55.60 E 497.7 N 679.3 E N 56.70 E 535.4 N 735.5 E N 56.00 E 572.6 N 791.4 E N 56.00 E 633.3 N 881.3 E N 56.00 E 714.2 N 1001.2 E N 56.00 E 753.1 N 1058.9 E N 56.00 E 780.0 N 1098.9 E N 55.60 E 819.0 N 1156.3 E N 56.70 E 858.5 N 1215.1 E N 56.30 E 898.0 N 1274.8 E N 56.70 E 936.6 N 1333.1 E N 56.70 E 974.8 N 1391.3 E Page 3 11/21/91 --- CLOSURE DISTNCE BEARING 398.4 N 52.54 E 415.9 N 52.57 E 434.2 N 52.59 E 452.8 N 52.64 E 471.7 N 52.68 E /1oo 2.60 2.4b 1.99 2.31 490.8 N 52.72 E 1.69 510.2 N 52.77 E 1.35 529.7 N 52.82 E 2.58 549.7 N 52.88 E 3.27 591.6 N 53.03 E 3.53 642.9 N 53.19 E 687.5 N 53.33 E 731.1 N 53.46 E 778.5 N 53.60 E 842.2 N 53.77 E 909.7 N 53.95 E 976.8 N 54.11 E 1085.2 N 54.30 E 1229.8 N 54.50 E 1299.4 N 54.58 E 1347.6 N 54.63 E 1416.9 N 54.69 E 1487.8 N 54.76 E 1559.4 N 54.84' E 1629.2 N 54.91 E 1698.8 N 54.98 E 2.99 0.85 0.66 0.68 0.42 0.66 0.6t~''-'~ 0.61 0.94 0.22 0.48 0.26 0.69 0.25 0.41 0.33 #1 MEAS INCLN DEPTH ANGLE 3749 49.30 3841 48.80 3935 48.60 4026 48.60 4118 48.40 VERTICAL-DEPTHS SECTION BKB SUB-SEA DISTNCE 3073.5 2910.5 1759.4 3133.8 2970.8 1828.7 3195.9 3032.9 1899.2 3256.0 3093.0 1967.3 3317.0 3154.0 2036.1 4210 48.30 4302 48.10 4393 48.10 4486 47.90 4578 47.50 3378.1 321.5.1 2104.8 3439.5 3276.5 2173.3 3500.2 3337.2 2240.9 3562.5 3399.5 2310.0 3624.4 3461.4 2378.0 3 4669 47.70 3 4763 47.20 3 4857 46.80 3 '4949 46.40 3 5038 46.60 3685.7 3522.7 2445.1 3749.3 3586.3 2514.2 3813.4 3650.4 2582.8 3876.6 3713.6 2649.6 3937.9 3774.9- 2714.1 3 5129 46.90 3 5221 47.00 3 5316 47.40 3 5406 48.00 3 5499 48.30 4000.2 3837.2 2780.3 4063.0 3900.0 2847.5 4127.6 3964.6 2917.2 4188.2 4025.2 2983.7 4250.2 4087.2 3053.0 3 5590 48.00 3 5683 48.00 3 5776 48.80 3 5867 49.80 3 5897 50.20 4310.9 4147.9 3120.7 4373.1 4210.1 3189.8 4434.9 4271.9 3259.3 4494.2 4331.2 3328.2 4513.5 4350.5 3351.2 3 5928 50.40 4533.3 ~Survey Codes: 3/MWI~" 4370.3 3375.0 RECORD OF SURVEY DIRECTION BEARING N 57.40 E N 57.00 E N 57.00 E N 57.80 E N 57.80 E N 57.90 E N 58.10 E N 58.10 E N 58.10 E N 58.10 E N 58.10 E N 57.00 E N 57.80 E N 58.10 E N 58.80 E N 58.50 E N 58.80 E N 59.50 E N 59.20 E N 59.20 E N 58.80 E N 58.50 E N 58.50 E N 58.10 E N 58.50-E N 58.50 E . RELATIVE-COORDINATES FROM-WELL-HEAD 1012.6 N 1449.7 E 1050.3 N 1508.1 E 1088.7 N 1567.3 E 1125.5 N 1624.8 E 1162.2 N 1683.1 E 1198.8 N 1741.3 E 1235.2 N 1799.5 E 1271.0 N 1857.0 E 1307.5 N 1915.7 E 1343.4 N 1973 . 4 E Page 4 CLOSURE DISTNCE BEARING 1768.3 N 55.06 E 1837.8 N 55.15 E 1908.4 N 55.21 E 1976.6 N 55.29 E 2045.4 N 55.37 E 11/21/91 2114.1 N 55.45 2182.6 N 55.53 2250.3 N 55.61 2319.3 N 55.69 2387.3 N 55.75 1378.9 N 2030.5 E 2454.5 N 55.82 E 1416.1 N 2088.9 E 2523.7 N 55.87 E 1453.1 N 2146.8 E 2592.4 N 55.91 E 1488.6 N 2203.5 E 2659.2 N 55.96 E 1522.4 N 2258.5 E 2723.7 N 56.02 E 1556.9 N 2315.1 E 2789.9 N 56.08 1591.9 N 2372.5 E 2857.1 N 56.14 1627.6 N 2432.4 E 2926.7 N 56.21 1661.5 N 2489.6 E 2993.2 N 56.28 1697.0 N 2549.1 E 3062.3 N 56.35 DL /1oo 0.55 0. 0.21 0.49 0.22 0.12 0.25 0.00 0.22 0.43 0.22 0.82 0.62 0.47 0.47 0.37.,__,, 0.2~ 0.58 0.69 0.32 1865.0 N 2824.1 E 3384.4 N 56.56 E 0.65 1731.9 N 2607.2 E 3130.1 N 56.41 E 0.41 1767.9 N 2666.3 E 3199.1 N 56.45 E 0.18 1804.2 N 2725.6 E 3268.6 N 56.50 E 0.86 1840.5 N 2784.3 E 3337.6 N 56.53 E 1.13 1852.5 N 2803.8 E 3360.5 N 56.55 E 1.55 Stewart p oleum Company Denali Tb-w~rs North, Suite 1300 2550 Denali St~e-e't, Anchorage, Alaska 99503 (907) 277?4004 · FAX~_(907) 274-0424 December 29, 1992 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Mr. Dave Johnston, Commissioner Gentlemen: In response to facsimile instructions received 12/21/92 from Mr. Bob Crandall of your offices, Stewart Petroleum Company has initiated the following actions in order to complete the AOGCC requirements for issuance of our Statewide Drilling Bond in the amount of $200,000: 1. Stewart Petroleum Company has instructed Bank of America, Alaska, to issue the requested letter to AOGCC which guarantees availability of $200,000 in funds represented by two(2) $100,000 Certificates of Deposit previously submitted. 2. By Copy of this letter, Stewart Petroleum Company also instructs Bank of America, Alaska to reissue each Certificate of Deposit, at maturity date, to be made payable to "Alaska Oil & Gas Conservation Commission" only. Interest shall continue to accrue for the account of Stewart Petroleum for deposit under existing arrangements. Please note that Certificate 100018645 matures 1/2/93. Certificate 100025331 matures 6/2/93. We have recently made applicatioj~ with Corporate Sureties authorized to do business in Alaska for a Surety Bond in the amount of $200,000. Upon approval, we plan to submit such Surety Bond to AOGCC as substitute collateral and will request release at that time of the Certificates of Deposit discussed above. RECEIVED DEC ~ 0 1992 Alaska 0ii & (~as Cons. Commission Anchorage Page 2 Thank you for your assistance in these matters. cc: Mr. Duane Klein Bank of America, Alaska Sincerely, W.R. Stewart President RECEIVED DEC 5 0 1992 Alaska Oil & Gas Cons. CommiSSiOn Anchorage STEWART PETROLEUM COMPANY WEST MCARTHUR RIVER OPERATING ACCOUNT PH. 907-563-2830 3111 C STREET, SUITE 400 ANCHORAGE, AK 99508 SECURITY PACIFIC BANK 1655 PAY TO THE ORDER OF, "1 DOLLARS$ '100..00 ,. State of Alaska Department of Revenue ,'00 & ?-, 5 5,' m:].252006q].l:Oi, O01,62 RE'¢EIVED DEC ~ 0 1992 Alaslm.Oil & Gas Cons. Commissio~ Anchorage I ~.~JND flUMBER ~1/*11: U', ALASKA OIL AND GAS CONSERVATION COMMISSION' iI' BOND PENALSUM $ 200,000.00 KNOW ALL MEN BY THESE PRESENTS, That we,.....................................--.-..-.---.----.--------------'Stewart Petroleum Company .............................................................................................................................. of Alaska, as obligor of Anchorage Statl ............................................................................................ of the City ................................................................................. ~k/~~. a corporation organized under the laws ........................................................................... ~,. · · ··ee··· ·el eec · · ··ce · el e e· · ··· · ·· ·· ·· ···ce··· ce· e eee·e el eeeeeleleeeeelee~e .cell-· lee eeeeleeeee lee lei lee e- . . )~. the' State of Alaska and ' , ~ a~oH~ to do bminm in the State of Almka, ~ held -'": .... :" .... ': ..... :'"::':'":';::[;'~;;";~"~;'"~'~;~;~;~'"~mi.iQnA~~a~- - i~imt~. ,~, money of ~e Unit~ S,t--. for ~i~ p~yment. ~11 and ~uly to ~ m~e. ~,~ ~~ a~.~~ge~, ~~:~i~ - r ............ ~ _.:_. :_~._a~ firml- p. ~,. p~n, Tn~s ~n~ ~s secureo ny ~er~uu~ is~a[o~ o s~[~~,,~~-~~& l~9~'~n"~r "of ~f~'.by B~nk o~ ~r~c~, Alask. ~e ta~n~ the penal s~ indica=e~,cop~es O~ ~q~W" =~5 %~=~'~_T.~__~'iTi~i...i~,.,i.-W.:~/ .... ~...-- ~%~6. ~.~.n ~oro~ to e~ in ~ arming, pr~l~ a~ o~rlu~ o~ · ~,, u, ~,,, ,u. u,, a,,u,u. ~. '" ....... T~:.::: ."::;_ ..... ..... j..~ ;~hJc in'fo~itio- n- in a~ u~n ~e i,~s si~l~ wigan ~e S.te of Alaska, ~~~ or pro~ zo.arlll no~ Tut ~u.~ F v SINGLE WELL BOND~inimum mi sum $1~~ Unit or ~lM N~e I Well N~Mr ' kM of ~ I ,, ~~ Well L~ti~~., T~., Rng..nd M~. BLANKET BOND-minimum penll sum $200,000 Any and all wells drilled and operated by the principal in the State of Alaska. NOW, THEREFORE, the above bounden ~ ~rhail comply with all of the provisiom of the law~ of the Sta~e of Alaska end the rules, relulations and ordem of the Alaska Oil and Gas Comervation Commission, and file with the Alaska Oil and Gas Conservation Commiedon all notices and records required by said Commission. · This obligation ~hall remain in full force and effect until released by the Alaska Oil and Gas Conservation Commission at the request of'~z~ obligor. Witnm Our hands and sasls this tewar Company '/'4 92 ....... ...'~.......~J. ....... dw of December ,19 ............. 11~~1) .... i~.". .................... f.L; ............................................. .......................................... w.R. Stewart, President RECEIVED ............................ dmKak, .......................... ' ............. ,tS:x ......... d6tem~x ........................ : ................................................. : ....... Data: Approved: .................................................................................................................. Commissioner Approved: .......... ............................. ~;~i~'i'&'~'& ................................... Date: ..................... Date: Approved: ................................................................................................................... t'V Commiulonor O signatures) ALASKA OIL AND GAS CONSERVATION COMMISSION F~ 10.402 · R~. 7-140 DEC O' 1 92 co"o;cora sio- ' .ChLO. r_a q :..':; · . ''?' (Resident Agent, if necessary) Rebecca L. Stewart, Secretary lulmtit In dul)lk:su-ono foffn w!ll I)e r~urn~l · · · · . · iSECURITY PACIFIC BANK ALA,.,~.A SECURITY PACIFIC BANK ALASKA. N.A. ,.o. aox ~o~o~7 _ ANCHORAGE. AK 99510'7007 Anchorage Alaska, Jtlly 17 ' ~ ~D~D ~O~S~D ~D ~O ~S* AS DEPOSITED · S~~ ~O~ CO~Y~ EOR ~OGCC* 19 9____0 ACCOUNT NO. 100018645 ~, ~)2-O099169 DOLLARS~ S * 100,000 · 00' ... AYAI~%T~ ---~---'--'--"---1-C31:3~ This TimeCertificate°fDep°sitmaturesJ'anlaary 1_~_3,19 9~ YEAR. ILL ACCRUE A~ER ~E MA TaRt- his DAY _ MONTH PAYMENT AS IT IS NOT AUTOMATICALLY RENEWABLE AND NO IN,REST ~ CCESSIVE TERMS EACH EQUAL TO ~E ORIGINAL TERM, ] P~SENT THIS CERTIFICATE PROMPTLY AT MATURITY FOR ~ DA TE SHOWN. AUTOMATICALLY BE RENEWED FOR SU ~N A MATURffY DATE OR WITHIN TEN TY DATE STATED ABOVE, BUT WILL ONALLY PRESENTED FOR PAYMENT . TO ~DE~ THIS CER- ~ THIS CERTIFICATE MATUR~_9~ ~J] ...... DITIONS ~CURS' 11 THIS CER~[~.I~.~5~ .... T RITY DATE OF THE DEPOSIT0~ S INTENTION M THIS CER -- UNLESS AND p~TIL ONE OF 1,~ ~U~LM~';~"S WRITE" NOTICE FROM ~[~O~,.u, -= ..... 7~SITOR WRITTEN NOTICE OF I~S INTENTIg~_T~gE~__ beainni~ TIFICATE: al ~u. u~ -, .............. . " erest rote will DO the Same w, -.,=- · MATURITY DATE _ ~=~v ~ATE OF on the maturity ~a~e: T~ iht ........ inimum balance ~f any) end ot~[ featur~ a~ this TIFICATE ON A ' ACCRUE AT THE -~ ....... wnicn nave the se,m ~ ......... e and we will tel~ GU I ~E S T FIRST MATUR T ATE WILL matur~ da~ II us ~ or s~ly before the matunty dot ~E PAID AS INDICATED BELOW: METHOD FREQUENCY --] MONTHLY FQUARTERLY SEMI-ANNUALLY ANNUALLY AT MATURITY [] MAIL CHECK H OLD CHECK CAPITALIZE [] CREDIT ACCT. NO. Notify this institution immediately of any change in the above address. AUTHORIZED SIGNATURE NOTICE: See Other Side for Penalty on Payment of Time Deposit Before Maturity Bank of America Alaska, N.A. MAIN AK 001 Office PO B~,ex 107007, Anchorage AK 99510-7007 STEWART PETROSEUM COMPANY THIS CERTIFIES THAT *ONE HUNDRED THOUSAND DOLLARS NO/].O0* HAS DEPOSITED 100025331 ACCOUNT NO. DOLLARS, $ _ *100,000 · 00' PAYABLE To*STEWART PETROLEUM COMPANY, FOR AOGCC* This ~ DAY_ 12r'~H MONTH 92NDyEAR' , This Time Certificate of Deposit matures- JUNE 2'" 19 93. [] .PRESENT THIS CERTIFICATE PROMPTLY AT MATURITY FOR PAYMENT AS IT IS NOT AUTOMATICALLY RENEWABLE AND NO INTEREST WILL ACCRUE AFTER THE MATURI- u.g O?~ TIFICATE: 3) NOT LESS THAN 30 DAYS BEFORE A MATURITY DATE THIS INSTITUTION MAILS TO A DEPOSITOR WRITTEN NOTICE OF ITS INTENTION TO REDEEM THIS CER- AUTOMATIC RENEWALS: Each renewal term will be the same as the original term, beginning TIFICATE ON A MATURITY DATE. INT~I~ST TO FIRST MATURITY'~ _'~ WILL ACCRUE AT THE YEARLY RATE OF on the maturity date. The interest rate will be the same we offer on new certificates on the 3 , ..~ ..~ % USING A .-. --- DAY/YEAR. ACCRUED INTEREST WILL maturity date which have the same term, minimum balance (if any) and other features as this i inal certificate. You may call us on or shortly before the maturity date and we will tell you BE PAID AS INDICATED BELOW: ]. 80 DAYS ~, th, interest rate will be for,l~e ney, t renewal term. We.will~etpsylnterestafter thelast ~t'~r~t'~ da'te. If this certificate~JnQt ~l~t~m. atic_all¥~eweu / A .~ MONTHLY [] MAIL CHECK , QUARTERLY [] HOLD CHECK -- ~/'~" ~/ AUT//OR?Z.~D S,G,~U,E [ ANNUALLY [~CREDIT ACCT. NO. 1 7 0 01 1 13 5 Notify this institution immediately of any ch~ge in the above eddress. SEMI-ANNUALLY [] CAPITALIZE NOTICE: See Other Side for Penalty on Payment of Time Deposit Before Maturity [] AT MATURITY r~O~l David L. Baker Credit Analyst Bank of America Bank of America Business Banking Center, AK050 550 West Seventh Avenue, Suite 1700 Post Office Box 107007 Anchorage. Alaska 99510-7007 Telephone (907) 263-3273 FAX (907) 263-3272 ITEM C1) Fee (2) Loc APPROVE DATE '[2 thru . 3. 4 5 6. 7. 8. 9. CHECK LIST FOR NEW WELL PERMITS Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... .~ Is well located proper distance from other wells... Is sufficient undedicated acreage available in this pool (3) Admin [~)~ r ~ [9 tb u 13] [10 & 13] [14 thru 22] 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (5) BOPE ~i~/d~. )'~'~' [23 thru 28] (6) Other ~ 7J~. [29 thru 31'] (7) Contact ~ 1- I ~- ~) 2] (8) Add1 ~.W~, ).Z/--~'~ 9eol ogy' DWJ 29. 30. 31. 32. rev 12/92 jo/6.011 Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can pemit be approved before 15-day wait ............................ Lease & Wel 1 9 NO eng i neer i rig' MT~ RAD'])l'qd~ BEW . JDt-~I4 i;~-;~ LGU~-~, ~-~, t o 33. Does operator have a bond in Force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... ~__ Does well have a unique name & n~nber ................................ Is conductor st r ing prov i ded ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. /~ Is enough cement used to circulate on conductor & surface ............ ~ REMARKS Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................ Is a dJverter ~ystem required ........... Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of' diverter & BOPE attached, . Does BOPE have sufficient pressure rating -- test to ~,~,~,~,~,~,~,~,~,~'O~O psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHiC WELLS: ~ Are data presented on potential overpressure zones ................... /~ Are seismic analysis data presented on shallow gas zones ............. ~ If offshore loc, are survey results of seabed conditions presented... /~.~, Name and phone n~nber of contact to supply weekly progress data ...... /( Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE MERIDIAN' UM SM ~ ~ TYPE: Exp/Dev ~<~ Inj ..... Redr i 1 1 Rev Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well. Permitting Process but is part of the history' file. To improve {he readability of the Well History file and to . . simp!ify finding information, informati~)n of this '. nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically · organize this category of information. ALASKA COMPUTING CEN?ER ~ ~mmmmmm~mmmmm~mmm~mm~m~mmmmm~ ~mmm~m~m~mm~m~mmmmmmmmmmmmmmm~ F~ELD NA~E : WEST MCARTHUR RIVER BOROUGH : KENAI PENN. STATE : AbRSKA API NU~R : 50-133-20446 REF~eENC~ NO : 93086 ?ace verification Listing chlU~berger Alaska Computing Center 1-MA~-1993 11:58 SERVICE ~AME : G8764S DATF : 93/01/22 ORIGIN : CSU RFEI, NAME : 548876 CONTINUATION # : O0 PREVIOUS REEL : COM"ENT : SCHLtI~BERGER WELt SERVICES CSU TAPE **** TAPE HEADER **** SFRVICE NA~E : G87648 D~T~ : 93/0]/22 ORIGIW : CSU TAPE NAME : 54~876 CONTINUATION # : O0 PREVIOUS T~PE : COMMENT : SCHLUMBERGER WELL SERVICES CSU TAPE PAGE: **** FILE HEADER **** FILE NA~E : TOH ,005 SERVICE : tOG VERSIOn! : ]2,6 DATE : 93/01/22 ~AX R~C SIZE : 1024 FIL~ TYPE : PR bAST FILE ~ ** DATA FORMAT 8P'ECIFICATION RECORD ** ** 8ET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 2 66 3 4 66 5' 66 6 73 7 65 8 73 9 65 11 66 13 66 14 65 15 66 16 66 0 0 0 1. 1 I~CH 1 1 0 IS Tape Ver~ca~on blst~no c>l~mberqer Alaska Computing Cente~ PAGE: ,** SET TYPE - CHAN ** ID ORDER # LOG TYPE CLASS .~OD NUMB SAMP EbE,v, CODE (HEX) MS TON IN 07 282 01 0 5 ! 1 2 49 8000000000 TOD TON S 07 000 00 0 5 1 ! 4 73 8200000000 TIMF TOH MS 07 636 21 0 5 I I 4 68 8000000000 ETI~ TOH $ 07 636 21 0 5 ! 1 4 68 8000000000 CS TOH F/H~ 07 636 ~! 0 5 ! 1 2 49 8200000000 DIFF TOH F 07 636 21 0 5 1 1 4 68 8000020000 TENS TOH LBF 07 635 ~1 0 5 I 1 4 68 8000000000 MAR~ TON F 07 150 01 0 5 1 1 2 49 8000000000 I~V TOM F3 07 282 01 0 5 1 1 2 49 8400000000 ICV TOH F] 07 282 Ol 0 5 1 I 2 49 8400000000 RSH! TOR OH~ 07 250 O1 0 5 3 1 6 49 8000020000 RSh~ TON ORM~ 07 252 O1 0 5 3 1 6 49 8000020000 R~CA TOH IN 07 280 O! 0 5 ! 1 2 49 8000020000 SMLT TON 07 280 O0 0 5 I 1 2 79 8000020000 BMIN TOH OHMM 07 250 01 0 5 3 I 6 49 8400000000 B~NO TOH O~Mu 07 252 O1 0 5 3 1 6 49 8400000000 MCAL T0H IN 0~ 280 01 0 5 1 I 2 49 8400000000 RIRD TOH MM/M 07 000 00 0 5 1 I 4 68 8000000000 I~DZ TOH MM/~ 07 000 00 0 5 1 1 4 68 8000000000 IRDP TOM MM/M 07 000 O0 0 5 1 1 4 68 8000000000 IRD~ TOH M~/M 07 000 00 0 5 1 1 4 68 8000000000 RIXD T0H MM/M 07 000 00 0 5 1 I 4 68 8000000000 IXD~ TOM MM/M 07 000 00 0 5 1 1 4 68 8000000000 IXDP TOH ~M/M 07 000 O0 0 ~ ! 1 4 68 8000000000 IXDN TOH MM/M 07 000 O0 0 5 1 1 4 68 8000000000 RIRM TOR MM/M 07 000 O0 0 5 1 1 4 68 8000000000 IRMZ TOH M~tM 07 000 00 0 5 I 1 4 68 8000000000 IRMP TOH MM/M 07 000 00 0 5 '1 1. 4 68 8000000000 IRNN TOH ~M/M 07 000 00 0 5 ! 1 4 68 8000000000 R~X~ T0H MM/M 07 000 00 0 5 I 1 4 68 8000000000 IXMZ TOH MM/M 07 000 O0 0 5 I 1 4 68 8000000000 ~XNP TOM 'MM/M 07 000 00 0 5 I 1 4 68 8000000000 IXMN TOH MM/M 07 000 00 0 5 1 1 4 68 8000000000 DCID TO~ MM/M 07 000 00 0 $ 1 1 2 49 8000000000 DCIM TOH MM/M 07 000 00 0 5 1 I 2 49 8000000000 XDO~ TOH 07 000 00 0 5 I 1 2 49 8000000000 IMOF T0H 07 000 00 0 $ 1 1 2 49 8000000000 D~O~ TOH 07 000 00 0 5 1 1 2 49 8000000000 RSFV TOH NV 0~ 000 00 0 5 1 1 4 68 8000000000 SFVP TOH ~V 07 000 O0 0 5 1 I 4 68 8000000000 SFVZ T0H ~V 07 000 00 0 5 ! I 4 68 8000000000 RSFC TOH MA 07 000 O0 0 5 1 I 4 68 .8000000000 SFCP T0~ ~A 07 000 o0 0 5 1 1 4 68 8000000000 SFCZ T0~ MA 07 000 O0 0 5 ! ! 4 68 8000000000 DCSF TO~ M~/M 07 000 00 0 5 I 1 2 49 8000000000 SFQF TOH 07 000 00 0 5. 1 1 2 49 8000000000 RSFB TOH MA 07 000 O0 0 5 1 1 2 49 8000000000 SFBZ TOH MA 07 000 00 0 5 1 1 2 49 8000000000 SFBP TOH MA 07 000 00 0 5 ! 1 2 49 8000000000 R~FO TOM V 07 000 00 0 5 1 1 2 49 8000020000 IS ?ane Verification hist~ng chlumberger Alaska Comp~]tin~ Center PAGE: N RV U~!IT SERVICE APl AP1 APl A FILE gU NUMB S ZE REPR CE$6 ID ORDER # LOG TYPE CLASS MOD ~IU~B SAMP ELE~ CODE (HEX) ---------------------------------------------------------------------------------------~* Of ~0~ V O7 000 O0 0 5 1 1 2 49 80000~0000 RXFO TOH XFOC TOH V RSP~ TON NV SPAZ TOH NV SPAP TOH HV RIT~ TON DEGF D)H¥ TOH V FTV~ TO~ V FTVZ ?ON V RPSD TOM EPSD XPSD TON IPSO TOH 2IRP TOH [~DA TOH 2IXP TOH VODC TOH IWF! TOM IWF2 IND~ TOM SVT TOM 5VT TOH S2IV ~SVS DECS TOM DERS TOM IFRE TOM IFBA, TON CIDP TOM CI~P TOH II×D TOM IIRM ?0~ I'IX~ TO~ IXD TOM OHMM CILD TOM MM/M CI[,~ TOH IL~ TOH OH~ IL~ TOH DMR8 TOH ObRA TOH SFB TOH MA SFV TOH MV 07 000 O0 0 5 I 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 1 1 2 49 ~7 000 O0 0 5 1 1 ~ 49 07 000 O0 0 5 1 1 2 49 07 OOO O0 0 5 1 1 2 49 07 000 O0 0 5 ! 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 I 1 2 49 07 000 O0 0 5 ~ 1 2 49 07 000 O0 0 5 1 I 2 49 07 000 O0 0 5 I 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 I I 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 $ I 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 1 I 2 ~9 07 000 O0 0 5 1 1 2 49 07 000 O0 0 5 1 1 2 4.9 07 000 O0 0 5 I 1 2 49 07 000 O0 0 5 I I 2 49 07 000 O0 0 5 1 ! 2 79 07 000 O0 0 5 ! 1 2 79 07 000 O0 0 5 1 1 2 79 07 000 O0 0 5 1 1 2 79 07 000 O0 0 5 1 I 2 49 07 000 O0 0 5 i 1 2 49 07 110 46 0 5 1 I 2 49 07 110 4.4 0 5 1 1 2 49 07 120 46 0 5 I 1 2 49 0.7 120 44 0 5 1 I 2 49 07 000. O0 0 5 I i 2 49 07 000 O0 0 5 1. 1 2 49 07 000 O0 0 5 1 1 2 49 07 000 O0 0 '5 I 1. 2 49 07 120 46 0 5 1 I 2 49 07 120 44 0 5' 1 I 2' 49 07 1 10 .46 0 5 1 1 2 49 07 110 44 0 5 1 1 2 49 07 120 46 0 5 I 1 2 49 O? 120 44 0 5 I i 2 49 07 120 O0 0 5 1 I 2 49 07 935 04 0 5 I 1 2 49 07 000 O0 0 5 I I 2' 49 07 000 O0 0 5 I I 2 49 8O0OO2OO00 8000020000 80O00O00O0 SO00000000 8O0O0OO00O 80OO0O0OOO 80000~0000 SO00020000 8000000000 8000000000 8000020000 8000020O00 8000020000 8000020000 8000020000 8000020000 8OOOO2OOOO 8O0002OOOO 80OOO2OOOO SO00020000 8000020000 8000020000 8000020000 8000020000 8000020000 800002000'0 8000020000 8000020000 8000020000 8000000000 8000000000 8000000000 800000000O 8OOO0O0OOO 8000000000 80OO0O0O00 8OO0OOO0OO 8000000000 8OO0OO00O0 8000000000 8000000000 8000000000 8000000000 SO00000000 8000000000 8000000000 SO00000000 8000000000 8000000000 8000000000 IS Tane Verlf!cntion Listlnq chlumberqer AlasKa Computlnq Center 1-MAR-1993 11:58 IU ORDER CSFL ?OH CSF~ TOH SFLU TOH OH~ I~ ?OH D~GF I?T ?OH TTI TOH US T?2 TOH TT3 TOH A~PI, TOH NV CSL TO~ ~V TO ?OH ~V SRAT TOH TT TOH US CBSL TOH TTSL TOH US C~LF ?OH MV DT TOH ROR TOH GAP! ST~ ~OH HT~N TOH RHT~ TOH MRE$ ?OH OHM~ AMTE-TOH D~GF DTgN TOH DC/K c¢§w TOH ' HV ?OH V RSP TOH MV SPA T0H NV &PAR'TOH SPPV TOH MV $~ TOH MV Immmmmm#mmm,~m#~mmm~mmmmmm mmmmmmmmmmm APl AP1 A LOG TYPE CL ** DATA ** ** DEPTH = Ss.TO. C$.,TOH 3.15,000 IHV,TOH 0,000 RMC~oTOH 6,008 MCAL.,TOH 4.867 I~DN.TDH 186~'897 IXDN.TOH 196 ,345 07 000 OD 07 210 O1 07 210 O1 07 2~0 Ol 07 222 01 07 000 O0 07 529 82 07 522 83 07 522 83 o? 522 83 07 522 83 07 522 85 07 524 86 07 524 ~2 07 580 87 07 522 83 07 524 86 07 522 83 07 524 86 07 520 80 07 310 O1 07 310 Ol 07 000 O0 07 000 O0 07 000 00 07 000 00 07 000 00 07 000 00 07 000 00 07 660 21 07 000 O0 07 000 O0 07 OlO O1 07 010 ., 07 010 01. O? 010..01. 1464,500 FEET TODTOH ICV,TOH SNLT.,TOH RIRD.TOM RIXD.TOH. RIR. M.TOM 0 5 I t 2 49 8000000000 0 5 1 1 2 49 8000000000 0 5 1 I 2 49 8000000000 0 5 1 1 2 49 $000000000 0 5 1 1 2 49 8000000000 0 5 ]. 1 2 49 8000000000 0 5 1 1 4 68 8000000000 0 5 1 1 2 49 ~000000000 0 5 I I 2 49 8000000000 0 5 1 1 2 49 8000000000 0 5 1 1 2 49 5400000000 0 5 1 1 2 49 8000000000 0 5 1 i 2 49 8000000000 0 5 1 1 2 49 8000000000 0 5 1 I 2 49 8000000000 0 5 1 1 2 49 8000000000 0 5 1 I 2 49 8000000000 0 5 1 1 2 49 8000000000 0 5 1 1 2 49 8000000000 0 5 ! I 2 49 8200000000 0 5 1 I 2 49 8000020000 0 5 1 I 2 49 8400000000 0 5 ! 1 2 79 8000000000 0 5 1 1 2 49 8000000000 0 5 ! I 2 49 8000000000 0 5 1 1 2 49 8000000000 0 5 1 I 2 49 8000000000 0 5 1 1 '2 49 8400000000 0 5 I I 2 49 8000000000 0 5 1 ! 2 49 9.000010000 0 5 1 1 2 79 9000010000 0 5 1 1 2 49 90000.10000 0 5 ! I 2 49 8000020000 0 5 I 1 2 49 8800000000 0 5 I 1 2 49 8000000000 0 5 1 I 2 49 8000020000 0 5 l' '1 2 '49 8800000000 ** -0,350 TEN$.TOH 1565,i MARK,TOH 28.10~ IRDZ,TOH -28, IRDP.TOH -111..069 'IXDZ,TOH ~2,895 IXDP,TOH .18.88~ 'IR~Z...TOH 43.246 I~BP.TOH 5.912 86.,250 2,850 1854i 37 182 37 '~231,410 ,IS Tape Verification Listin~ cblumberger Alaska Computing Center 1-MAR-!993 11:58 IR~M.TOH 3240.839 RIXM.TOH IX~N.TOH 3271.657 DCID.TOH I~OF.TOH 2.000 DEOF.TOt~ SFVZ.TOH 1.364 RSFC.TOM DCSF,TOH 0,000 SFOF,TOH SFBP,TOH 547.000 RRFO,TOH XFOC.TOH 0,008 RSPR.TOH RITE,TOH 66.875 RD~H.TOh F'TV~.TON 0,022 RPSD.TOH IPSD.TDH 2.240 !EMA.TOH 2~XP.TOH 2.270 VODC.TOH INOB.TOH 3.666 15VT.TOH CIMP.TOH 74.063 IDPH OH IIX~.TOH 183 75 CIBD.TOH IL~.TOH 13.1~8 DMRA,TOB SFV.TOH 15.773 SFC.TOH SFLU.TOH 13.414 SFLA.TOH TTi.TOH 826..500 TT2,TOH AMPL,TOH 23,828 CB~.TOH TT.TOH 0,000 D?.TOH 118.625 RGR.TOM HTEN.TO~ 5048.000 RHTE.TOH A"T~.TOH 72.063 DTE~.TOM B$.TOH C$.TOH ~HV.TOH R~CA..TOH IRON,TON I.XDN.,TOH I~N.TOH IXM~I.,TO.H SFV.Z.TOH DCS~.TOH $~BP.TOH XFOC.TOH RITE.TOH FTV~.TOH IPSD.TOH 2IXP,TOH 15VS.TOH I~XD...TOH ** DEPTH 8,500 3114.,000 8,336 0O8 1863857 ,099 272,292 0,000 1357 o:o 6 54~.500 .009 6706 0 01~ ~ 0 67.3~ 0 5 7,465 6~?,000 -130.782 IX~Z.TOH O.000 DCIM.TOH 7.000 RSFV.TOH ~.538 SFCP.TOH l.O00 RSFB.TOH 0.~92 RFOC,TOH 79. 88 SPAZ,TOH ~42.250 DIHV.TOH 1.859 EPSD.TOH 0.014 2IRP.TOH 4.344 IWF1,TOH 4.703 ~5VT.TOH 2 DECS.TOH 0.000 IPBA.?OH 15,188 IMPH,TOH 71.~75 IIX~.TOH 67.875 CI[.M.TOH 0.896 OLRR.TOH 2.504 CSFL.TOH 13.414 ITEM.TOH 580.500 TT3.TOh 0.115 TO.TO~ 0.000 TTSL..TO~ 41.313 GR.TOH 5048.000 MRES,TOH ~.000 CTE~..TOH ~2,000 SPA,TOH ,688 1400,000 FEET .TOH -0.300 ICV TOH 0.,000 SM~TiTOH 0 RIRD,TOH 15 178 mIXD.,TOH -105::253 RIRM.TOH ~.339 ZX :TO -13 .653 DCID TOH 0 009 o:ooo RSFC.TOH 2',953 SFOF,..TOH 0,000 RRFO.,TOH 0 I 0 RSPR,,OH 62!6~8 RDIH.,TOH 242 IR~A,'TOH !'019 VODC,TOH :340 5VT".TOH 4,703 ECb,TOH 0 IFBA.TOH 0,.~00 IDPH.,TOH 19~ 78 !.I. RM..TOH 58,938 CILD'.TOH 53,906 TIME. TOH TE)~$:TOH RS~I..TOH BMIN,TOH IRDZ.TOH IXDZ,TOH IRMZ.TOH IXMZ,TOH DCI~,TOH RSFV,TOH SFCP,TOH RSFB, TOH RFOC,TOH SPAZ,.TOH DIHV,TOH EPSD..TOH 2IRP.,TOH IWF1,TOH 25VT.TOH DECS,TOH IPBA.,TOH I'MPH='TOH IIX~,TOH CILM.TOH -26.690 0.000 17.726 12 293 9:266 0.089 2.291 254.750 2.225 2.264 2.074 2.445 7344 1.000 13.484 5.449 75.813 4.449 74.500 67.938 802.000 .:ooo 000 156 74.688 0.000 584.~000 '28,172 -12..861 -43..112 -26..605 016 4'73 0..080 2,23'0 25~,000 ..230 ..254 .064 2.445 6144 .000 1,.454 62..094 IX)~P.TOH IDOF.TOM SFVP.TOH SFCZ.TOH SFBZ.TOM RXF~.TOH SPAP.TOM FTVP.TOM XPSD.TOH IRDA.TOH IWF2.TO~ SIIV.TOB DER$.TOH CIDP,TOH IIRD.TOH IXD.TOH ILD.TOH SFB.TOH CSF~.TOH ITT.TOM TT4.TOM SRRT.TOM CBSF.TOM STSG.TOH ~T~M.TOH C~$W.TOH AR.TOH ~ARK:TO, RS~N.TOH BMNO.TOH IRDP.?OH IXDP. TO.H IR~P.TOH IXMP.TOH .IDGF.TOH .SFVP.TOH SFCZ.TOH SFBZ,TOH RXF~.TOH SPA .,TOH FTVP.TOH XPSD.TOH IRDA,TOH IWF2,TOH $2IV,TOH DER$,TOH CIDP.TOH IIRD.TOM ,.TOM PAGE: 257.313 3.000 315.928 -0.034 -1,644 0,039 1012.000 3.811 1.864 0.024 2.055 0.087 228 65,813 61.031 1462.000 14.719 11,133 74.500 0.000 573.500 0,482 0,115 176 72.063 6144 0,000 83,723 86,500 2,850 2,811 1855,.197 182,492 3232,328 '258,036 0,000 315.,936 · 034 0.,036 1011!000813 1..869 0,029 .055 ,36i 116 52,375 48.656 1~3,875 8,531 IS :aue Verification bistln~ chlum, beroer Alaska Comoutlnq Center 1-M~R-1993 IL~,TOW 16,094 DMRA,TOH SFV,TOH ~1,313 SFC,TOH SFLtJ.TOM 15.609 SFI, A.TOH TT1..TOH 826.500 TT2.TOH AMPL.TOH ~3,825 CBb. TOH TT.TGN 0,000 CBML,TOH DT,TOH 118,625 RGR,TOH F?E~,TOH 5058,000 RHTE,TOH A~TE.TON 72,063 DTEM.TOM HV.TOH 250,500 RSP,TOH SP~V,?OH '-556,000 SP.TOH 0.868 OLRA.TOH 2.908 CSFL.TOH 17.703 ITEM,TOH 5B0.500 TT3.TOM 0.125 TO.TOH 0.000 TTSb,TOH 41,313 GR.TOH 5068,000 ~RES.TOH 0.000 CTEM.TOH 17.500 SPA.TON ~38.813 ' ** DEPTH = 1]08,000 FEET BS.TOH 8.50(, TOD.TOH ,~v.~o, ~ ~4 ~cv.~o~ ~c~.~o~ ~.oo~ ~C~,.To. 4.~ IX,N.?O, )229,529 IM~F.TOH 0.000 DEQF.TOH SFVZ.TOH 1',357 RSFC.TOH DCSF.TOH '2.715 SFOF, TOH SFBP,,TOH 546,500 RRFO,TOH XFOC,,TOM 0.010 RSPR,TOH RITM.TOH 68.,000 RDIH,TOH o 2IXP.TOH 2,283 V0DC.TOH IMDB,TOH 3,861 15VT,.TOH IFR TON 20 IFB TOM CIMP. TOM 107.,9~8 IDPH,TOH IIXD.TOH 6~.219 IIRM,TOM I~:..TOH 1950.000 CII, D,TOH ,TO, 9,055 $[bU,TOH 2.871. 8FbA.TOH TT],TOH 418,000 TT2,T'OM AMP[..TOH 6,227 CB~..TOH TT.TOM .0,000 C8$L,TOH DT.TOH 55,563 RGR.TOM HTEN..TOH 5084,000 RHTE.,TOH A~T~.TOM 71,563 DTEM.TOH HV'~0M 250,500 RSP.TOH SPMV,TOH '556,000 SP,'TOH 422148495 -0.250 0.000 0 -28.667 -51,160 -20,686 -415.724 0,002 0.000 -0.512 0,000 0.373 156,375 239.000 1 869. o:o2~ 4,348 4.703 2 °i ~04 o 5084,000 o 6 ~656 TIME.TOH TENS,TOM RSMI.TOH IRDZ,TOH IXDZ.TOH IRMZ.TOH IX~Z.TOH DCIM,TOH RSFV,TOH SFCP.TOH RSFB.,TOH RFOC.,TOH SPAZ.TOH DIHV,TOH EPSD,TOH 2IRP..TOH IWFI ~OH 25VT TOH DECS TOH IPBA TOM IMPH TOH CIGM,TOH OLRA.TOH CSFG,TOH ITEM.TOH TT3,TOH T0,TOH TTSL.,TOH GR,'TOH .MRES,TOH CTEM.TOH SPA,TON ** END o.r DATA ,, 2.195 64.000 68.188 802.000 4.000 0,000 44.156 -0.189 77.188 0.000 577.000 1505 000 , .$87 .004 -28.249 12.912 :43.180 ,605 '2~,068 7O7 250 .068 ..445 3 -265 5O 0 13 348,000 69..250 0 , O0 78.875 0.,000 SF'~.TOP CSFA.TOH ITT.TOH TT4.TON SRAT.TON CBLF.TOH STSG.TON ~TEM,TOH CCSW.TOH SPAR.TOH ETIM,TOM MARK.TOH RSMN.TOH BMNO.TOH IRDP,TOM IXDP..TOH IRMP.TDH IXMP.TOH IDGF.TOH SFVP,TOH SFCZ,TOH SFB~.TOH RXF .TON SPAP..TOH FTVP,TOH XPSD,TOH IRDA,TOH IWF2,TOH S2IV,.TOH DERS.TOH CIDP,TOH IIRD.TOH IXD.TOH ~hD.TOH SFB.TOH CSFA.TOH ITT.TOH TT4..TOH SRAT.TOH CBLF.TOH STSG.TOH MTEM.TOH CCSW.TOH SPAR,TOH PAGE: 9.492 56.469 0.008 573.500 0.482 0.115 176 72.063 6144 0.000 190.357 86.563 2,340 2.277 1837,020 -292.000 3190.766 -530.521 0.000 315.814 -0,034 -1.625 0.039 1.864 0,024 2.074 0.283 244 19.672 19,047 47., 4 22,016 309,250 o.:o~ 308,250 0.613 0,065 176 71.563 6144 0.000 I8 TaDe Verification Llstinq chlumberqer Alaska Computinq Center FIL~ NAME ~ TOH ,005 SERVICE : IJCG VERSION ~ 32.6 OAT~ : 93/01/22 ~tX AEC SIZE ~ 10~4 FILF TYPE : PR **** Flbg HEADER FILF NAME : TOH ,008 SFRVICE : LOG VERSION : 32 6 DATE ' ) MAX AEC SIZ~ : 10~4 FIL~ TYPE : PR bAST FILE 1-~AR-1993 11:58 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64ES TYPE REPR,CODE. VALUE 1 66 0 ~ 66 0 3 79 348 4 66 i 5 66 6 73 -528 ? 65 INCH 8 73 60 9 65 liN 13 66 ~4 6~ ..0 66 mmmmmmmmmmmmmm~mmmmmmmm~mmmmmm .**:SET TYPE.- CHAN,.** ...... NAME EERV UNIT SERVICE APl AP1 APl' APl FILE NUMB NUNS SIZE REPR PROCESS .... ID. ,.ORDER #, LOG' TYPE-CLASS ~OD NUMB. EA. MP. ELEM.., CODE,. (HEX) .ES TOH IN 0'7 282' 01 0 8 1 1 2 49 8000000000 TOD TOH S 07 000 00 0 8 1, 1 4 ?~' ~200000000 TIME TOH ~S 07 6~6 21 0 8 1 1 4 68 8000000000 ETI~ TOH $ 07 636 21. 0 8 I I 4 68 8000000000 IS Tame Verification 6istino chlumberqer Alaska Computlnq Center 1-MAR-1993 11:58 [~ M SERV UNIT SER ICE AP! API AP1 A I ILE NU. NUMB IZE REPR P ID ORDE~, # LOG TYPE CLASS MOD NUMB SA~P EbEM CODE (HEX) CS TOH F/MR 07 6~6 ~! 0 8 ! ! 2 49 8200000000 DIFF TOH TENS TOH MARK TOH IHV TOH ICV TOH RS~! TOH R$~ T0H R~C~ TOD{ S~6T TOH BMNO TOH MCAL TOH R]RP TOH IRDZ TOH I~DP TOH RIX~ TON IXDZ ?OH IXD~ TOH IXDN TOH R2R~ ?OH IRMZ ?OH IRMP ?OH I~N ?OH RIX~ T0H IX~Z TON IXMP TOH IX~N TOH DCID TOH DC~ T0H ]PO? TON I~0? DEQF RSFV TOH SFVP TOH SFVZ'TOH RSFC TOH SFCP 'rOM S~CZ DCSF TOH SFOF TOH RSFB TOH SFBZ TOH SFBP ?OH R~FO RFOC ?OH RXFO XFOC TO~ RSP~ TON SPAZ ?OH F F3 OHMM IN OHMM OH~M IN MM/M MM/M MM/M MMIM MM/M MM/M MM/M MM/M MV MV ~V MA MA MA MA V V V V 07 636 21 07 635 07 150 01 07 282 01 07 282 O! 07 250 O1 07 252 01 07 280 01 07 280 O0 07 250 O1 07 252 01 07 280 Ot 07 000 00 07 000 00 07 000 00 07 000 00 07 000 00 O7 000 O0 07 000 O0 07 000 O0 07 000 00 07 000 O0 07 000 00 07 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 00 07 000 00 07 000 00 O7 000 O0 07 000 O0 O7 000 O0 07 000 00 07 000 O0 O7 000 00 07 000 00 O7 000 O0 07 000 O0 07 000 O0 07 000 O0 O7 000 O0 07 000 O0 07 000 00 07 000 00 07 000 O0 07 000 O0 07 000 0O 07 000 00 07 000 00 0 8 I 1 4 68 8000020000 0 8 i 1 4 68 8000000000 0 8 ! ! 2 49 8000000000 0 ~ 1 I 2 49 8400000000 0 8 1 1 2 49 8400000000 0 8 3 I 6 ~9 8000020000 0 8 3 ! 6 49 8000020000 0 8 1 1 2 49 8000020000 0 B ! 1 2 7g 8000020000 0 8 3 1 6 49 8400000000 0 B 3 I 6 49 8400000000 0 8 1 1 2 49 8400000000' 0 8 1 1 4 68 8000000000 0 8 ! 1 4 68 8000000000 0 8 1 1 4 68 8000000000 0 8 1 1 4 68 8000000000 0 8 1 1 4 68 8000000000 0 8 I 1 4 68 8000000000 0 B 1 1 4 68 8000000000 0 8 I 1 4 68 8000000000 0 8 I I 4 68 8000000000 0 B 1 1 4 68 8000000000 0 8 1 1 4 68 8000000000 0 8 1 I 4 68 8000000000 .0 8 ! ! 4 68 8000000000 0 8 ! 1 4 68 8000000000 0 8 1 1 4 68 8000000000 0 8 1 ! 4 68 8000000000 0 8 1 .1 .2 49' 8000000000 0 8 ! 1 2 49 8000000000 0 8 ! ! 2 49 8000000000 0 8 1, I 2 49 8000000000 0 B 1 1 2 49 B000000000 0 8 1 1 4 68 8000000000 0 8 1 1 4 68 8000000000 0 8 1 i 4 68 B000000000 0 8 1 1 4 68 8000000000 0 8 ,1 1 4 68 8000000000 0 8 1 1 4 68 8000000000 0 B 1, 1 2 49 8000000000 0 8 1 I 2 49 8000000000 0 $ 1 1. 2 49 8000000000 0 8 1 I 2 49 8000000000 0 8 ! 1 2 49 8000000000 0 B !. 1 2 49 8000020000 0 8 ! 1. 2 49 8.000020000 0 B 1 1 2 49 8000020000 0 8 1 I 2 49 8000020000 0 B 1 1 2 49 B000000000 0 8 ! 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V 0~ 000 00 0 8 ~ 1 2 ~O 8000020000 ~V. ?U. v o~ 000 oo 0 8 1 ~ 2 4~ 8000000000 ~mvz mo. v ov 000 oo 0 8 ~ ~ ~ 4~ ~000000000 ..s~ mo. o~ ooo oo o 8 ~ ~ 2 4~ 8000020000 EPSD TOH 07 000 O0 0 8 I 1 2 49 8000020000 X"SU ~0. 0~ 000 00 0 8 ~ ~ ~ ~9 8OOOO2000O ~S~ TOH 07 ooo oo o 8 1 1 2 4~ 8oooo~oooo Im~ TOH 07 000 00 0 8 I I 2 49 8000020000 2~.~ ~o. o~ ooo oo o 8 ~ ~ ~ ~9 8000020000 Z.D~ To. o~ ooo oo o 8 ~ 1 ~ 4~ 8oooo~oooo ~xP mo. o~ ooo oo o 8 1 1 2 ~v eoooo2oooo roue mo. o? ooo oo 0 8 ~ ~ 2 49 80000~o000 ~ ~0, ov 00o oo 0 s t t 2 4~ 8000020000 z.~ ~0, o? 000 oo 0 ~ t ~ 2 4~ s000020000 ~n~ ~0. o~ 000 oo 0 8 1 ~ ~ 4~ 8000020000 15VT TOH 07 000 O0 0 8 1 1 2 49 8000020000 ;SV? ;0, O? 000 O0 0 8 I t ; 4V SO000~O000 s~v ?o. o? ooo oo o ~ i ~ 2 49 8000020000 lsvs TO. 0~ 000 00 0 8 1 t 2 89 8000020000 D~Ct, TO. 07 000 00 0 8 ~ ~ 2 79 8000020000 DECS TOH 07 000 O0 0 8 I I 2 79 8000020000 ~s ?o. 07 ooo oo o 8 ~. ~ 2 ~9 8oooo~oooo I~ mo. 07 ooo oo o 8 1. 1 2 7~ 8ooooooooo z~ ?o. o~ ooo oo o 8 1 1 2 49 8ooooooooo [PS~ TO. 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M~ 07 000 O0 0 8 i 1 ~ .~v 8000000000 s~v mo. ~v o7 ooo oo o 8 I I I 4~ 8ooooooooo s~c mo. ~A o~ ooo oo o e i 1 ~ 49 eooooooooo csrt, ~o~ ~/~ o7 ~o ol o 8 ~ 1 2 49 8ooooooooo csra ?o. ~,~. o72~'o o 8 ol i 1 ~ 4¢ 8ooooooooo sr~u mo, o~.. o7 ~lo ol o 8 1 ~ 2 49 8ooooooooo s~ mo. o,~., o7 121 ol o 8 ~ ~ ~ s9 8000000000 ,I8 ?ame Verification btstin~ ,chlumberger AlasKa Comput[nq Center 1-MA~-lgg3 11:58 PAGE~ ]0 ........................ SERV Ur)IT SERVICE API''''''''''''''''''''''''''''''''API ID ORDEr~ # bOG TYPE CLASS MOD NUmB SAMP' ELF,..~ CODE (HEX) TEM TOH 07 000 O0 0 1 1 9_ 49 8000000000 ITT TOH S 07 529 82 0 8 1 t 4 68 8000000000 TT1 TOR Un 07 522 A] 0 8 1 I 2 49 8000000000 TT2 TOH US 07 522 83 0 8 1 I 2 49 8000000000 TT3 TOM US 07 522 83 0 8 1 t 2 49 8000000000 TT4 TON US 07 522 83 0 8 I 1 2 49 8400000000 A~PL TOH ~V 07 522 85 0 8 I 1 2 49 8000000000 C~t TOH MV 07 524 86 0 8 1. I 2 49 8000000000 TO TOH MV 07 524 32 0 8 ! i 2 49 8000000000 SRA~ TOH 07 580 87 0 8 ! 1 2 49 8000000000 TT ?OH }IS 07 522 83 0 8 I 1 2 49 8000000000 C~$}., TO~ MY 07 524 86 O 8 1 1 2 49 8000000000 TTSt, TOH US 07 522 83 O 8 1 1 2 49 ~000000000 CB~F TOH ~V 07 524 86 0 8 I I 2 49 8000000000 DT TON US/F O? 5~0 80 0 8 1 ~ 2 49 8200000000 R~R TOH GAP! 07 310 01 0 ~ 1 1 2 ~9 8000020000 GR TOH GAP! 07 310 01 0 8 1 1 2 49 8400000000 STSG TOH 07 000 00 0 8 1 1 2 79 8000000000 HTEN TOH 5BF 07 000 00 0 8 I 1, 2 49 8000000000 RATE TOH bBF 07 000 O0 0 8 1 1 2 49 8000000000 ~RES TOH OHMM 07 000 O0 0 8 1 1 2 49 8000000000 ~TE~ TOH DEGF 07 000 O0 0 8 1 I 2 49 8000000000 AMTE TOH DEGF 07 000 00 0 8 I 1 2 49 8400000000 DTEM TOH DC/K 07 000 00 0 B 1 I 2 49 8000000000 CTEM TOH DEGF 07 660 21 0 8 1 I 2 49 9000010000 CCSW TOH 07 000 00 0 8 1. i 2 79 9000010000 HV TOM V 07 000 00 0 8 ! ! R 49 9000010000 RSP TOH MV 07 010 01 0 8 1 I 2 49 8000020000 SPA TOH MV 07 010 01 0 8 I 1 2 49 8800000000 SPA~ TOH MV 07 0i0 Oi 0 8 ! I 2 49 8000000000 8PMV TO~ MV 07 010 O1 0 8 ! t 2 .49 8000020000 SP TOM.. NV . . 07. 010 Oi 0 8 I ! 2 49 .8800000000 DEPTH = 4551.000 FEET C8,TOH 19 0.00 DIFF,.TOHm '.. TEN :~OH I .000 MARK,TOM I.HV,TOH 0,000 ICV,TOH 0 000 RSMI,TOH 4,203 RSMN.TOH E~CA.TOH 6,0.04 M TOH -1 5,212 IXMZ,TOH 25 877 IX~P TOH · '3302,.1.02 R~XM,.TOH 3 - IXMN..?OH 333~,..342 DCID,TOH 0°000 DCI~,TOH 0. 000 IDOF. TOH IMOF:TOH '~,.000 DEOF,TOH 7,000 RSFV,TOH 21:763 SFVP:TOH SFVZ,TOH .1.368 RSFC,TOH 5,)i4 SFCP°TOB !2,25) SFCZ,TOH DCSF.TOH 0,000 SFOF,TOH 1o000 RSFB,TOH 5°590 SFBZ.TOH i 'i469 8188 953 6,.051 1889,533 196,546 3294,055 291,.,,594 . 3,000 314,726 '0,032 -1,581 ,IS ?ame verification tistlno cblumberger Alaska Computing Center SFBP.TOH 545.000. XFOC,TOH O.O01 RTTE,TOH 85,313 FTVZ,TOH 0,024 IPSO.TON 2,260 27XP.TOH 2.221 IHDS.TOH 3.729 15VS.TOH 4.70] IFRE,TOH 20 CIMP.TOH 92.56] X{XD,TOH 6.672 {XM.TOH 195.000 Tt, V.TOH 10.586 SFV.TOH 19.734 SFLU.TOH 8.047 TT1.TOH 654.000 AMPI,.TOH 30.031 TT.TOH 0.000 DT.TOH 88.8{3 HTE~.TOH -336.000 AMTE,TOH 92,313 Hv.TOH 248.250 SPMV.TOH -571.000 ** DEPTH = . .. soo iHV.TOH .582 RMI~.TO" 1.004 MC .?OH .863 IRDN.TOH 1894,657 IXDN.TOH 2000.935 IRMNeTOH 3301.978 XXM,.TOH 3.33.6.771, XMOF.TOH 0.000 SFVZ.TOH 1.,371 DCSr. TOH 0.020 SFBP.TOH 545,000' XFOC.TOH RTTE..TOH 8~.438 FTVZ.TOH IPSD.TOH 2,215 2IXP.ToH 3.738 1 '.'~0~ I~R~,TOH 4,699. C,',P.TOH 93,.I~0 ~XD,TOH 6,. 2 IXM..TOH 191.,2~0 lt,~.TOH 10.5.6 SFV TOH 19,719 SFLIJ:TO.~ 8.047 TT1.T'OH 654.000 RRFO.TOH RSPR.TOH RDIH.TOH ~PSD.TOH IR~A.TOH VODC.TOH 15VT.TOH DECb,TOM IFBA,TOH IOPH.TOH IIRM.TOt{ CILD.TOH DMRA,TOH SFC.TOH SFL~.TOH TT2 CBSL. RGR. RHTE OTE~ RSP SP.. TOH TOH TOH TOH TOH TOH TOH 0.134 RFOC.TOB ~16.625 SPAZ.TOH 233.000 DIHV.TOH 1,859 EPSD,TOH 0,039 2IRP.TOH 4.359 IWF1.TOH 4.684 25VT,TOH 2 DECS.¥O~ 0.00o IPBA.TOa 13.508 I~PH.TOH 89.438 IIX~,TOH 76.188 CILM.TOH 0.806 OLRA.TOH 5.219 CSFb. TOH 8,047 ITE~.TOH 486.750 TT3.TOH 0.339 TO.TOH 0.000 TTSb. TOH 91.313 GR.TOB 4364.0~0 M~ES.TOH 0.0 0 CTE~.TOH 554. 0 SPA.TOH 4500.000 FEET TOD.'TOH 412250281 TI~E.TOH DIFF.TOH -2,0~0 TENS,TOM ICV.TOH 0.0 0 RSMI,TOH SMLT,TOH 0 BMIN,TOM RX. RD,TOH .36,354 IRDZ.TOH RIXD..TOH -I05.666 XXDZ.,TOH R~RM,TOH 39.0~5 IR~Z.,T~, RIXM.TOH -135,~ 4 IXMZ.TO, 0'0 O0 DCID,TOH DC2M,TOM DEO'F'~:TOH 4.000 ~SFV,TOH ,src..To. :,o8 src , oH SFOF,.TOH 000 RSFB,.~OH RRFO,TOH. 0,:{25 RFOC,TOH RSPR,.TOH 2J. 6,625 SPAZ,TOH RDXH, TOH 236,500 DIHV,TOH RPSD..TOH 1.864 EPSD,,TOH .IRMAoTOH 0,014 2IRPoTOH VODC,T H 0 IWF1,TOH DECb'TOH 0 DEC$,TOH IFBA,TOH iiO00 IDPH..,OH ! .~ 'XPBA..TO, IIR,,..TOH 8 ~ ~ IMPH.TOH XIX~,TOH ILD.TOH 7 QLRA,TOH SFC.,TOH 5,~I~ .CSF~..TOH SFLA.,TOH 8. ITE~,TOB TT2.TOH 486.1~0 TT3,TOH CB~..TOH O, 9 TO,TOH o.058 -1.610 245.875 2.244 2.211 2.068 2.377 7312 1.000 0.797 15,125 94.438 27.469 124.125 87..563 639.000 4.000 0.000 97.625 3. 5 0.000 715,000 3390.000 4, ~70 -1.2 21 46 5,590 0,054 249, 40 2".~70 2, ,2 9 6144 .ooo I .719 94,438 27...469 ,688 .000 6 :ooo RXF~. SPAP. FTVP. XPSD. IRDA. IWF2. $21V. OERS. CIDP. IIRD. IXD. IbD. SFB. CSFA. ITT. TT4. SRAT. CBLF. STSG. MTE~. CCSW. SPAR, ETIM.. MARK. R8MN. .BMNO. IRDP. IXDP. IRMP. IX~P IDQF SFCZ SFBZ RXFO. SPAP, FTVP, XPSD, IRDA. IWF2- S2IV, DERS. C/DP, IIRD, IXD. SFB. C'SFA. ITT, TT4. S~AT, TOH TOM TOP, TOH TOH TOH TOil. TOM TOM TOH TOH TOH TOM TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOM TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOM TON TOM TO. TOH TON TOH TOH TOM TOH PAGE: 0,026 1004.500 3,797 1.859 0,024 2.064 0.029 2O 73.938 68,250 149,750 13.125 7.344 124.125 0.000 451.000 0.310 0.339 176 92.313 6144 0.000 I13.049 87,563 5.953 6 51 196.546 3294,735 000 314,741 =0.032 -1.'575 0,049 1004.500 3,803 1,859 0.,01.4 2,.078 0.048 , 20 73,188 68..250 149.750 i3 125 7 336 124 125 0 OO5 451 000 0 310 11 IS ?ape verification I, lstlnq chlumberger Alaska Computina Center TT.TOW 0,000 DT.TOH 88.813 HTEN,TOH 375.500 ~UTE.TOH 92,313 HV.TOH 245o~75 SO~V.TOH -571.000 ** DFPTH = BS.TOH 8.500 CB.TON 2378,000 {HV.TOH 34,281 RPCA.TOH 9,813 MCAL,TOH 9,414 I~DN,TOW 1896,120 IXDN,TO~ 2002,790 IR~N,TOH 3305.614 lX~N.TOH 3340,849 I~OF.TOH 0.000 SFVZ,TOH 1,373 DCSF.TOH 0.044 SFBP.TOH 544,500 XFOC,TOH 0,007 RITE,TOH 87,313 FTVZ.TOH 0,024 IPSD,TO~ 2,234 2~XP.TOH 2,250 INDB.TOH 3,734 15V$.TOH 4,699 IFRE,TOH 20 CIMP.,TOH 120,875 IX.,.TOH .1 :375 SFV,TOH 16, 8 SFLU.TOH 9,523 TT1.TOH 667,000 AMpS.TOH 29'500 TT,TDH 0.000 DT,TOH 98,313 HTE'H.TOH 376,250 A~TE. TOH '9~.000 HV:TOH 245,875 SP~V.TOH -570,500 DEPTH = CBSb,TOH RGR,TOH RHTE,TOH DTEM,TOH RSP.TOH SP,TOH 4400.000 TOD.TOH DIFF.TOH ICV,TOH SMLT.TOH RIRD,TOH RIXD,TOH RIRM,TOH RIXM,TOH DCID,TOH DEOF,TOH RSFC,TOH SF~F,TOM ~RFO,TOH RSPR.TOH RDIH.TOH RPSD,TOH IRMA.TOM VODC,TOH 15VT,TOH DECL.,TOH IFBA,TOH IDPH,TOH IXP~,.TOH CXLD,.TOH DMRA.,TOH. SFC.TOH S.FLA,TOM TT2,TOH CBb,TOH CBSb. TOH RGR.TOH RH'T~,TOM DTE~.,:TOM RSP,TOM SP,TOH 4300,000 TOD:,TOH DIFF.,TOH ICVTOH $~LT TOH RIRD TOH RIXD TOH RIRM TOM RIX~ TOH F~ET FEET' 1-MAR=1993 11:58 0.000 TTSL,TOH 91.3i3 GR,TOB 5072,000 MAES,TOM 0.000 CTE~.TOH 554.000 SP.~.TOH -16.71g 412150435 TIME,TOH =2.000 TENS,TOH 8,578 RSMI.TOH 0 BMIN.TOH 79,329 IRDZ,TOH -98,505 IXDZ,TOH 63,679 IRMZ,TOH '1.30,331 IXMZ,TOH 0,090 DCI~,TOH 0.000 RSFV,TOH 3.650 SFCP.TOH 0.000 RSF~,TOH 0,214 RFOC,TOH 227,750 SPAZ,TOM 234,000 DIHV,TOH 1,859 EPSD,TOH 0,029 2IRP,TOH 4,398 IWFI.,TOH 4.680 25VT,TOi~ 2 DECS,TOH , 000 IPBA.,TOH 11 'i09 IMPH.,TOH , 25 IIXM.,TOH 12 ,688 CIL~.,TOH 1,~63 QLRA.,TOH 3, 96 CSFb,TOH 8,891 ITEM..TOH' 468,000 TT3,TOH O. 75 TO,TON 00 b,TOH 8 O0 MRES,TOH .0 00 CTEM.,TOH 55 ,500 SPA,TOH -11.883 ~1. 0 TENS,TOH 24,578 RSMI,.TOH 0 B~IN.TOH 105,31~. I. PDZ,TO, -89,! IXDZ..TOH -126.004 IX~Z:TOH 0.000 97.625 =0.].44 1.03.~75 0.000 755.000 3225.000 5 570 . .496 12.403 -43.302 -25.805 0,057 17.991 12.250 0.336 0.101 1.809 246.750 2.260 2.254 2.025 459 1..000 8.266 7,781 120.188 5.809 1~4..938 89.688 664.000 4.000 0,000 88,500 -0.'145 105'500 0.000 754:.000 5.000 31'8~,352 .414 -28,.172 -~2.395 :43. CBLF.TOH STSG.TO~ MTE~.TOH CCSW.TOM ETIM.TOH MARK.TOH RSMN.TOH BMNO.TOH IRDP.TOH [XDP.TOH IRMP,TOH lIMP,TON IDQF.TOH SFVP.TOH SFCZ.TOH SFBZ,TO~ RXFO,TOH SPAP.TOH FTVP TOH XPSD:TOH IRDA.TOH IWF2,TOH $2IV.TOH DERS.TOM CIDP,TOH iIRD,TDH IXD,TOM ILD.,TOH SFB,TOH CSFA,TOH ITT,TOM TT4..TOH SRA. T,TOM CBLF,TOH STSG,.TOH MTEN,TOM CCS~.TO~ SPA ..TOM ETI~'TOH. NARK,TOH RSNN,TOH BNNO.TOH IRDP.TOH IXDP,TOH IR~P.TOH IX~.P,TOH PAGE: 12 0.339 176 92.313 6144 0.000 267.006 86.438 6.105 6.191 1890.996 197.432 3297.959 294.012 0,000 314.662 -0,032 -1.563 0.039 1004.000 3,801 1.859 0.024 2,049 0,034 .204 123.,i88 110,938 11~,000 ,824 12,195 112,~75 0.,014. 462,750 0,307 0,375 ..176 92.000 6144 0,000 1.7,069 486,3.13 8 750 8 883 1892 09.4 198 209 3300 447 295 879 .IS Tape V'erlficatlon Listing cblumberger AlasKa Computino Center IxN~.'roH 3343.428 I"OF,TOH 0,000 SWV'Z,TOH J,378 DCSF.TOH 0.026 SFBP.TOH 544.500 XFOC.TOH 0,002 RTTF.TOR 88.563 FTVZ.TOH 0.024 IPSD.TOH 2,225 2TXP.TOH 2.254 INDB.TOH 3,744 15VS.TOH 4.695 IFRF,TOH 20 CIMP.TOR 149.625 IIXD.TOH 14,930 IX~.TOH 107.250 Zb~.TOH 6.520 SFV,TDH 15,945 SFbU.TOH 8,180 TT1,TOH ~96,000 AMPL.TOH 33.094 TT,TOH 0,000 DT.,TOH 106,438 HT~",TOH 381,'250 A~T~,TOH 92.563 HV,TOH 247,000 SP~V.TOH '571,000 DEPTH = BS,TOH 8,.500 .C$,TOH 2396,000 IHV.TOH 120,000 RMCt. TOH 9,500 ~CAL:TO, 9,039 I~DN,TO~ 1897,584 IXO~,,mO, 2004,317 I~N',TOfl 3310,092 IX~N,.TOH 3345.365 ~O~,TOH ~ 000 S~VZ,TO, :373 DCSF. TOH 0,050 SFBP~TO~ 544,500 XFOC TOH 0,005 RZTE:TOH 89.~8 ~PSD.TOH 221 15V$,TOH 4,691 IFRE,TOH 20 DCID,TOH DEOF.IOH RSFC,TOM SFOF.TOH RRFG.TOH RSPR.TOF ~DIH.TOH RPSD.TOH IRmA.TOM ~0DC.TOH 15VT.TOH DECS.TOH IFBA.TOH IDPH.TOH IIRM.TOH CILD.TOH DM~A.TOH 5FC,TOH SF[,A,TOH TT2,TOH CBL.TOH CBSb,TOH RGR,TO~ ~NTE,TOH DTEM,TOH RSP.,TOH SP.TOH 4200.000 T.OOi, TOH DIFF.TOH ICV.,TOH 8~LT,TOH RX~D,TOH RIXD,TOH RIR~.,TOH RIXR,.TOH DCZ'D,TOH DEOF,,TOH RSFC, TOB SFOF TOH RRFO, TOH RSPR:TOH RDIH, TOH RPSDTDH I, RMA, TOH ODC,TOH 5'VT.TOH DECb. TOH IFBA.TOH IDPH,TOH IIRM.,TO~ CI. bD,TOH DMRA,TOH FEET I-~,!AR-.1.993 11:58 0.073 DCI~.TOH 0,000 RSFV,TOB 4.217 SFCP.TOH 0,000 RSFB.TO~ 0.173 ~FOC,TOH t90.875 SPRZ.TOH 236,125 DIHV.TOH 1,864 EPSD.TOH 0.014 2IRP,TOH 4,410 IWF1,TOH 4.680 25VT.TOH 2 DECS.TOH 0.000 IPBA,TOH 0.057 17,843 12.249 g.055 .079 2,055 ~9,125 2,~54 2,264 2.068 2.426 7360 1.000 i'~~ IMPH.TOH 6.680 14 , u ZXX~.TOH . 155,750 CZb~,TOH i,016 O~R ,TOH 0.672 4,148 CSFb.,TOH 122,.188 91,000 8,164 ITE~,TOH 478,000 TT3,TOH 0o{60 TO.TOH 0,000 ?TSL.,TOH 44.500 GR,TOH 5080.000 MRgS,TOH 0.000 CTEM,TOH 527.100 SPA,TOH -43, 56 696 000 . -0.143 lo7,563 0,000 41.2150735 TZME,TOH · RS~I,.TOH 0 BMI.N.,TOH 70 ~55 '~R.DZ,TOH -99': 42 IXDZ,TOH 54,,~67 IRMZ,TOH '129. ~6 IX~Z,TOH 0,000 DCI~,TOH i.,~O0 RSFV,,TOH , 26 0,000 RSFB,TOH 0,198 RFOC,,?OH DIHV,TOH ! 859 EPSD,TOH ,4 8 I}~FI.,TOH ,684 25VT,TOH 0o000 IPBA,,TOH 8"~30 I~PH,TOH 04! 75 IIXM..,$ON 115 ~88 CILM,TOH 1, 43 Ob~A,TOH 75O 000 o :ooo .934 7,266 -28 172 -1] 395 -4 240 -2~ 719 017 18 i09 12 .247 531 g 095 -2 363 253 125 2 240 2 270 ,045 6144 1,000 ?73 1~0,375 3.395 IDQF.TOH SFVP.TO~ SFCZ.TOH SFBZ.TOH RXFO.TOH SPAP.TOH FTVP,TOH XPSD.TOH IRDA.TOH XWFR.TOH S2IV.TOH DE~$.TOH CIDP.TOH IIRD.TOH IXD.TOH ILD.TOH $FB.TOH CSFA TOH ITT:TON TT4.TOH SRAT,TOH CBLF,TOH $TSG.TOH CCSW.TOH SPAR.TOM ETIM,.TOH MARK.TOH RSM.N,TOH B~NO.TOH IRDP,TON IXDP,.TOH .IR~P..TOH IXNP.TOH IDOF.TOH ~FVP.TOH SFCZ,TOH '~FBZ,TOH RXFO,TOH SPAP.TOH FTVP.TOH XPSD,TOH IRDA.TOH ..TOH DERS,TOH CIDP.TOH IIRD,TOH IXD,TOH ILD TOH SFB~TOH PAGE: 0,000 314,593 -0,032 -1,563 0.029 1003,500 3,797 1,854 0.019 2,064 0.029 220 153.000 137,000 66,938 6.414 9,852 122,375 0,024 480,000 0.777 0.36O 176 0,000 566 6 1892 199 3302 297 0 314 -0 Oo 100], 1' o! 0 02, ~09. I.'t 939 313 227 672 466' 321 368 751 000 5 9 $ 9' 000 7{)5 .874 019 O35 029 875. 625 IS Taee Verlflcation [.,istincl chlumberger Alaska Computina Center SFV.TOH 1,6.203 SFC.TOH SFLU.TOH 9,156 SFt, A.TOH TT1,TOH 704.000 TT2.TOH AMPb.TOH 17.64! CBL.TOM TT.TOH 0.000 CBSL.TOM DT.TOH 110.918 RGR.TOH MTEN.TOH 398,250 RHTE.TOH AMTE.TOH 91.625 DTEM.TOh HV.TOH 249.375 RSP.TOH SPMV.TOH -571,000 SP.TOH DEPTH = 4165.500 FEET B$.TOH CS.TOH IHV.TOH R~CA.TOH ~CAL.TOH IRDW.TOH IXD~.TOH I~MN.TOH IMQF,TOH SFVZ.TOH DCSF.TOH SFBP.,TOH XFOC.TOH RITE.TOH FTVZ.TOH IPMD. TOH DB.TON 15rS.TOW I~RE.TOH CIMP..TOH IIXD.TOH lX~.TOH SFV.TOH SF~U,TOH TT1.TOH A~PL,TOH TT.TOH DT. TOH HTEN:TOM AMTE,TO'H HV.TOH SPMV,TOH 8,500 2404,000 135,750 10.195 9,867 ~897.775 2004.509 ]~10.092 3346.011 0,000 1.373 0.050 544.500 0.009 89.563 0,017 2,260 2,225 3,734 4..684 2O 119,175 7.527 98 500 16 266 8 461 732 000 ~8 406 0 000 109,813 380,000 91.500 248,250 -571,000 TOD.TOH DIFF.TOH ICV.TOH SMLT.TOH RIRD.TOH RIXD.TOH RIRM.TOH RIX~.TOH DCID,TOH DEOF,TOH RSFC.TOH SFOF.TOH RRFO,TOH RSPR.TOH ~DIH..TOH RPSD,TOH IRMA,TOH VODC,TOH 15VT,TOH DECb. TOH IF. BA,.TOH IDPH,TOH. IIRM,TOH C'ILD,TOH DMRA,TOH SFC:,TOH SFbA,TOH TT2,TOH CBb. TOH CBS~,TOH RGR,TOH RHTE.TOH DTEM.TOH RSP,,TOH SP,TOH ** EN'O OF DATA ** 1-MAR-1993 11:58 3,770 CSFL,TOM 9.344 ITEM.TOM 488,000 TT3,TOH 0,222 TO.TOH 0.000 TTSL.TO~ 94.813 GR.TOH 5096.000 MRES.TDH 0.000 CTEM.TOH 555.000 SPA.TOH =15.602 .$ 412150787 TIME.TOM -1.900 TENS.TOH 47,406 RSMI,TOH 0 BMIN,TOH 67.394 IRDZ,TOH -101.195 IXDZ.TOH b4,115 IRMZ.TOH -127,530 IX~Z,TOH 0,051 DCIM,TOH 0.000 ~SFV,TOH 4.159 $FCP.TOH 0.000 RSFB.TOH .180 CFOC.TOH 22 ,~50 SPAZ,TOH 237, ~5 DIHV.TOH. 1.8 9 EPSD,.TOH 3 IWFI,TOH 4,695 25VT,T'OH 0 DEC$.,TOH !!ooo 906 I~PH..TO~ 1 063 ~13,500 CIb.~,TOH 0,94 O.5RA.. 4'09~ TOH CSFL.,TOH ITEM,TOH TT3,TOH O, TO,TON o,g 0 TTSb,TOH 55.250 GR.TOH 5080,000 ~R~$,TOH ~,000 CTE.~ TOH ,000 SP.A:TOH 4,742 109.188 9;.125 704.000 4.000 0.000 91.375 =0.145 108.375 0.000 744,000 2955.000 4..469 4.668 :28..2i0 12.355 -43.~15 -25. 87 0.070 18.,177 12 246 O. $ 250.625 2.234 2.426 6144 1.000 8,367 10,148 12o. 5 -4.7 2 11.8.063 92,.188 735..000 5,'000 0.000 ~7,750 '0..145 108,375 0.000 CSFA.TOH ITT.TOM TT4.TOH SRAT.TOH CBLF.TOB STSG.TOH MTE~.TOH CCSW.TOH $PAR.TOH ETT~.TOM ~ARK.TOH RSHN.TOH 8MNO.TOH IRDP.TOH IXOP.TOM IRMP.TOH IX~P.TDH IDO~,TO~ SFV .TOH SFCZ.TOH $FBZ,TOH RXFO,TOH SPAP,TOH FTVP,TOH XPSD.TOH IRDA..,TOH IWFg,TOH B2IV,TOH DERS.TOH CIDP.TOH I'I.RD..TOH 'IXD.,TOH ILD,TOH SFB,TOM CSFA.?OH ITT.,,TOH TT4,TOH SRAT.TOH CBLF.TOH STSG..TOH ~TEM.,TOH CCSW,,TOH SPAR,TOH PAGE: 14 107.000 0.035 495.500 0.546 0.222 176 9~.625 6144 0.000 618,618 86.313 5.191 5.289 1893.193 199.544 3303.059 298,689 0,000 314.475 -0.031 -1.553 0,034 1003:000 3.797 1.854 0,029 2,064 0.'185 220 132 750 8 805 10 695 102 ~3 0.039 499,500 0 77 ,176 91..500 6144 0.000 Tape Verification Listin~ chlumoerger Alaska Computing Center **** FIDE TRAILER *~* F~[.,~ NA~E ~ TOH .008 DAT~ = g3/01/~2 MAX REC STZE : 1024 F~LE TYPE ~ PR L~S? FILE ~ **** FILE NEADMR **** FTLF NA~E ~ TOH .009 SMRVICE ~ LOG VE~SlO~ : 32,6 MAX R~C SIZE : i024 FIL~ TYPE = PR L~ST FILE 1-P,~R-1993 11 PAGE: 1.5 ** DATA FORMAT SPECIFICATION RECORD ** *'* SET TYPE - 64EB ** TYPE REPR CODE VILUE 1 66 0 2 66 0 3 79 34e 4 66 5 66 ! 6 73 -528 9 65 l'IN ., 12 6~ 13 66 1 15 66 16 66 ! 0 66 .. ........ **,,$E?.?¥pE,...CHAN.** ...... ,.., NAME SERV UNIT SERVICE APl APl AP1. AP1 FILE NUMB NUMB SIZE REPR PROCESS ID.... ORDER # .bOG TYPE CLASS MOD NUMB. SAMP EbEM CODE (HEX) B$ TUH IN O? '282 01 0 9 ! ! 2 49 8000000000 TOD 'TOH S O? 000 O0 0 9. ! ! 4 73 8200000000 TINE TOH ~$ 0'? 6~6 2! 0 9 1 ! 4 68 8000000000 ETI~ TOH S O? 636 21 0 9 ! 1 4 68 8000000000 Tape Verification Listino chlumberger AlasKa Computtn~ Center 1-MAR-1993 11~58 16 '''~AME ............... 8ERV' UNIq' ~''''''VTCE ..... API AP!='''''''''~API ........ Fi[.,E N''''''''''''''''''''''''''''''''''MB NUM REPR ID ORDER ~ hOG TYPE CLASS ~OD NUMB SAMP ELEM CODE CHEX) CS TOH F/HR 07 636 ~! 0 9 1 I 2 49 8200000000 DIFF TOH ~EN~ TOH ~RK TOH IHV TOH ICV TOR RSM~ TOH RSMN TOH RMCa TOH S~LT TOH MCA[, TOH RIRD TOH I~DZ TOH I~DP TOH I~DN TDH ~IXP TOH IXDZ TOH IXDP TOH IXDN TOH RIR~ TOH I~MZ TON IRMP TOH IRMN TOH RIX~ TOH IX~Z TOH IXMP IXMN TOH DCID TOH DCI~ IDQF TO~ I~QF TOM D~Q~ ?OH RSFV TOH SFVP ~OH 8FV'~ ?0~ RSFC TOH SFCP TOH SFCZ TOH DCSF SFOF ?OH RSFB TOH SFBZ TOH SFBP TOH RRFO TON RF0C T0H RXFO TOH XFOC TOH RSPR TOH SPAZ F bBF F F3 F3 IN OHM~ MM/~ M~/M MM/~ MV I~V ~V MA MA MM/~ MA V V V V MV O7 636 21 07 635 21 O7 150 01 07 282 01 07 282 01 O7 250 O1 07 252 01 O7 280 01 07 280 O0 O7 25O 01 O7 252 01 07 280 O1 07 000 O0 07 000 O0 07 000 O0 O7 000 O0 07 000 O0 07 000 O0 07 000 00 0'7 000 O0 07 000 O0 07 o00 O0 07 000 O0 07 000 O0 O? 000 O0 O? 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 O7 000 O0 O7 000 O0 O7 000 O0 07 000 O0 O? 000 O0 O7 000 O0 O7 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 07 000 O0 O? 000 O0 O? 000 O0 O? 000 O0 9 1 1 4 68 8000020000 9 I 1 4 68 8000000000 9 I 1 2 49 8000000000 9 1 I 2 49 8400000000 9 1 l 2 49 8400000000 9 3 I 6 49 8000020000 9 3 1 6 49 8000020000 9 1 I 2 49 ~000020000 9 1 I 2 79 8000020000 9 3 1 6 49 8400000000 9 3 I 6 49 8400000000 9 1 I 2 49 6400000000 9 1 1 4 68 8000000000 9 1 1 4 68 8000000000 9 I 1. 4 68 8000000000 9 I 1 4 68 8000000000 9 I I 4 68 8000000000 g 1 I 4 68 8000000000 9 1 1 4 68 8000000000 9 ! 1 4 68 8000000000 9 I I 4 68 8000000000 9 1 1 4 68 8000000000 9 1 1 4 68 8000000000 9 1 1 4 68 8000000000 9 I 1 4 68 8000000000 9 I i 4 68 8000000000 9 1 1 4 68 8000000000 9 1 1 4 68 8000000000 9 1 1. 2 49 8000000000 9 1 1 2 49 8000000000 9 1 1 ,2 49 8000000000 9 1 I 2 49 8000000000 1 I 2 49 8000000000 ~ 1 1 4. 68 8000000000 9 1 I 4 68 8000000000 9 1 I 4 68 8000000000 9 1 I 4 68 8000000000 9 I 1 4 68 8000000000 9 1 I 4 68 8000000000 9 I I '2 49 8000000000 9 1 I 2 49 8000000000 9 1 1 2 49 8000000000 9 1 1 2 49 8000000000 9 1 1 2 49 8000000000 9 1 I 2 49 8000020000 9 1 1. 2 49 8000020000 9 1 I 2 49 8000020000 9 1 1 2 49 8000020000 9 1 1 2 49 8000000000 9 1 1 2 49 8000000000 Tape Verification Listlnq chlumberaer AlasRa Computlnq Center 1-FAR-1gg3 11:~8 P A C.,E: 17 ID ORDER # LOG TYPE CLASS ~OD NUMB SAMP ELEM CODE (HEX) SPAP TOM NV 07 000 O0 0 9 1 I 2 49 RITF TOH DEGF 07 000 00 0 9 I I 2 49 R~I~ TOH V 07 000 O0 0 9 I I 2 ~9 D~HV TOW V 07 000 00 0 9 I 1 2 49 FTVP TOW V 07 000 O0 0 9 1 1 2 49 FTVZ TOM V O? 000 O0 0 9 1 1 2 49 ~PS~ ?OH 07 000 00 0 9 1 1 2 49 EP$~ TO~ 07 000 O0 0 9 I 1 2 49 XPSD T0H 07 000 O0 0 9 1 1 2 49 IPtO TOH 07 000 O0 0 9 1 1 2 49 ImM~ TO~ 07 000 O0 0 9 1 i 2 49 2IRP TOH 07 000 O0 0 ~ 1 1 2 49 IRDA TOH 07 000 O0 0 g 1 1 2 49 2TXP TOH 07 000 O0 0 9 1 1 2 49 VODC TO~ 07 000 O0 0 9 1 t 2 49 IWF1 TOH 07 000 O0 0 9 1 1 2 49 I~F~ TOH 07 000 O0 0 9 1 1 2 49 ~ND~ TOM O? 000 O0 0 9 1 I 2 49 15VT TOH 07 000 O0 0 9 ~ 1 2 49 29VT TOH 07 000 O0 0 9 1 I 2 49 $2IV TOH 07 000 O0 0 g I I 2 ~9 15V$ TOH O? 000 O0 0 9 1 1 2 49 D~CL T0H 07 000 00 0 g I 1 2 79 DEC~ TOH 07 000 00 0 ~ I I 2 79 DER$ TOH 07 000 O0 0 g. 1 1 2 7g IFRM TOH 07 000 O0 0 9 1 1 2 79 IFB~ TOH 07 000 O0 0 9 ! I 2 49 IPBA TOW 07 000 00 0 9 I I 2 49 CIDP TOH NN/~ 03 110 ~6 0 9 I 1 2 ~9 IDPH TO~ OH~ 07 120 46 0 9 I 1 2 &9 IMPH TOH 0HMM 07 i20 44 0 9 1 I 2' 49 IIRD ?OH ~M/M 07 000 O0 0 9 1 1 2 49 I]XD T0H MM/M 07 000 00 0 g 1 I 2 4'9 !lR~ ?OH MM/M 07 000 O0 0 9 I 1 2 49 iIX~ TOH ~/~ 07 000 O0 0 9 i i 2 49 IXD TOH OMMM 07 120 46 0 9 1 1 2 49 iXM TO~ OHMN '07 1'20 44 0 9 1 I 2 49 CIhD T0H M~/M 07 110 46 0 9 ! I 2 49 CILM TOH MM/N 07 110 44 0 9 1 1 .2 49 ILD T0H OHMM 07 ,12 0 46 0 9 I 1 2 49 IbM TOM 0HMM 07 120 44 0 9 t 1 2 49 DM~ TOH 07 120 O0 0 9 1 I 2 49 OLRA TOH 07 9~5 04 0 9 1 1 2 49 SFB T0H ~A 07 000 00 0 9 1 I 2 49 SFV ?0H ~V 07 000 00 0 9 i i 2 49 SFC TOH MA 07 000 00 0 9 I 1 2 49 CSFL TOH ~/~ 07 210 01 0 9 ! 1 2' 49 CSF~ TOH ~/~ 07 230 0i 0 9 ~ 1 2' 49 S~LU T0H 0H~ 07 220 0i 0 9 1 ! 2 49 SFLi TON 0. HMM 0? 222' 01 0 9 I I 2 49 8000000000 @000000000 8000020000 80O0O200O0 8000000000 8000000000 8000020000 8000020000 80000200O0 8000020000 8000020000 8000020000 8000020000 8000020000 ~000020000 8000020000 8000020000 8000020000 8000020000 8000020000 8000020000 8000020000 8000020000 8000020000 8000020000 8000000000 ~000000000 800OO0O0O0 SO00000000 8000000000 8000000000 8000000000 8000000000 SO00000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8OO00O0OOO 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 IS Tape Verification Listing chlumberqer Al, asMa Computing Center 1-MAR-1993 11{58 PAGE: NR,. SERV UNIT SERVI API AP1 APl APl F1 E gUM UMB SiZ REPR PRO ID ORDER # LOG TYPE CLASS ~OO NUMB SAMP ELEM CODE (HEX) ITEM TOH DEGF 0 000 0 0 9 ! I 2 9 BO0000000 ITT TOH $ 07 529 82 0 9 I I 4 68 8000000000 ITt TOH US 07 522 83 0 9 1 ! 2 49 8000000000 TT2 TOH US 07 522 83 0 9 1 1 2 49 8000000000 TT3 TOH US 07 522 83 0 a 1 1 2 49 8000000000 T?4 TO~ US 07 522 83 0 O I 1 2 49 8400000000 A~P{. TON ~V 07 522 85 0 9 1. 1 2 49 8000000000 CBL TOR ~V 07 524 86 0 9 I 1 2 49 8000000000 TO TOR MV 07 524 32 0 9 ! ~ 2 49 8000000000 SRA? TO}{ 07 580 87 0 9 1 ! 2 49 ~000000000 TT TOM US 07 5~2 83 0 9 1 I 2 49 8000000000 C~SL TON MV 07 524 86 0 9 ! ! ~ 49 8000000000 TTSL TOH US 07 522 83 0 9 1 1 2 49 8000000000 C~LF TOH MV 07 5~4 86 0 9 ~ 1 2 49 8000000000 DT TOH US/F 07 520 80 0 q ~ 1 2 49 8200000000 RGR TON GAP/ 07 310 01 0 9 S 1 2 49 80000~0000 G~ TON GAP! 07 310 0! 0 9 1 I 2 ~9 8400000000 STS~ TOH 07 000 O0 0 9 1. 1 2 79 8000000000 HTEN TOH LBF 07 000 00 0 9 i I 2 49 8000000000 AHT~ TOH bBF 07 000 O0 0 9 1 ! 2 49 8000000000 M~ES TOH OHMM 07 000 00 0 9 1 1 2 49 8000000000 MTEM TOH DEGF 07 000 00 0 9 1 1 2 49 8000000000 AMTE TOH DEGF 07 000 O0 0 9 ! 1 2 49 8400000000 DTE~ TOH DC/K 07 000 O0 0 9 1 1 2 49 8000000000 CTE~ TOH DEGF 07 660 21 0 9 ! ~ 2 49 9000010000 CCSW TOM 07 000 O0 0 9 I X 2 79 9000010000 HV TOH V 07 000 00 0 9 1 I 2 49 9000010000 RSP TOH NV 07 010 .01 0 9 ! ! 2 49 8000020000 SPA TOH MV 07 010 O1 0 9 1 ! 2 49 8800000000 SPAR TOH MV 07 .010 01 0 9 i I 2 49 8000000000 SPMV TOH ~V 07 010 Ol 0 9 1 1 '2 49 8000020000 SP TOH, MV 07 '010 .01 0 9 1 i 2 49 8800000000 ** DATR ** '** DEPTH = 4552.000 FEET' ** ,S TO, ,.,soo OoZ?o. 1 lo s.ooo CS,~TOH .179-500 DIFF,TOH . 050 TENS,TOH 1 15..000 MA IHV,TOH 0,,000 ICV,TOH 0 000 ~SMI.TOH 4.090 RS~N.TOM ~CA.TOH 6,.191 S~ST,,TO,H ,, 0 BMIN.TOH 4,,148 MCAt,.TO, 5.'086 RIRD,.TOH 36,575 IRDZ.TOH -28,.249 IRDP.TOH IRDN,mO, 1899,417 RIXD.TOH -.195.374 IXDZ..TOH -12,287'IXDP.TOH 'IXDN.,TOH 2006,612 ~IRM,,TOH 39.~92 IR~Z,.TOH -4{.3,41 IR~P.TOH I~M~.TOH 3~15.,864 ~IXM.TOB -13{.780 IXMZ,,TOH ',25,.,712 IXMP,TOM IXMN'.TO~ 3351.685 DCID,,TOH 0.,000 DCI~.~OB 0.000 IDQF TOH IMQW.TOH 2,000 DEQF,T(~H 7.,000 ~SFV,TOH ~1, o,785 SFVP':~OH SFV'~,TOH 1,{74 RSFC,,TOH 5 ,301 8FCP..TOH 1,2,240 SFC~.TOH DCSF.TOH 0.000 SFOF.T,OH 1:000 RSFB.TOH 5.566 SFBZoTOH 101,025 43 293 ,5,359 1894.657 202,34i 3308.172 304. i59 3i000 314 3.35 -0,031 -1.551 I,,5 ..Tame ~erificetion Llstlno chlumberqer A!as~a ComputinQ Center SrBP.TOH 544.500 XFOC.TOH 0.003 RITF.TOH 89.688 F?V~.TOH 0.021 IP$~.TOH 2.244 2IXP.TOH 2.254 INDB.TOH 3.748 15VS.TOH 4.699 IFRE.?OH 20 IIXD.TOH 6,871 IX~.TOH 150,875 )L~,TOH 10.594 SFV.TOH !9,781 SFbU.TOH 8.078 TTi.TOH 649.000 AMPt..TOH 32,031 TT.?OH 0,000 u?.?o~ 88,25o HTEN.TOH -323.000 R~TF.TOH 92,813 HV TOH 252,875 SPMV~TOH -571,000 DEPTH = B$.TOH 8.500 CS,TOH 2250.000 IHV..TOH 7,344 R~CA.TOH 6,1191 ~CAL,TOH 5,086 IRDN.TOH 1899.417 IXDN.TO" 2006.612 IR"~,.TO" 3315.~ '{XM~.TDH 3352, IMgF,~OH 0,000 SrVZ,TOH 1',371 DCSF.~OH 0,054 S~BP,?OH 544,000 XFOC.TO, 0,~! IPSD,'TOH 244 I.XP TOH ~',234 15V$..TOH 4.695 IFRE:?OH 20 ClMP,TOH 93,000 .~XP.TOH 6.87! iIXM,TOH 152,875 IL~,TOH {.0,586 SFbU. TOH TTliTOH 649, AMPb TOH RRFO.TOH RSPR.TOH RDIH.TOH RPSD.TOH IRMA.TOH VODC.TOH 1SVT.TOH DECb,TOH IFBA.TOH IDPH.TOH 2I~,TOH ClLD.TOM D~RA.TOH SFC.TOH ~FI, A.TOH TT2.TOH CBb,TOH CBSL,TOH RGR,TOH RHTE,TOH DTEM.TOH RSP.TOH 8P.TOH 4500,000 FEET TOD,TOH D~FF TOH ICY TOH 8ML, T TOH RIRD TOH RIXD TOH RIR~ TOH RI.XM,TOH DCID.TOH D£OF.TOH RSFC.TOH SFOF, TOH RRFO,TOH RSPR,TOH RDIH.TOH A,.TOH VODC,TOH 15VT',TOH FB .~TOH IDPH.TOH IIRM,TOH CILD.YOH D~RA.TOH SFC,TOH SFbA,TOH TT2.TOH CBb,TOH 1-MARm1993 11:58 0,131 ~FOC,TO~ 226,000 SPAZ.TOH 238.875 DIHV.TOH 1 . 864 EPSD. TOH 0.029 2IRP.TOH 4.418 IWF1.TOH 4.680 25VT.TOH 0 D~C$.TOH 0.000 IPBA.TOH 13.5~3 IMPH,TOH Bii3~5 IIX~.TOH 7 0 3 CILM.TOH 8 6 QLRA,TOH 5.2~1 CSFh..TOH 8.0 8 ITE~.TOH 485,000 TT3.TOH 0,3~8 T0,TOH 5 GR.TOH o.ooo ~:500000 SPA.TOH 412151245 -2.050 TB~S.TOH o.ooo $6'57~ B"IN.~OH IRDZ,TOH -1~5.]74 IXDZ,TOH 9.4,40 IRMZ..TOH -133,793 IXMZ,TOH 0,000 DCIM,'TOH 4 000 R.SFV,TOH 5:298 SFCP,TOH 0.000 RSFB TOH o.1~6 RrOC:TO~ 22~,000 SPAZ,TOH 24 ,375 DIHV,TO~ 1,859 EPSD..,TOH 0.019 2~RP..TOH 4,410 IWFi,'?OH 4.680 25VT.TOH 2 DEC~:.,TOH 0,000 IPBA,TOH 13.664 1M. PH",TOH 89*375 'IIX~,TOH 0:806 ObRA.T0.~ 5,2~1 CSF~.~OH 8.0 8 ,ITE .TOH 485,000 TT3,TOH 0.368 T0,TOH 0.05B -2.a6t 252.125 2.260 2.250 2.064 2.436 6144 1.000 0.813 16.621 94.313 27.297 123.688 92.313 4 O0 0.000 85.188 1~ o*142 0,125 0.000 804.000 3200.000 4 090 4.148 -28249 -1.2.287 -43 336 '25 605 0 04.1 21.774 12 239 5.574 0.060 -2.1861 254,625 ~.,0~4 2.'182 7312 1.000 10.742 '94.375 27.297 123,.688 92. RXFO.TOH SPAP,TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH S2I¥.TOH DER$.TOH CIDP.TOH IIRD.TOM IXD.TOH ILO.TOM SFB.TOH CSFA.TOH ITT.TOH TT4.TOB SRAT..TOM CBI..F.TOH STSG.TOH MTEM.TOH CCSW,TOH SPA~.TOH ETIM..TOM MARK.TOH B~NO.TOH IRDP.TOM IXDP.,TOM iR}~P,TOH IXMP,TOH IDQF,TOH SFVP.TOH SFCZ.TO~ SFBZ.TOH RXFO.TOH $PAP.TOH FTVP.TOM XPSD..TOH [RDA,TOH IWF2.TOH S2IV,TOH DERS.TOH CIDP.TOH IIRD.TOH IXD,TOH ILD.TOH 8FB.TOH CSFA,TOH ITT,TOW TT4, TOM PAGE: O. 1002. 3. 1. O. 2. 0. 73. 68. 145. 1~. 7. 1.23. 0. 445, O. 0. 92[ O. 96. 5. 1894, 202, 3308. 304. 31.4, -0 O, ool: O, 68, 145, 13, 19 029 000 797 [{54 029 O45 024 108 875 188 375 133 301 688 000 000 276 368 176 144 000 689 563 293 359 657 492 416 000 3O6 03! 547 O25 000 799 854 02.4 O.'{5 O83 12.5 188 3'75 O! 000 2'/6 IS ?are Verification bi chlUmher~erAlaSka Comp uting Center 1-~AR-1993 11=58 TT.TOH 0,000 CBSL.TOH 0.000 TTSS,TOH DT.TOH R8,250 RGR,TOH 79,625 GR,TOH BTE~.TOH 391.000 RHTE,TOM 5088.000 ~RES,TOH A~TE,TOH g2.8~3 DTE~.TOH 0.000 CTE~,TOH HV.TOH 249.375 RSP.TOH 545,500 SPA.TOH SPNV.T~H -571,000 SP.TOH -25.125 DEPTH 4400.000 FEFT TOD,TOH OIFF,TOH ICV.TOH SMbT.TOH RIX TOH RIRM,TOH RIXM,TOH DCID.,TOH DE~F,TOH RSFC.TOH SF~F,TOH RRFO,TOM RSPR.TOH R.DIH,TOH RPSD,TOB IRMA,TOH VODC,TOH ~SV~.~OH IDPH,TOH IIRM,TOH CILD,TOH DMRA TOH SF TOH SFL~.TOH TT2 TOH ebb TOH CSSL,TOH RGR,,TOH RHTE,,TOH DTE~.,TOH RSP, TOH SP,TOH 4300,000 FEET B$.TOH 8,500 CS.TOH 2244,000 THV.TOH 36,625 R~Ca.TOH 9.773 I~DN:TOH 189 968 IXDN,TOH 2006,995 IR~N,TOH 3317.141 IXNN,TOH 3353,622 I~QF,TOH 0,000 .TOH 0.024 s4 :ooo x oc. o,.ODS RITE TO. 90,313 FTVZiTOH 0.022 IPSD.TOH 2,264 2IXP.TON 2,22i INDB TOH 3,.758 IFR~.TOH · 20 C~MP,TOH 1~i,6~5 IIXD TOH Ib~,TOff 8,320 SFV,TOH 16,156 SrbU.TO~ 9.7'73 TT~,T0~ 664,000 R'~PL,TOH 30,047 TT,TOH 0 000 DT.TOH 96:625 .v.?o. :soo · * DEPTH = CS,?OH 2254,000 ~HV.~OH 79,875 R~CA,TOH 9,21,1 MCAL,TDH 8,695 I~DN,TOH IXD",TOH ~007,~78 IRMN,TO~ 3318.435 412151405 TIME,TOH -2.000 TENS.TOH 9.367 RSMI,TOH 0 B~IN.TOH 79,985 IRDZ.TOH -98,204 IXDZ.TOH 64.085 IRMZ,TOH -129.300 IX~Z.TOH 0.030 DCI~,TOH 0,000 RSFV,TOH 3,571 SFCP,TO~ 0,000 RSFB.TO~ 0.114 RFOC.TOH 236, 50 SPAZ,TOH 239,750 DIHV,TOH 1.8~4 EPSD,TOH 0.0 4 2IRP..,,TOH 4,398 IWFI,'TOH 4,672 25VT,TOH 0 DECS,TOH 000 IPBA, TOM 1.065 3,521 CSFL,TOH 8,961 ITE'~.'TO~ 468:000 TT3,TOH 3~5 T0,TOH ~"0 ~ TTSb.'TOH 85:500 GR,TOH 5068,000 MRES,.TOH ,0 00 CTEM.,TOH ~5 ,000 8PA,TOH 17,797 0.000 85.188 -0.142 109.813 0.000 799.000 3275.000 5 758 .210 : -43.38~ -25.712 0,~39 18. 48 12,239 10.633 0.~02 -2. 51 2.21! 6144 1 000 8,789 120.06.3 -6,203 102,.250 92.875 667,500 5 000 0:000 , :ooo - 143 625 CBL, F.TOM STSG.TOH MTE~.TOM CCSW.TOH SPAR.TOM ETIM,TOH MARK.TOB R$~N.TOH B~NO.TOH IRDP.TOM IXDP,TOH IR~P.TOM IXMP.TOH IDOF,TOH $FVP.TOH $FCZ.TOH SFBZ.TOH RXFO,TOH $PAP.TOH FTVP.TOH XPSD.TOH IRDA.,TOH IWF2.TOH S2IV,TOH DERS,TOH CIDP.TOH IIRD.TOH IXD.TOH 'ILD,,TOH SFB.TOH CSFA.TOH ITT,TOH TT4.TOH SRAT.TOH CBLF,,TOH $TSG.TOM CCSW,TOH SPAR.TOH TOD,TOH 412151565 TINE.,TOH 80t,~00 ~TZM.TOH DIFF,TOH -2,000 TEN$,TOH 300~ -. 00 MARK,TON ICV..TOH 25,922 RSNI,TOH : 7,352 RSNN.,TOH 8MLT,TOH 0 BMIN.,TOH 7,520 BMN'O,TOH RIRD.TOH 105,573 IRDZ,TOH 28,230 IRDP,TOH RIXD,TOH -88,672 /XDZ,TOM ~2,.322 IXDP.TOH RIRM..TON 96.079 IRMZ,TOH .-43.381 IRMP,TOH RIX~:TOH '.125,.182 IXMZ,TOH -25.667 PAGE: 20 0.368 176 92.813 6144 0.000 256.441 86.500 5.953 6.121 ]895.027 202.936 3310.113 306.437 0.000 314.278 -0.031 -1,547 0,034 1001.500 3,799 1..869 0.024 0,043 52 12 75 12.,.484 111,500 0t4 0.333 0,315 .176 92°563 6144 0,000 ,375 8 648 8 844 1895 388 203 982 3311 374 308 260 IS ?~pe Verification I.,lstlnq chlumberqer AlasKa Computing Center I~'MN TON DCIO.TOH IMQ~'TOH DEQF TOH · . SFVZ.TON RSFC.TOH DCSF.TOH SFOF.TOH SWBP.TON RRFO,TOH XFOC,TON RSPR,TOH RIT~,TOH RDIH,TOH f'TVZ.TON RPSD.TOH IDSD.TON IRNA.TOH 2lXP,TOH VODC.TOH INDB,?OH i5VT,TOH 15V$,TOH DECL,TOH IFRE,TOH IFBA,TOH CIMP.TOH IDPN.TOH IIXD.TON IIEM.TOH IXM.TOH CILD.TOH TLc.TOM DMRA.TOH SFV.TOH SFC.TOH SFLU,TOH SFLA.TOH TT1,TOH TT2,TOH A~P[..TOH CB~.TOH TT.TON CBS~.TOH DT,TOH RGR,TOH HTE~,TOH RH?E.TOB A~TE,TOH DTEM.,TOH HV,TOH RSP.TOH SP~V.TOH SP,TOH · * 4~00.000 FE~T DIFF,TOH ICV,TOH SM~T,TOH RIRD..TOH IHV.,TOH R~CA.?OH IRON,TON I~DN.,TO~ IMOF,TOH SFVZ,TOH DCSF,TOH SFBPvTOH XFOC.TOH R~TE,TOH FTVZ,TOH lPSD,.TOH 21XP,?OH iNDB,TOH 15VS,.~OH C{~P.TOH XD.~OH IIX~..TOH IL~,TOH 3354,914 0.000 1,373 o.082 544.000 0.002 90.938 0.027 2.24O .234 .787 4.684 2O 149.500 15.094 100.875 6.520 16.016 8.195 696.000 32.563 0..000 106.625 5.750 3~2.875 250,500 -571,000 DEPTH =. ., 8,500 2256,000 123,563 9.,.602 9,156 !900,.886 2007,76i 3319.o703 3356.853 0,000 1',37~ 0,04 544,000 0 005 0.,024 2,~40 0 4,680 2O 108'658 9!430 9 055 RIXM, DCID. DEOF~ RSFC,: SFQF, RRFO~ ,TOH ,TOH .TOH ,TOH ,TOH ,TOM .TOH RSPR,TOH RDIH.TOH RPSD.,TOH IRMA,TOH VODC,TOH 15VT,TOH DECh,TOH IFBA.TOH IDPH.,TOH CI~D.TOH DMRA.TOH 1-~AR-1,993 11:58 0.070 DC[M.TOH 0.000 RSFV.TOH 4.226 SFCP.TOH 0.000 RSFB.TOH 0.170 RFOC.TOH 200.250 SPAZ.TO~ 239,500 DIHV.TOH 1.859 EPSD,T~H 0.019 2IRP.TOH 4,430 IWF1,TON 4.680 25VT.TOH 0 DEC$,TOH 0.000 IPBA.TOH 6.539 INPH.TOH 144,625 IIXM.TON 155,625 CIL~.TOH 1.015 OLRA.TOH 4,]b4 CSFL.TOH 8. 80 ITEM.TOH 478.000 TT3.TOH 0,375 'TO,TOH 0..~00 TTSb. TOH 37. 44 GR.TOH 5072.000 ~RES,TOH 0.000 CTEM.,TOH ** 41.2152725 TIME,TOH ;~.950 TEN$,TOH ,844 RS~I,TOH 0 B~IN.,TOH 70.9~0 "9~,644 "IXDZ. TOH -129o459 IXMZ,TOH 0,059 DCI~,TOH o ooo' 3:838 0,000 RSFB,TOH 0,~90 RFOC,TOH 21~. O0 2 ,875 DIHV,TOH 1.864 0,019 2IEP,TOH IWFI,,,TOH IPBA,,TOH 08,~5 I~PH,TOH 5 IIXN.,TOH I :ooo ,.0~2 OhR. A,TOH 0.097 17.900 12.236 8.086 0.076 -3.025 252.875 2.045 2.416 6144 1.000 6.688 9.906 153.250 -10,719 122.000 93.500 697,000 4.000 0.000 46.844 -0,i42 112.,.063 0.000 ,. 797.000 31.00.000 7.OO8 7.293 -28.172 -~2 .315 -43 347 -25 620 0 095 237 9 563 0 093 2~3.-191 1.125 oo IDOF.TOH SFVP.TOH SFCZ.?OH SFBZ.TOH RXFO.TOH SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH S2IV.TOH DERS,TOH CIDP,TOH IIRD.TOH IXD.TOH ILD.TOH SFB.TOH CSFA,TOH ITT,TOM TT4.TOH SRAT.TOH CBLF.TON $TSG,TOH ~TEM,TOH SW,TOH ETI~.TOH MARK',TOH RSMN,TOH BMNO,TOH 'I. RDP:,TOH IXDP TOH IRMP~TOH IX~P,TOH 'IDOF,TOH SFVP.TOH SFC'Z.TOH SFBZ.TOH R. XFO.TOH &PA~.TOH XPSD,TOH IRD~.TOH IWF .,TOH $2I~,TOH DER .TOH CIDP.TDH IIRD.TON IXD,.TOH ILD,TOH '$FB.TOH PAGE: 21 0.000 314.221 -0.031 -1.542 0.031 .500 1001.797 1.850 0.014 2.049 0.053 4 152.750 136.875 66.188 6,422 9.875 12~.125 .024 480.000 0.779 0.375 176 144 0,000 576,514 86,313 7.074 6 723 1896 120 204 651 3313 305 309 578 0 000 314.,205 "0,,03! '1'.,5.42 loo 500 ,'797 1.859 0!029 2 029 0 029 188 '1~.1..,688 1.02,125 106,000 8,688 11',391 chl. um~erqer A18ska Computinq Center SFV.TOR 16.266 SFC.TOH SFLU.TOH 9,148 SFLA.TOH TTi.TOH 705,000 TT2,TOH A~PL.TOH 17.328 CBB.TOH TT.TOH 0,000 CBSh. TOH DT,TOH 110,625 RGR.TOH HTE~.TOH 400,000 RHTE.?OH A~TE.TO~ 02,313 DTEM,TOH HV,TOH 3?3.250 RSP.TOH SPEV.TOH -571,000 ** DF. PTH - 4~00,0 B$.TDH 8,500 TOD, CS,TOH 2232,000 DIFF. IHV,TOH 170,375 ICV. R~CA.TOH 9,375 SMLT. MCAL TOH 8,891 RIRD. IRD~:TOR 1901.621 RIXD.. IXDN,TOH 2009.295 RIRM. I~M~.TO~ 3321.626 RIXM. IXMW.TOH 3358.6~7 DCID. I~GF,TO~ 0,000 DEOF, SFV~.TOH 1,.368 RSFC, DCSF.TOH 0,058 SFOF, SFBP.,TOH 544,000 RRFO', XFOC.TOH 0,009 ~SPR, FTVZ,TOH 0,014 RPS~, IPSD T0~ 2,~60 IRMA, 2IXP:TO~ 2,~11 VODC, I~DB,TO~ 3,764 ~SVT, I VS,TOH 4,703 DECL, IFR~.,TO~ 20 IFBA, CI~ ,TON 107,063 IDPH., I~XD.TOH 8,906 IIR~. X~.,TOH 118,000 CILD, ~LM,TOH 9.,211 D~RA, SFV,TOH 16,234 SFC, SFLU,TOH 9. 11'7 SFLA TT1,TOH '738:000 TT2 A~Pb,TOM 2~. 500 TT,TOH :O00 CB$~ D? TOM 112,.375. RGR HTEN:TOM 396,500 RHTE A~TE.,TOH 91,]75 DTEN HV,TOH 249,375 RSP SPNV,TOH -571,,000 ** DEPTH = B$,TOH 8,500 C~,TOH 2736,000 ~HV,TOH 214.625 R~.~CA,TOH 9,164 O0 FEET TOH TOH TOH TOH TOH TOM TOB TOH TOH TOH TOR TOH TOH TOH TOH TOH TOH TOH 4000'000 F~jET DIF. TOH ICV., TOH SMLT..TOH 1-~AR-1993 11:58 3.783 CSFL.TOH 9.344 ITE~,TOH 488,250 TT3.TOH 0,240 T0.TOH 0.000 TTSL.TOH 74.500 GR,T~H 5100.000 MRES,TOH 0,000 CTE~,TOH 549.000 SPA,TOH -2~,453 412151885 -1,950 62,969 0 70,065 -99,225 53.219 -129,947 0.016 0,000 3.845 0.000 0,I02 231. 75 237,~00 1. 59 4.6~4 0 0,0~0 o 0 240 0 000 53 19 5096 ~00 0 00 -24 703 412152028 -1,900 80,563 0 TINE.TOH TEN$,TOH RS~I,TOH B~IN,TOH IRDZ,TOH IXDZ.TOh IR~Z.TOH IX~Z.TOH DCI~,TOH RSFV,TOH SFCP,TOH RSFB,TOH ~FOC,TO~ SPAZ,TOH DIHV,,TOH EPSO,,TOH 2IRP,TOH lWF1,TOH 25VT,TOH DECS.,TOH IPBA.TOH IMPH,TOH IIX~,,TOH CIL~,TOH OLRA,TOH CSFb.,TOH ITE~,TOH TT3,.TOH TO,TOM TTSLoTOH GR,TO~ ~RE$,TOH CTEM,TOH SPA,TOH TI~E.TOH TEN$.TOH RS~I,TOH B~IN.TO~ !09.188 93.813 702,000 4.000 0.000 9,250 !0.143 200.625 0.000 816.000 3050.000 6.367 7.043 -28.198 -12.230 -43.324 -25.510 5 1~,.235 .414 099 250.000 2.234 8 1.000 9,.336 8,469 108.,500 -2,404 1.09.563 94.1 5,.000 0,..000 63,000 -0,14,4 ,.000 661"000 3070.,,000 6,629 6,879 ITT.TOH TT4.TOH SRAT,TOH CBLF.TOH STSG.TOH ~TE~.TOH CC$~.TO~ SPAR,TOH ETI~.TOH ~ARK,TOH RSNN,TOH B~NO,TOH IRDP,TOH IXDP,TOH IR~P.TOH IXMP,TOH IDQF,TOM SFVP,TDH SFCZ.TOM SFBZ.TDM RXFO,TOM SPAP,TOH FTVP.TOH XPSD.TOH IRDA,,'TOH IWF2,TOM $2IV,TOM DER$,TOH CIDP,TOM IIRD,TOH IX.D..TOH IbD,~OH $FB,TOH CSFA,TOM ITT,.TOH TT4,,TOH $RAT.,TOH CBLF.,TOM STSG,TOH ~TEM,TOH CC$~.TOH SPAR:TOH ETIM,TOH MARK,TOM RSMN,TOM PAGE: 22 106,938 0.035 494,000 O.56~ 0.240 176 92.313 -368 O,000 736.495 86.188 6.973 7.203 896.852 1205.498 3314.580 311.465 135 -0.031 -1.547 0,031 1001,000 3,795 1.850 0.~19 2, 64 0.068 ,140 111 063 101~188 8 1 250 0.,047 519,000 0,350 0..240 176' 0.000 879,950 86,375 7.531 7.699 IS Tape Verification Listing chlumberger Alaska Computina ('enter IPDN,TOH IXDN,TON IX~N,TOH I~OF.TDH S~VZ.TO~ DCSF,TOH SFBP.TOH XFOC.TOH R1TF,TDH FTV~,TOH 2~XP.TOH I~R~,TOH IIXD.TO, IX~,TO~ I~,TOH SFV.TOH SFLU,TOH TT1.TOH A~PL,TOH TI,TOM D?,TDH HTEN.,TOH APT~,TOH Hr.?OH SP~V,TOH CS, ~CAL, IRDN, IXDN. SFVZ, DCSF, SFBP, XFOC, FTVZ, 2~X.P, DB, TOH TOH TOH TOH TO}{ TOH TON TOM TOH 8.b33 1901,988 ~009,295 3322,268 3360.088 0,000 1.368 0.021 544.000 0.007 91.000 0.021 2,260 2.211 3,787 4.695 2O 90,063 9,211 145,375 10,336 21,g38 i3,773 709,500 31,750 0 O0 419...~50 90,'750 -,000 DEPTH = 500 oI:ooo .000 25~,.188 902'72~ 010,062 ,384 0 O0 , :goo 0 o$ 0,021 2,234 4,684 2O RIRD.TOH RIXD.TDH RIRM.TOH RIXM,TOH OCID.TO~ DEOP,TOH RSFC.TOH SFOF.TOM RRFO.TOH RSPR.~OH RDIH.TOH RPSD.TDH IR~.TOH VODC,'roH 15VT.TOH DECL.TOH IFBA.TOH IDPH.TOH IIRN.TOH CILD,TON DMRA.TOH SFC TOH SFLA TOH TT2 TOM · CBb TOH CBSb TOH RGR RHTE.,TOH .DTEM.TOH RSP.,TOH SP.TOH 3900,000 FEET CV TOH SMLT,TOH RIRD,.TOH ..TOH R~XM~,TOH DCID,TOH DEOF.TOH RSFC,TOH SFOF,TOH RRFD.TOH RDIH,TOM RPSD,TOH iRMA,TOM VODC,TOH 15VT.,TOM DECb.,TOH IFBA..TOH ~ 'NAR-199.3 11:58 60.900 IRDZ.TOH -99,991 IXDZ.TOH 41.9~8 IRgZ.TOH -132.5 I IX~Z,TOH 0,042 DCI~,TOH 0.000 RSFV,TOH 3,435 SFCP.TOH 0,000 RSFB.TOH 0.200 RFOC.TOH 233,750 SPAZ,~OH 238.500 DIHV,TOH 1..864 EPSD.TOH 0,029 2IRP.TOH 4.410 IWF1.TOH 4.680 25V~.TOH 0 DECS,TOH 0,000 IPBA,TOH 10,023 IMPH,TOH 91,563 IIXM.TOH 102,625 CILM..TOH 1.061 OLRA,TOH .3 91 CSFL,TOH I ,156 iTE~,TOH 497,000 TT3,TOH 0.346 TO..TOH 0.000 TTSL,TOH 69,500 GR.,TOH 5116,000 ~RE$,TOH 0.000 CTEM.,TOH '~ll.500 SP~.TOH ', ,094 ,063 0 26 738 -10~ 723 686 -135 174 o 058 0,0~0 3,627 0.000 0,175 220,125. 237.750 1.859 0.,0i9 4,457 4.672 0 0,000 TIME.,TOH TEN$,TOH RSN.I,.TOH BMIN.TOH IRDZ,TOH 'IXDZ.,.TOH IRMZ,TOH 'IXNZ,TOH DC~,TOH RSFV.TOH ~FCP,TOH RSFB,TOH RFOC,TOH .$PAZ.TOH D'IHV.~OH .EPSD,TOH 2IRP,TOH IWF1,TOH 25VT.TOH CS.TOH -28.172 12.309 -25.b02 0.001 23.987 12,235 9,516 0.094 -3.414 251.750 6144 1.O00 11.102 6.875 96.688 -6.152 .563 2.500 714.000 0.000 77.313 -0.145 11~.500 .000 649:ooo ~ ~$o '28,249 '12.161. =43 384 -2~ {.80 0.081 -.3.,607 251..000 2 221 , 029' .455 61.44 .1.o0o IRDP.TOH IXDP.TOH IR~P.TOH IX~P.TOH ID~F,TOH SFVP,TOH SFCZ,TOH S~BZ.TOH RXFO.TOH SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH $2IV.TOH DER$.TOH CIDP.TOH IIRD.TOM IXD.TOH ILD,TOM SFB.TOH CSFA.TOH ITT.TOM TT4,TOH SRAT..TOH CBLF.TO~ STSGoTOM ~TE~ TOH CCSW~TOH SPAR.TOH ETI~.TOH MARK,.TOH RSNNeTOH BMNO.TO~ IRDP,TOH IXDP.TOH ,TOH 'i RMP TOH X~P. 'IDQF,TOH SFVP.TOH 5FCZ,TOH SFBZ.TOH RXFO.TOM SPAP.TOH FTVP,TOH XP$.D,TOH IRDA,TOH IWF2,TOH $2IV.TOH DER$,TOH CIDP, TOH PAGE." 1897.584 20b,393 3315.864 312.600 0.000 314.135 -0.031 -1.536 0,036 1001.000 3,795 1.859 0.019 2.064 0,063 llb 99.688 92.063 108.500 9,742 11.336 89.563 0.058 495.500 0,826 0,346 176 90,750 6144 0.000 1010,468 86.250 11,297 i1.,594 1897,584 206. 313.738 0..000 314,078 -0,03! -1,536 0.,031 oo : oo ?95 1,859 0.029 064 28 63,969 23 Tape verification bistl, ng chlumberqer Alaska Comp,itinq Center 1-~A~-1993 11.:58 CIMP.TOH ITXD.TOH IXM.TON ILP,TOH SFV.TON SPLII.TOH TT1,TOH ANP[..TOH TT,TOH DT,TOH HTEN.TOH AUTE.TOH HV,TOH SPMV.TO~ C8, IRDN, IX'DP, IMOF. S~V~, DCSF. SFBP, XFOC. RITE, FTVZ' IPSO. 2IXP,. IND., 15V'$. IFR~, IlXP. IbM, SFV. SFLU, TTI., AMPI,. T?, DT, HTEN, AMTE~ SP~V. TOH TON TOH TOH TOH TOH TOH TOH TOH TOH TOil T0H TO~ TOH TOH T0H TOH TOH TOH .TOH TOH TOH 60.969 4.563 140.750 16.281 29.688 17.656 681.500 32.781 o.000 103,563 389.250 90.125 249,375 -571.500 DEPTH = 8.500 ~792.000 299.000 9,070 8.523 1903,460 2010.446 3325.478 3362.681 0.000 1.378 0,029 s4 :.ooo O05 90,438 0,019 2.230 2.24O 3,773 4.684 2O 106.9~8 8,.203 225,0OO 9.271 1.8.453 1.0.063 s:soo 34.063 0.000 5OO ~00 249.375 -571.000 DEPTH = IDPH.TOH 15.125 IIR~.TOH 58. 81 CILD.TOH 65.000 D~RA.TOH 1.059 SFC.TOH 3.578 SFLA.TOH 17,656 TT2.TOH 471.500 CBb. TOH 0.382 CBSb. TOH 0.000 RGR.TOH 64,56~ RHTE.TOH 5088.000 DTE~.TOH 0.000 RSP.TOH 521.000 SP.TOH -50.000 3BO0.O00 FEET TOD.TOH 41215 87 DIFF.TOH -1~00 ICV,TO~ 111.500 SMbT..TOH 0 ~IRD.TOH 64.788 RIXD.TOH -100.554 RIRM,TOH 52.~5 RIX~eTOH '133. 3 DCID.TOH 0,~2.4 DEOF.TOH O, O0 ~SFC.,TOH 3.~3 SFOF.TOH 0:, 0 RRFO,~OH 0.I~5 RSPR,TOH 227, 5 RDIH,TOH 238.750 RPSD.TOH I 859 IR,A..TOH 0!~29 VODC..TOH 4 84 15VT..TO~ 4 DECL..TOH . IFBA..TOH 0.000 IDPH.TOH 9,547 IIR~,TOH 1~½.938 CIbDoTOH I ,875 D~RA,TOH 1.,001 SFC.TOH 3,906 SFbA,.TOH 10,570 TT2,TOH 493°250 CBh. TOH 0,360 CBSb. TOH 0.000 RGR,.TOH 5 R~TE..TOH 509]''281 .000 O~EM..TOH ,000 RSP.TOH 52~o500 SP.TOH -45.188 37oo.,ooo ** IMPH.TOH IIXM.TOH CILM.TOH QLRA.TOH CSFL.TOH ITEM.TOH TT3.TOH T0.TOH TTSb. TOH GR.TOH ~RES.TOH CTE~,TOH SPA.TOH TI~4E,TOH TENS.TOH RSMI.TOH B~IN.TOH IRDZ.TOH IXDZ.TOH IR~Z.TOH IX)~.Z,TOH RSFV',TOH SFCP,TO~ R&FB,TOH RFOC.TOH SPAZ.TOH DIHV,~OH EPSD..TOH RP.,TOH 25VT.TOH lPBA TOH IMPH~TOH IIXM,TOH CILM.~OH OLRA.TOH CSFS.TOH ITE~,TOM TT3,TO~ TO.'~OH TT~h,TOH GR,TO~ MRES.'TOH CTE~,TOH SPA,TOE 6.391 17.098 61.375 -6.285 56.563 93.375 681.500 4.000 0.000 63.969 -0,145 112.063 0.000 645.000 2870.000 7.160 7.359 -28.210 -12.'309 -4.3.384 -25.489 0.009 20.412 2,232 18.438 0.~83 -3. 71 252.000 2.211 ..234 .025 2,654 6144 1.000 9.344 '5,984 99,313 703 O0 .000 ~..000 0..~469 ~0.:147 000 IIRD.TO~ IXD..TOH ILD.TOH SFB.TOH CSFA.TOH ITT.TOH TT4.TOH SRAT.TOH CBLF.TOH STSG.TOH ~TEM.TOH CCSW.TOH SPAR.TOM ETIM.TOH MARK.TOM RSMN.TOH BMND.TOH IRDP.TOH IXDP.TOH IR~P.TOH IXMP..TOH IDOF.TOH SFVP.TOH SFCZ.TOH SFBZ.TOH RXFO.TOH SPAP.TOH FTVP.TOH XPSD.TOH I. RDA,TOH INF2.?OH S2IV.TOH DER$.TOH ClDP TOM 2XD.TOH ILD.TOH SFB..TO~ CSFA..TOH ITT,TO~ TT4.TOH SRAT,TOH CBLF.TOH STSC.TO~ ~TE~,TOH CCSW.TOH SPAR..TOH PAGE{ 24 58.063 219.125 15.367 9.867 56.594 0.069 465.000 0.789 0.382 176 90.125 6144 0.000 1138.805 86.125 8.852 9.023 1897.950 207.066 3318.435 314.877 0.000 31.4,078 0.,0~9 1001.000 3,795 1,854 0'.029 2.039 0.048 .100 104 688 121,813 266 94.500 0,080 493,750 0,821 0.360 ,1,176 9.500 6~44 0.000 IS Tase Verification Listino Chlumberqer Alaska Computin~ Center SS.TON 8,500 TOD.TOH C$,TON 2806,000 DIFF.TOH THV.TOH 340.750 ICV,TOH R,C~.TOH 9,500 SMLT.TOH MCAL.TOH 9,039 RIRD.TOH I~DN.TOM 1903,421 R. IXDoTDH IXDN.TON 2010.830 RIRM,TOH IP~K.TOH 3326.120 RIX~.TOH IX~.TOH 3363.135 DCID,TOH IMQF.TOH 0,000 DEOF.TOH SFVZ.TDH 1,373 RSFC.TOH DCSr,TOH 0,111 SF~F.TOH SFBP.TOH 544,000 ~RFO,TOH XFOC,TOH 0,009 RSPR.TOH R?T~.TOH 89.875 ~DIH.TO~ FTVZ,TOH 0.014 RPSO,TOH IPSD,TOH 2,225 IRMA,TOH 2IX~.TOH 2,2.50 V0DC,TOH I~DB,TO~ 3,768 15VT,TOH I~VS,TO~ 4,701 DECb,TOH I RE.TO~ 20 CIHP.TOH 140,375 IDPH.,TOH IIXD,TON 10,172 IIR~,TOH IX~.TOH 97,500 CISD,TOH .IL~:TOM 7.152 D~RA.TOH SFV.TON 11.531 SFC,TOH SFLU,TOH 6,340 SFLAoTOH TT] T0H 7~2.500 TT2,TOM A"Pb:TOH 31.'875 CBL,TOH TT T0H RGRoTOH HTE~ TOH 415,000 RHTE,TOH A~TE~TOH 88,688 DTE~,.TOH HV,TOH 249,375 RSP.TOH $~V,T0~ =571..,000 SP.,TOB ** DEPTH = 3600,000 FEET B$.TOH 8,500 TOD'TOH I~,TOH 2800,000 DIFF,TOH .TOH 3,2..'750 ICV,TOH IXDN..TOH 2011i.214 RIR~,TOH IRMN,TOH 33~7 406 RIXM,TOH IXMM,,TOH 3363,979 DCID~TOH I~F,TOH 0.000 DE~F,.TOH SF~Z,TON 1,377 DCSF,TOH ,025 RITE.TOH 8 4]8 RDIH,TOH FTVZ,TOH 0,024 RP~D.,TOH IPSD,TOH 2,221 IEMA.TOH 1-MAR-1903 11:58 412152416 TIME.TOH =1.850 TENS,TOB 126,435 RS~I.TOH 0 B~IN.TOH 91.187 IRDZ,TOH -95.274 IXDZ.TOH 83,46] I~Z,TOH -124,847 IXMZ.TOM 0.020 DCIM,TOH 0.000 RSFV,TOH 3,928 SFCP,TOM 0.000 RSFS.TOH 0,200 RFOC,TOH 2~0,~0 SPAZ,TOH ~37, 5 DIHV,TOH 1,864 EPSD.TOH 0.019 2IRP.TOH 4.~0 IWF1,TOH 4. 0 25VT.TOH 2 DECS.TOH 0,000 IPB~.TOH IIX~,TOH .40,250 C2.L~,TOH 1'..00~ OLRA,TOH 1 ITE~.,TOH 50 5~0 TT3.,TOH 0.{.6 T0,TOH .:ooo 813 GR,TOH 5112.0~0 ~RES,TOH 0.0 0 CTE~,TOH 5~7,~00 SPA.TOH -23, 56 ?1',8650 TEN$,TOH 141. 25 RSMI,TOH 1, 46 'IRDZ,.TOM -88, 01 IXDZ,TOH '125, IX~Z,.TOH 0.0 DCIM,TOH 000 RSFV,TOH .6 5 H , DZHV,~OH 1,859 FPSD,TOH 0,024 2IRP.TOH 640,000 3055.000 4.582 4.844 -28.t72 -12.161 =43.384 -25.465 0,079 13,264 12.232 9.625 0.098 2~3-6o7 1.i25 2.215 2.250 2.045 2.469 7312 1.O00 7.121 10.250 139 750 1.57. 0 000 67.688 1~0.,.'147 .2.063 0.000 641' 279~ 7 0 20 12 8 0 2 .000 ..000 .313 .5.47 .249 ..151 .393 .53.4 .029 .344 ,..23t ,219 ..079 .387 ,250 .205 ..240 ETIM.TUH MRRK,TOH RS~N.TOH B~NO.TOH IRDP.TOH IXDP.TOH fRMP.TOH IXMP.TOH IDOF.TOM SFVP.TOH SFCZ,TOM SFBZ,TOH RXFO.TOM SPAP.TOH FTvP.TOH XPSD.TOH IRDA.TOH IWF2.TOH S2IV.TOH DERS.TO~ CIDP.TDH IIRD.TOH IXD,TOH ILD.TOH SFB.TOH CSFA.TOH ITT.TOH TT4.TOH SEAT.TOM CBLF.TOH STSG,TOH ~TEM,TOM CCSW.TOH' .SPAR.TOM ETI~.TOH NARK.TOH RSMN.TOH B~NO,TOM IRDP.TOH ~XDP..TOH ~RNP,TOM I. XMP.TOH IDOF,TOH SFVP,.TOH SFCZ.TOH SFBZ.TOH RXFO.TOH SPA~..TOH FTV .?OH. XPSD.TOH IRDA.TOH PAGE: 25 1267.405 96,000 4,781 4.789 1898.684 207,628 3319.703 315,447 0,000 314,078 -0,030 -1,542 0.031 1000.500 3.793 1.854 0,029 2,035 0,048 180 139,375 121,875 98.250 7,125 11.~61 147.,000 0 91 0,6,75 0.346 .176 88.688 6144 0..000 1395,617 86.938 9,516 766 '20~.'544 332 .985 336,399 0,000 31.4,021 -0.031 -1.:542 0,034 000 t,854 0,019 IS Tape Verification Listing cblUmberger Alaska Computl. n~ Center 2IXP.TO~ 2,254 VODC,TDH IMDR.TDH 3,787 I5VT,TOH 1.5VS.TOH 4.691 DECL.TOH IFRE.TOH 20 IFOA.TOH CTMP.TOH 150,875 IDPH,TON ITXD.TOH 14.781 IIRM.TOM IX~.TOH 110.125 . CILD,TOH IL~.TON 6,629 D~RA,TOH SFV.TOH 18,391 SFC,TOH SFLU.TOH 10.195 SFbA,TOH TT].TOH 746,500 TT2.TOH A"Pt,.TOH 28.406 CML.TOM TT.TOH 0.000 CBSb. TOH D?.TOH 117.750 RGR.TOH HTEF'.TOH 399.250 RHTE, TOH APTF.TDH 88,188 DTEM.TOH HV.TOH 250.500 ~SP,TOH SP~V.TOH -571.500 SP.TOH ** DEPTH = 3500.000 FEET BS.TOH 8,500 TOD, CS TON , 2814,.000 DIFF,. ~CAL,.TOH 8,539 RIRD, IADN,TOH 1904,565 RIXD, IXDN TOM 201i,598 IRM~TO,H 3328,692 I~C'? TO, ,365.721 'DCID., I~F:TOM 0,000 DEQF, SPVZ.TOH 1.37, RSFC, DCS[ ,OH 0!088 SF F. XrOC.TOff 0 .006 SPR RIT$,TOH ~8 938 RDIH FTVZ.TOH 0,019 'IPSD,TOH 2,244 IRMA. 2IXP,TOH 2,240 VODC:. INDm,TOH 3,,78'7 15VS,,TO, 4~684 [FR£.TOH 2.0 CINP,TOH 264,87'5 IDPH IIXD.TOH 055 I~.,TOH 6,043 OffRl. SFV.TOH 14,555 SF5U.TOH 7,.156 TTI,TOH 732,000 TT2,, A~'PL.TOH 30,828 CB'b, T?.TOH 0,000 CB$5, DT,,TOH 112,438 RGR NTEN. TOH 406,500 A~T~:TOH 87.438 DTEN.. HV,TOH 248.250 TOH TOH TOH TOH TOH TOH TOH TOH TOH TO}{ TOH TOff TOH TOH TOH TOH TOH TOH .TOH ~OH TOH ?OH TOH TOH TOH TOH TOH TOH TOH 1-MAR=1993 11:58 4.480 IWF1.TOH 4.684 25VT.TOH 0 DECS.TOH 0.000 IPBA.TOH 6.2~0 I~PH.TOH 142.250 IIXM.TOH 163.750 CIbM.TOH 1.085 Ob~A,TOH 3.844 CSFS.TOH 9.469 ITE~,TOH 515.500 TT3.TOH 0.250 TO.TOM 0.000 TTSL,TOH 59.813 GR,TOH 5096.000 ~RES.TOH 0.000 CTEM.TOH 504.500 SPA.TOM -66.438 412152 M , TOH 155.125 RSMI.TOM 122, 44 IRDZ.,TOH "86.~38 IXDZ.TOH .108. 0 122.~I~ IRMZ..T H IXMZ,TOH O.ll9 DCIM,TOH 0,.000 RSF'V,TOH 4.395 SFCP,TOH g:O~0 RSFB,TOH 3' RFOC.,TOH 225.,~50 SPAZ,TO}{ 237,375 OIHV,TOH 1.859 EPSD..TOH 0.019 2IRP,TOH 4.469 IWFI.,TOH 4.680 25VT TOH 5,70 IMPH,.TOH 1~,875 IIX,.TOH 1 .500 CIb~,TOH 1 ~66 ObRA.TOH 4~ 28 CSFb,,TO, 7,359 ITEM.,TOH 498,000 0,]54 TO,TOH 0,'000 TTSL,TOH 73,875 5104.000 MRES.,TOH 0.000 CTE~,TOM 521,000 SPA,TOH 2.029 2.469 6144 1.000 6.621 750 -18.703 98.063 91.875 746.500 4.000 0.000 60.281 -0,148 111.563 0o000 i.000 .ooo 6.367 28 95 12.230 009 16.374 12.230 7.328 0.0'7~ .=3.49 .230 o 55 101,672 165,.~75 -11. 47 139,625 91.56~ 728,000 4.,000 0,,000 11.1.563 0.000 IWFI.TOH S2IV,TOH DERS.TO~ CIDP.TOH IIRD.TOH IXD.TO~ ILD.TOH SFB.TOM CSFA.TOM ITT.TOH TT4.TOH SRAT.TOH CBLF.TOH STSG.TOH MTEM.TOH CCSW.TOH SPAR.TOH ETIM.TOM MARK,TOH RSMN,TOH BMNO.TOH IRDP.TOH IXDP,.TOM )R~P.TOH X~P.TOH IDOF.TOM $FVP.TOH SFCZ.TOH $FBZ.TOH RXFO.TOH $PAP,.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWFI.TOM S'2IV,TOH DER$.TOH CIDP.TOH IIRD.TOM IXD,:TOH IbD.TOH $FB,TOM CS'FA,TOM ITT,TOH TO 8RA ,TOH CBbF.TOH $TSG..TOH ~TE~.TOH CCSW.TOH SPAR.TOM 2.064 0.043 252 160.375 141.875 67.625 6.105 10.016 105.500 0,102 516.000 0.667 0.250 176 88.188 6144 0.000 1523 899 85 688 7 531 7 750' 1899 208.416 3~21 626 17:162 0,000 314.021 -0.031 -1.547 0.031 1000,500 3,.793 1.864 0.024 2,029 0.092 . 60 1.7~,000 15 ,750 9,102 135,750 0..il. 4 495,.500 0 123 O~ 54 276 87,438 62.44 0.000 ?ave Verification Listing cblumberoer Alaska Computing Center SP~V.?OH -571,000 ** DEPTB = ES.TO[4 8,500 CS.TOH 2802.000 IHV.TOH 464.500 W~CA.TOH 9.023 ~CAS.TOH 8.469 I~DN.TOM 1904.889 IXD~.TOH 2012.367 IR~.TOH 3329°336 IX~N.TO~ 3367.2~5 I~OF.TOH 0.000 SFVZ.TOH 1.378 DCSF.TOH 0.02~ SrBP.TOH 544.000 XFOC,TOH 0,007 RITF.TOH 88.375 FTVZ,TON 0,0~9 IPSD.TOM 2,264 2~XP.TOM 2.215 DB,TOH 3.768 15VS.TOH 4.840 IFRE.TOH 20 C~P,TOH 158.875 I'IXD,TOH 16,t72 IX~.TOH 94,~8 IL~,TOM 6,i64 SFV.TOH 14,703 SFLU,TOH .8,305 IT~.TOH 731.000 A~PL:TOH 33,156 TT.TOH 0,000 DT.TOH 113,813 HTE~,TOM .401,500 A~TE,TOM 86~625 HV. TOH 249..375 SP~V:TOM "571,500 DEPTM =' BS,~OH 8.500 eS,TOM 2802,000 IHV.,TOH 505,500 R~CA.TO~ 9,2t9 ~C.AL.TOH 8.703 IRD~,TOH 190)..302 IXDN,TOM 201 ,654 IRMN ?OM 3330.624 :TOM 1,378 DCSF,TOH 0,035 SFBP,TOM 544,000 1-~AR-1993 11:58 SP.TOH -49.750 3400.000 FEET TOD,TOH 412152802 DIFF.TON -1,800 ICV.TOH 170.000 S~LT.TOi{ 0 RIRD.TOH 116,318 RIXD.TOM -85.916 RIR~.TOM 104,994 RIXM.TOH -122.138 DClD,TOB 0.032 DE~FoTOH 0,000 RSFC.TOH 3.821 SFOF.TOH 0.000 ~FO.TOH 0o[80 RSPR,TOH 232, O0 RDIH.TOH 237.~25 RPSD.TOH 1,859 IRMA.TOH 0.019 VODC.TOH 4,a06 15VT.TOH 4,684 DECL,.TOH IFBA.TO~ 0,00 IDP ~ 063 .IiR~'TO'M .TO. 15:875 C1bD..TOH 167.875 DMRA,TO~ 1..035 SFCoTOH 3,768 SF~A:,TOH 7,645 TT2,TOM 502.000 ~BS.TO~ 0..339 CBSL..TOH 0.000 RGR..TOM 84.125. RHTE,TOH 5100.000 o.ooo SP..TOH ,406 3300,0'00 FEET TOD~TOM 412152930 DIFF.,TOH 1 S~t,T..TOH 0 RIRD.TOH 89,051 RIXD,TOH -~4.526. RIR~,TOH 7.917 RfX~.TOM -130"607 DCID..TOM 0:067 DEQF..TOH 0.000 RSFC,TOM 4,79! SFOF.,TOH 0.000 RRFO.TOH 0,12.2 TI~E.TOM TENS.TOH RS~I.TOH B~IN.TOH I~DZ.TOH IXDZ.TOH IRNZ.TOH IXMZ.TOM DCIM.TOM RSFV.TOM SFCP.TOH RSFB.TOH RFOC,TOH SPAZ.TOH DIHV.TOH EPSD. TOH 2IRP:TO~ IWFI..TOH 25VT,TOH DECS.TO~ IPBA.TOH I~PH,TOH IIX~.TOM CIL~.TOH QLRA.:TOH c'sr.b,WOa ]TE~,TOH TT3.TOH TO,TOH TTS.L,TOH GR,TOM MRBS,TOH CTE~,TOH SPA,TOM TENS,TOH RS~I...:TOH B. MIN,TOH 'IRDZ,.TOH IXDZ..,TO~ IR~Z.,.TOM IXMZ,.TOH DCIM.,TOH 'RMFV,TOH 8FCP,TOM RSFB,'TOH RFOC,TOH 643.000 2905.000 6.328 6.613 -28.210 -12.190 -43.509 -25.465 0.124 16.536 12.232 523 -3.635 250,500 2.234 2.484 7312 1.000 6,,289 10.609 ~62..125 11.023 120,313 91.000 73~.000 ,000 0,000 84..625 1. 63 0.000 645,000 268~.000 .375 8.594 -28,172 -12.156 -43,384 '25.512 0,009 23.336 12.,231 5.309 0.053 ETIM.TOH MARK.TOH RSMN.TOH B~NO,TOH IRDP.TOH IXDP.TOH IRMP.TOH IX~P.TOM IDOF.TOH ~FVP.TOH SFCZ.TOH SFBZ.TOH RXFO,TOH SPAF.TOH FTVP.TOM XPSD.TOF IRDA.TOH IWF2.TOH S2IV.TOM DER$.TOH CIDP.TOH IIRD.TOH IXD.TOM ILD.TOH SFB.TOH CSFA.TOM ITT,TO~ TT4.TOM SRAT,TOH CBLF.'TOH $TSG,TOH MTE~,TOH CC$~.,TOH SPAR,TOM ~ARK,TOH RSHN..TOH BMNO,TOH IRDP.TOH XDP,TOH IXMP.TOH IDOF.T'OH ,TO~ SFBZ..TOH RXFO,TOM PAGE: 27 1653.322 86.563 5.445 5.660 190ii492 20 303 332 268 317.734 0.000 3~4.049 '0,030 '1.542 0.034 lO01.000 3.793 1.854 0.01.9 O29 180 147.125 61.781 5,953 10.328 130,750 0.126 500.750 0.781 0.339 t76 6144 0,000 81 620 1786i375 10 023 208 641 ..332~.55! 314.021 -0..030 '1",547 0.029 -I~ Ta~e Verification £,istino ;chlumberger Alaska Computing Center ×FOC.TOH ~TT~.TOH FTV2.TOH IPSD.TOH 2IXP,TON IND~,TOH 15VS,TOH IFRE.TOH CIMP,TDH I!XD TOH IL~.TOH SFV.TOH SFbU,TOH TT4,TOH AMPL.TOH TT.TOH DT.TOH HTEN.TO~ A~TE,TOH HV,TOH BM,TOH CS..TON IHV..TOH R~C~.TOH MCAL.TOH IRD~ TOM IXD~ TOH IRNN' TOH IX~ TOH IMOF TOH .TOH, SFBP, TOH RITE,TON FTVZ TOH IPSD:TOH 2.IXP.TOH INDB,TOM 15VS.TOH IF~.,TOR CI.~P,~OM I~XD,TOH I'X~.,TOH i~,TDH SFV,TOH SFbU TOH 'TT~:TOH ~Pb. TOH TT,TOH 0,003 RSPR.TOH 87.750 RDIH,TOH 0.021 RPSD.TOH 2.254 IRMA.TOH 2.221 VODC.TOH ~.777 15VT.TOH 4.6fl4 DECL.TOH 20 IFBA.TOH 112.875 IDPH.TOH 11.81] IIR~.TOH 156.250 CILO.TOH 8.859 DMRA.TOM 21,297 SFC.TOH 9.617 SFLa. TOH 732,000 TTI.TOH 28,344 C~6,TOM 0,000 CBSL.TOH 1~5,313 RGR.TOH 406,250 RHTE,TOH ~6.000 DTE~,TOH 249.375 RSP.TOH -571.500 MP.TOH DEPTH =. 3200,000 FEET 8,500 TOD.TOH 2812,000 DIFF.TOH 548.,000 leV TON 9,414 SM~T~TOH B,g3B ~IRD.TOH 1905.990 RIXD.,TOH 20i3 420 RZR~,TOH 333.1.:!845. RIX~,,?OH 3369 605 DCID, TOH 0,000 DEOr,T'O~ 1,373 RSFC,TOH 0,073 SFQF,TOH 544,000 RRFO,TOH 0,003 RSPR,.TOH 87,188 RDIH,.TOH 0,019 RPSD,,TOH 2,!15 IRMA,TOH 2, 54 VODC',TOH 3,' B3 15VT,.TOH 4.695 DEC.b. TOH 20 IFB.A,TOH .B75 iDPH,.TOH 1'~:766 IIR~.TO. 13~,750 CI[.D.,TOH ,414 DMRA.,TOH 13,031 SFC,TOM 7,383 SFL.A.TOH 765,000 TTI,TOH 28,766 CBb. TOH 0,000 CBSL,TOH 1-~AR-lg93 11:58 ~34.125 SPAZ.TOH 240.625 DIHV,TOM 1.859 EPSD.TOH O.0).q 2IRP.TOH 4.426 IWFI,TOH 4.680 25VT,TOH 2 DECS,TOH O.OOO IPBA.TOH 7.992 INPH.TOH 106.688 IIXM.TOH 127.500 CIbM.TOH 1.130 OLRA.TOH 4.7~5 CSFL.TOH 9.6 5 ITEM.TOM 500.500 TT3.TOM 0.339 T0.TOH 0.000 TTSS.TOH ?,.ooo , 500 SPA.TOM -44.594 412153058 TZME,TOH 'I .150 TENS.TOM 200: 50 RSMI,TOH 0 BMIN,TOM B7..42i IRDZ.,TOH -94,03 IXDZ,TOH 79,227 IRNZ.TOH '127,658 IXMZ,TOH 0,045 DCI~,TOH 0 ~00 RSFV,TOH 3~. 10 SFCP.,TOH 0,000 RSFB., TOH 23~!'!75 RFOC,TO~ 75 'SPA. Z.,TOH 237 50 DIHV.,TOH 1,859 EPSD,TDH 0,029 2IRP,TOH 4,445 .IWFi,TO~ 4,680 25VT.,TOH 0 DEC~,TOH 0,000 IPBA.TOH 12.;..516 INPH,TOH .313' 'IIXN,.TOM 134,875' CIb~..TOH 1,000 .TOH 7,875 TTE~,TOH 51q.500 0 255 TT3..,TO.H O,TOH o:ooo -3.498 254.250 2.254 2 225 :o55 2.377 7360 1. 000 8.852 6.398 112.750 -9.445 103.g38 90.313 734.000 4.000 0.000 76.188 -0.154 109.81.3 0.000 2542 00 .o.:.goo 5.871 6,066 -28.172 -12..242 -43 384 -25 512 0 142 14 805 1~.23i 547 0 O83 -3 414 250250 2.240 2.254 2.045 2.449 ~144 ½:ooo 461 363 89,625 764.OOO :ooo 000 SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF'2.TOH S2IV.TOH DER$.TOH CIDP.TOH IIRD.TOH IXD.TOM ELD.TOM SFB.TOH CSFA.TOH ITT.TOM TT4.TOH SRAT.TOM CBbF.TOH STSG.TOH MTEN.TOH CCSW.TOH SPAR.TOM ET'IM'.~OH MARK,TOH RSMN,TOH BMNO.TOM iRDP,TOH IXDP,TOM IR~P..TDH IX~P.TOH IDOF.TOH 8FVP.TOM SFCZ,TOH SFBZ.TOM RXFO.TOH MPAP,.TOM FTVP.,~OH XPSD,*TOM IRDA.TOH IWF2.TOH $2IV,TOH DERS,TOH ClDP.,TOH I, IRD,TOH IXD'*TOM IbD,TOH SFB.TOH CSFA..TOH ITT.TOM TT4.TOM SRAT.TOM CBLF,TOH 1001,000 3.793 1.864 0.019 2,029 0.034 252 125.063 112.938 84.563 7.$40 7.035 103,125 0.137 503.000 0,739 0.339 176 86.000 6144 0o000 1909,945 86,313 5,902 5.996 1901,253 208,980 3325.436 318,881 0,000 314.049 '0,031 O26 10 000 3.797 864 073 33,000 10,352 126,.875 0 49 0.705 0.255 ?ave Verlflcation List~no chlumheroer AlasKa ¢omputlnq Center D~.TOH 120.000 RGR.TOH HTE~.TOH ~3.000 RHTE.TOH A~TE.TOH 85.563 DTE~.TO~ HV,TOg 249.375 RSP.TOH SP~V,TOH -571.000 SP.TO~ BS,TDH CS.TOH {HV.TON RMCA.TOH NCAL.TOH I~DN,TOH IXDN,TOH I~OF.TOH SFUZ.TOH DCSF.TOH SFBP.TOH X Of.TO. RITF.TOH FTVZ.TOH IPSD,TOH 2/XP.TOH IND~.TOM 15¥~ TOH IFR~:TOH CI~P,TOH IIXD,TOR IX~ .TOB IL~TO~ SFV,TOH SFLU,TON TT,,TO~ DT,TOH HTEN,TOH A~TE,TOH HV.TOH SP~V,TO~ B$,TOH IC$',TOH HV.,TOH RMCA,TOH M. CAt,,TO~ I~D~.TOH. IXDN,TOB IRMN,TOH IXMN,TOH ** DEPTH = 3100.000 FEET 8,500 2806.000 591,500 10.133 9.797 1906,725 2014.187 3332.557 3369,605 0,000 1,378 0,021 544,000 0,002 86,625 0,029 2,234 .244 ~.787 4,680 · 20 133,000 9,,750 114,875 7,508 13 242 7 980 776000 28,000 0 000 120 625 4'~3.750 4,938 ,I~8,250 = 0,000 DEPTH = 8.,500 2~80,000 33,500 9,188 . 8,664 t907.093 2014,187 333~,771 337 ,549 TOD. DIFF. ICV. SMLT. RIRD. RIXD. RiR~. RIXM DCID DEOF RSFC SF~F RRFO. TOH TOH TOM TOH TOH TOH TOH TOH TOH TOH RSPR.TOH RDIH,TOH RPSD..TOH IRMA,~OH VODC.TOH 15VT,TOH DECL TOH IFBA, IDPH, IIRM, CibO,. DMRA, '$FC, SFLA CBSb. RGR RHTE DTEM RSP, TOH TOH TOH TOH TOH TOH T0H TOH TOH TOH TOH TOH TOH TOH 3000,000 TOD' TOH DIFF . RiRD RIXD RIRM, RIXM, DCID FEET TO~ 'TOH TOH 11:58 74,000 GR,TOH 5132.000 MRES,TOH 0,000 CTE~,TOH ~35,000 SPA.TOH 35.813 412153187 =1.750 216.875 0 79.132 -97.154 77.463 -126.207 0.044 0.000 3,581 0.000 0,188 236,250 237.375 1,859 0,029 4.4~5 4.676 0,000 7.918 i25,750 127,125 0.955 3533 8,906 540 000 0210 0 000 65 0~3 5112 000 0 0 5OO oo '938 -94..,i -.129,6 0,08~ TI~E,TOH TENS.TOH RSPI.?OH BMI~J.TOH IRDZ,TOH IXDZ.TOH IR~Z.TOH IX~Z,TOH DCI~.TOH RSFV.TOH SFCP.TOH RSFB,TOH RFOC.TOH SPAZ,TOH DIHV,TOH EPSD,TOH 2IRP,TOH 'IWF1,TOH 25VT.TOH DECS,TO~ IPBA,TOH IMPH,TOH IIXM,TOH CIL~,TO~ OLRA,,TOH CSFL,TOH ITEM,TOH TT3.,TOH T0,TOH TTSL,TOH GR,TOH MRES,TOH CTE~,TOH SPA,TOH T'IME.TOH TENS,TOH RSMI,TOH. BMIN,,'TOH IRDZ,'TOH IXDZ,TOH IR~Z..TOH I. XM 'TOH 76.56] -O.156 110..06] 0.000 646.000 2725.000 4.813 4.938 -28.172 -12.230 -43.384 -25 489 0~010 15,032 12.230 8.930 ,0,084 3.414 250,.875 225 23 .049 2,498 7.344 1.000 7.5t2 8.703 133..12) -5,..67 1.25, O0 0 000 69 .~ 8 110 063 0 000 275~.000 ' ,426 7.641 .1~'-172 STSG.TOH MTEM.TOH CCSW.TOH SPAR,TOH ETIM.TOH MRRK.TOH RSMN.TOH BMNO.TCH IRDP.TOH IXDP.TOH IRMP.TOH IXAP.TOH IDOF.TOH SFVP.TOH SFCZ,TOH SFBZ.TOH RXFO.TOH SPAP,TOH FTVP,TOH XPSD.TOH IRDA.TOH 'IWF2.TOH S2IV..TOH DERS.TOH C~DP,TOH i'IRD,TOH IXD,TOH ILD.TOH SFB,TOH CSFA.TOH ITT,TOH TT4.TOM SRAT.TOH CBLF.TOH STSG.TOH MTEM..TO~ CCSW,TOH 8P.AR.TOH ETIM.TOM MARK.TOH R.SMN.TOH O.TOH IXDP.,TOH IR~P.TOH IX~'P,TOH IDOF.TOH PAGE: 29 176 ~5.563 6144 0.000 2038.130 86.063 5.750 5.875 ]901,621 208,980 3326.076 319.033 0,000 314.022 -0.031 -1.536 0,034 oo :ooo 1,854 0.014 2,029 0,102 132 126,188 ! 50O 10,742 112,188 0,,160 54~,00,0 ,576 0.210 176 84~938 144 0,000 2165 031 86 000 10 734 11 203. 1902 356 209 205 3326 763 319.646 0,000 IS Ta~e Verification Listing ChlUmberger AlasRa Computing Center 1-~AR-1993 .11:58 I~OF,?OH 0,000 DEOF,TOH SFVZ,TOH 1,378 RSFC,TOH DCSF.TOH 0.016 SFOF.TOH SFBP,TOH 544,000 RRFO,TOH XWOC,TGH 0,003 RSPR,TOH RITE.TOH 86,125 RDIH,TOH FTVZ.TOH 0,017 RPSD,TOH IPSD.TOH 2.260 IRHA.TOH 2~XP.TOH 2,22! VODC.TOH INDB.TOH 3.783 15VT.TOH 15V$.TOB 4.691 DECL.TOH IFRF,TOH 20 IFBA,TOH CI~P,TOH ~6,750 IDPH,TOH IIXD.TOH 12,031 TIR~.TOH IX~.TOH 152.625 CILD.TOH ILM,TOH 8,461 DMRA,TOH SFV.TOH 25.609 SFC.?OH SFLU.TOH 12.359 SFLA.TOH TT~.TOH 785.000 TT2.TOH A~PS.TOH 21,734 CB5.TOH TT,TOH 0,000 CBSS.TOH DT TOH 125,625 R~R.,TOH HTEN:TOH 431.750 RHTE:TOH A. MTE.TOH 84,313 DTEM.TOH HV.TOH 248,250 RSP.TOH SP~V.TOH -570,000 SP.TOH ** DEPTH.= 2900,000 FEET TO. 8 500 oo. 2862:000 DZFF. HV.TOH 500 zcv. R~CA,TOH ~,:656 SMLT NCAL,TOH. 9,227 RIRD I~DN..TOH 1907,46~ RIXD 'IXDN,TOH ~015,062 RIRM I~N.TOH 3334.,.4~3 RI'X~ IXMN,TOH .3372 .198 DCID DCSF,?OH 063 SFOF XFOC.'TOH 002 RSPR RITE.TOH 85.563 RDIH, FTVZ.TOH 0,017 RPSD' IPSDoTOH 2,2~ IRNA. 2IXP.TOH 2e254 V0DC. INDB.TOH .3~777 ~SV? 15V$.TOH 4,695 DECb. IFRE,TOH . 20 IFBA C.~P,TOH 122,93B IDPH IIXD,TOH 12.43.0 IX~.?OH 126~438 CILD, SFV:TOH i5.961 SFC.. 0,000 RSFV,TOH 4,479 SFCP,TOH 0.000 RSFB,TOH 0.126 RFOC,TOH 188.375 SPAZ,TOH 240.375 DIHV.TOH 1.864 EPSI).TOH 0.019 21RP.TOH 4.418 IWF1.TOH 4.67~ 25VT.TOH DECS.TOH 0.000 IPBA.TOH 7.762 IMPH.TOH 111.688 II~.TOH 131.250 CIL~.TOH 1.111 OLRA.TOH 4,410 CSFL.TOH 1~.~2 ITE~.TOH 53 , 0 TT3.TOH 0.235 T0.TOH 0.000 TT$5.TOH 47.906 GR,TOH 5128.000 ~RES,TOH 0.000 CTEM,TOH 489.000 SPA.TOH -80.813 TOH TOH TOH ..']['OH TOB TOM TOH TO{'{ .TOH TO~ TOH TOH TOH TOH TOH TOH TOH ?OH TOH TOH TOH 412153439 TIME,TOH -1.650 'TEN$..TOH 249,500 R$~I,TOH 0 BMIN,TOH 69, 22 RDZ,.?OH -95.~ 43 IXDZ,'TOH 60,~35 'IRMZ,.?OH 74 IX~Z,TOH '120.i000 RSFV,TOB '028 DCIM,TOH 5,0~9' SFCP,TOH 0.0 0 RSF'.?OH 0.~6 RFOC.TOH 230, 5 'SPAZ,TOH 238.3~5 DIH'V,'TOH 1,8 9 EPSD,TOH IWF1,TO,H 4,676 25VT,,~OH 0 DECS,TOH 0',000 IPBA,TO~ 9,~1 i~PH,TO, 109. 0 IIXM,TOH 109.250 CIL~,TO~ 0.945 QLRA,~OH 4,988 CSFL.~OH 27.779 12.231 5.137 0.058 -3.414 253.750 2.250 2.221 2.049 2.455 6144 1.O00 8.555 6.543 118.063 -21.969 80.875 88.625 786.500 4 000 . 0.000 45.938 -0.159 109.375 0.000 631.000 2625..000 5.379 5,695 -28...172 .4~ .230 ,.451 -25,489 0..O29 ,.232 5,:074 0'-.058 '31387 1 5'00 252 240 .270 .,064 2.377 6t44 1.000 8i.125 7 906 . 146 ~50 SFVP.TOH SFCZ.TOH SFBZ.TOH RXFO.TOH SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH S2IV.TOH DER$.TOH CIDP,TOH IIRD,TOH IXD.TOH ILD.TOH SFB.TOH CSFA,TOH ITT.TOH TT4.TOH $RAT.TOH CBLF,TOH STSG.TOH ~TEM.,TOH CCSW.TOH $PAR,TOH NARK.TOH R. SMN.TOH 0MNO.TOH IRDP.TOH I,X. DP,TOH R~P..TO,H IX~P,TOH IDOF..TOH $FVP,TOH SFC'Z,TOH SFBZ..TOH RXFO..TOH SPAP.TOH FTVP.TOH XPSD..TOH IRDA.TOH IWF2,TOH S2IV.TOH DERS..TOH CIDP,TOH IIRD.TOH IXD. TOH $FB,TOH CSFA.TOH PAGE: 314.021 -0.031 -1.547 0.024 1001.000 3.795 1,850 0.024 2.079 0.058 240 1~8,750 114.b88 83.063 7.617 6.859 77.750 0,172 537.500 0.599 0.235 176 84,313 6144 0.000 0.,'394 22~5,,938 5.039 5.340 1903.092 209.431 3327.406 319.978 0,,000 314i021 '"0 031 '1' 542 o.gg i001., 0 3,795 1.859 0,0'24 2.035 0.048 84 105,,,625 100,125 '80.438 9, t48 3O ,IS Ta~e Yer{ileatlon LlstinO ~ehlumberger Alaska ¢omoutino Center 1-MAR-1,993 11i58 SFhU.TOM ~,809 SFLA,TOH TT1,TOH 7~ ,500 TT2.TOh AMPL.TON §.063 CBL.TOH TT.TOH .000 CSSLoTOH DT.TOH ~,688 RGR,TOH HTEN.TOH 4~ ,250 RHTE.TOH A~T~.TOH 3.750 DTE~,TOB DEPTH = 2800.000 FEET B$.TOH TOD, TOH C$,TOM DIFF.TOH IHV.TOH ICV.TOH RMC~.TOH SMLT.TOlt MCAL,TDH RIRD,TOH I~DN.TOH RIXD,TOH I×DN.TO~ RIR~,TOH IRMN.TOH RIX~.TOH IX~..TOH DC~O,TOM IM~F TON DEDF,TOH SFVZ~TOH RSFC.TOH DCSF.TOM SFQF.TOH SFBP.TOH RRFO.TOM XFOC.TDM RSPR.TOH RITE.TOM RDIH.TOM FTVZ,TOM RPSD,TOM IPSD,TOH 21XP.TO.H VODC,TOH IND~,TOH 1SVT.,TOH 15V~,TOH 'IFR~',TOH IFBA.,TOM CIMP,TOH IDP.H,TOM I'IXD,TOM IIRM.,TOH IX~,TOM CILD,TOH I~M.~OH DMRA,TOH SFV.TOM S'FC,TOH '$FSU..TOH SFSA,TOH TTI...TOM TTt,TOH AMpL.TOH CB .TOH C .S ,TO. A~T~,TOM DTEM.TOH HV,TOH RSP.TOH SPMV.TOH SP.TOH BS ~OH .C$ TOH I'H¥ TOH RMCA TOH ~Clb TO.H 8,500 2858,000 7~2,500 9,492 9.031 1907,879 2015,062 3335.699 33721847 0,000 1,378 0.,039 544,000 0,.006 85.063 0.014 2.254 .225 ].777 4.691 ~0 134,125 12,000 8~,.375 ,4.30 ~4,56 ,.00~ 44 0,0'00 129,375 429,750 83,000 250,500 '569,500 ** DEPTH '= 2700.000 FEET 8'500 TOD,T'OH 2868,000 DIFF..TOM 769.000 .ICV..TOH 9,766 SMLT:.TOH 9,352 RIRD..TOH 8.719 ITEk. TOH 569.500 TT3.TOH 7.238 TO.TOH 0.000 TTSL.TOH 79.438 GR.~O~ 5128.000 MPES.TOH O.000 CTEM.TOH 526.500 SPA,TOH -42.688 412153564 TI~E.TOH -1.650 TENS.TOM 267.750 RSMI.TOH 0 92.603 IRDZ.TOM -93.1~5 IXDZ.TOH 78. 6 IRMZ.TOH -122.749 IXMZ.TOH 0.067 DCIM.TO, 0.0~0 RSFV.TOH 3.9 I SFCP.TOH 0.0OO RSFB,TOH 0.168 RFOC,TOM 2~7,000 SPAZ.TOH 239.625 DIHV.TOM i.859 ~PSD,TOH 0.024 2IRP..TOH 6 25VT,TOH 2 DECS.TOH 0.'000 IPBA..,TOH 2 063 IIX~,TOH 411000 CIL~.TOH 048 OLRA,TOM ,875 CSFL',TOH . ,52] 'ITEM,TOM 558,500 TT3..TOH 0.254 T0.TOH 0.000 TTSL,TOH 74,750 GR,TOH '5128 000 MRES,TOH 0}.000 CTE)f,.TOH 527.000 SPA,TOH -42 531 88.063 729.000 4.000 0.000 80.563 -0.161 108,000 0.000 639.000 . 7.402 -28.~10 -12. 75 -43.461 -25.698 0.090 12. 2 7,676 0..081 -3,i91 253.000 2.23O 2.221 416 7360 1..O00 7,449 ,t1..71i 134.500 -8..266 124,938 87.625 808,000 4..000 0 00 -0,162 10'1.563 .000 628,000 2445,000 24.969 2~,656 -2 .2! 0 I1'T.TOH TT4.TOH $RAT.TOH CBLF.TOH STSG.TOH ~TEM.TOM CCSW,TOM SPAR.TOH ETIM.TON HARK.TOH RS~N.TOH BMNO.TOH IRDP.TOH IXDP.TOH IRMP.TOH IX~P,TOH IDQF.TOH SFVP.TOH SFCZ.TOH $FBZ.TOH RXFO.TOH SPAP,TOH FTVPoTOH XPSD.,TOH IRDA,TOM IWF2,TOH DERS.TOM CIDP.TOH IIRD.,TOM IXD,TOH ILD.,TOH SFB,TOM CSFA.TOH ITT.TOH TT4. TOH SRAT:TOH CBLF,TOH STSG..TOM ~TEM,TO.H CCSW.TOH SPAR,TOM ETIM.TOH MARK.TOH RSMN.TOM BMNO.TOH IRDP.TOM PAGE 0.184 547.500 0,654 7.238 ~76 83,750 ~144 0.000 2415.943 85.875 8.141 336 209.318 3328.638 320.356 0.000 '1,547 .026 000 1003i793 O, 2,055 0.019 138.500 23, 9,461 6 O0 0.'~54 ~. 76 0,000 2541.643 85,688 16.. 375 844 loi: TaPe Verification bisting ,chlumberger Alaska Computing Center IRD~.?OH {.908.255 RIXD.TOH IXD~I.TON 2015.722 ~IRM.TOH IRMa,TOM 3336.342 RIXH,TOH IXMN.TOH 3373.496 DCID,TOH IMQr. TOH 0.000 DEOF.TOH SFVZ.TOH 1.378 RSFC,TOH DCSF.TDH 0.005 SFOF.TON SFBP.TOH 544.000 RRFO,TOH XFOC.TOH -O,OOl RSPR,TOH RITE,TOH 84,688 RDIH.TOH FTVZ.TOH 0.02i RPSD,TOH IPSD.TOH 2.225 IRMA.TOM 2{XP.TOH 2.264 VODC,TDH IND~.TOH {,797 15VT.TOH 15¥~.TOH ..684 DECb.TOH C~MP,TOH 56,875 IDPH.TDH IIXD.TOH 10.641 IX~.TDH 130.375 CILD.TOH IbM.TO~ 15,211 DMRA.TOH SFV.TOH 48.5)1 ~FC,TOH S~bU.TOH 32.063 SFbA,TOH TTI,,TOH 829.000 TT2,TOH A~PL.TDH ]5,156 CB~,TOH TT,,TOH 0.000 CBS~.TOH Dm,TON 133.500 HTEN,~O~ 4~7,250 RdTE,TOH AMTF.TOH 8~,500 DTEM.TOH HV.TON 25 .500 RSP,TOH SPNV.TOH -569,5'00 'SP,TOH 26.00,000 FEET BS'.TOH ~,500 TOD,TOH C$.TOH 286 ,000, DIFF,TOH MCAL,TOH 9,047 RIRD TON IRDN.TOH 1908,565 R~XD:TOH 2XDN..TON 2016.106 RiRM'.TOH IRMN,,TON 33.36.985 RIXM,~OH IXMN.TDH 3374 794 DCID.TOH I~OE.TOH 0:000 DEOF,TON SFVZ.TOH 1,378 RSFC TOH DCSF.TOH 0,074 SFOF:TOH SFBP.TOH 544,000 RRFO,TOH XFOC.TON 0.005 RITE.,TON 83..813 RDIH,TOH FTVZ.TOH 0,0]9 RPSD,TOH IPSO.TOH 2,270 2IXP,TOH 2.205 VODC,TOH iNDB.TOH 3,787 1. SVT..,.TO~{ 15VS.TOH 4,68.4 DEC~..TOH IFRE.TON 20 IFBA.TOH CI~P.TOH 150,250 IDPH.TOH 1-MAR-1993 11:58 100.406 IXDZ.TOH 12,145 IRMZ.TOH ] 32.534 IXMZ,TD~ 0.042 DCTM.TOH 0.000 RSFV.TOH 3,262 SFCP,TOH O.000 RSFB.TOH 0,~il RFOC,TOH o 0.024 2IRP.TOH 4.449 IWF! ,TOH 4.691 25VT,TOH 2 D£CS.TOh 76.938 CIbM.TOH 1.111 OLRA,TOH 3,2 1 CSFL,TOH 16.828 ITEM,TOH 568.000 TT3,TOH 0,233 T0.TOH 0,000 TTSb,,TOH 35,~25 GR.TOH 5124, O0 MRE$,~OH 0,000 CTEM.TOH 530,~0 SPA.'OH -39. 5 412153816 -t,600 3O5.500 -91.,I 97, 0.01 3 28.3 OiOC:O 0 1~:0 252 .25~0 238, 125 1',864 0,019 4.406 4,680 2 0,000 6.457 TIHE..TON TEN$.TOH RSMI,TOH B~IN,TOH IRDZ,TOM IXDZ.TOH 'IRMZ,TOH DCI~,.TOH RSFV,TOH SFCP.TOH RSFB,,TOH RFOC,TOH '$PAZ,TOH DINV'TOH EPSD:TOH 2IRP,TOH IWFI..TON 25VT TOH DECS:TOH IPBA. TOH I'MPH:TOH -12.282 43.393 22s.4 s 0.009 51.407 12.232 5.766 0.058 -3.164 251 000 22244 2.254 ~.029 2.377 7360 1.000 17.563 -11,406 31,156 BT.000 ~30..500 4.000 0.000 41,563 -0,164 107,063 0o000 631, O0 00 71 '28'*')76 -12, 10 25,558 0,046 12.705 232 ,0.090 . 3,275 000 2.215' 2.025 2,406' 7344 1,000 6~652 IXDP.TOM IRMP.TOH IX~P.TOH IDOF.TOH SFVP.TOH SFCZ.TON SFBZ.TOH RXFO,TOH SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOM S2IV.TOH DERS.TOH CIDP.TOM IIRD.TOH IXD.TOH TbD.TOH SFB.TOH CSFA,TOH ITT,TOH TT4.TOH SRAT.TOH CBLF.TOH STaG,TOM MTEM.TOM CCSW.TOH SPAR.TON ET'IM.,TOH HARK.TOM R$MN,TOH BMNO,TOH I, RDP,TOH IXDP,TOH IR~P.TOH IXMP,TON IDQF,~OH $FVP,TOH SFCZ,TO~ SFBZ,TOH RXFO.TOH $PAP,TOH F?VP.TOH XPSD.TOH IRDA..TON IWF2,TOH $2IV,TOH DERS..TOH CIDP.TOH IIRD,TOH PAGE: 32 209.996 3329.336 320.545 0,000 314.049 -0.030 -1.547 0,01.9 1001.500 3.797 1.859 0,024 2.064 0,053 236 71,000 7~.375 93.875 12,984 7.504 59.406 0.209 575.500 0.709 0,233 176 82,500 6144 0,000 5.293 5,504 1904.155 .209,544 3330,561 320,545 °°° 078 547 0,029 1001,500 3 O! 0,024 2,078 0.0'39 154, 196 750 136.000 IS Tape vertflcation Listing chlumberger AlasKa Computing Center TXn. TOH 12.258 IIRN.TOH I'X~.TOH 86.3,3 CILD.TOH IL~.TOH 6.477 D,~RA.TOH SFV TO, ~0.9~4 S~U:TO~ 7.2~9 SF[.A OH TT,.TO, 790.500 TT2OH:~ A,PL.TO, 28.000 CB~.TO~ T',TOH O,OO0 CBSb,TO~ DT.TON 122.625 RGR.TOH H,E~.TO, 4,,.250 ,HTE.TOH A,T~.TO, ,,.750 DTE~.TOH HV.TOH 248.250 RSP.TOH SPMV.TO, -570,000 SP.TOH ** DEPTH = 2500.000 FEET RS.TOll 8.500 CS.TOH 2a50.000 IHV.TOR 856,500 REC~,TOH 9.344 NCAL.TOH 8.852 ZRDN,TOM 1.909.]02 IXDN,TOM 2016,491 IRMN.TOH 3337.628 IX~r. TOM 3375,444 IMOF.TOH 0,000 SF'VZ.T~H 1'.'378 I')CSF,TOM 0,012 SEBP..TOH 544,000 XFBC..TOH 0.00~ RITE.TOH 83..500 FTVZ.TOH 0.024 IPSD..TOH 2.22! 2 x,p. oH 2 , 6o INDF.TOH 3:83 ~SVS..TDH 4'691 IFR~.TOH CI,P.,OH 13.~. ~50 IIXD.TOH .1 ~ 30 ~X~,TOH I! ,.938 IL~.TOH ?,496 SFbU'.~0H · 6,25 TT~.?OH 799,500 A~Pb..TOM 32.,8~3 TT..TOM 0.000 DT..~OH 123,375 HTE~!.TOH 4~I,750 APT~,TOH .06~ HV,TOM SP~V,TOH 70,000 TOD.TOt1 DIFF.TOH ZCV.TOM SMST.TOH RIRD.TOH RIXO,TOM RIRM,TOH RIXM.TOM DCZD.TOH DEOF,TOH RSFC.TOH SFOF TOH RRFO TOH RSPR TOM RDIH TOM RP~DTOH IRmA T'OH VODC.'TOH 15V?,TOH DEC~,TOH IF'BA,~OH IDPH,TOH ~IRN,TOH. CZLD,TOH DMRA.TOH SFC,TOM SFLA.TOH TT2,TOH CBL.,TOH CBSb,TOM RGR.TOH RHTE..TO.H DTEM,TOH RSP TOM 1-MAR-J993 ]l:58 145.500 TIX;4.~OH 156,250 CIL~.TOH 1.012 OLPA.TOH 3,240 CSFL,TOH 6.574 ITEM,TOH 545.500 TT3.TOH 0.650 TO.TON 0,000 TTSb,TOH 55,375 G~.TOH 5116.000 MREM.TOH 0.000 CTE~.TOH 530.000 SPA.TOH -39.185 4,12153942 -1.600 321.500 0 94.411 -89.761 77.953 -125.914 0.114 0.000 4.301 0.000 0.131 .500 1,854 0.0~9 4,4 7 4,660 2 0,)00 12~ ''02 . 14~, 175 ~71 4 ~38 10 t13 543 iO0 0 0 O0 48 56 5136 O0 0 000 49~ 000 -76 688 TIME.TOH TENS.TOH RS~Z.TOH BMIN.TOH IRDZ.TOH ~XDZ,TOH IRMZ,TOH ZXMZ,TOH DCI~,TOH RSFV,TOH SFCP.TOH RSFB. TOH RFOC:TOH SPAZ,TOH DIHV,TOH E.PSD T0H ~IRP:TO.H 'IWF1,TOH 25VT,TOH DECS,TOH IPBA TOH I~PH.:TOH IIX~,TOH C~L~,TOH QbRA.,TOH CSFb,TOH ITE~.~.TOH TT3,TOH TO',TOH TTSL',TOH GR..TOH MRES,'TOH CTE~,TOH $PA,TOH 11.570 154.375 -i.287 138.500 86.063 790.500 4.000 0.000 64.063 0.165 ~6.563 0.000 637.000 2425.000 7.918 8.289 -28.172 -12.230 -43,384 -25.602 0 072 .232 ..057 =3..19t 251,625 2.221 2.250 2.055 2..396 7360 1,000 7..555 8.336 133,, ~375 -'16 656 103, 813 85 625 80i 000 4..000 O, 000 49. 28 ! -o 0 '000 IXD.TON ILO.TOM SFB.TOH CSFA.TOH ITT.TOM TT4.TOH SRRT.TOH CBLF.TOH STSG.TOH ~TEM.TOH CCSw.TOW SPAR.TOH ETI~.TOH EARK.TOH RSMM.TOH IRDP.TOH IXDP.TOH IR~P,TOH IX~P.TOH IDQF,TOH FVP.TOM ~FCZ..TOH SFBZ,TOH RXFO,TOH SPAPoTOH FTVP,TOH XPSD.TOH IRDA.TOH ZWF2,TOH $2IV.TOH DERS'.TOH CIDP,TOM IR.D.TOH IIX. D.TOH I~D.TOH S.FB.,TOH CSF.A,TOH ITT..TOH TT4'TOH SRAT:TOH CBL'F.,TOH STSG.,TOM MTEM.,TOH CCS'W..TOM SPAR.TOM PAGE: 81. 6. 11. 152. O. 546. O. O. 81. 6 O. 2793. 85, 10. 10. 1904. 209: 33311 320 0 314. ~0, ¥.: 1003.* 1. O: 2. O. l o' 125, 66. 6. 7. O. 33 563 395 047 000 22! 000 7O8 65O 176 75O 144 000 164 625 078 375 196 544 845 734 000 078 03.1 547 026 5OO 797 859 O24 0.35 068 156. 625 125 938 938 000 766 261 000 ** DEPTH = 2400.,000 FEET ** IS Tare verification Listing chlumberger Alaska Computin~ Center 1-MAR-1993 11:58 B$.TOH 8.500 TOD.TO)! CS.TOH 2856.000 DIFF.TOH THV.TOH 902.000 ICV.TOH R~C~.TOH 9,320 8MLT.TOH ECAL.TOH 8.820 RIRD,TOH IRDN.TOH 1909,302 RIXD.TOH IXDN,TOH 2016,875 RIR.4.TOH IRMN.TOH 3338,9~6 RIXM.TOH I%MN.TOH 3376.094 DCID.TOH I~QF.TOH 0,000 DEQF.TOH SFV~,TOH 1.37~ RSFC.TOH DCSF,TOH 0.0]0 SFOF.TDH SFBD,TOH 544,000 RRFO,TOH X~OC,TDH 0.007 RSPR.TOH RIT~,TOH ~2,750 RDIH,TOH FTVZ,TOH 0,019 RPSD,TOH IP$~,TOH 2,~40 IRMA.TOH 2~XP.TOH 2.244 V0DC..TOH I~JDB,TOH 3,777 ~.SVT,TOH ~SV~.TOH 4,684 DECS,TOH IFRE.TOH ~0 IFBA.TOH CIHP.TOH 108.125 IDPH.TOH IIXD,TOH 10.055 IIR~,TO~ { X~,TOH 156,875 CILD,TO~ bE.TO, 9.141 DMRA.TOH SF¥,TO, 16..~I~ 8FC,TO, SFLU,TOH 13: SFLA.TOH TTI,,TON 795,500 TTI.TOH A~PL,TOH 34,031 CB ,TOH TT,TOH 0,000 CB85. TOH DT.TOH 121,500 RGR:TOH HTEN,TOH 438,750 RHTE,,,TOH ANTE.TOM 80,625 DTE~.TOH Hv,TOH 249,375 RSP,.TOH SPMV,TOH -570,000 SP.TOH ** DEPTH - 2300.000 FEET' BS,TOH 8,500 TOD,TOH CS,TOH 2864,000 DIFF,TOH IHV,TOH 948,000 IC~,,TO~ RMC~.,TOH 9,813 SML~...TOH ~CAL,.TOH 9,414 RIRD.TOH I~DN,TOH 19.1.0.038 RIXD.,TOH IXO~.TOH 2017,2.59 ~{RM,TOH IR~..TOH 3339 560 ,IXN.TOH IX~N,TOH .3377~394 DCID,TOH I~F,TOH 0,000 DE~F,TOH SFVZ.TOH 1.378 RSFC.,TOH DCSF..TON 0,042 'SFOF,TOH SFBP,TOH 544,000 RRFO.TOH XFOC TOH 0,006 RSPR,TOH RIT~:TOH 82,000 RDIH,.TOH FTVZ,TOH 0,0~9 RPSD,TOH IPSD,TOH 2,260 IRBA,TOH 412154067 TIME.TOH 1.550 TENS.TOg 3~O.000 0 BMIN.TOh 72.034 IRDZ,TOH -97.~5~ IXDZ.TOH 54, 45 IRgZ,TOft -129.897 IXMZ.TOH 0.044 DCIM.TOH 0.000 RSFV.TOH 2.538 SFCP,TOH 0,000 RSFB.TOH 0,205 RFOC,TOH 224.000 SPAZ,TOH 239.125 DIHV,TOH 1,B59 ~PSD,TOH 0,024 2IRP,TOB 4,430 IWF{,TOH 4.680 25VT,TOH 0 DECS,TOH 0.000 IPBA,TOH 8,797 INPH,TOH 103.438 IIXg..TOH 117.188 CIL~,TOH 1.071 ObRA.,TOH 2.512 CSFL.TOH 11.227 ITE~,TOH 540,000 TT~. TOH 0,297 X :TOH 0,000 TTSL,TOH 67,500 -GR,TOH 5136,000 MRES,TOH 0.000 CTEM,TOH ~15,000 SPA TOH 54,688 412154194 TINE'TOM . 500 TENS,TOH IEDZ,TOH ;90'478 IXDZ.TO~ o2 996 -125']65 IX~Z,TOH 0.046 DCI~.TOH 0.000 RSF¥,TOH 3,338 ~FCP,TOH 0.0~0 RSFB,TOH 0,1 2 ~FOCo?OH 23i.,]'75 SPAZ,,TOH 237,37~ DIHV,TOH 1.85 EPSI.).TOH 0.024 635.000 2295.000 8.789 9.000 -28.210 -12.242 -43.393 -25.6O2 0.158 18.204 12.234 10.063 0.098 -3,080 252,250 ~,254 2,254 2.068 2.416 6144 1.000 9.242 6,37! ~09.313 12.078 72..~50 85.000 1..000 794.000 0.000 67,.438 1~0 .168 0,000 628..000 s ::ooo 820 6 922 -12..269 -43.461 2 . 50 2.~50 2. 25 ETIM.TOH NARK..TOH RSkN.TOH BMNO.TOH IRDP.TOH IXDP.TOH IRMP.TOH IXMP.TOH IDOF.TOH SFVP.TOH SFCZ.TOH SFBZ.TOH RXFO.TOH SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH S2IV,TDH DERS.TOH CIDP.TOH IIRD.TOH IXD,TOH ILD,TOH $FB,TOH CSFA.,TOM ITT.TOH TT4 TOH SRAT.:TOH CBLF,TOH STSG.TOH MTEN'TOH CCSW.TOH SPAR.TOW ETIM.TOH MARK.TOH RS~N.TOH BMNO.TOH IRD. P.TOH IXDP.TOH IRMPoTOH IX~P.TO~ IDOF.TOH $FVP,TO~ SFCZ.TOH $FBZ.TOH RXFO,TOH SPAP.TOH FTVP.TOH XPSD.TOH IRDA,TOH PAGE: 29]B,590 85.438 10.891 1904,8B9 209.770 3333.128 320.796 0.000 314.078 -0.031 -1.547 0,034 1001.500 3,797 1.864 0.024 2,045 0.083 100 113.625 102.688 99,375 8.523 11,906 89,000 0,246 534.000 0.71.3 0,297 80,625 6144 0.000 86,375 5,750 . 209.936 3333..771 0 o:g 1001 500 0 ,,02~ 34 Tame verification Llstinq ehlumberQer Alaska Computtnq Center 1-MAR-1993 ].1:58 2IXP.TOH 2,215 VODC.TOH IND~.TOH 3.826 1.5VT.TOH 15VS.TOH 4.695 DECh,TOH IFR~,TON 20 IFRA,TOH C~P,TOH 157.875 IDPH.TOH I~XD,TOH 12,891 IIR~.TOH IXM.TON 153,125 CILD.TOH Tt, M.TOH 6,281 DM~A,TOH SFV.TOH 9.633 SFC,TOH SFLU.TOH 6.230 SFLA.TOM TT~.TOH 855.500 TT2,TOH A"PL.TOH 23.891 CBL,TOH TT.TON 0.000 CBSL.TOH DT.TOH 132.375 RGR,TOH HTEN,TOH 446.500 RHTE.TOH A~T~.TOH 80,125 DTEM.TOH HV.TOH 250,500 RSP.TOH SP~v.TON -570.000 8P.TOH 4.410 ~NF1.TOH 4.684 25VT.TOH 2 DECS.TOH 0.000 IPB~,TOH 6,434 IMPH.TOH 1,50,000 IIX~,TOH 156,625 CIL~,TOH 0.984 OLR~.,TO~ 3,295 CSFL,TOH 6.211 ITEM,TOH 587,000 TT3,TOH 0.106 TO.TOH 0,000 TTSL,TOH 53.469 GR,TOH 5144.000 ~RES.TOH 0.000 CTEM.TOH 19.500 SP~.TO~ 50.031 ** DEPTH ~ 2200.000 FEET BS,TOH RMCA.TOH MCAL.TOH IRDN.TOH IXDN.TOH IXMN~TOH IMQF,TOH SFYZ,TON DCSF,TON SFBP,TOM XFOC,TOH RITE.,TOH FTVZ,?OM 2IXP,~OH ZNDB.TOH 15¥~,TOH IFR~,TOH C~NP.TOH IIXD,'TOH XX~.TOH ILP,?0H 8FV.,TOH A~PL,TOH TT,TOH DT..TOH HTEN,TOH A~T~,TOH HV,TOH. .500286 ,000 995,500 9.664 ~91~ '234 .776 40,849 3378.044 0,000 ~,378 0.095 544 000 0 005 81 563 0,01 ~ 2 244 2 234 3 777 4.680 20 129.750 8 375 7 ~3 5 445 854 000 20 0 000 143,.875 .445,500 79,438 248.250 TOD.,TOH DIFF,TOH ICV.,TOH 8~LT.,TOH RIRD,TOM. RIX. D.TOH RIRM.TOH RIXM.TO'M DCID.TOH OBQF,TOH RSFC,TOH SFOF,TOH RRFO.TOH RSPR,TOH RDIH..TOH RPSD,TOfl ZRMA, TOM VODC:TOH iSVT,TOH DECL..TOH FBA,TOH IDPH,~TOH IIRM.'TOH CILD.TOH DMRA ~OH 8FC TO.H 8FLA:TOH TT2 TOH CSh TOH CGSL TOH RGR TOH R.HTE'TOH DTE~ TOH RSP, TOH 412~54319 TIME.TOH 1.500 TENS,TOM 380.500 RS~I,TOH 0 BMIN,TOH 71.6~9 IRDZ.TOH '99.'5 4 IXDZ.,TOM 74.340 'IR~Z,TOH "126,934 IXMZeTOH 0 ~ DCI~, ,' 09 TOH O: O0 RSFV,TOH 5.450 SFCP TOH 0.000 RSFB~TOH .102 RFOC TOH 23 ,875 SPAZ:TOH 240,250 DIHV.TOH 1.859 EPSD,TOH 0,029 ~IRP,TOM 4 445 WF1,TOH 4~680 ~5VT.TOH 2 OEC$,~OH 0..000 IPB.A,TOH ~.758 iMPH,TOH 22,438 I'IXM.,TOH '~16,,688 CILM,.IOH 0,900 OLRA.TOH 5. TT3~TOM 0..8~6 TO.TOH 0.0 0 TTSL,TOH 66...~3 GR.TOH 5144. 0 MRE$.TOH 0 CTE~,TOH 2.064 2.436 7360 1.000 6.328 6.527 159.125 1,263 1.60.375 84.125 856.000 4.000 0.000 64.750 -o.16n 103.500 0.000 635 000 213o:ooo 5 605 5 656 -28 .172 -12 269 -43 509 -25 602 12.234 3.46! 0,04 253 375 ! 000 7.2.50 129.500 ~2,.273 18,3.500 83,688 853,,000 000 :ooo ~9,..500 0.171 105.563 0,000 IWF2.TOH S2IV.TOH DERM.TOH CIDP.TOH IIRD.TOH IXD.TOH 8FB.TOH CSFA.TOH ITT.TOM TT4.TOH SRAT.TOH CBLF,TOM STSG,TOH MTE~.TOM CCSw.TOM SPAR.TOM ETZ~.TOH MARK.TOH RSMN.TOH BMN0,TOH IRDP,TOH IXDP,TOH IR~P,TOH IX~P.TOH IDOF,TOM SFV'P.TOM SFCZ.TOH SFBZ.TOH RXFO,TOH SPAP.TOH FTVP.TOM XPSD.,TOH IRDA.TOH 'IWF2,TOH $~IV.TOH DERS.TOH IDP.,TOH IRD,TOH 'IXD,TOH ILD.TOH .SFB.TOH CSFA,TOH ITT.TOH TT4,TOM SRAT,TO.N CBLF,TOH STSG.TOH MTEM,TOH C'CSW.TOH SPA,R.TOH PAGEI 35 2.029 0.073 108 155.250 137.500 77.500 6.379 1. O.961 160.875 0.259 590.500 0.396 0.106 176 80.125 6144 0,000 86, 5 4,883 5,129 ].906,040 209,825 3333.771 321,18n o,ooo 314.1o6 '0,031 '1,559 0.029 1002,000 3,801 .02~ 045 0,063 06.3, t[ :ooo .1 119.375 8i563' 5 .148 148 750 585, 0 4,1 79~438 144 0,000 IS Tape Verification listing chlumherger Alaska Computing Center 1-MAR-1993 11:5~ SPMV.TOH -569,500 SP.TOH ** DEPTH : 2100.000 FEET BS.TOH 8,500 TOD.TOH C$.TOH 2912,000 DIFF.TOH IHV.?OH 1042.000 ICV.TOH RMCA.TOH 9.977 SMLT.TOH NC~L.TON 9.609 RIRD.TOH ~ROM.TOH 1910.776 RIXD.TOH IXD~.TOH 2018.413 RIRM.TOH IRMa. TON 334~.138 RIXM.TOH IXMN.TOH 337 .695 DCID.TOH Iw0F.TOH 0.000 DEOF.TOH SFVZ.TOH 1.372 RSFC.TOH DCSF TOH 0.2~9 SFBP:TOW 544.000 RRFO.TOH XFOC.TOH 0.009 RSPR.TOM RITF.TOH ~1.000 RDIH.TOH FTVZ.TOH 0.019 RPSD.TOH IPSD.?OH 2.2~1 IRNA.TOH 2~XP.TOH 2.260 VODC.TOH INDB.TOH 3.787 15VT.TOH 15VS.TOH 4,680 DECb,TOH IFRE.TOH 20 IFBA.TOM TOW 199..500 ~ ~.:TON 19.750 IIRM.TOH ~T~..TOH 830.000 AMPL..TOH 19,063 CBb,?OH TT..TOH ~. 000 C~SL:.TOH DT..TOH 12 :625 RGR,TOH HTEN.TON 440,000 AMTE.TOH 78,750 HV,TOH 249.375. RSP,TOH SPMV.TOH -570.,000 SP.TOH ** DEPTH = 2000.000 81,500 TOD T0H 2924,000 DIFF TOH 1089.000 ICV TOH 9,617 ~M~T TOH o.ooo MS.TOH ICS..TO~ HV.TON R~C~.TOH ~CA[,.TOH IRDN.TOH IXDN.TOH IX~N,TOH IMQF.?OH SFVZ:TOH DCSFoTOH SFBP.TOH -52.250 ~1~154445 TIME.TOH -1.450 TENS.TOH 400.250 R$~I.TOH 0 BMIN,TOH 135.567 I~DZ.TOH 79.784 IXDZ.TOH ~4.120 IRMZ.TOH -1~3 32~ ~X~Z.TOH 0~079 ~CI~.?OH 0.000 RSFV.TOH 3.465 SFCP.TOH 0.000 RSrS.TO~ 0.190 RFOC.TOH 245.000 SPAZ.?OH 23q.250 DIHV,TD~ 1.864 EPSD,TOH 0.019 2IRP,TOH 4.46~ IWF1,TOH 4.680 25VT,TOH 0 DEC$.TOH 0.000 IPBA,TOH 0: 5 ObRA.TOH 3.418 CSFb,TOH .695 ITEM,TOH 56 .000 TT3,~OH 0.113 T0.TOH ,000 TTSb,TOM 5 ,594 GR.'TOM 5140.000 MRES,TOM CTEM,TOH 8PA,TOH 0o000 .875 412i54568 ?IMg,TO~ ..400. TEN$.TOH 42, .000 RS~I.TOH BMIN TOH 82.59 IRDZ~TOH -95,877 IXDZ.TOM 6~. 247 IRMZ,.,TOH -12:445 IXMZ.TO~ 0..137 DCI~,TO~ 0,000 RSFV,TOM 3.315 SFCP,TOH 0,000 RSFB,TOH 0.175 RFOC,TOH 616.000 2185.000 4.582 4.336 :28.249 12.230 -43.384 -25.534 0.096 7 979 12:235 9.109 0.090 -2.916 252.750 2.225 254 '029 ,. 2.410 '6144 1..000 5,008 201.500 3.850 250,500 828.000 4.000 0..000 063. .000 617,O00 2160..000 7,273 7.332 -2~ ~1o -12 196 -43 530 -25 671 0 013 14.6'79 12.235 8.20.3 o:o o ETIM.TOH MARK.TOH RS~N.TOH BMNO.TOH IRDP.TOH IXDP.TOH IR~P.TOH IX~P,TOM IDGF.TOH SFVP.TOH SFCZ,TOH SFBZ.TOH RXFO.TOH SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH 82IV.TOH DER6.TOH CIDP.TOH IIRD.TOH IXO.TOM ILD.TOH SFB.TOH CSFA,TOM ITT.TOH .TT4.TOH SRAT.TOH .TOH MTEM.TOH CCSW.TOH ~PAR.TOH ETIM,TOH MARK,TOH RSHN,TOH BMNO.TOH IRDP..TOH IXDP..TOH IRM'P.TOH IXMP,TOH IDOF.TOH SFVP. TOH SFBZ.TOH RXFO,TOH PAGE~ 3296.487 86.250 3.461 3.520 1906,358 209,996 3334,491 321,564 0.000 314.135 -0.031 -1.553 0.036 100~.000 .793 1.859 0.024 2.064 0.073 196.500 1651,875 50.594 5,086 10.930 212,875 0.286 564,000 0 274 0~113 1'76 78.750 61.44 0.000 3419,699 .039 8,156 1906,72.5 2.10,223 '3335,782 320.988 0,000 314,148 '-0..031 -1.559 0.034 36 Tape Verification Listino ,cblom~erger AlasKa Computing Center XFOC.TOg RI?E.TOH F?VZ.TOH IPSD.TOH lSVS,TO~ IFRE.TOH CIMP.TOH IIXD.TOH IX,.TO, lh~.TO~ SFV.TOH SFLU,TOH TT~oTOH ~P[,,TO~ TT,TOH DT.TOH HTE~.TOH A~TE,TOH B$.TO~ R~CA:TOH ~CAL,TOH I~DN,TOH DN.TOH IX~:,TOH I~OF,TOM SFV~.,TO~ DC~F.TON SFBP.TOH XFOC.TON FT~ '?OM ,TON IPSP,TO~ 2IXP..TOH IND',TOM CIMP,TOH oTO~ ~oTO, SFV,TOH SFbp. TO~ TT~,TOW TT,TO~ 0.005 80,563 0.024 2.2~5 2.264 3.7~3 4.695 ~0 1~.250 10.508 195.500 8,055 12.906 8.398 822,500 31,813 0 000 129 125 430 500 78 125 249 375 =569 500 292[ '5°° ,000 000 8,805 1911,51'4 I018,798 ..343,428 3381.032 0,000 1',373 0.033 544.000 0.,000 625 2..,250 2.'234 3,783 4,723 20 R2'..875 875 641 .'789 839,500 35..094 0,000 ~SPR.TOH RDIH.TOH RPSD.TOM IRMA.TOM VODC.TOH 15VT.TOH DECL.TOH XFBA.TOH IDPH.TOH IIR~ TOH D~RA.TOH SFC.TOH SFbA.TOH TT2.TOH CBb. TOH CBSL.TOH RGR.TOH RHTE.TOH DTEM,TOH RSP,TOH SP.TOH 1900,000 TOD.TOH OlFF.TOM ICV.,TOH 8MLT.,TOH RIRD'.TOM RIXD.,TOH RIR~..,.TOH RIXM,,TOH DCID.,TOH DEOF.TOH RSFC,TOH SFOF.,TOH RRFO,TO~ RSPR,TOH R'DIH~TOM RPSD'TOH IRMA.TOM VODC, TOH SVT, TOH ECh, TOH XFBA,TO~ ~DPH.TOH IXRM,TOH CILD,TOH DMRA,TOH SFC~.TOH SFLA,TOH TTI,TOM CBL,TOH CBSL.TOH 1-MAR-1993 1.1:58 249.375 SPAZ.TOfi 239.250 DIHV,TOB 1.854 EPSD,TOH 0.029 2IRP.TOH 4,438 IWFI.TOB 4.680 25VT.TO~{ 0 DECS,TOH 0,000 IPBA.TOH 7.988 IHPH,TOH 117,313 IXX~,TOB 127.250 CIL~,TOH 1,0~5 O[,R~.TOH 3.2 3 CSFL.TOH 8,~6 ITEM.TO8 556, 0 TT3,TOH 0,~97 T0,TOH O. 00 TTSL.TOH 66.~3 GR.TOH 5128, 0 '~RE$.TOH 0,000 CTEM,TOH 519,000 SPA.TOH -50,250 412154692 Ti~E,'rO.H ~t,350 TENS,TOH 0 BMIN,TOH 5o,,s z oz.'ro. -to2: 5 , 063 DC'I~,TOM ,,000 RSFV,TDH, 3,'545 ~FCP,TOH 0,000 RSFB,TOH RFOC,TOH '! 2IRP,TOM DECS,TOH 8 INPH,TOH 90, 50 CIh.~,TOH C'SFB,TOH 240 TO,TON 0,000 TTSb,TOH -2.721 252.375 2.244 2.270 2.049 2.377 6144 1.000 8.109 5.113 124.063 -1,759 119,000 82,563 824,000 4,000 0,000 73.688 -0.173 103.063 0.000 ,i:ooo 211 000 8.906 9.234 -28,133 '12,276 -43,.32.4 -25...698 0..069 24,735 236 0 69 -2-.~09 ,253 75 2 2 .494 6144 000 5,,~74 ..469"~ .4.38 81.563 839.500 :ooo .000 SPAP.TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH S2IV.TOH DER$.TOH CIDP.TON IIRD.TOH XXD.TOH ILD.TOH SFB.TOH CSFA.TOB ITT.TOH TT4,TOH SRAT.TOH CBLF.TOM STSG.TOH ~TEM.TOH CCSW.TOH SPAR.TOM ETIM.TOH MARK.TOH RSHN,TOH BMNO.TOM 1RDP,TOH IXDP,TO~ IRMP.TOH IX~P.TOH IDOF.TOH 8FVP.TOH SF'CZ,TOM SFBZ.TOH RXF,O,oTOH SPAP.TOH FTV,P, TOM XPSD,'TOM IRDA.,TOH WFI,TOH $2IV.TOH DERS,TOH DP,TOM IXD,TOM LD.TOH .8FB.TOH CSFA,,TOM ITT,TOM TT4,TO~ '$RAT.TOH CBLF.TOH PAGE: 37 1002.000 3,797 1.854 0,029 2,064 0,034 100 125,125 112,938 95.125 7.855 10,016 122,500 0.299 556.000 0.678 0,297 176 78,125 6144 0.000 3544.022 86,125 'il,703 1. t,875 19'07,, 3336, 8 3.t4,192 -0,03! -1,559 0,021 1002,500 3..797 1',859 0 029 0.063. 252 88,250 81.438 128.875 8 72 71,625 0.313 566.000 0,7~8 0,240 chlumberger Alask C. omput nQ C..entet DT.TOH 133,125 RGR,TOH HTEN.TDH 430.250 RHTE.TOH AMTE.TOH 77.750 DTEM.TOH HV.TOH 251,750 RSP.TOH SPMV,TOH -569,500 SP.TOH B$.TOH CS.TOH IHV.TOR R~CR.TOH MCAL,TOH I~DN,TON IXDN,TOH I~N.TOH IXM~),TOH SFVZ,TOH DCSF,TOH 8FBP.,TOH XFOC,TOH RITE.TOH FTVZ.,TOH IPSD,TOH 2IXP.,TOH INDB.,TOH 15V$,TOH IFRE.,TOH C]MP,TOH I~XD,TO, IX~.TOH ILM,TOH 8FV.TOH SFSU,TOH TT1.TOH A~Pt,.~0H T?.'TOH DT,TOH HTEN,TOH AMT£,TOH HV T0~ SPMV~TOH BS,TOH C$,TOH IHV TOH IRD~,TOH IXDN,T'OM I~MN..TO~ IXMN.TOH DEPTH = 1800,000 FEET 8,500 2926,000 1180,000 9,531 9,O78 1912,178 2019,569 3343,428 3380.648 0.000 1,373 0,020 544.000 0 07 0,019 2,254 .230 ~,783 4,680 , 20 12~,688 ,238 33~..'750 · ,875 11..203 7 230 828 000 26 719 13 i°°° 875 436 250 77 188 75O ooo DEPTH =, 8,500 2928,000 8'938 1912,622 2019,569 3344,6OO 3381.681 TOD.TO}] DIFF.TOM ICV,TOH SMLT,TOH RIRD,TOH RIXD.TOH RIRM.TOH RIXM,TOH DCID.TOH DEOF TO}{ RSFC TOH RRFO RSPR RDIH RPSD IRMA VODC TOH TOH TOH TON ,TOH ,TOM TOH DECb,TOH IFBA.,TOH IDPH,TOH {IRa,TOM CILD,TOH DMRA,TOH SFC,TOH SFLA,TOH TT2.TOH CBb. TOH CSSG.,TOH RGR,TOH RHTE.,TOM DTEM,TOH RSP,,TOH 8P,TOH ?oo..ooo DIFF,TOH ICV,.TOH .SMLT,TOH RIRD.TOH RIXD,.TOM RIRM,TOH RIX~'.,TOH DCID.TOH I'MAR-1993 11:58 56,813 GR.TOH 5]28.000 ~.~RES,TOH 0,000 CTE~,TOH 493.250 SPA,TOH -76.438 412154816 TIME.TOH -1,350 TEN$,TOH 457.750 RSMI,TOH 0 B~IN.TOH 79,761 IRDZ.TOH -99.890 IXDZ,TOH 72.266 IRMZ,TOH -131,254 IX~Z,TOH 0,107 DCXM,TOH 0,000 RSFV,TOH 3.342 SFCP,TOH 0,000 RSFB,TOH ,1 80 RFOC,TOH .375 SPAZ.,TOH ~ 9,250 DIHV.TOH ! 864 EPSD.TOH 0~019 2IRP,TOM 4,406 IWF1,TOH 4,.680 25VT,TOM 2 DEC$..T'OH 0,000 IPBA,TOH 11~,141 INPH,TOH ,938 IIXM.,TOH ~'2~,063 CIb~,TOH ,985 QLRA,TOH 3,299 CSFh,TOH 7,4~8 ITE~,.TOH 564,000 TT3e'TOH 0.220 TO.TOM 0,000 TT$~,TOH 53,281 GR,TOM 5136,000 MRES,,TOH 0,000 CTE~,TOH ~1,500 SPA,TOH ,813 4121549'39 TiMB.,TOH '1,]50 TENS,TOR 4.77,500 ~SM~,,TOH 0 BMIN,,TOH 50,775 IRDZ,TOH -103.994 IXDZ,TOH 29,496 IR~Z,TOH 0 DCI~,TOH ~0.875 0.175 {03.063 0.000 619 000 6.547 -28,249 -12.322 -43.509 -25 698 . ,064 237 8.344 0.085 -2.,637 252.250 .270 .. 36O 1o000 7,953 2.949 126 3 57 138 ~25 ,8! 38 829 000 4 000 0,.000 55,6~8 -0,1 5 3.,063 100,000 617 000 1950~000 8,406 8,805 -28.172 -12.309 -43,393 -25,698 0,,117 STSG.TOH MTE~.TOH CCSW.TOH SPAR.TOH ETI~.TOH MARK.TOH RSMN,TOH BMNO.TOH XRDP,TOH IXDP.TOH IR~P,TOH IX~P,TOH IOOF,TOH 8FVP,TOH SFCZ.TOH SFBZ.TOH RXFO,TOH SPAP.TOH FTVP,TOH XPSD,TOH IRDA,,TOH IWF2.TOH S2iV.TOH DER$,TOH CXDP,TOH IIRD,TOH IXD,TOH ILO,TOM SFB,TOH CSFA.TOH ITT,TOH TT4,TOH 3RAT,TOH CBbF.TOH STSG.TOH MTEM,TOH CCSW,TOH SPAR,TOH ET'IM.TOH MARK.TOH RS~N.TOH B~NO.TOM IRDP..TOH IR~P.TOH IX~P.TO~ IDOF.TOH PAGE: 38 176 77.750 6144 0,000 36~7,211 7,000 5,852 5,980 1907,461 209,883 3337.628 321,180 0,000 314.192 -0,031 -i,559 0.034 1002,500 3,801 1.,859 0,019 2,068 0,102 92 122,750 109,8{.3 138,000 7 992 10 156 13~ 750 · 326 566 000 0 669 0 220 176 77,i88 6144 0,000 3790.087 87..000 11.344 11.750 1908:197 209,544 3337.,720 321.372 0.000 Tame Verification Llstlno chl. umberqer Alaska ComputinO Center IMOF.?O~ OEOF.TOH SFVT.TOH RSF'C.TOH DCSF.TO, SFOF.,OH SFBP.TDH RRFO.TOH XFOC.TOH RSP~iTO~ RIT~.TO, FTVZ.TOH RPS TOH IPS~.TOH IR~A.TOH 2IXP.TOH VODC.TOH IND,.TOH ,SVT.TOH 15VS.TOH IF,~.TO, IFBA.TOH C'~P.TO. I,XD.TOH ,X,.TOH CILD,TO, ,~.TO, D~R.A.TOH HTEN,TOH RHT~..TOH A~TE.TOH DTEM'.TON HV,TOH RSP,TOH SP~V,TOH SP.TOH .C$.,TOH IHV.TOH R~Ca TOM IXDN,TOH I~Q~,TOH SFVZ,~DH DCSF.TOH SFBP,TOH .XFOC.TOH FTV TON IPSD,TOH 2IXP,TOH INDB,TOH 15VS,TOH CIMP.TOH IIXD..TOH IS~.TOH 1600,000 FEET 0,000 1.378 0.000 544.000 0.003 78.813 0.026 2,264 2.205 3.777 4,69! 2O ~0,375 6,543 1357.000 12.086 26.016 14.9~4 907.500 33,688 0,000 149,000 4~6.500 76.750 250,500 -570,000 DEPTH = 8 500 2924 000 1271 000 9 594 9-148 1912 546 .243 3~82i330 0 000 1,'37' 0,03~ 544 5O0 .0.:000 78,125 0,029 2,250 2,230 3,783 4,691 72.750 1.,5..is6 8,875 13,555 21,i25 TOD.TOH DIFF.,TOH ICV.TOH 8MLT,TOH RI~O.TOH RIXD TOH RIX~ TOH DCID TOM OEOF TOH RSFC TOH SrOr TOH RRFO TOH RSPR, TOH RDIH TOH RPSD TOH IRNA TOH VODC TOH ~.5VT ~O'H OECb .TOH IFBA TOH IDPH TOH IIRM,TOH C'iLO,TOH DMRA.TOH SFC..TOH l'.,A~-19q3 11158 0.O00 RSFV.TDH 3,749 SFCP.'rOH 0,000 RSFB.TO~ 0.141 RFOC,TON 217.125 SPAZ,TOH 239,750 DIHV.TOH 1.864 EPSD.TOH 0.019 2IRP.TOH 4,3~1 IWFI,TOH 4.6 4 25VT.TOH 0 DEC$.TOH 0,000 IPBA,TOH ~1,484 IMPH,TOH 78,375 IIX~.TOH 90,688 CIL~.TOH 1.097 OLRA.TOH ],695 CSFL.TOH 15.1.88 ITE~,TOH 603,500 TT3.TOH 0,445 TO.TOH 0,000 TTSL,TOH 42.625 "GR.TOH 5124,000 ~RES.TO~ 0.000 CTEM.TON 479,250 SPA,TOH -90.658 41215506' 495,750 35 5~ 20,176 132,849' 0o000 0.000 3.727 0o000 0 239.,250 1,859 4, 4,680 0 0,000 14,o~0 69,93~ 3,676 TIME,TOH TEN$.,TOH RSMI TOH BMIN TOH IRDZ TOH IXDZ, TOH IR~Z TOH IX~Z~TOH DCIM,TOH RSFV.eTOH 'SFCP,TOH RSFB.,TOH RFOC,~0H '$PRZ..TOH DIHV.,TOH '~PSD,TOM 2I. RP.,TOH IWFI.,TOH '25VT,TOH DECS,'~OH IPBA.,TOH iMPH,TOH CIL~,'TOH QLRA,TOM CSFL,TOH 28.206 12.237 5.680 0 06i - :soo 252.750 2.240 2 21~ 2.449 6144 1.000 12.438 0.737 82.688 -13.938 66.688 80.563 907,500 000 :ooo 45,625 -0,176 102,563 0,000 375 8 688 i 0,063 -2o475 2.4~6 61.44 742 5,586 73.75O 0.79O 81.625 SFVP.TO~ SFCZ.TON SFBZ.TOH RXFO.TOH SPAP,TOH FTVP.TOH XPSD.TOH IRDA.TOH IWF2.TOH 82IV.TOH DERS,TOH CIDP.TOH IIRD.TOH IXD.TOH ILD.TOH SFB.TOH CSFA,TOH ITT,TOH TT4.TOH SRAT.TOH CBLF.TOH STSG.TOH MTEM.TDH CCMW,TOH $PAR.TOH ETIM,TOH NARK,TOH RSNN,TOH BMNO.TOH IRDP.,TOM IXDP,TOH IRMP,TOH IXMP.,TOH IDOF.TOH 'SFVP.TOH SFCZ'.TOH $.FBZ..TOH RX. FO,TOH SPAP,TOH FTVP,TOH XPSD,TOH lW'F2. T0. H S2Iv TOM DER$ TOM CIDPTON II~D TOM 'IXD.TOH ILD..TOH 8FB,'TOH CSFA,TOH PAGE: 314.1q2 -0,031 -1.563 0,034 1003,000 3.803 1.864 0,014 2.045 0,087 180 87.000 81.313 152,750 11.023 0.340 604,000 0,914 0,445 176 76,750 6144 0,000 3913..~ 10.2 10,3 1908,1 2°9,I 3338, 320.7 ,:i! 1002,5 3,8 0 68,0 65,9 193,8 13.9 27 52 97 0 O0 21 O0 O7 59 24 12 0 75 45 48 75 39 ,Is ?aoe Verification blstlnc .ChlUmberqer Rlaska ¢omputinq Center SFLU.TOH 12,242 SFLA.TOl{ TT1.TDH 856,000 TT2,TOH A~PL.TOH 33.438 CML.TON TT.TDH 0.000 CBSL,TOH DT.TO~ 139,000 RGR,TOH HTEN,TOH 415,500 RHTE,TOH A"TE.TOH 76,188 D'rE~.TOH HV.TOH 251.750 RSP,TOH SPMV.T~H -570,000 SP,TOH DEPTH = 1500.000 FEET B$.TOH ~:500 C8.TOH 293 000 IHV.TOH I 31 6.000 RuCA,TOH 9,~91 ~CAb. TO, 8,906 I,ON.TOH 1g13.~2 IXDM.TOM 2020. 6 IR~N,TOM 3345,243 IXM~.TOH 3382.330 I~Or. TOH 0,000 $FV'~.TOH 1.3'68 DCSF TOH 0.019 SFBP,:TOH 544.500 IPSD.TOH 244 INDB TOM 87 15VS[?08 4.703 I'~RE. TOH 20 IMP,TOH 55 88 .x,..,o, T .TOH 891.500 A~P,L.TOH' 35.344 TTeTOH DT,,O, 148,000 HTEN. TOH 4~ HV TOH 251,.750 SP~V:TOH -570,000 TOD,TOH DIFF,TOH ICV,TOH RIRD.TOH RIX, D,TOH RIR~.TOH RIX TOH DEQF,TOH RSFC,TOH $FOF,TOH RRFO,TOH RSPR,TOH R, DIH,,TOH RPSD~TOH IRMA, TOH VODC. TOH ~SVT~TOH DECL:TOH IFBA. TOH IDPH TOH I/R~ TOH CILD TOH O~RA TOH 5FC. TOH 8FLA TO.H TT2 TOH CBb, TO~ CBSb',TOH RGR, TOH RHTE,TOH DTE~,TOH R~P,TOH ** DEPTH = 1400.000 FEET 1-MAR-1993 11:58 13,~1 ITE~.TOH 577. 0 TT3,TOH 0.226 TO,TOH 0,000 TTSL,TOH 52,094 GR,TOH 511~.000 ~RES,TOH 0.000 CTEM,TOH 509,500 8PA.TOH -60,219 412155184 -1.300 514.000 0 25.i53 -109.612 3,866 -143,308 0.172 0.000 3.260 0.000 0,146 242.375 240,750 1,850 0.019 4.~69 4..72 53.4 ~ 9 000 4~.406 0 0 ooo "625 TIME,TOH TENS.TOH BMIN.TOH IRDZ,TOM IXDZ,TOH IRMZ,TOH IXMZ,TOH DCI~,TOH RSFV,TOH $FCP,TOH RSFB,TOH RFOC,TOH 'SPAZ,TOH DIHV.TOM EPSD,TOH IIRP,TOH WF1,TOH 25VT,TOH DECS,TOM IPBA,TOH IMPH,TOH IIXM,TOH CILM.,TOH ObRA.,TOH CSFb,.TOM ITE~,TOH TT3,TOH TO,TOH .TTSL.,.TOH GR,TOH ~RES:.TOH CTE~.,TOM SPA,TOH ,,, BS.T0~ 8,500 TOD.TOH' 412155308 TIME.,TOH CS,TOH 3 ..000 I'HV,TOH !368.000 ICV.,TOH 539,~0 RShI:TOH R~CA.,TDH 9,930 $~LT.TOH 0 B~IN,TOH MCAL,TOH 9,547 RInD,TON {6,965 IRDZ,TOH 79.688 R57.000 4.000 0.000 58.594 -0.177 101.750 0.000 614.000 1700.000 9.891 10.328 -28.326 -12.230 -43.530 -25.698 0.089 34.326 12.239 6.234 0,067 ~2..525 2 ~..875 ,221 2.,230 2,029 2.357 7360 1,000 .113 56,281 -10.047 47,28! 79,688 892,000 4..000 0 !00 100,06 0,000 619',.000 l :ooo 996 ITT.TOH TT4,TOH SRAT,TOH CBLF.TO~ STSG.TOB ~TEM.TOH CCSW.TOH SPAR.TOH ETIM.TOH MARK.TOH RSMN.TOH BMNO,TOH IRDP.TOH IXDP.TOH IRMP.TOH ~XMP.TOH IDOF,TOH SFVP.TOH SFCZ.TOH SFBZ,TOH RXFO,TOH SPAP.TOH FTVP.TOH XPGD,TOH IRDA..TOH .TOH DERS,TOH CIDP.,TOH IIRD,TOH IXD.,TOH IbD,TOM .$FB.,TOH CSFA,TOM ITT,TOM TT4,TOH SRAT,TOH CBLF.TOH ~TSG.,TOH MTEM,,TOM CCSW,TOH 8PAR.TOH ETIM,TOH MARK TOM B~NO,TOH IRDP,TOH PAGE: 4O 0.354 578.000 0,725 0,226 176 '144 0.000 4035,900 86,938 13,641 13.969 1908,197 209.544 3339.560 320,796 0,000 314,234 '0..031 '1.559 0.. 029 1003.000 3,797 1.,854 0,029 2,064 0.078 92 56' 251. 1~ 141 992 49,344 0.369 596',000 0.695 0.247 .176 44 0,000 ,, 4159,168 87.625 9,,969 10,242 1908.872 Tape Verification Listing .chlumberqer AlasKa Computing Center IMOF,TOH SFVZ.TOH DCSF.TOH SFBP,TOH XFOC,TOH RTTE,TOH FTVZoTOH IP$~,TOH 2]XP.TOH INDB,TOH 15V$,TOH IFRE.TOH IIXP.TOH IX~.TOH IL~,TOH ~FV,TOM SFbU,TO~ ?T1,TOH ~MPb,TOM TT,TOH WTEN.,TON HV,TO~ SPMV,TOM C$,TOH IHV MCAL. TOM I~D~.TOH I. XD~ IRMN TOH IXMN ?OH IMQF TOH SFVZ,TOH DCSF,TON SFBP,TOH XFOC.TO~ FTVZ,TOH IPS@.TO.H 2IX~,,?O~ INDB ~5vS.:TOH CI~P.TOH 19]3,650 020,724 346,657 33~3.629 0,000 1,368 0,010 544.500 0.009 77.500 0.0]7 2,230 2,250 3.959 4,723 20 67,563 7.980 207,250 15.969 22.938 16 203 864 000 3~ 281 000 140 000 44~ 500 75.250 248.250 -570,000 DEPTH =. 8.500 2930,000 8,000 1419,727 9 05 ~o ,782 ,.000 1',378 2~4 .500 O45 76.875 0,039 2,21.5 2,260 3,959 4,691. 2O 127.875 ~IXD.TOH RIRM.TOM RIXM.TOH DCID,TOH DEQF,TOH RSFC,TOh SFOF.TOH RRFO.TOH RSPR.TOH RDIH.TOH RPSD,TDH IR~.TOH VODC.TOh 15VT.TOH DECL,TOH TFBA.TOH IDPH,TO~ IIR~.TOH CILD.TOH D~RA,TOH SFC TOM 8FLA TOH TT2 TOH CBb TOH CBSb,TOH RGR,TOH RHTE TOH DTEM TOH RSP TOH 8P,TOH 1300,000 FEET TOD,TOH DIFF..TOH ICV,TOH SMLT,TOH RIRD TOH RIXD .TOH RIRM TOH RX'XE TOH DCIDTOH DEaF RSFC TOH SFOF TOH RRFO TOH RDIH TOH RPSD TOH IRMA. TOH VOD¢ ~OH 15VT..,TOH DZC£.TOH IFBA,TOH IDPH,TOH 1-MAR-1993 11:58 '106.318 IXDZ,TOH 9.394 IR~Z.TOH -]34.349 IXMZ.TOH 0,0~ DCIM,TOH 0.000 ~$FV.TOH 3,050 SFCP,TOH 0.000 RSFB,'roH 0.163 ~FOC,TOH 19~.500 SPAZ,~OH 236,500 DIHV.TOH 1.B59 EPSD.TOH 0.039 2IRP,TOH 4,461 IWF1.TOH 4,695 25VT,TOH 2 DECS.TOH 0.000 IPBA.TOH 19.281 IMPH.TOH 59,406 IIX~.TOH 53,875 CILM,TOH 0,861 QLRA.,~OH 3.014 CSFL,TOH 17,~1 ITEM,TOH 581. 0 TT3,,TOH 6B~370 TTSL,TOH 5 GR,TOH 5140,000 MRES.TOH 0.~00 CTEg..TO~ 498. 50 SPA,.TOH -71,500 41215543.0 TIM£,TOH .-1,.250 TENS,.~OH 562,500 TOH RSMI. 0 BMIN.TOH ,006 IXDZ,TOH 47~,551 IRMZ:,TOH - .16! IXMZ,'TOH 0.039 DCI, M,TOH 0,000 RSFV,TOH 2.067 SFCP.TOH 0,000 .RSFB,TOH RFOC.,TOH 45 IWFI.~OH 4,680 25VT..TOH 2 DEC$,TOH IPBA.TOH $7, PAGE: -12.315 IXDP ~OH 209.544 0.068 IDOF.TOH 0.000 25.036 SFVP.TOH 314.249 23~ SFCZ.TOH '0.03~ ~:~o2 s?~z.~o. 0.077 Rx?o.~oH o.o~4 ,oo,.ooo ,o.ooo g:ooo o.7oo 563 CCSW,TOH 6144 90'000, SPAR.TO~ 0,000 613'.000 1795.000 .0.000 0,162 -28.210 -12.435 -43 46! -25 602 0098 0.955 3O5 O, 6 251,625 ..215 2.,260 ,,045 2~3ae 322 t6 ETIM.TOH MARK,,TOH RS~N TOH BMNO TOH 'IRDP TOH 'I'XD~ TOM XRMP TOH IXMP TOH IDQF,'TOH SFC$.TOH RXFO. TOH SPAP~TOH FTVP..TOM XPSD.'TOH IWF2.?OH S~I¥.,TOH DER$.TO~ RD.TOH 4282. ~0'. 1896. '246, 3312, '443., 0,, 314. Oo i7. 015 625 015 000 031 O4 ~oo O34. O39 2O 4! 'I8 Tape Verification histinq cblumberger Alaska Computing Center 1-MAR-1993 11:58 I~XD.TON 82,313 {IRM.TOH .X~.TOH 1950.000 CILO.TOH IL~.TDH 7.480 DMRA.TOH SFV.TOH -0.410 SFC.TOH SFLU.TOH 9696.001 SFLA.TOH TT1.TOH 418.750 TT2.TOH A)~P[..TOH 8.i48 CBL.TOH TT.TOM 0.000 CBSD.TOH DT.TOH 56.125 RGR.TOH ,V.TON 250.500 RSP.TOH 126.188 IIX~.TOH 18.500 CIL~.TOH 0.138 OLRA.TOH 2.070 CSF[~.TOH 9696.001 ITEM.TOH 307.500 TT3.TO~ 0.012 T0.TOH 0.000 TTSL,TOH 40.250 CR.TOH 5152.000 ~RES.TOH 0.000 CTE~.TOH 587.500 SPA.TOM 19.172 DEPTH = 1295.500 FF.,ET BS.TOH 8,500 TOD.TOH CS TOH 2934,000 DIFF.TOH ~HV~TOH 1420.000 ICV.TOH R~CA.TO~ 9.734 SMLT.TOH NCAL.TOH 9.320 RIRD.TOH IRDN.TOH 1899.784 RIXD,TOH IXDN.TOH 2006.230 RIRM.TOH IR~N..TOH 3~17.i4! RIXM.TOH IX~N.TOH 3353,622 DCIO.TOH I~QF.TO~ 0.100 DEQF.TOH SFVZ..TOH ~.. 68 RSFC,TOH DCSF,TOH 19.109 SFOF..TOH SFBP.TOH 544.500 RRFO.TOH XFOC.TOH 0.042 RSPR.TOH RIT~.TOH 76.875 RDIH.TOH FTVZ,.TOH 0 021 RPSD,TOH IPSD.TOH 2:.230 IRMA,TOH ,'TOH 2,254 VODC,TOH ~ ~.TO" 3.969 15VT,~OH 15V~,TOH. ~.703 DECh,TOH IFRE.TO~ 20 ~FBA.TOH CIMP,TOH 126.175 IDPH..TOH IIX~.TOH 75,' 00 IIR~,TOH IX~,TOH 1950.000 CI[,D.,TOH 'ILM,TOH 7,793 DMRA,'TOH sSFV.TDH "0,426 SFC,TOH F'bU,TON 9696,001 SFLA,TDH TT! ?OH 41~,000 TT2..TOH A~PL~TOH ..813 CBS:,TOH TT.,TOH 0.000 CBSL.TOH DT.TO~ 56,438 RGR,TO.H HTEN.TOH 459,2'50 ~HTE,TOH A~TE,TDH 74°250 DTE~:,'TOH HV..TD~ 250,500 RSP...~OB SP~V.TOH -569.500 SP.TOH 412155436 TIME.TOH -1,250 TENS,TOH 563,500 0 B~IN.TOH -27i~56 IRDZ.TO, -38 95 IXDZ.TOH 5 14 IR~Z.TOH -456.942 IX~Z.TOH 0.0lO DCIM.TOH 0.000 RSFV.TOH 1.774 SFCP.TOH 0.~00 RSFB.TOH O. 73 RFOC.TOH 23 , 50 OlHV,TOH 1. 59 EPSD.TOH 0.053 2IRP,TOH 4 465 IWF1.TOH 4:680 25VT,TOH 0 DEC$.TOH 0.000 IPBA.TOH 5~.656 INP.H, TOH 1~ ,188 IIX~,TOH 9,203 CILM.TOH 0.149 OLRA.,TOH 765 CSF.L..~OH 308.000 TT3.TOH 0.010 T0.TOH 000 TTSS,TOH 5356.000 ~RES.TOH 0.000 CTE~..TOH .375 END OF DATA -305 750 m - .875 -2376.000 78.750 417.000 4.000 0.000 40.125 -0.179 99.000 0.000 611.000 1765.000 0.000 -0.162 -28.249 -12.388 -43.520 -25.838 0.025 0.~28 12. 38 14.133 0.133 -2.303 251.875 ,215 ~.240 .045 ].352 6144 1.000 7.910 -291..500 .- 2.000 -1945 000 8 62'5 72 250 414 000 0:000 48 531 -0.181 99,500 0.000 IXD.TOH ILO.TOM SFB.TOH CSFA.TOH ITT.TOH TT4.TOH SRAT.TOH CBLF.TOH STSG.TOH ~TEM.TOH CCSW.TDH SPRR.TOH ETIM.TOH ~ARK.TOH RBHN.TOH BNNO.TOH IRDP.TOH IXDP.TOH IX~P SFVP. TGH SFCZ. TOH SFBZ TOH RXFO TOM SPAPTOH FTVP~?OH XPSD.TOH IRDA.TOH IWF2.TOH S'2IV,TOH DER$.TOH CIDP.TOH [IRD.TOH 'IXD.TOH ILD.TO~ SFB:.TOH CSFA,TOH ITT.TOH TT4.TOH SRAT.,TOH CBbF.,TOH STSG.TOH ~TE~,.TOH CCSW.TOH SPAR.TOH PAC;E: 42 12,14! 54.000 35.234 '2368.000 0.392 303.500 0.789 0.012 74.313 6144 0.000 4287.527 87,625 0 000 -0 129 1896 120 -247 859 3310 733 -446.307 249 -0.031 l"l 2' O. 1003..000 3.805 1,864 0,029 ,,049 .180 · . 1.2 17.953 17 516 13 234 52 .063 16 094 -2035 000 0 392 300 250 0 785 0,010 .176 74.250 61.44 0.000 Ver~ticatlon Listing Alaska Computing C?entet ]-MAR-lgg3 11:58 PAGE: 43 **** FILE TRAILER **** F~LE N~E ~ TOH ,009 SERVICE : LOG VFRSION : 32 6 DATE : 93~01/22 M~X RgC SIZE : 1024 FILE TYPE : PR LAS? FILE **** TAPE TRA~LER **** SERVICE NAME ~ G87645 DATE : 93/01/22 TAPE NAME : 548876 CONTINURTION # ; O0 PREVIOt;$ TAPE : COMMENT : SCHLUMBERGER WELL SERV%CES CSU TAPE **** REEL TRAIl,ER **** SERVICE NAME : G8764S DATE : 93/01/~2 ORIGEN : CSU REEL NAME ~. : 5.48876 CONTINUATION # : O0 PREVIOUS REEL : COMMENT : SCHLUMBERGER WELL SERVICES CSU TAPE