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194-113
MEMORANDUM TO: FROM Jim Regg P. I. Supervisor Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 8/20/19 SUBJECT: Location Inspection WMRU #3 ' Cook Inlet Energy PTD 1941130 - 8/19/19: 1 arrived on site and met up with Brad Bird with Glacier Oil and Gas. We found the location of WMRU #3 on the pad. WMRU #3 was plugged and abandoned in December of 2000 and there had not been a location inspection performed by a State of Alaska Petroleum Inspector until now. The location, where WMRU #3 was, has been graded level with the rest of the pad and the well is completely buried. The area is clean with no signs of hydrocarbon spills or debris. Attachments: Photos (2) 2019-0819_Location_Clear_WMRU-3_gc.docx Pagel of 2 N3 0 1. L � o m I p U) = c CL ov �U U)O cQ o 0) N O 0 o O t J d 'co PLL-GGI'-,G & LOCATION CL~,~.R~_NCE REPORT State of Alaska 0iL & GAS CONSERVATION COH~ISSION ~--e well ~= ~ =, and-comment un pluqqing, well head and !oca=icn c!ear=ca - provide loc. clear, code. Well head Harkar pos: or plata: Locanion Clearance: Conclusions: Code FORE I 0 N February 13, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Attn: Steve Davies Re: WMRU #3ST Mr. Davies, This letter is a follow-up to'our phone conversation pertaining to the Plug and Abandon of West McArthur River Unit #3ST. The plug and abandon operation and all well operations on WMRU #3ST were completed in July 2000. However, it was not until December that we had the rig removed from over the top of the wellhead and all of our production lines modified. Once the area around the wellhead was completely clear, the wellhead was removed and a marker was installed. This was performed of December 6, 2000 and was witnessed by an AOGCC representative. The attached report from the our WMRU field operator indicates this information. If there are any questions, please contact me at 907-258-8600. Drilling Engineer-Alaska Division Forest Oil Corporation Attachments: West McArthur River Unit Production Report for 12/6/2000 \~NCHFLSI'C, ANC_DRILLING\WMRU #3S'lSWellhead Removal.doc Date Modified: 2/13/01 Date Prepared: 2/13/01 FORE S T O I L C_-, O R P O R A T e .. :~7~. 2'(/~~ January 30, 2001 Alaska Oil and Gas Conservation Commission 333 West 7~h Suite 100 Anchorage, Alaska 99501 Re '. Well Completion Report and Log (Form 10-407) West McArthur River Unit #3ST I o N Enclosed is Forest Oil's Well Completion Report and Log for the West McArthur River Unit #3ST well. We re-entered this well with the intentions of sidetracking it to a new bottom hole location. While pulling the completion, the well experienced a catastrophic collapse in the 10 ~" intermediate casing at a depth of 4,947' MD. The well was permanently plugged and abandoned shortly thereafter. Included are form 10-407, well plug and abandon schematic and daily report summary. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager - Alaska Division Forest Oil Corporation RE. CE VED JAN 3 1 200t Alaska Oil & Gas Cons. C;omrnission Anchorage ORIGINAL 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 Forest Oil Corporation 7. Permit Number 94-113 3. Address 310 K Street, Suite 700 8. APl Number Anchorage, Alaska 99501 50-133-20461 4. Location of well at surface LOC,,AI"~(~ 9. Unit or Lease Name 2381' FNL, 1323' FWL, S16, T08N, R14W, SM i ~~i~'jrc~t~~ West McArthur River Unit At Total Depth . .. 10. Well Number 773' FNL, 867' FEL, S10, T08N, R14W, SM ~,,...~,...~. West McArthur River Unit #3ST .... ~"~--"~'~' 11. Field and Pool West McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. West McArthur River Pool 163 KB ADL 359111 12. Date Spudded 13. Date T.D. Reached. 14. Date Comp.,j~usp. or Aband., 15. Water Depth, if offshore,,'.~ .~, 16. No. of Completions 11/13/97 11/26/97I I!Z" (~ 'Oc "F2~.5/D0 n/a feet MSL 0 15,450' MD / 10,096' TVD Surface - Wellhead Removed Yes: No: X n/a feet MD 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 20" 133# K-55 Surf. 117' driven n/a None 16" 75# K-55 Surf. 2,361' 18 1/2" 2027 cuft None 10 3~4" 45.5# K-55 Surf. 7,343' 13" 511 cuff None 7 5~8" 29.7 # L-80 6,817' 14,161' 8 1/2" 286 cuft None 5 1/2" 29.7 # L-80 6,390' 6,243' 6 3/4" 448 cuft None 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED n/a 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 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 => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .on :JI N 3 'I 200t Anchorafle Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ~-,~:~ , :~._ ~ . ~. ~ ~.. .... ~. ... J~N 3 ;I 200t Alaska Oil & Gas Co¢~s. '¢ ~ ¢Corr~n?ss'o¢ Anchorage 31. LIST OF A~ACHMENTS Well Schematic Dail~perations Summaq 32. I h~ ~~~eg~ is tree and correct to the best of my knowledge Signed~~ ~ v~ v Title__Drilling Manager Date ~ & q 0 I Form 10-407 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". WMRU #3ST Abandonment Schematic 20"133#, L-80 ~' 2361' MD, 2278"1'VD TOL 6807' MD 10 3/4' 45.5~, K-55 BTC 7343' MD, 5234' TVD ACementPlug 0- 150' Bullheaded Cement 10 bbl (100 ft , Cement Plug 2262 -2512 Collapse Zone ~ Cement Plug 4250' -5015' TOL 13,480' MD 7-5/8" 29.7#, L-80 14,161' MD, 8993' TVD Packer ~ 14, 581' MD 5-1/2' 17#, L-80 15,450' MD, 10,096' TVD ,JAN 3 ] 2001 Alaska (.)il & Gas Cons. Commissior, Anchorage 23-Jun-O0 24-Jun-O0 25-Jun-O0 26-Jun-O0 27-Jun-O0 28-Jun-O0 29-Jun-O0 30-Jun-O0 01-Jul-00 02-Jul-O0 03-Jul-00 Daily Drilling Reports Well 3RD RIGGING UP RIGGING UP RIGGING UP RIGGING UP RIGGING UP 22 HRS FINISHED WITH RIG REPAIRS. PITS FILLED WITH LEASE WATER. VOLUME PIT FILLED WITH FREASH WATER. NEW MUD LINE TESTED. RIG TO CIRC. ACCEPTED RIG AT 0400 HRS. KILL WELL. WELL STATIC. SET BPV REMOVE PIPE SLIDE, PRODUCTION LINES AND TREE. N/U BOP CIRCULATED WELL RETURNS TO HEATER TREATORS. RATE 3 BBL/MIN. MAX PRESS 750 PSI. RECOVERED 640 BBLS CRUDE OIL. PITS 95 % EMPTY NOTIFIED AOGCC OF BOP TEST. NIPPLE UP BOP TESTED CHOKE MANIFOLD VALVES. AOGCC WITNESSED. TEST BOP. 14 HRS TOTAL. AOGCC WITNESSED. REPAIRED ALL FAILURES. R/U CATCH CAN ON TOP OF PICTURE NIPPLE. R/U TBG TOOLS. CIRC OUT CRUDE FROM UNDER TBG HANGER. RETURNS TO PRODUCTION. BACK OUT LOCK DOWN STUDS. PULLED 90000~ ON TBG. LAYED DOWN HANGER. STRING WEIGHT 75000~. FILLING HOLE IN WITH PIPE DISPLACEMENT PLUS. Alaska Oil & Gas Co~s. Anchorage PULL 2 7/8" COMPLETION STRING. STOOD 150 STANDS BACK IN DERRICK. L/D SEAL ASSEMBLY AND PUMP CAVITY. LAY DOWN TUBING TOOLS. CHANGE RAMS TO 5". TEST RAMS, SAFETY VALVES ECT. RUN WEAR RING. PICK UP 4 3/4" BIT, 5 1/2" SCRAPER, 2 718" AOH PIPE AND RUN IN HOLE. PICK UP 3 1t2" DRILL PIPE. PICK UP DRILL STRING WITH 5 1/2" CSG SCRAPER. WELL FLOWING. SHUT IN - 30 BBL GAIN. BIT AT 3200' +-. PRESSURE STABLE AT 450 CSG AND 300 D.P. CIRC THRU CHOKE AT 3+ BBL/MIN. 700 PSI STANDPIPE. 480 PSI ON CHOKE. BEGIN MIXXING CA-CL2. CHECK RETURNS - 9.3 PPG DRILLING MUD AT BOTTOMS UP. STOP MIXXING CA-CL2. Prepared by Apdi C Lee 12/11/00 Page 1 04-Jul-O0 05-Jul-O0 06-Jul-O0 07-Jul-O0 08-Jul-O0 Daily Drilling Reports Well 3RD SHUT IN. CSG AND DRILL PIPE PRESSURE STABLE AS BEFORE. ClRC AGAIN AT SAME RATE. 700 PSI STANDPIPE, 450 PSI ON CHOKE WELL SHUT tN. PRESSURE REMAINS STABLE. PICKING UP 3 1/2" DRILL PIPE IN THE MOUSE HOLE. RACKING STANDS BACK IN THE DERRICK. JaN 3 '_/ ZO0~ Alaska Oil & (-;as Cons. Commissior, Anchorage M/U 3 1/2" DP. & STAND BACK IN DERRICK, (WELL FLOWING BEFORE SHUT IN TO P/U DP) INSTALL 3 1/2" DART VALVE & FLOOR VALVE, RIH, ENCOUNTER BRIDGE @ 4947' (GAINED 80 BBLS.) POH T14928', ESTABLISH FLOW RATE OF 1 BBL/MIN, SHUT WELL IN & MONITOR PRES BUILD UP CALCULATE & MIX WEIGHTED DRLG FLUID @ 2/10th$ POUND INCREMENTS & OBSERVED WELL PRES BUILD UP STARTING FROM 8. 3 PPG TO 10. 8 PPG, CHECK PRES & FLOW, PREP TO POH CONDITION MUD TI 10 . 8 PPG, THRU CHOKE WI 400 PSI BACK PRES. LOST PUMP PRES. & OBSERVED COAL @ SHAKERS, OPEN CHOKE TO BLOW COAL PIECES THRU & OCILLATE MUD PUMP TO REGAIN PRES. (COAL UNDER SUCTION VALVE) CHECK FLOW: @ 2 BPH, POH WI 4 3/4" BIT & 5 1/2" SCRAPER ASSY. , L/D BHA SHUT IN WELL & OBSERVE PRES BUILD UP OF 30 PSI, WHILE TURNING KELLY HOSE & SERVICING TOP DRIVE BEGIN STRAP, DRIFT & P/U # 1 - 4 1/2" SWEDGE ASSY. BEGIN STRAP, DRIFT & P/U 5" S-135 DRL. PIPE. (PERIODICLY PUMP OFF DRLG. MUD & STORE IN TANKS @ # 5 PAD W/VAC TRUCK, (DUE TO FLOW FROM WELL) PUMP OFF & INJECT FRESH WATER FROM VOLUME PITS WI VAC TRUCK RIH W/# 1 - 4 1/2" BAKER SWEDGE ASSY. TI 4922' WASH DOWN TI 4947' (2' OF FILL) & BEGIN SWEDGING 10 3/4" CSG. MADE EST. 5" - 6" OBSERVED 1675 UNITS OF GAS, GAINED 10 BBLS,CIRC & COND MUD THRU CHOKE MANIFOLD CLOSE IN CHOKE & MONITOR PRES BUILD UP, WT. UP MUD FROM 10. 0 PPG T/10.7 PPG CLOSE IN CHOKE , CHECK PRES. = 0 PSI CHECK FLOW, PUMP SMALL PILL, POH L/D # 1 SWEDGE ASSY. & M/U # 2 - 5 1/2" SWEDGE ASSY. RIH TI 4922' CIRC BOTTOMS UP (GAS UNITS 1700) THRU CHOKE MANIF. WASH DOWN TI 4947' & BEGIN SWEDGING 10 3~4" CSG. CHECK FLOW & PRES BUILD UP, PREP TO POH CHECK FLOW, PUMP SMALL PILL, POH & L/D # 2- 5 1/2" SWEDGE ASSY. PULL WF_AR BUSHING, TEST BOPE FI 250 PSI TI 5000 PSI, RIG DN TEST EQUIP (LEAVE WEAR BUSHING OUT; 9" ID, STAB 9 3~4" OD) WILL LOOK INTO LARGER ID WF_AR RING IN THE A.M. MAKE UP #1 - 8 112" TAPER MILL ASSY. RIH - (WELL FLOWING @ 20 BBLS. / HR RATE, TRANSFER FLUID WITH VAC TRUCK TO# 5 PAD INJECT. TANKS TO ACCOMMODATE INCREASING VOLUME) TAG FILL @ 4740' (= 7' OF FILL), PICK UP, CHECK FLOW, SHUT IN WELL & MONITOR PRES. BUILD UP (300 PSI IN I - HOUR), WHILE RIG UP PRE - HYDRATION TANK & TRANSFER MUD VOLUME TO SAME BEGIN WEIGHT UP DRLG FLUID WEIGHT UP KILL MUD TO 10.6 PPG, BEGIN WELL CONTROL PUMPING SCHEDULE, SHUT IN WELL PERIODICALLY TO TRANSFER WEIGHT MUD FROM AUX. PITS & TANKS TO SUCTION PIT, INJECT LIGHT MUD TRANSPORTED BY VAC TRUCK OPEN WELL, CHECK FLOW, CHECK PARAMETERS, RIH & TAG TIGHT SPOT @ 4946' (6' FROM JARS & BUMPERSUB OPEN MANDRELS) MILLING 10 3~4" CSG. W/8 1/2" TAPER MILL ASSY F/4946'T/4947 OBSERVED STEADY TORQ& NO R.O.P. - CHECK FLOW, PUMP PILL, POH L/D # 1 TAPER MILL, OBSERVED 100% WEAR ON BOTTOM 3" OF MILL & SOME LIGHT WEAR 5 1/2" UP FROM BOTTOM OF MILL, MAKE UP 6" TAPER MILL TANDEM W/8 3/8" STRING MILL PREP TO RIH Prepared by Apdi C Lee 12/11/00 Page 2 09-Jul-O0 lO-Jul-O0 11-Jul-00 12-Jul-00 13-Jul-00 Daily Drilling Reports Well 3RD ~J/~N 3 '~ 2001 RIH W/# 2 TAPER MILL ASSY. Alaska Oil & Gas Cons. Con'~n~ission SERVICE TOP DRIVE & RIG Anchorage RIH, T/4900' BREAK GIRO, BEGIN MILLING F/4945' T/4945' OBSERVED GAIN IN FLOW (MAX GAS UNITS = 2200) SHUT IN WELL, BEGIN GIRO GAS CUT MUD THRU CHOKE MANIF. & GAS BUSTER MILL F/4945' T/4946' CHECK FLOW, POH 2 STANDS, OBSERVED FLOW (11 BPH) W/GAS (975 UNITS), RIH SHUT IN WELL, MONITOR PRES BUILD UP (175 PSI, SIDPP) BARGE ATTEMPTED TO BRING LOAD OF BARITE, LOW TIDE RAN OUT FROM UNDER RED DOG BARGE t000' + FROM SHORE RECEIVE BARGE, OFF LOAD BARITE,BACK LOAD C.I.C. EQUIP/EMPTY TRAILERS,BEGIN MIX KILL MUD WITH KILL MUD MIXED BEGIN PUMPING SCHEDULE, OPEN WELL, CHECK FLOW KILL WELL W/11.3 PPG MUD OPEN WELL, CIRCULATE CONVENTIONALLY POH W/#2 MILL ASSY L/D MULL ASSY. & M/U #3 "JUNK" MILL ASSY INSTALL VETCO GRAY 10" ID WEAR RING TO ACCOMMODATE 9 3/4" STABS RIH TO 4856' CUT & SLIP 275' OF DRLG LINE & SERVICE TOP DRIVE RIH TO 4940' REAM FROM 4940' TO 4945' MILL FROM 4945' TO 4951' CREW RESPOND TO H2S ALARM IN SHAKERS, EVACUATED RIG WHILE DRILLER AND & HAND SHUT IN WELL MILL F/4951' TI 4965'. OBSERVED LOSS OF 4000 FT/LBS OF TORQ @ 4955' MILL F/4965' T/4975'. (ROP OF 50-100 FT/HR W/WEIGHT ON MILL OF 2-4 k) 4975' = DEPTH OF NEXT CSG. COLLAR, WASHED DOWN (NO ROTATE) TOOK WEIGHT @ 4975' CBU - CHECK SAMPLES @ 5' INTERVALS F/4961' T/4975'. (70-80% METAL, 20-30% FORMATION) CHECK FLOW, PUMP PILL, POH W! #3 MILL ASSY. POH LiD MILL # 3 SERVICE RIG AND WAIT ON ORDERS. PICK UP NEW MILL ASSEMBLY AND RIH WITH MILL ~4. REAM 4925' TO 4975'. MILL 4975' TO 5015'. POH WITH MILL #4. HOLE STABLE. CHECK TOOLS. HOLE APPEARS TO BE SIDETRACKED. LAY DOWN MILLING ASSEMBLY. RERACK 5" DRILL PIPE IN DERRICK. PICK UP TOOLS FOR CMT STRINGER STRING. RACK AND STRAP 2 7/8" DRILL PIPE. PICKING UP PIPE TO PLUG BACK WITH. RUN IN THE HOLE WITH CMT STINGER PIPE. CIRC THE HOLE CLEAN AT 4967. MUD WEIGHT CONSTANT 10.8 PPG WASH TO BTM OF MILL SECTION AT 5015' PLUG BACK. PULL SLOW TO 4355' CIRC DRILL PIPE CLEAN. LAYING DOWN DRILL PIPE. PLUB BACK F/5015' TO EXPECTED TOG 4750'. TESTED LINES TO 1000 PSI. PUMP 20 BBL WATER. MIX AND PUMP 15.8 LB, 1.14 YEILD, 25.5 BBL SLURRY, 125 SACKS CLASS "G" CMT. DISPLACED WITH 1 BBL WATER AND 75.5 BBL MUD. CIP 1750 HRS. BALANCED PLUG. LAY DOWN DRILL PIPE. 2 7/8" ANS 3 1/2". Prepared by Apdl C Lee 12/11/00 Page 3 Daily Drilling Reports Well 3RD RIG SERVICE. RIH With 4 3~4" BIT AND 3 1/2" DRILL PIPE. TAG CEMENT AT 4717'. CIRC. WITNESSED BY AOGCC. LAY DOWN 3 1/2" DRILL PIPE. RIH WITH 2 7/8" TBG WITH MULE SHOE TO 4250'. L/D TBG. 28 JOINTS. AT 3380' WELL FLOWING. SHUT IN. MONITORING PRESSURE BUILD UP. TOTAL PIT GAIN 8 BBLS. J/ N ,3 ]. ZOO1 Alaska Oil & Gas Cons. Commission Anchorage. 14-Jul-00 WELL SHUT IN DUE TO FLOW WITH TBG AND MULE SHOE AT 3372'. PRESSURE BUILT TO 170 PSI BOTH SIDES. ORDERED AND BARGED IN BULK CEMENT. WORKED WITH A.O.G.C.C. ON ABANDONMENT PLAN. SLUG TBG WITH WEIGHTED VOLUME. RIH TAG UP AT 4717'. CIRC MUD TO EVEN DENSITY ALL AROUND. LAY A 500' BALANCED CMT PLUG FROM 4717'. PULL 900' PIPE. BEGIN CIRC. _PUMPED 10 BBLS OF CMT INTO 16" BY 10 3~4" ANNULUS. MAX PRESSURE 200 PSI 15-Jul-00/CEMENT IN PLACE. FINISH PULLING 400 ABOVE EXPECTED TOC. CIRC PIPE CLEAN. /AT 3817' HOLD 200 PSI ON CSG. BLED TO 150 PSI AFTER 2 1/2 HOURS. /DRY JOB. POH AND LAY DOWN TBG. ~RIH WITH 2 7~8" TBG OUT OF DERRICK, TAG TOC AT 4250' WITH 15000 LBS. .. ~POH LAY DOWN TBG. RUNNING IN FROM DERRICK AND CONTINUE LAYING DOWN. __~'~'" \PLUGGED BACK FROM TOP OF FIRST PLUG AT 4717' TO 4250. 467. ~ ~PUMPED 5 BBLS H20, TEST TO 1500 PSI, PUMP 10 BBL H20, 48 BBLS "G" CMT 15.8 PPG, 16-Jul-00 LAY DOWN TBG. RIH WITH MULE SHOE TO 2512'. CIRC EVEN DENSITY ALL AROUND. PLUG BACK F/2512' TI EXPECTED TOC 2262' 250' PLUG. PULL 500' ABOVE PLUG. WASH STRING OUT. FINISH LAYING DOWN ALL 2 7~8" TBG. RIH W/3 1/2" M.P. TO 150'. PUMP CEMENT TOP JOB. WASH UP. L/D PIPE. CHANGE RAMS TO 5" IN LOWER BOP. N/D BOP. CLEAN PITS. PUMPED 20 BBL WATER THEN 250' 24 BBL, 118.5 SX, 15.8 PPG "G" CMT AT 2512' DISPLACED WITH 12 BBL MUD. ON TOP JOB PUMPED 5 BBL WATER THEN 14.4 BBL 15.8# CMT AT 150'. GOOD CMT RETURNS. 17-Jul-00 NIPPLE DOWN BOP. CLEAN PITS. VACUUME TRUCK LIQUIDS TO INJECTION. SUPERSUCKER SOLIDS TO DWMA CELL #3. UNABLE TO REMOVE WMRU #3 WELL HEAD DUE TO GAS IN 16" X 10 3~4" ANNULAS. WHILE CLEANING PITS REMOVE TOP DRIVE POWER PACK, RIG DOWN EPOCH, PREP TO SKID SUB AHEAD, JACK SUB UP AND GREASE SKIDS. PULL WIRES, DRAIN WATER TANKS, SET IN SKIDS MATS. 18-Jul-00 18 HOURS CLEANING PITS. HAUL SOLIDS TO DWMA #3 WITH SUPERSUCKER. HAUL LIQUIDS TO INJECTION. SKID RIG AHEAD. BURY WMRU ~ CELLAR. LANDSCAPE. Prepared by April C Lee 12/11/00 Page 4 Daily Drilling Reports Well 3RD REALEASED RiG FROM WMRU #3RD AT MIDNIGHT. CLEAR OUT SUCTION PIT, PUMPS AND PUMP HOUSES. CLEAN RIG LINER. CONTINUE CLEANING PITS. ,JAN 3 J. ~007 Alaska Oil & Gas Cons. Cornmission Anchorage Prepared by Apdl C Lee 12/11/00 Page 5 J. Z! Db/'/I~IlOD ~b:qq ~lllbbZqb ~UKU~K~¥ WI~IKU FORCENERGY DATE: 12/6100 WEST McARTHUR RIVER UNIT OPERATIONS SUMMARY PERSONNEL ROSTER NAME HOURS POSITION I :DAVID HALL 12 " LEASE OPERATOR 2 ED HOUSE 12 !OPERATOR "A" ' ................ 3 "TOMMY ELLiSO'N ..................... ~ .... 'OPERATOR 4 ! DOLI-G YOUNG 6 OPERATOR "A" '5 AARON BOOKS "'i0 .... OP'E~YOR ;"A'; .............. .. . ... .......... $ TOM QUINT ' '8 '~)PERATOR "A'" 7 JIM NEWSTEAD 8 ELECTRICIAN 8 RU~'~EL BUCHANAN 8 RAVEN 9 KERMIY"BRAMMEIER 8 RAVEN 10" CRAIG SKVARCH' 8 RAVEN 11 AARON BUR~'HAM 12 'D +'D 'WELDING- ......... 12 MARK KRUEGER 12 D + D WELDING ......... 13 ! Ric'i~' POQUETTE - 12 'BAKER ....... 14 HUGH CATTNACH 12 COOK 16 KAREN CROMER '12 HOUSEKEEPER 16 SHERRI CADDELL 12 BULLCOOK ....... WEATHER: 30 DEG. AND CLEAR. RECYCLED 10-K TANK. ELECTRICIAN WORKED ON WIRING V.F. D IN MCC #4. FINISHED CUTTING 20", 16", !0 3!4" SURFACE PIPE AND REMOVED WMRU ~3 WELL HEAD, WELDER STARTED CAPPING PIPE. HAULED 6,000 GALS. OF DIESEL FUEL FROM EVERTS AIR. THAWING OUT BJ INJECTION TANKS. WELDER MADE DRY HOLE MARKER FOR WMRU N3 OIL WELL. WORK CONTINUES ON POWER OIL AND RETURN LINE REPLACEMENT PROJECT. ROADED UNOCAL'S CRANE TO LEASE AND USED ON WMRU #3 PROJECT. GRADED RUNWAY, LEASE AND ROADS, SANDED ROADS. DWY. Forcenerg~/...well #3 abandonment Subject: Forcenergy...weli #3 abandonment Date: Wed, 13 Dec 2000 14:51:51 -0900 From: "DAVID/MIKE/TRADINGBAY" <fen 14@pobox.alaska.net> To: "tom maunder" <tom_maunder@admin.state.ak. us> Here are the pictures of well #3 .... If you have any questions please call me at 776-5580, 776-5297. if everything looks good please fax me something saying i can cover up abandoned well...fax~..776-5246,. Thanks alot .... Jim Cartwright .... i ,I' Name: 222.jpg i ~-~222.ipgi Type: JPEG Image (image/jpeg)l i ]Encoding: base64 ir--~ i Name: 33jpg ~33.iD.qi Type: JPEG Image (image/jpeg)! ~ i Encoding: base64 j [~65.ip.q · Name: 65.jpg Type: JPEG Image (image/jpeg) i Encoding: base64 Name: 67.jpg JPEG Image (image/jpeg)t Type: i Encoding: base64 ]. ~ 'I Name: Mvc-O03f. jpg [-~ i Type: JPEG Image (image/jpeg)i i! Mvc-003f'iP'qi Encoding: base64 . 1 of 1 9/11/01 3:51 PM STATE OF ALASKA ALASKA OI-AND GAS CONSERVATION C,JMMISSION 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) Forcenergy Inc. Development: X 163 RKB feet 3. Address Exploratory: 7. Unit or Property name 310 K Street, Suite 700 Stratigraphic: West McArthur River Unit Anchorage, Alaska 99501 Service: 4. Location of well at surface RECEIVED 8. Well number 2381' FNL, 1323' FWL, Sec.16, T8N, R14 W, SM West McArthur River Unit #3ST At top of productive interval 9. Permit number 1027' FNL, 1254' FEL, Sec.10, T8N, R14W, SMJUL2 12000 94-113 At effective depth 10. APl number 2381' FNL, 1323' FVVL, Sec. 16, T8N, R14 W, SM AJask8¢0~""~ G, ~ (~,S 00t't$. 00!~i~i0P. 50- 133-2o461 At total depth Anchorage 11. Field/Pool 773' FNL, 867' FEL, Sec. 10, T8N, R14W, SM ' West McArthur River Field 12. Present well condition summary Total depth: measured 15450 feet Plugs (measured) 4717 feet to 5015 feet true vertical 10096 feet Effective depth: measured 4717 feet Junk (measured) 4950 feet (10 3/4" Casing Collapse) true vertical 3730 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 117' 20" Driven 117' 117' Surface 2361' 16" Surface 2361' 2278' Intermediate 7343' 10 3/4" 6343' 7343' 5234' Production 7354' 7 5/8" 13161' 14161' 8993' Liner 1970' 5 1/2" 13622' 15450' 10096' Perforation depth: measured 14,696' - 14,860' 6spf true vertical 9,491' - 9,622' 6spf Tubing (size, grade, and measured depth) N/A - completion pulledORIGINAL Packers and SSSV (type and measured depth) Baker Model D - 14,581' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 13-Jul~O0 16. If proposal well verbally approved: Oil: Gas: Suspended: X Tom Maunder 13-Jul-O0 Name of approver Date approved Service: 17. I hereby certi~e f.f~oorego~d correct to the best of my knowledge. Signed: Robert Stinson Title: Drilling Engineer Date: 18-Jul-O0 FOR COMMISSION USE ONLY Co nd itio ns of approval: Notify Commission so representative may witness lApp roval No__ Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~O'1' (.~J,~~- ~__.,.~ C(..~"c~. Approved Copy Returned ORIGINAL SIGNED BY D Taylor Seamounf Approved by order of the Commissioner .~(-~_&~j.~=r~ M/W 9 I:..,r.-,., ~r~_A~q D~w n~/l~/~t~ C::I I~I~AIT Ikl '11'[31 I WMRU #3ST Abandonment Schematic 20"133#, L-80 ~ 16 1, 7'K_ M5 D5 'B 1T 17C 'TVDI 2361' MD, 2278'TVD TOL 6807' MD 10 3/4" 45.5#, K-55 BTC 7343' MD, 5234' TVD Collapse[ Zone ~ Cement Plug 0 - 150' Bullheaded Cement 10 bbl (100 ft , Cement Plug 2236 -2486 Cement Plug 4217' -4950' TOL 13,480' MD ~ ~ 7-5/8" 29.7#, L-80 14,161' MD, 8993' TVD Packer ~ 14, 581' MD 5-1/2" 17#, L-80 15,450' MD, 10,096' TVD SCANNED MAY g 9 21302 I I oU~_ 2 1 2000 Alaska Oi~ & Gas cons. ,,om,'mssm Anchorage Forcenergy Inc July !8, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approvals (Form 10-403) West McArthur River Unit #3ST Forcenergy plans to plug and abandon West McArthur River Unit g3ST due to a casing collapse in the lower portion of the 10 3fi ,, intermediate casing. The top of the initial cement plug has been tagged at 4,717' MD. We will continue the abandonment from this point by laying another 500' of cement in the 10 3~ ,, intermediate casing, on top of the existing plug. The top of this new plug will be tagged, at an approximate depth of 4,217' MD. We will then bullhead cement from the surface into the 10 3fi ,, x 16" annulus, not to exceed 100' of cement. Then we will spot a balanced cement plug 250' in length, inside the 10 3fi,, casing, across the 16" surface casing shoe, from approximately 2,236' MD to 2,486' MD. To complete the abandonment, a 150' surface cement plug will be set. After the wellhead has been removed, we will perform a top-job on the 10 3A" x 16" annulus if we were unable to bullhead cement in this annulus previously. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. ,JUL 2 1 2000 0[; c~ Gas" .... Ant, cmge HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 305/856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 07/13/00 TIIU 15: $ 7 FAX 9 0 ? 2 $ 8 8 $ 01 FORCENERGY ALASKA ~- Forcenergy Inc 310 K Street, Suite 700 Anchorage, Alaska 99501 {907] 258-8600 258-8601:FAX FAX TRANSMITTAL SHEET TO: DATE: PAGES TO FOLLOW ,. Phone; ~-ONFIOENTIALITY NOTE: The information in this facsimile transmittal is legally p_fivtle~ed and confide~fia! inf'°~ma~;i'O-n~ intended only for tho use of the individual or entity named above. If l~he reader of thi~ message is not the intended recipient, ! you ate hereby notified that any d;sseminatlon, distribution or copy of the transmittal is strictly prohibited. If you receive transmittal in error, please immediately notify us by telephone, and return the original transmittal to us at the above address I ~ie the United States Postal Service. Thank you. I~AT(ALA. DOC ?.J'] 1/97 MESSAGE: E[VED 6CANNED MAY ~ 9 2002 ,ItJL 1 ~ 2000 AJaska 0~; & '" s o* ,.'. ua C,,~o. ¢0mmi~si0n An~0rage 07/13/00 TItU 15:57 FAX 907 258 8601 Forcenergy Inc Alaska Division MEMORANDUM TO: FROM: DATE: SUBJECT: Blair Wondzell Paul White / Rob Stinson July 13, 2000 WMRU #3ST Blair, As per my phone conversation with you and Tom Monder, i would like to summarize the revised abandonment plan for West McArthur River Unit #3ST. The top o! the initial cement plug has been tagged at 4,717' MD. We will continue the abandonment from this point by laying another 500' of cement in the 10 ~A" intermediate casing, on top of the existing plug. The top of this new plug will be tagged, at an approximate depth of 4,217' MD. We will then bullhead cement from the surface into the 10 sA" x 16" annulus, not to exceed 100' of cement. Then we will spot a balanced cement plug 250' in length, inside the 10 aA" casing, across the 16" surface casing shoe, from approximately 2,236' MD to 2,486' MD. To complete the abandonment, a 150' surface cement plug will be aet. After the wellhead has been removed, we will perform a top-job on the 10 aA" x 16" annulus if we were unable to bullhead cement in this annulus previously. If you have any questions, please contact me or Rob Stinson at 258-8600. \\FGEANCH\VOLI~Ddiling\W MRU #3RD\Wondzell3RD(4) Revised Abandonment,doc Page1 of 1 Date Modified: 7/13/00 O~e Prepared; 7/13/00 Forcenergy Inc Alaska Division MEMORANDUM TO: FROM: DATE: SUBJECT: Blair Wondzell Paul White / Rob Stinson July 13, 2000 WMRU #3ST Blair, As per my phone conversation with you and Tom Monder, I would like to summarize the revised abandonment plan for West McArthur River Unit #3ST. The top of the initial cement plug has been tagged at 4,717' MD. We will continue the abandonment from this point by laying another 500' of cement in the 10 %" intermediate casing, on top of the existing plug. The top of this new plug will be tagged, at an approximate depth of 4,217' MD. We will then bullhead cement from the surface into the 10 %" x 16" annulus, not to exceed 100' of cement. Then we will spot a balanced cement plug 250' in length, inside the 10 %" casing, across the 16" surface casing shoe, from approximately 2,236' MD to 2,486' MD. To complete the abandonment, a 150' surface cement plug will be set. After the wellhead has been removed, we will perform a top-job on the 10 %" x 16" annulus if we were unable to bullhead cement in this annulus previously. If you have any questions, please contact me or Rob Stinson at 258-8600. C:\TEMP\WondzelI3RD(4) Revised Abandonmentl.doc Page1 of 1 Date Modified: 7/13/00 Date Prepared: 7/13/00 hew MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector DATE: July 12, 2000 SUBJECT: Plug & Abandonement West McArthur River Unit #3RD Forcenergy Inc. West McArthur River Unit P.T.D. #200-088 Section: 16 Lease No.: Operator Rep.: Mike Murray' .N, ON: CONFIDENTIAL Township: 8N Range: 14W Ddlling Rig: Nabors 160 Rig Elevation: 30' Meridian: Serward Total Depth:. 1,0,09,6. CasinoJTubin_o Data: Conductor: 20" O.D. Shoe@ 117' Surface: 16" O.D. Shoe@ 2361' Intermediate: 10 314 O.D. Shoe@ 7343' Production: O.D. Shoe@ Liner: O.D. Shoe@ Tubing: O.D. Tail@ CasinR ,Remov, at: Casing Cut@ Casing Cut~ Casing Cut@ Casing Cut@ Casing Cut@ Casing Cut@ Feet Feet Feet Feet Feet Feet TvDe Pluq Founded on Bottom (bottom up) of Cement Above restriction! Balanced i 5015' , 1, I ,. Pluooin~ Data: TOp of Cement Depth Verifi,,ed, ? , 4717 ! Drillpipe ta~ I I Mud Weight above pl.u~l 10.6 Pressure Test Applied None Type PluQ Fqunded ,on: Verified? Open Hole Bottom Drillpipe tag Perforation Bddge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface i arrived to find the dg ready to tag the plug that was set above a obstruction that was possibly collapsed casing, The ddllpipe was lowered to 4717' (R.K.B.) where the pipe fetched up solid. 20 K was set down on the plug and I noticed no sticking when the drillpipe was pulled off of the top of cement. cc; Attachments: Well schematic (1) Distribution: odg - Well File c - Operator c - DNPJDOG c - Database c - Rpt File c- Inspector Rev.:5/28100 by L.R.G. 200-088-000712P&A WMRU-lg.xls 9/11/01 ~iyrRu ~3rd'Abandonment Subject: WMRU #3rd Abandonment Date: Wed, 12 Jul 2000 08:07:09 -0800 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Paul White <pwhite~forcenergy.net> CC: Tom Maunder <torn_maunder~admin. state.ak.us> Good Morning Paul' We received your e-mail description of the problems at your WMRU #3rd and of your plan to abandon the well. We find your plan acceptable and hereby give verbal approval to proceed. You must also file a 10-403 "APPLICATION FOR SUNDRY APPROVALS" within three working days. Good Luck, Blair Wondzell, 7/12/00. 7/12/00 8:10,4AM Forcenergy Inc Alaska Division MEMORANDUM TO: Blair Wondzell FROM: Paul White DATE' July 11,2000 SUBJECT: WMRU #3~1- Blair, We have been unsuccessful at re-entering the West McArthur River Unit #3~1~ wellbore. An attempt to mill through a casing collapse at 4,950' resulted in side-tracking outside the 10 %" intermediate casing. As discussed in our phone conversation, our abandonment plan is to run in the hole with a cement stinger to the collapse / sidetrack area at 4,950' MD and lay a 200' displacement plug. While waiting on cement, we will use the top section of the wellbore to lay down drill pipe and then pump a 150' top plug at the surface. Cement will also be bullheaded down the 10 %" x 16" annulus. The wellhead will be removed and the well will be cut off 4' below the current gravel pad elevation. Once the rig has moved off of the location we will cut the well off 4' below the original ground elevation. If you have any questions, please contact me at 258-8600. C:\TEMP\Wondzell3RD(3).doc Page1 of 1 Date Modified: 7/11/00 Date Prepared: 7/11/00 bew I D~D WMRU #3 Abandonment Schematic 20"133#:, L-80 ~ 161,, 1, 7'K_M5 D5 ,BlT17C 'TVDI Collapse Zone 2361' MD, 2278'TVD TOL 6807' MD ~ 10 3/4" 45.5#, K-55 BTC 7343' MD, 5234' TVD TOL 13,480' MD 7-5/8" 29.7#, L-80 14,161' MD, 8993' TVD Cement Plug 0- 150' Bullheaded Cement Cement Plug 4.4.23¢~4950' Packer ~ 14, 861' MD 5-1/2" 17#, L-80 15,450' MD, 10,096' TVD ~.e:,WM~U 3RD Subject: Re: WMRU 3RD Date: Thu, 06 Jul 2000 15:49:12 -0800 ';~:, ~ From: Blair Wondzell <blair_wondzell~adrnin.st~te.ak.us> Organization: State of Alaska, Dept of Adrnin, Oil & Gas To: Paul White <PWhite~forcenergy.net> Paul, Thanks for the memo. Blair Its as we discussed. Good Luck. Paul White wrote: > ~ High Priority ~* > Blair, Please see attached memo. Thanks, Paul White Name: Wondzell3RD (2) . doc Wondzell3RD (2) . doc Type: Microsoft Word Document Encoding: base64 (app l i ca t i on/m s word) 7/12/00 8:10 AM Forcenergy Inc Alaska Division MEMORANDUM TO: Blair Wondzell FROM: Paul White DATE: July 6, 2000 SUBJECT: WMRU #3~ Blair, As per our phone conversation, I would like to summarize our current operations on West McArthur River Unit #3~. We have experienced a casing collapse in our 10 %" Intermediate casing at approximately 4,950' MD. We have attempted to swedge this collapse area open and were unsuccessful. We are preparing to RIH with a mill to mill through the collapse. If we are successful with this operation, we will tie-back the existing 7 5/8" ddlling liner to surface. If this_operation is not successful, we will set a whipstock in the kick off above the collapse to drill to the WMRU ~ targets or skid the rig back to WMRU #lA, abandon those perfs and kick off, drilling to the WMRU ¢f3~ targets. If we are unable to establish access to the WMRU #.3ST below the collapse, we will lay a cement plug across the collapse zone to abandon the well. We feel that cross-flow communication in the production perfs at 14,696' - 14,860' is not an issue from a reservoir standpoint, due to the extremely high water cut from these zones at the time of well shut-in. C:\TEMP\Wondzell3RD(2).doc Page1 of 1 Date Modified: 7/6/00 Date Prepared: 7/6/00 bew MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Dan Seamount Commissioner '~//?,_//O C.) THRU: Blair Wondzell P.I. Supervisor FROM: Jeff Jone~~ Petroleum ~s~tor NON. CONFIDENTIAL DATE: June 29, 2000 SUBJECT: Blowout Preventer Test Nabors Rig 160 Forcenergy Inc. West McArthur River Unit # 31~ 200-088 West McArthur River Field & Pool Operator Rep.: Mike Murray Contractor Rep.: Mary Rodqers Op. phone: 776-5580 Rig phone: 776-5597 Op. E-Mail: wmru@gci.net Rig e-mail: Test Pressures Rams: 5000 MISC. INSPECTIONS: P/F Location Gen.: Housekeeping: PTD On Location Standing Order: F Sign: F Rig cond: P Hazard: P BOP STACK: Annular: 2500 Choke: 5000 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm P/F Quantity P/F Trip Tank P P P Upper Kelly 1 Pit Level Indicators P P P Lower Kelly 1 Flow Indicator P P P ' Ball Type 1 Meth Gas Detector P P , Inside BOP 1 H2S Gas Detector P P - Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13-5/8" P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 2-7/8" F Quantity P/F System Pressure 3000 P Lower Pipe Rams 1 3-1/2" F No. Valves 13 F After Closure 1250 P Blind Rams 1 N/A P Man. Chokes 2 P 200 psi Attained 28 sec. P Choke Ln. Valves 1 4" F Hyd. Chokes 1 P Full Pressure 3.5 min. P HCR Valves 1 4" P Blind Covers (All Stations): P Kill Line Valves 2 2" F N2 Bottles (avg.): 4@2400 P Check Valve 0 N/A Test's Details On June 29, 2000 I traveled to Forcenergy's West McArthur River Unit well #3RD to witness an initial BOPE test. After flight delays for weather I arrived on location at approximately 1300 hrs. where I found Nabors drilling personnel were still installing BOPE. While waiting I inspected the location and the drilling rig and found conditions to be substandard, however, rig personnel were working to correct these conditions. I witnessed testing of the H2S and methane gas detection alarm systems for the mud pits, rig floor and sub-base and observed no failures. The BOPE testing continued till midnight and after some repairs, resumed again at 0600 the next morning. At 1700 hrs. I instructed the company and the contractor representatives to continue the equipment repairs and re-test all of the failures until they passed the pressure test and e-mail the completed test report to the Anchorage AOGCC office. I then left the location and arrived back in Nikiski at 1800 hrs. Total Test Time: 20 hrs Number of failures: 7 Attachments: 0 cc: Forcenergy West McArthur 7/10/00 NOTE TO FILES 200-107 AND 200-088 SPACING EXEMPTION WEST MACARTHUR RIVER UNIT #31~AND #6 On June 22, 2000, AOGCC approved the application for the permit to drill for the West McArthur River Unit (WMRU) #3RD oil well. That approval included a statement that the "Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Forcenergy, Inc. will assume the liability of any protest to the spacing exception that may occur." A spacing exception was required because the proposed target of 600'FNL, 2420 FWL, Sec. 10, T8N, R14W, SM lies 950 feet from the producing zone in the WMRU #5 well, a violation of 20 ACC 25.055 (a)(3) which specifies a 1,000 foot-limit. On June 16, 2000, Forcenergy notifies the DNR that an application would be submitted for the WMRU #3RD. On June 20,2000, Forcenergy submitted to AOGCC the documentation for a spacing exception. On June 29,2000, A notice of Public Hearing was published in the Anchorage Daily News. On July 13, 2000, Blair Wondzell and Tom Maunder of AOGCC was informed that Forcenergy discovered that casing had collapsed in the WMRU #3 well, and that it was unusable to drill a sidetrack well to the proposed bottom hole location for WMRU #3RD. July 14, 2000, Forcenergy submitted a permit to drill application for WMRU #6, a new well to be drilled to the same proposed target and bottom hole location as originally proposed for the WMRU #3RD. On July 21, 2000, AOGCC approved the application for the permit to drill for the WMRU #6 well, which also included the contingency statement that "Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Forcenergy, Inc. will assume the liability of any protest to the spacing exception that may occur." August 1, 2000, AOGCC received an application for exemption for the provisions of 20 ACC 25.055, Drilling Units and Well Spacing, West McArthur River Unit #6. Because the intent of Forcenergy remains the same, to drill the same target and bottom hole location in WMRU #6 as originally proposed for WMRU #3RD, and because correlative rights are not jeopardized, all supporting documentation originally submitted for the WMRU #3RD is carried over, and adequate to support the spacing exemption application for the WMRU #6 well. oN OR B¢FO c:cOg.~x~M.~°c Forcenergy lnc June 9, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approvals (Form 10-403) West McArthur River Unit #3ST Forcenergy plans to plug back the existing 5 ¥5" production liner and perforations on West McArthur River Unit #3ST. It is proposed to abandon the current perforations with the down squeeze method. This will be accomplished with a retainer set 20 feet above the 5 ¥5" Model D packer in the existing 5 ~/~" liner. 100 feet of cement will be pumped through the retainer, then 100 feet of cement will be displaced on top of the retainer. The well will then be re-drilled as per the 10-401 submitted on June 6, 2000. This well will be called West McArthur River Unit #3RD. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 305/856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 STATE OF ALASKA .... ALASKA AND GAS CONSERVATION C .MMISSION co APPLICATION FOR SUNDRY APPROVALS .. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X 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) Forcenergy Inc. Development: X 163 RKB feet 3. Address Exploratory: 7. Unit or Properly name 310 K Street, Suite 700 Stratigraphic: West McArthur River Unit Anchorage, Alaska 99501 Service: 4. Location of well at surface ~ ,v/ ,,/' 8. Well number 2381' FNL, 1323' FWL, Sec 16, T8N, R14W, SM/ West McArthur River Unit #3ST At total depth 9. Permit number 623' FNL, 857' FEL, Sec 10, T8N, R14W, SM 94-113 ~ 10. APl number 50- 133-20461 11. Field/Pool West McArthur River Field 12. Present well condition summary Total depth: measured 15,450 feet Plugs (measured) true vertical 10,096 feet Effective depth: measured 15,280 feet Junk(measured)ORIGINAL true vertical 9,776 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 117' 20" Driven 117' 117' Surface 2,361' 13 3~8" To Surface 2,361' 2,278' Intermediate 7,343' 10 3/4" 6,343' 7,343' 5,234' Drilling Liner 7,354' 7 5/8" 13,161' 14,161' 8,993' Production Liner 1,970' 5 1/2" 13,622' 15,450' 10,096' Perforation depth: measured 14,696'- 14,860' 6 spf i~-.-.>? ii ...... ? "" !~ .... ¢,i ';', '; .;:' , ~ "ii true vertical 9,491' - 9,622' 6 spf · , ;,,-: ?.000 Tubing (size, grade, and measured depth) 2 7/8" L-80 14,601' (mule shoe) Packers and SSSV (type and measured depth) Baker Model D Packer - 14,581' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: June 20, 2000 16. If proP0,saL~.ell verbally approved: C)~t ~' Oil: x Gas: ~ Suspended: Na Date approved Service: Disposal 17. , her~.~rtify that the foregoing is true and correct to the best of my knowledge. Signed~~~:==~'_~/~--' PaulVVhite Title: Drilling Manager Date: (O 0~ O'~ '~ ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprovalNo. Plug integrity_ ~.~. BOP Test Y~. Location clearanceI ,~O(~) -'" ~/$'-5 Mechanical Integrity Test Subsequent form required 10- ~--~ ~ ' · )RiGINAL SIGNED By, ~, Taylor Searnount Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE , 2. 3. 4. 5. 6. 7. . OUTLINE PROCEDURE Reverse out jet pump. Kill well with produced water. Install BPV Move in and Rig up Nabors Rig 160 Nipple down tree. Nipple up and test 5000 psi BOPE Ensure well is dead. Recover BPV. Engage tubing hanger and recover 2 7/8" tubing from BWD packer at 14,581' Set retainer at 14,561' Down squeeze 13 cuft (100 linear feet) cement, un-sting from retainer, displace 13 cuft (100 linear feet) cement, PU to 14,400', circulate clean. WOC and tag TOC. Test casing to 2000 psi WMRU #3 ST Plugging Schematic 2361' MD, 2278'TVD TOL 6807' Nfl) 10 314' 45.5~, K-55 BTC 7343' MD, 5234' TVD TOL 13,480' MD 7-5/8" 29.7#, L-80 14,161' MD, 8993' TVD Retainer @ 14,561' MD Packer ~ !3.rg6'l' MD 5-1/2" 17#, L-80 15,450' MD, 10,096' 'I'VD Perforations 14,696' - 14,860' Nabors Rig #160 13-5/8" 5000 psi BOP Stack 3' Kill Line 1 = HCR Valve 2 = Gate Valv& 5000 psi Annular Preventer I I 5000 psi Pipe Rams ! I 5000 psi Blind Rams Drilling Spool 5000 psi Pipe Rams 13-5/8"x 11 11~ 5M Wellhead 10-3/4" Casing Choke Line Forcer , ergy inc January 23, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Well Completion Report and Log West McArthur River Unit #3ST Gentlemen: Please find the attached Well Completion Report and Log for our West McArthur River Unit #3 Side Track. All of the relevant information should be included in this packet. If there are any questions please contact me at 258-8600. Robert D. Stinson Drilling Engineer Forcenergy Inc. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX ,-,-- STATE OF ALASKA ALASKA O,-AND GAS CONSERVATION L, OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LQ,G, 1. Status of Well Classification of Service WeJ~ OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Forcenerg, Inc. 397-178 3. Address 310 K Street, Suite 700 8. APl Number Anchorage, Alaska 99501 : - -. ·: :;;,: ~ 50- 133-20461 Anchorage 4. Location of well at surface · ' "'" ~ i ~11~~ 9. Unit or Lease Name 2381' FNL, 1323' FWL, Sec. 16, TgN, R14W, SM ?~.~'~.7.~ i ~~ West McArthur River Unit At Top Producing Interval 10. Well Number 1027' FNL, 1254' FEL, Sec. 10, T8N, R14W, SM ~ ~ : i I' WMRU #3 At Total Depth . _...~_.~ .... 11. Field and Pool 773' FNL, 867' FEL, Sec. 10, T8N, R14W, SM West McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. West McArthur River Pool 163' KBI ADL 35911 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 11/13/97 11/26/97I 12/22/97 N/A feet MSLI one 17. Total Depth (MD+TVD)15,450, / 10,096' 18. Plug Back Depth (MD+-I-VD)15,280, / 9,963' I 19' Directi°nal Survey I20' Depth where sssv setYes: X No: N/A feet MD I21' Thickness °f Permafr°stN/A 22. Type Electric or Other Logs Run Induction Sonic, Neutron-Density, Gamma Ray, SP (triple combo) 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 5 1/2" 17 lb. L-80 13,494' 15,450' 6 3/4" 80 bbls 15.8 ppg 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" 14,601' 14,526' 3 3/8" casing guns / 6spf 14,696' - 14,860' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9,491' - 9,622' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Hydraulic Jet Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO 12/31/97 24 TEST PERIOD => 602 141 931 N/AJ 234 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. N/A 50 24-HOUR RATE => 602 141 931 28 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ~ion Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~-~.- ~' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Hemlock Bench I 14,532' 9,349' Hemlock Bench 2 14,579' 9,386' Hemlock Bench 3 14,630' 9,427'i . ' Hemlock Bench 4 14,785' 91551' Hemlock Bench 5 14,930' 9,667' Hemlock Bench 6 14,979' 9,718' West Forelands 15,006' 9,709' 31. LIST OF ATTACHMENTS a) Daily Operations Summary c) Current Well Schematic ~ b) Final Survey d) Abandonment Schematic Signed .I.~'(...~'~ ~' l~e l~b_~..'~~'~"-~ Date 1[/~2-~ /~'((~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Form 10-407 Force ;ergy inc WNIEU #3ST December 22, 1 997 16" 75# K-55 BTC 10 3/4" 45.5# K-55 BTC shoe @ 2,361' MD / 2278' TVD cement to surface Top of liner @ 6,81 7' MD 2 7/8" 6.5# L-80 EUE Tubing shoe @ 7,343' MD / 5,234' TVD 7 5/8" 29# L-80 STL WMRU #3 Original Completion Abandoned November 7, '1997 Top of Liner @ 13,494' MD / 8,619' Whipstock @ 13,640' MD / 8,699' TVD 5 1/2" 1 7# L-80 FL-4S Perforations - 3 3/8" guns 6 spf: 14,696' - 1 4,860' MD 9,491' - 9,622'TVD Trico Type A Jet Pump @ 14,526' 5 1/2" Baker Mod D Perm Pkr @ 14,582' Tubing Tail @ 14,601' PBTD @ 15,280' shoe @ 15,450' / 10.096' TVD HEADQUARTERS Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 305/856-8500 Suite 800 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX Force ",ergy Inc WMRU #3 Abandonment 16" 75~, K-55 BT&C · 10-3/4' 45.5~, K-55, BTC · REVISED 11/3/97 .@ 2361' MD, 2278' TVD with cement to surface Top of 7-5/B' liner (~ 6817' MD @ 7343' MD, 5234' TVD 7 5/8" Cement Retainer ~) 13,644' 73 sxs cement / Top of 5-1/2' Liner @ 13,878' MD ] 7-5/8" 29.04~, L-80, STL "BWD" Packer @ 14,738' 3 3/8" TCP Gun tail ~ 15,063' 5-112' 17#, L-80; FL-4S · ''11= 7 5/8" Cement Retainer @ 13,778' L @ 14,161' MD, 8993' 'i'VD Perforations - 14,805'-14,836' MD 9417'-9439' TVD 14,852'-15,060' MD 9451'-9607' TVD Retainer @ 15,070' MD - Squeeze Perfs @ 15,074'-15,076' Tag Cmt inside liner @ 15,185' MD l~ 15,338' MD, 9824' TVD HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 ^_ _1 ...... ^1_ _1 _ TELEPHONE 907/258-8600 FAX Forcenergy WEST MCARTHUR RIVER UNIT #3ST OPERATIONS SUMMARY October 12, 1997 Report #1 Commenced operations. Unloaded equipment. October 13, 1997 Report #2 Continued Rig-up operations October 14, 1997 Report #3 Continued Rig-up operations October 15, 1997 Report #4 Continued Rig-up operations October 16, 1997 Report #5 Continued Rig-up operations October 17, 1997 Report #6 Continued Rig-up operations October 18, 1997 Report//7 Continued Rig-up operations October 19, 1997 Report #8 Continued Rig-up operations October 20, 1997 Report #9 Continued Rig-up operations October 21, 1997 Report #10 Continued Rig-up operations October 22, 1997 Report #11 Continued Rig-up operations October 23, 1997 Report #12 Continued Rig-up operations October 24, 1997 Report #13 Continued Rig-up operations Forcenergy ,nc WEST MCARTHUR RIVER UNIT #3ST OPERATIONS SUMMARY October 25, 1997 Report # 14 Rig-up completed-1200 hours. Reversed out Jet pump and killed well. Commenced Nippling-up BOP's October 26, 1997 Report # 15 Continued Nippling-up BOP's. October 27, 1997 Attempting BOP's test. Report #16 October 28, 1997 Report #17 Completed BOP's test. Engaged tubing hanger and pulled free. Pulled completion string. October 29, 1997 Report #18 Depth- 13,878' Completed pulling out of hole. Change rams. Picked up bit and scraper. October 30, 1997 Report #19 Depth- 13,878' Cleaned out well to 13,878' Pulled out of hole. October 31, 1997 Report #20 Depth - 13,878' Completed pulling out hole. Picked up 7 5/8" cement retainer. November 1, 1997 Report #21 Depth- 13,878' Could not set retainer, pulled out of hole. Picked up 6 3/4" bit and boot basket. Ran in hole to 13,800'. Pull out of hole. November 2, 1997 Report #22 Depth - 13,778' Completed pulling of hole. Set retainer at 13,778'. November 3, 1997 Report #23 Depth - 13,778' Ran in hole. Engaged retainer, could not breakdown perforations. Spotted 13.7 barrels, 15.8 ppg cement on top of retainer. Pull out of hole. November 4, 1997 Completed pulling out hole. Pulled out of hole. Report #24 Depth - 13,360' Picked up bit and ran in hole to obstruction at 4933' Forcenergy ,nc WEST MCARTHUR RIVER UNIT #3ST OPERATIONS SUMMARY November 5, 1997 Report #25 Depth - 13,649' Picked up bit and scraper. Cleaned out firm cement to 13,649' November 6, 1997 Report #26 Depth- 13,649' Displaced well to polymer drilling fluid. Pull out of hole. November 7, 1997 Report #27 Set Bridge Plug at 13,644'. Depth - 13,644' November 8, 1997 Report #28 Depth - 13,644' Ran into hole with whipstock to 8,091'. Whipstock hung-up. Pull out of hole. November 9, 1997 Report #29 Depth - 13,644' Pull out of hole. Redressed whipstock and ran in hole to 13,126'. November 10, 1997 Rig Repair. Report #30 Depth- 13,644' November 11, 1997 Report #31 Depth- 13,640' Run in hole to 13,411' Orient tool face. Run in hole to 13,640', set tool face 48 degrees to the right of high side. Set whipstock on bottom. November 12, 1997 Report #32 Started milling. Tripped for new mills. Depth- 13,640' November 13, 1997 Report #33 Depth- 13,658' Run in hole with new mills. Mill from 13,622' to 13,651', continued milling to 13,658' Conduct FIT to 10.6 ppg EMW. Pulled out of hole. November 14, 1997 Report #34 Depth- 13,658 ' Lay down Milling assembly, picked up bit and motor. Ran in hole. November 15, 1997 Report #35 Directionally drilled from 13,644' to 13,738' Depth- 13,738' November 16, 1997 Report #36 Depth- 13,771' Directionally drilled from 13,740' to 13,771' Pull out of hole. Forcenergy WEST MCARTHUR RIVER UNIT #3ST OPERATIONS SUMMARY November 17, 1997 Report #37 Depth- 14,153' Run in hole. Directionally drilled from 13,771' to 14,153'. November 18, 1997 Tripped for bit. Report #38 Depth- 14,153' November 19, 1997 Report #39 Directionally drilled from 14,153' to 14,505' Depth- 14,505' November 20, 1997 Report #40. Depth - 14,628' Directionally drilled from 14,505' to 14,628'. Tripped for bit. November 21, 1997 Report #41 Run in hole with bit. Rig repair. Depth - -14,628' November 22, 1997 Report #42 Directionally drill from 14,628' to 14,681' Depth - -14,681 November 23, 1997 Report #43. Directionally drill from 14,681' to 15,040' Depth- 15,040' November 24, 1997 Report #44 Depth- 15,102' Directionally drilled from 15,040' to 15,102'. Tripped for bit. Tested BOPs. November 25, 1997 Report #45 Depth - 15,137' Completed trip. Directionally drilled from 15,102' to 15,137' November 26, 1997 Report #46 Directionally drilled from 15,137' to 15,450' Depth- 15,450' November 27, 1997 Report #47 Short tripped to window at 13,622'. Depth- 15,450' November 28, 1997 Report #48 Depth - 15,450' Strapped out of hole. Rig-up wireline. Quad combo would not pass 14,400'. Run in hole with BHA. November 29, 1997 Report #49 Depth - 15,450' Tagged bottom at 15,450'. Circulated bottoms up. Pulled out of hole. Forcenergy WEST MCARTHUR RIVER UNIT #3ST OPERATIONS SUMMARY November 30, 1997 Report #50 Depth - 15,450' Ran compensated neutron litho-density and dual induction log from 15,448'. Attempted RFTs. Unable to Pass 13,900' Commenced wiper trip. December 1, 1997 Report #51 Depth- 15,450' Completed wiper trip. Commenced running 5 ½" liner. December 2, 1997 Report #52 Depth - 15,450' Ran 5 ~/5" 17# FL-4S L-80 liner to 15.450'. Cemented casing with 80 bbls 15.8 ppg cement. Pull out of hole. December 3, 1997 Report #53 Depth - 15,450' Pull out hole. Picked up 6 3/4" bit and scraper. Run in hole to 13,420', wash to 13,494'. Pulled out of hole. December 4, 1997 Report #54 Depth- 15,280' Picked up 5 ½" scraper and ran in hole to 15,280'. Tagged firm cement. Pull out of hole. December 5, 1997 Report #55 Depth - 15,280' Completed pulling out of hole with 5 1/2" Mill and scraper. Ran CBL / CBT. Picked up 9 7/8" Mill and scraper. Ran in hole. December 6, 1997 Report #56 Depth - 15,280' Ran in hole with mill and scraper to 6,817'. Circulated bottoms up and pulled out hole. Picked up 5 1/2" liner packer setting tool. Ran in hole. Attempted to reset liner top packer. December 7, 1997 Report #57 Depth - 15,280' Pull out of hole. Picked up 7 5/8" RTTS and ran in hole. Set RTTS and performed negative test on 5 1/2" liner lap. Performed positive test to 1500 psi.- leaked. Pulled out of hole. December 8, 1997 Report #58 Depth - 15,280' Tripped for Polish Mill. Cleaned out liner hanger tie back sleeve from 13,496' to 13,502' Forcenergy WEST MCARTHUR RIVER UNIT #3ST OPERATIONS SUMMARY December Pulled out receptacle. 9, 1997 Report #59 Depth- 15,280' of hole. Picked up new 5 1/2" liner top packer. Attempted to set in tie back No success. Pull out of hole. Redress packer. December Test BOPs Pulled out 10, 1997 Report #60 Depth- 15,280' · Run in hole with 5 1/5" liner top packer to 13,494'. Set packer at 13,400'. of hole. December 11, 1997 Report #61 Depth- 15,280' Ran in hole with RTTS and set at 13,442'. Good test no flow. Performed positive 2000 psi test - OK. Pulled out hole. Ran in hole with Baker PBR Mill to top of 7 5/8" liner. Cleaned out tie back. December 12, 1997 Report #62 Depth- 15,280' Pulled out hole. Picked up 7 5/8" liner top packer and ran in hole. Set packer in tie back sleeve at 6817' Tripped for RTTS. Set RTTS at 6,175' Performed negative test -no flow. Performed positive test to 1400 psi.-good test. Pulled out of hole. December 13, 1997 Report #63 Depth- 15,280' Completed pulling out hole. Ran in hole with 2 7/8" Mule shoe to plug back TD at 15,280' Displaced well to lease water. December 14, 1997 Report #64 Depth- 15,280' Pull out of hole. Laid down drill pipe. Tripped in hole with tubing. December 15, 1997 Report #65 Depth- 15,280' Displaced well to crude oil from 15,211' Pull out of hole. December 16, 1997 Report #66 Depth- 15,280' Completely pulling out of hole. Rig-up wireline. Perforated the following the intervals with 3 3/8"guns at 6 SPF:14,860' to 14,824'; 14,825' to 14,795'; 14,796' to 14,756'. Well flowing. Shut in with 110 psi. December 17, 1997 Report #67 Depth- 15,280' Continued perforating from: 14,756' to 14,726'; 14,726' to 14,696'; 14,696' to 14,660'; 14,660' to 14,645' Picked up 5 1/2" production packer. Forcenergy ,nc WEST MCARTHUR RIVER UNIT #3ST OPERATIONS SUMMARY December 18, 1997 Report #68 Depth- 15,280' Run in hole with packer. Could not enter liner. Pulled out hole. Redress guide shoe and mn in hole. December 19, 1997 Report #69 Set packer at 14,581' Pull out of hole. Depth- 15,280' December 20, 1997 Report g70 Depth - 15,280' Completed pulling out of hole. Picked up jet pump, and ran in hole on 2 7/8" tubing, locate packer, spaced out and landed hanger. December 21, 1997 Report gT1 Depth - 15,280' Set standing valve in pump cavity at 14,545' Bundle tested well to 1100 psi for 15 minutes. Nipple down BOP's, nipple-up andtest tree. December 22, 1997 Report #72 Depth - 15,480' Well to production. Released Rig at 0600 hours December 22, 1997. Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 06 Jan 1998 Client .... : Field ..... : Well ...... : Vert sect.: DD engnr..: Units ..... : FORCENERGY INC. Cook Inlet WMR-3ST 56.73 deg az FEET Position calc.: DLS calc meth.: Survey Date...: KB Elevation..: Reference ..... Magnetic dcln.: Minimum Curvature Lubinski 06 Jan 1998 163.00 ft +21. 756 (E) WELLHEAD coordinates ' 0,0 S MEASURED INCLN T DEPTH ANGLE 8 0.00 0.00 0 285.00 0.50 0 537.00 1.50 0 693.00 1.90 0 724.00 1.90 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) Pg' 1 DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM DL/ WELLHEAD 100 0.00 0.00 -163.00 0.00 56.00 285.00 122.00 1.24 32.00 536.96 373.96 5.34 49.60 692.89 529.89 9.76 45.40 723.87 560.87 10.77 0.00 N 0.00 E <TIE 0.70 N 1.03 E 0.18 4.11 N 3.69 E 0.42 7.52 N 6.74 E 0.42 8.21 N 7.50 E 0.45 0 755.00 2.10 0 787.00 2.50 0 838.00 2.80 0 863.00 3.10 0 895.00 3.40 45.90 754.85 591.85 11.83 40.40 786.83 623.83 13.08 55.70 837.77 674.77 15.39 47.70 862.74 699.74 16.67 50.70 894.69 731.69 18.47 8.97 N 8.27 E 0.65 9.90 N 9.15 E 1.43 11.45 N 10.90 E 1.50 12.25 N 11.90 E 2.03 13.44 N 13.27 E 1.08 0 925.00 3.60 0 957.00 3.70 0 988.00 4.20 51.80 924.63 761.63 20.29 50.40 956.57 793.57 22.32 49.50 987.49 824.49 24.44 14.58 N 14.70 E 0.70 15.86 N 16.29 E 0.42 17.24 N 17.92 E 1.63 Page 1 0 1019.00 4.60 50.40 1018.40 ^Station Types- O/UNKNOWN 8/TIE-IN 855.40 26.80 18.77 N 19.74 E 1.31 Page 2 WMR-3ST S MEASURED INCLN T DEPTH ANGLE 1050.00 5.00 1081.00 5.70 1113.00 6.10 1144.00 6.80 1175.00 7.40 1207.00 7.90 1238.00 8.90 1269.00 9.70 1301.00 10.10 1332.00 10.90 1363.00 11.40 1394.00 12.20 1425.00 12.90 1457.00 13.50 1488.00 14.30 1518.00 15.20 1548.00 15.80 1579.00 16.60 1610.00 17.10 1641.00 17.80 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 50.70 1049.29 886.29 29.38 49.80 1080.16 917.16 32.25 51.30 1111.99 948.99 35.52 48.50 1142.79 979.79 38.98 50.60 1173.55 1010.55 42.78 20.41 N 21.75 E 22.26 N 23.97 E 24.35 N 26.51 E 26.60 N 29.17 E 29.08 N 32.09 E 49.80 1205.27 1042.27 47.01 49.60 1235.94 1072.94 51.51 51.00 1266.53 1103.53 56.48 49.10 1298.05 1135.05 61.95 51.30 1328.53 1165.53 67.56 31.81 N 35.36 E 34.74 N 38.81 E 37.94 N 42.67 E 41.47 N 46.88 E 45.08 N 51.23 E 50.70 1358.95 1195.95 73.52 49.60 1389.29 1226.29 79.82 51.30 1419.55 1256.55 86.52 49.00 1450.71 1287.71 93.77 50.10 1480.80 1317.80 101.16 48.85 N 55.88 E 52.92 N 60.75 E 57.20 N 65.94 E 61.89 N 71.55 E 66.72 N 77.22 E 50.10 1509.81 1346.81 108.75 50.00 1538.72 1375.72 116.71 49.80 1568.49 1405.49 125.30 50.80 1598.16 1435.16 134.23 50.70 1627.73 1464.73 143.47 71.62 N 83.08 E 76.77 N 89.22 E 82.34 N 95.84 E 88.08 N 102.75 E 93.96 N 109.95 E 06 Jan 1998 DL/ 100 1.29 2.27 1.34 2.47 2.11 1.60 3.23 2.68 1.61 2.89 1.66 2.68 2.55 2.49 2.72 3.00 2.00 2.59 1.86 2.26 Page 2 1673.00 1705.00 1735.00 1767.00 1798.00 1829.00 ^Station T 18.70 49 19.00 50 19.50 49 20.00 49 20.60 49 21.20 49 ypes- O/UNKNOWN .70 1658.12 1495.12 153.43 .30 1688.40 1525.40 163.70 · 60 1716.73 1553.73 173.52 · 80 1746.84 1583.84 184.25 .70 1775.92 1612.92 194.92 · 60 1804.88 1641.88 205.90 100.37 N 107.02 N 113.38 N 120.38 N 127.33 N 134.49 N 117.65 E 125.57 E 133.14 E 141.39 E 149.60 E 158.02 E 2.98 1.12 1.84 1.58 1.94 1.94 Page 3 WMR-3ST S MEASURED INCLN T DEPTH ANGLE 1860.00 1892.00 1923.00 1954.00 1986.00 2017.00 2048.00 2080.00 2111.00 2142.00 2174.00 2204.00 2242.00 2274.00 2306.00 21.80 22.60 23.00 23.80 24.40 25.20 25.90 26.70 27.50 28.30 29.10 29.90 31.00 32.00 32.20 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 50.50 1833.72 1670.72 217.18 49.40 1863.35 1700.35 229.19 50.30 1891.93 1728.93 241.11 49.70 1920.38 1757.38 253.34 49.20 1949.59 1786.59 266.30 141.78 N 166.73 E 149.56 N 175.99 E 157.31 N 185.17 E 165.22 N 194.60 E 173.72 N 204.53 E 49.10 1977.73 1814.73 279.19 48.50 2005.70 1842.70 292.43 47.50 2034.38 1871.38 306.45 48.20 2061.98 1898.98 320.40 47.70 2089.38 1926.38 334.73 182.22 N 214.36 E 191.03 N 224.42 E 200.52 N 234.96 E 209.99 N 245.43 E 219.71 N 256.20 E 47.70 2117.44 1954.44 349.91 48.20 2143.56 1980.56 364.51 48.40 2176.31 2013.31 383.56 48.30 2203.60 2040.60 400.10 48.20 2230.71 2067.71 416.92 230.05 N 267.57 E 239.94 N 278.54 E 252.76 N 292.91 E 263.87 N 305.41 E 275.19 N 318.09 E 06 Jan 1998 DL/ 100 2.21 2.82 1.71 2.69 1.98 2.58 2.41 2.86 2.78 2.69 2.50 2.79 2.91 3.13 0.65 Page 3 2416.00 33.80 2447.00 34.90 2478.00 35.50 2509.00 36.70 2540.00 37.70 48.50 48.70 49.80 48.70 49.10 2571.00 38.70 2602.00 39.50 2633.00 40.00 2664.00 40.10 2696.00 40.40 49.40 49.30 49.30 49.50 49.10 2727.00 40.80 2322.96 2159.96 476.19 2348.55 2185.55 493.50 2373.88 2210.88 511.22 2398.93 2235.93 529.33 2423.62 2260.62 547.90 2447.98 2284.98 566.90 2472.04 2309.04 586.29 2495.87 2332.87 605.95 2519.60 2356.60 625.73 2544.03 2381.03 646.23 50.10 2567.56 2404.56 666.25 ^Station Types: O/UNKNOWN 315.00 N 326.57 N 338.23 N 350.16 N 362.48 N 374.99 N 387.72 N 400.65 N 413.63 N 427.11 N 440.19 N 362.86 E 375.98 E 389.52 E 403.35 E 417.48 E 432.00 E 446.83 E 461.86 E 477.01 E 492.68 E 508.05 E 1.46 3.57 2.82 4.40 3.32 3.28 2.59 1.61 0.53 1.24 2.46 Page 4 WMR-3ST S MEASURED INCLN T DEPTH ANGLE 2757.00 41.20 2788.00 41.70 2820.00 42.20 2850.00 43.00 2882.00 43.70 2912.00 44.10 2942.00 44.30 2973.00 44.80 3004.00 45.50 3035.00 45.90 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 50.40 2590.21 2427.21 685.81 50.60 2613.44 2450.44 706.21 50.70 2637.24 2474.24 727.48 51.00 2659.32 2496.32 747.68 51.30 2682.59 2519.59 769.54 452.77 N 523.18 E 465.83 N 539.01 E 479.39 N 555.55 E 492.21 N 571.30 E 505.99 N 588.41 E 51.60 2704.21 2541.21 790.25 51.80 2725.72 2562.72 811.09 51.40 2747.81 2584.81 832.75 50.90 2769.67 2606.67 854.62 50.60 2791.32 2628.32 876.68 518.95 N 604.68 E 531.92 N 621.09 E 545.42 N 638.13 E 559.21 N 655.25 E 573.25 N 672.43 E 06 Jan 1998 DL/ 100 1.49 1.67 1.58 2.75 2.28 1.50 0.81 1.85 2.53 1.46 Page 4 3067.00 46.70 3097.00 47.20 3128.00 48.10 3158.00 49.10 3189.00 49.90 3220.00 50.30 3251.00 50.80 3282.00 51.00 3312.00 51.50 3343.00 52.40 3381.00 53.70 3467.00 56.80 3559.00 57.50 3651.00 58.00 3744.00 58.60 3841.00 58.70 ^Station Types- 50.20 49.40 49.50 49.20 49.20 49.10 48.80 48.20 47.70 48.00 47.90 46.70 46.90 46.80 46.70 45.90 0/UNKNOWN 2813.43 2650.43 899.68 2833.91 2670.91 921.44 2854.79 2691.79 944.17 2874.63 2711.63 966.48 2894.76 2731.76 989.85 2914.65 2751.65 1013.43 2934.35 2771.35 1037.14 2953.90 2790.90 1060.95 2972.68 2809.68 1084.07 2991.78 2828.78 1108.19 3014.62 2851.62 1138.20 3063.64 2900.64 1207.90 3113.54 2950.54 1284.03 3162.64 2999.64 1360.68 3211.50 3048.50 1438.61 3261.97 3098 . 97 1520.07 587.99 N 690.26 E 602.15 N 707.00 E 617.04 N 724.41 E 631.70 N 741.48 E 647.10 N 759.32 E 662.66 N 777.31 E 678.38 N 795.37 E 694.32 N 813.38 E 709.99 N 830.76 E 726.37 N 848.85 E 746.71 N 871.40 E 794.63 N 923.32 E 847.54 N 979.66 E 900.75 N 1036.42 E 954.97 N 1094.06 E 1012.20 N 1153.94 E 2.66 2.56 2.91 3.42 2.58 1.31 1.78 1.63 2.11 3.00 3.43 3.78 0.78 0.55 0.65 0.71 Page 5 WMR-3ST S MEASURED INCLN T DEPTH ANGLE 3935.00 58.70 4028.00 59.10 4122.00 58.60 4214.00 58.20 4307.00 58.20 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 46.30 3310.81 3147.81 1599.01 46.80 3358.84 3195.84 1677.39 47.00 3407.47 3244.47 1756.66 47.20 3455.67 3292.67 1833.91 47.00 3504.68 3341.68 1911.83 1067.89 N 1211.82 E 1122.66 N 1269.63 E 1177.62 N 1328.37 E 1230.96 N 1385.77 E 1284.77 N 1443.67 E 06 Jan 1998 DL/ 100 0.36 0.63 0.56 0.47 0.18 Page 5 4401.00 57.40 4493.00 56.80 4587.00 56.30 4679.00 55.70 4772.00 55.20 47.70 3554.77 3391.77 1990.31 47.50 3604.74 3441.74 2066.58 48.30 3656.56 3493.56 2144.08 48.10 3708.00 3545.00 2219.50 48.20 3760.75 3597.75 2295.24 4864.00 55.00 4957.00 54.70 5050.00 54.70 5141.00 54.50 5234.00 54.00 48.30 3813.38 3650.38 2369.87 48.40 3866.92 3703.92 2445.10 49.00 3920.67 3757.67 2520.25 48.00 3973.38 3810.38 2593.66 48.70 4027.72 3864.72 2668.33 5327.00 54.00 5421.00 53.80 5514.00 54.20 5608.00 54.20 5702.00 54.80 48.40 4082.38 3919.38 2742.81 47.40 4137.77 3974.77 2817.85 47.70 4192.43 4029.43 2892.13 47.60 4247.42 4084.42 2967.41 47.40 4302.00 4139.00 3042.95 5797.00 55.00 5891.00 55.30 5984.00 55.80 6077.00 56.00 6169.00 56.80 47.20 4356.63 4193.63 3119.62 47.50 4410.34 4247.34 3195.73 46.50 4462.95 4299.95 3271.31 48.40 4515.09 4352.09 3347.31 48.30 4566.01 4403.01 3423.12 6286.00 57.20 48.00 4629.73 4466.73 3520.14 ^Station Types- O/UNKNOWN 1338.66 N 1502.17 E 1.06 1390.75 N 1559.21 E 0.68 1443.33 N 1617.40 E 0.89 1494.17 N 1674.26 E 0.68 1545.27 N 1731.32 E 0.54 1595.51 N 1787.61 E 0.23 1646.05 N 1844.43 E 0.33 1696.14 N 1901.45 E 0.53 1745.29 N 1957.01 E 0.92 1795.45 N 2013.40 E 0.81 1845.26 N 2069.80 E 0.26 1896.18 N 2126.15 E 0.89 1946.96 N 2181.67 E 0.50 1998.32 N 2238.01 E 0.09 2050.02 N 2294.43 E 0.66 2102.73 N 2351.55 E 0.27 2154.99 N 2408.29 E 0.41 2207.29 N 2464.37 E 1.04 2259.37 N 2521.10 E 1.71 2310.29 N 2578.36 E 0.87 2375.76 N 2651.45 E 0.40 Page WMR-3ST S MEASURED INCLN T DEPTH ANGLE RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 06 Jan 1998 DL/ 100 Page 6 6379.00 56.90 6472.00 56.80 6565.00 56.50 6660.00 55.60 6754.00 55.20 49.50 49.00 49.60 49.20 48.80 6849.00 54.70 6945.00 53.70 7032.00 53.50 7125.00 52.70 7218.00 54.00 48.60 49.00 49.00 49.80 51.00 7265.00 55.40 7356.00 56.00 7450.00 55.60 7546.00 55.10 7640.00 53.90 51.40 51.80 52.30 52.30 51.80 7730.00 53.90 7824.00 55.60 7918.00 55.80 8012.00 56.00 8103.00 56.10 52.90 51.60 52.50 52.00 52.30 8198.00 56.70 8292.00 56.50 8386.00 56.90 8480.00 56.70 8573.00 56.70 51.40 51.50 51.80 51.40 51.20 8667.00 57.20 51.70 ^Station Types' O/UNKNOWN 4680.31 4731.17 4782.30 4835.35 4888.73 4943.29 4999.44 5051.07 5106.91 5162.42 5189.58 5240.86 5293.70 5348.28 5402.86 5455.89 5510.14 5563.12 5615.82 5666.64 5719.21 5770.96 5822.56 5874.04 5925.09 5976.36 4517.31 4568.17 4619.30 4672.35 4725.73 4780.29 4836.44 4888.07 4943.91 4999.42 5026.58 5077.86 5130.70 5185.28 5239.86 5292.89 5347.14 5400.12 5452.82 5503.64 5556.21 5607.96 5659.56 5711.04 5762.09 5813.36 3597.42 3674.62 3751.66 3829.82 3906.49 3983.49 4060.61 4130.00 4203.76 4277.91 4316.09 4390.97 4468.45 4547.19 4623.46 4695.96 4772.49 4849.88 4927.48 5002.72 5081.56 5159.70 5237.96 5316.30 5393.68 5472.14 2427.21 N 2710.12 E 1.39 2478.04 N 2769.11 E 0.46 2528.70 N 2828.00 E 0.63 2579.98 N 2887.84 E 1.01 2630.74 N 2946.23 E 0.55 2682.07 N 3004.66 E 2733.36 N 3063.24 E 2779.30 N 3116.09 E 2827.70 N 3172.56 E 2875.25 N 3230.05 E 0.55 1.10 0.23 1.10 1.74 2899.29 N 3259.94 E 3.06 2945.98 N 3318.86 E 0.75 2993.79 N 3380.16 E 0.61 3042.08 N 3442.65 E 0.52 3089.14 N 3502.99 E 1.35 3133.56 N 3560.57 E 0.99 3180.56 N 3621.25 E 2.13 3228.32 N 3682.49 E 0.82 3275.97 N 3744.03 E 0.49 3322.29 N 3803.64 E 0.29 3371.17 N 3865.86 E 1.01 3420.07 N 3927.23 E 0.23 3468.82 N 3988.85 E 0.50 3517.68 N 4050.49 E 0.41 3566.28 N 4111.15 E 0.18 3615.38 N 4172.77 E 0.69 WMR-3ST 06 Jan 1998 Page 7 Page 7 S MEASURED INCLN T DEPTH ANGLE 8759.00 56.90 8854.00 57.10 8948.00 57.80 9042.00 58.40 9134.00 58.40 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 51.80 6026.40 5863.40 5549.05 51.80 6078.14 5915.14 5628.43 52.20 6128.71 5965.71 5707.39 52.50 6178.39 6015.39 5786.96 52.10 6226.59 6063.59 5865.08 3663.17 N 4233.40 E 3712.44 N 4296.01 E 3761.22 N 4358.45 E 3809.97 N 4421.63 E 3857.89 N 4483.63 E 9230.00 58.70 9321.00 58.70 9415.00 58.20 9508.00 58.30 9602.00 58.20 52.30 6276.68 6113.68 5946.72 52.60 6323.96 6160.96 6024.26 53.00 6373.14 6210.14 6104.18 53.20 6422.08 6259.08 6183.10 52.80 6471.55 6308.55 6262.87 3908.08 N 4548.34 E 3955.47 N 4609.99 E 4003.90 N 4673.80 E 4051.39 N 4737.04 E 4099.49 N 4800.88 E 9696.00 57.80 9785.00 57.30 9881.00 57.40 9972.00 56.80 10066.00 56.70 53.00 6521.36 6358.36 6342.40 53.60 6569.11 6406.11 6417.37 52.30 6620.91 6457.91 6498.02 52.50 6670.34 6507.34 6574.21 51.70 6721.88 6558.88 6652.56 4147.58 N 4864.46 E 4192.46 N 4924.67 E 4241.16 N 4989.18 E 4287.78 N 5049.71 E 4336.07 N 5111.74 E 10160.00 56.90 10252.00 56.80 10342.00 57.10 10437.00 57.00 10530.00 57.00 52.10 6773.35 6610.35 6730.94 52.00 6823.66 6660.66 6807.71 52.10 6872.74 6709.74 6882.89 51.70 6924.41 6761.41 6962.33 50.40 6975.06 6812.06 7039.94 4384.60 N 5173.64 E 4431.97 N 5234.38 E 4478.36 N 5293.87 E 4527.55 N 5356.60 E 4576.58 N 5417.25 E 10621.00 56.40 10714.00 56.50 10807.00 56.70 10899.00 56.40 10993.00 55.60 50.10 7025.02 6862.02 7115.51 50.40 7076.42 6913.42 7192.52 51.20 7127.62 6964.62 7269.74 50.70 7178.33 7015.33 7346.12 50.00 7230.89 7067.89 7423.56 4625.21 N 5475.73 E 4674.78 N 5535.32 E 4723.85 N 5595.49 E 4772.20 N 5655.10 E 4821.93 N 5715.10 E 11087.00 55.40 50.70 7284.13 7121.13 7500.55 4871.36 N 5774.75 E ^Station Types- O/UNKNOWN DL/ 100 0.34 0.21 0.83 0.69 0.37 0.36 0.28 0.64 0.21 0.38 0.46 0.80 1.14 0.68 0.72 0.41 0.14 0.35 0.37 1.17 0.71 0.29 0.75 0.56 1.05 0.65 Page 8 WMR-3ST 06 Jan 1998 Page 8 S MEASURED T DEPTH 11181.00 11272.00 11363.00 11456.00 11546.00 11639.00 11731.00 11823.00 11916.00 12009.00 12103.00 12196.00 12288.00 12381.00 12472.00 12564.00 12657.00 12751.00 12844.00 12938.00 13030.00 13136.00 13230.00 INCLN ANGLE 55.80 56.60 57.00 57.60 56.90 56.50 56.70 57.30 57.20 55.80 55.80 55.40 55.80 55.80 55.40 55.70 55.70 55.80 56.60 56.70 56.90 56.60 56.10 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 50.20 7337.24 7174.24 7577.64 50.10 7387.86 7224.86 7652.76 49.00 7437.69 7274.69 7728.31 50.20 7487.94 7324.94 7805.96 50.30 7536.62 7373.62 7881.17 4920.75 N 5834.55 E 4969.20 N 5892.61 E 5018.60 N 5950.55 E 5069.32 N 6010.15 E 5117.72 N 6068.34 E 49.30 7587.68 7424.68 7958.33 50.20 7638.33 7475.33 8034.56 49.90 7688.44 7525.44 8111.20 50.20 7738.75 7575.75 8188.88 50.00 7790.08 7627.08 8265.91 5167.89 N 6127.71 E 5217.52 N 6186.33 E 5267.06 N 6245.48 E 5317.29 N 6305.44 E 5367.03 N 6364.94 E 49.50 7842.91 7679.91 8343.08 49.70 7895.45 7732.45 8419.22 49.60 7947.43 7784.43 8494.55 49.70 7999.70 7836.70 8570.89 49.70 8051.12 7888.12 8645.41 5417.26 N 6424.28 E 5467.00 N 6482.71 E 5516.15 N 6540.56 E 5565.95 N 6599.18 E 5614.51 N 6656.45 E 49.50 8103.16 7940.16 8720.68 49.50 8155.57 7992.57 8796.90 49.70 8208.47 8045.47 8874.00 49.20 8260.21 8097.21 8950.65 49.20 8311.88 8148.88 9028.50 5663.68 N 6714.22 E 5713.58 N 6772.64 E 5763.93 N 6831.81 E 5814.18 N 6890.53 E 5865.48 N 6949.97 E 49.60 8362.26 8199.26 9104.85 49.70 8420.38 8257.38 9192.82 50.20 8472.46 8309.46 9270.52 5915.58 N 7008.42 E 5972.98 N 7075.98 E 6023.33 N 7135.88 E DL/ 100 0.61 0.88 1.10 1.26 0.78 1.00 0.85 0.71 0.29 1.52 0.44 0.47 0.44 0.09 0.44 0.37 0.00 0.21 0.97 0.11 0.42 0.29 0.69 Page 9 13323.00 56.00 13416.00 56.10 49.80 8524.40 8361.40 9347.13 49.80 8576.34 8413.34 9423.72 13510.00 56.60 50 . 30 8628 . 43 8465.43 9501.43 ^Station Types- O/UNKNOWN 6072.91 N 7194.98 E 6122.71 N 7253.90 E 6172.95 N 7313.89 E 0.37 0.11 0.69 Page 9 WMR-3ST S MEASURED INCLN T DEPTH ANGLE 13604.00 56.20 6 13624.00 57.70 6 13666.00 56.10 6 13710.00 54.40 6 13715.00 53.90 6 13732.00 51.80 6 13760.00 50.80 3 13795.00 47.90 3 13889.00 41.10 3 13990.00 39.60 3 14082.00 37.80 3 14179.00 38.30 3 14273.00 39.40 3 14370.00 40.20 3 14464.00 37.40 3 14560.00 37.40 3 14659.00 36.60 3 14755.00 36.60 RECORD OF SURVEY (Calculated from a tie-in station at DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART 50.00 8680.45 8517.45 9579.21 50.37 8691.35 8528.35 9595.86 51.14 8714.29 8551.29 9630.86 51.95 8739.37 8576.37 9666.86 52.04 8742.30 8579.30 9670.90 52.35 8752.56 8589.56 9684.40 52.86 8770.07 8607.07 9706.20 53.50 8792.87 8629.87 9732.70 54.70 8859.87 8696.87 9798.47 55.60 8936.85 8773.85 9863.84 56.00 9008.64 8845.64 9921.35 54.90 9085.03 8922.03 9981.12 55.60 9158.23 8995.23 10040.06 53.80 9232.76 9069.76 10102.11 54.20 9306.01 9143.01 10160.93 53.50 9382.27 9219.27 10219.17 52.70 9461.34 9298.34 10278.62 56.00 9538.42 9375.42 10335.79 06 Jan 1998 0 MD) COORDINATES-FROM DL/ WELLHEAD 100 6223.12 N 7373.99 E 0.50 6233.86 N 7386.87 E 7.66 6256.12 N 7414.12 E 4.11 6278.60 N 7442.42 E 4.15 6281.09 N 7445.62 E 10.11 6289.40 N 7456.32 E 12.44 6302.67 N 7473.68 E 3.84 6318.59 N 7494.94 E 8.40 6357.23 N 7548.25 E 7.29 6394.60 N 7601.91 E 1.59 6426.94 N 7649.48 E 6460.84 N 7698.71 E 6494.45 N 7747.16 E 6530.33 N 7797.83 E 6564.95 N 7845.47 E 1.98 0.87 1.26 1.45 2.99 6599.35 N 7892.55 E 6635.12 N 7940.20 E 6668.47 N 7986.70 E 0.44 0.94 2.05 Page 10 3 14851.00 37.50 57.10 9615.04 9452.04 3 14946.00 36.40 57.10 9690.95 9527.95 3 15040.00 34.90 57.10 9767.34 9604.34 3 15149.00 34.90 57.10 9856.73 9693.73 3 15248.00 36.80 56.40 9936.97 9773.97 3 15343.00 37.60 57.10 10012.64 9849.64 3 15408.00 38.80 56.60 10063.72 9900.72 J 15450.00 39.60 57.00 10096.27 9933.27 ^Station Types: O/UNKNOWN 3/MWD 6/INCLIN ONLY Final closure from wellhead: 10816.1 FEET 10393.63 10450.74 6700.34 N 8034.96 E 6731.36 N 8082.90 E 10505.52 10567.88 10625.86 10683.30 10723.49 6761.12 N 8128.90 E 6794.99 N 8181.26 E 6826.79 N 8229.75 E 6858.28 N 8277.78 E 6880.26 N 8311.43 E 10750.04 6894.79 N 8333.64 E J/PROJECTED at 50.40 1.16 1.16 1.60 0.00 1.96 0.95 1.91 2.00 Page 11 Force ,ergy inc April 25, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 The attached Application for Sundry Approvals details the verbal request by Mr. Paul White and approval by Mr. Blair Wondzell on November 3rd, 1997 to change the plug back design of West McArthur River Unit #3. An injection rate could not be obtained below a cement retainer set above the producing perforations. Subsequently, approval was requested and granted to balance a cement plug above the cement retainer and cap the plug with an additional cement retainer. If there are any questions, please contact me at (907) 258-8600. Paul White Drilling Forcenergy Inc NOV 2 A~hOra~ HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX SUNDRY REVISION Background The original abandonment of the WMRU #3 production zone was designed to be down squeezed through a retainer set at approximately 13,700' with a volume of cement equal to the 7 5/8" and 5 1/2" liner volume to 15,070' (PBTD) plus 30 bbls or until cement lockup. The cement retainer was set at 13,778', however, an injection rate could not be established with 3,500 psi. Revision A verbal request was made to and granted by Mr. Blair Wondzell on November 3rd, 1997 to abandon attempts to down squeeze cement below the cement retainer at 13,778'. The agreed procedure was to balance a cement plug on top of the cement retainer, polish it to the new plug back depth of 13,649' and cap it with another cement retainer at 13,644'. These operations were completed on November 7th, 1997. Attached are the Sundry Application with the revised plugs and a detailed drawing of the abandonment. WMRU ft3 Abandonment 16' 75~, K-55 BT&C 10-3/4' 45.5~, K-55, BTC ~1 REVISED 11/3/97 I1~ . @ 2361' MD, 2278' TVD with cement to surface Top of 7-5/'8' liner ~ 6817' MD 7343' MD, 5234' TVD 7 5/8" Cement Retainer @ 13,644' 73 sxs cement / Top of 5-1/2" Liner @ 13,878' MDI 7-5/8" 29.04~, L-80, STL 66 bbls Cement Slurry "BWD" Packer @ 14,738' 3 3/8" TCP Gun tail @ 15,063' 5-1/2' 17#, L--80, FL-4S ~1 7 5/8" Cement Retainer @ 13,778' L @ 14,161' MD, 8993' TVD Perforations - 14,805'-14,836' MD 9417'-9439' ']'VD 14,852'-15,060' MD 9451'-9607' TVD Retainer @ 15,070' MD - Squeeze Perfs @ 15,074'-15,076' Tag Cmt inside liner (f~ 15,185' MD I- UP~I,~_I~IE.I~ y Il'iL., · :'l " 'rcenergy Inc . 310 K Street, Suite 700 Anchorage, Alasl~a 99501 (907) 258-8600 258-8601: FAX FAX TRANSMITTAL SHEET FAX: Phone: :-- ~ntend~ on~ f~ ~e u~ ~ ~e ~duM or ~ ,am~ abov.. If ~e ~er ~ ~a m~ le ~ ~, intend~"~iPlenb ~ a~.h~mby ~fl~ ~ ~y ~M~, ~b~on or copy of ~e ~ b ~y ~~. ~ y~ r~ve ~s ~~ In e~r, ~e~ i~~y ~ ~ ~ t~epho,e, a~ r~m ~e. ~ ~ ~ us ~ ~e a~ve address ~a ~e U~t~ ~ Po~ Se~. ~k y~.' F/CCAL.,lUTX3,C~/IIf~/ , MESSAGE: WMRU #3 Abandonment 16' 75~, K-55 BT&C ,~ 10-3/4' 45,5~, K-55, BTC ~ ,{~ 2361' MD, 2278' TVD with cement to surface Top of 7-5/B' liner ~ 6817' MD 7343' MD, 5234' TVD Top 0~ 5-1/2' Liner ~ 13,878' MD 7-5/$" 29.04~, L-80, STL 7 5/8" Cement Retainer @ 13,700' 14,161' MD, 8993' TVD 66 bbis Cement Slurry ~BWD~' Packer @ 14,7. 38~. 3 3/8' TCP Gun tail ~ 15,063' 5-1/2" 17#, L-80, FL-4$ J 14,805'-14,B36' MD 9417'-9439' TVD 14,852'-15,060' MD 9451'~9607' TVD Retainer ~ 15,070' MC) Squeeze Per~s ~ 15,074'-15,076' Tag Cmt inside liner ~ 15,185' MD 15,338' MD, 9824' TVD MEMORANDUM TO: David John.~~, Chairmarf~,¥ w THRU: Blair ondzell, P. I. Supervisor FROM: Chuck Scheve, /--- ~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 26, 1997 FILE NO: a6tkjzee.doc SUBJECT: BOPE Test- Nabors 160 West McArthur River 3RD PTD 94 -113 Sunday October 26, 1997: I traveled to the Forcenergy West McAdhur River Well # 3RD and witnessed the initial BOPE test on Nabors Rig 160. As the attached AOGCC BOPE Test Report shows there were 10 failures. The Pipe Rams, 4 Door Seals, 2 Choke Manifold valves and the casing pressure gauge failed during testing and were repaired at the time. The choke position indicator and the manual valve on the choke line required parts that were not available immediately but are to be repaired before drilling the window in the casing. The test proved to be a marathon with several other minor problems adding to the length. Throughout the duration of the test the Forcenergy and Nabors personnel demonstrated a desire to properly repair the equipment as problems arose. The Rig in general appeared to be in fair condition considering the extended shut down period. Summary: I witnessed the initial BOPE test on Nabors Rig 160 drilling the Forcenergy West McArthur River 3RD well. NABORS 160, 10126/97, TEST TIME 30 HOURS, 10 FAILURES Attachment: a6tkjzee.xls X Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: NABORS Operator: BPX Well Name: West McArthur River 3RD Casing Size: Set @ Test: Initial X Weekly DATE: 10/26/97 Rig No. 160 PTD# 94/113 Rig Ph.# 776-5580 Rep,: Mike Murray Rig Rep.: Paul Smith Location: Sec. 16 T. 8N R. 14E Meridian Seward Other ~lSC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Dri. Rig OK Hazard Sec. YES, BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 250/2500 250/5000 F/P 250/5000 F/P 250/5000 F/P 250/5000 P 250/5000 P N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Math Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 500~5000 P 1 500~5000 P 2 500/5,000 P 2 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 250/5,000 F/P 32 250/5,000 P 1 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 19oo 3,000 I P 1, 700 P 0 minutes 20 sec. minutes 20 sec. YES Remote: YES Psig. Number of Failures: lO ,Test Time: 30.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 2 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS:,. Failures on 4 Door seals repaired, Pipe Rams repaired, 2 choke manifold valves repaired, casing pressure Gague ret~ired , choke position indcator parts on order,~manual valve on choke line waiting on parts '~ Distribution: odg-Well File c- Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021L (Rev. 12/94) a6tkjzee ~ON 15:41 FAX 907 258 8601 P'OK~m~K~X aha~ha Forcehergy Inc October 20, 1997 Alaska Oil and Gas Conservation Commission Blair Wondzell 3001 Porcupine Drive Anchorage, AK 99501 Re: Revised Application for Sundn/Approvals West McArthur River Unit #3 Forcenergy requests approval to revise the cement abandonment on the previous Sundry Approval for WMRU ~3 submitted October 10~, 1997. It is proposed to set a cement retainer at 13,700' and down squeeze a volume of cement equal to the 7 5/8" And 5 %" liner volume to 15, 070' (PBTD) plus 30 bbls or until cement Iockup. Severe loss circulation is expected due to depletion in the current producing zone. Attempts to recover the packer and gun junk in the hole would necessitate the use of lost circulation matedal which could hinder an effective abandonment plan (attached) avoids the use of lost circulation matedal and isolates the perforations from excessive hydrostatic after the cement job with a retainer. If there any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc 199.7 PDW:jpk Alas!,-.a Oil & uao Cons. Anchora§~ F:W, OCP, JKRAMER~Ialr Won~tzel110-20.97.doc Date Modified: 10/20/97 Date Prepared: 10120/97 pc HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florid~t 33129-2237 TELEPHONE 30E856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street suite 700 A~chorag~, Alaska 99501 TELEPHONE 9071258-8600 FAX 907/258-8601 WMRU #3 Abandonment 16' 75~, K-55 BT&C ~1~ I, 10-3/4" 45.5~, K-55, BTC ~ Top of 5.1/2' Uner ~ 13,878' MD 7-5/8~ 29.04~, L~80, STL .~ 2361' MD, 227'8' TVD with cement to surface Top of 7-,,;~' liner i~ 6B17' MD 7343' MD, 5234' TVD 7 5/8" Cement Retainer @ 13,700' ~. @ 14,161'MD, 8993'TVD 66 bbls Cement Slurry Packer @ 14,738' 3 3/8" TCP Gun tail ~ 15,063' 5-1/2" 17#, L-80, FL-4$ perforations 14,805'.14,836' MD 9417'-9439' TVD 14,852'-15,06CY MD 9451'-9607' TVD Retainer ~ 15,07(7 MD Squeeze Perfs ~ 15,074'-1,5,076' Tag Cmt in$i~le liner ~ 15,185' MD 15,338' MC), 9824' 3'VD Date; 10/20197 Tlmm: 10;2'-,o,~ Ann Attachments 1. Outline Procedure 2. Abandonment schematic 3. Cement Calculations .d J. Perry To: Pa, Il VVhlte Date'. 113/~01~7 Time: 10:25:04 . 2. 3. 41 5. 6. 7. 8. i 10, 11, 12, 13, 14. 15. 16. 17, lg. 19. 20. 21. 22, WMRU #3st OUTLINE PROCEDURE Reverse out jet pump. Kill well with produced water. Install BPV Move in and Rig up Nabor,q Rig 160 Nipple down tree, Nipple up and test 5000 psi BOPE Ensure well is dead, Recover BPV. Engage tubing hanger and recover 2 7/8" tubing from BWD packer at 14,738' Set 7 5/§" cement relainer at 13,700' Mix and pump 70 bbls cement slurry. Down squeeze 66 bbl,q cement thru retainer. HesiIation squeeze .final five barrels, if necessary m secure lookup. Circulate mp of rerain,r clean. Test casing to 2000 psi RIH wilh 10 ~A" test packer to 6500' with 1000' air cushion Set rest packer and open lest valve performing negative test on liner lap. Make gauge ring and junk basket run to 13,700' Set and orient Whipstock at 13,700' Mill window in 7 5/8" casing Change over to drilling fluid, Perform Leak Off Test. Directionally drill 6 ~A" hole to 15,303' MD (9963 ~TVD) Run electric logs Condition hole Run and cement 5 IA" liner from 13.650' to TD. Set Liner top/production packer Run compl,tion string _ J. ~en~/ To; p~ul ~lt~ WMRU #3ST CEMENTING PROGRAM Cement Abandonment Squeeze - Volume Calculat, i, on Capacity of 5 ½" 17# liner -- Capacity of 7 5/8" 29.04 # liner $ ~" liner volume Required coverage = 1192' x .0232 bbl$/f~ = Plus Squeeze quaj~t~ = Plus 7 5/8" I/olume Minimum required coverage = 178' x ,0459 bbls/f~ = Total Slur~ Volmne 27.65 + 30.0 + 8.1.7 = .0232 bbls/ft ,0459 bbls/ft 15,070:-. 13,878' = 1192' 2'7,65 bbis 30 bbb 13,878'- 13,700' = 178' 8.17 bbls 66 bbb corcenCrgy Inc October 10, !997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approvals West McArthur River Unit//3 A sundry approval is requested to sidetrack West McArthur River Unit//3 to replace the 5 ~/5" production liner, which has a defective primary cement job. The well has produced excessive quantities of water since initial production. The cement bond log indicates very poor cement and we believe that any remedial squeeze operations would be ineffective. It is proposed to abandon the current perforations and plug back to 13,700' md / 8,734' tvd. The well would be sidetracked through the 7 5/8" intermediate liner and directionally drilled to 15,303'md / 9,963' tvd. This well will TD approximately 200' South and 45' West of the original bottom hole location. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. ORIGINAL HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX ,. _ STATE OF ALASKA AI~S~ OIL AND OAS CONSERVATION COI~MISSION APPLICATION FOR SUNDRY APPROVALS t. Type of Request: Abarldorl: Suspend: Operation shutdown: Re. enter suspended well: ,Nter casing: Rep~l;'~vell: X Piuggi~lg;. Time extension: SlJmulate'"T' Change approved p--'--~ram: Pull tubing: Variance: Perforate'. Olher;. Name of Operator Forcenergy Ina. Address 310 K Simon, Suite 700 Anchorage, ,Naska gg501 4. Location of well at surface 2381' FNt., 1323' FWL, Sec. 16, TSN, RI4W, SM At top ~f produolNe Interval 838' FNL, 1125' FEL, See. 10, TaN, R14W, SM At ore,ye depth 727' FNL, 989' FEL, Sec. 10, TSN, R14W, SM At total depth 623' FNL, 857' FEL, 8e¢. 10, TSN, R14W, SM Type of well: Development' x Expire'story: Stratlgra,ohi¢: ORIGINAL 12. Preserff well condition summary Total depth: measured 15338' feet Plugs (measured) true vertical 9824' feet 6. Dalum elevation (DF or KB) 163' KB 7. Unit or Properly name West Mr, Arthur River Unit 8. Well number WMRU a~3 g. Permit number 94-113 10, APl number ~0- 13320461 11. Field/Pool feet West McArthur River Reid '~-e-st McAdhur River Pool Cement Retainer @ 15,070' Effective depth; measured 15070' feet Junk (measured) -., ve ' t, th r 'c~ S~uml t 17' 20" D~en 1 lr Suga~ ~61' 16" 2027 cuff G ble~ 2361' 2278' Inte~dlate ~3' 10 314" 511 ~ff G blend 7~3' 52~' P~u~lon (Liner) ~' 7 518" · 286 ~ G blend 14161' 8993' LIne~ 1~0' 5 1~" 174 ~ G b~nd 15338' 9824' ~mflon depth: measu~ bench # 1 1.4,805'- 14836', bench #2 t4,852.'. 15,0~0', Squeeze Perf. 15,074'- 15,076' true vertical bench# 1 9,417'-9,439', bellCh~2 9,451'- 9,607' Tubing (size, grade, and rneasured depth) This is 1:O revise the cement_ abandonment on previo~s sundry 27/~",L.80 G.~ 8mdAB 14790' notice, Packer_sod ~uos w;]] be ]eft in hole and c, ement Pa~ersandS~'S~'-' and -as~dd "' retied, nar set_ ~,13,70U..thirt¥ BBLS slurry 'or' unt:~l lockup I,~pe me aptly) 'will be squeezed'below retainer Asper'at'~:achment. 5 1/2" BWD 14,735' 13. Attachernents Description s. ummary of proposal: X Detailed operations program: X 14. EslJmated date for comrnencJng' operation ~ 5. Status of well classification as: October 21. 1997 16. If proposal well verbally approved: O~; X Gas: · Name (~.,~pprov...e .r Date approved Sedco: 17. I herel~ c~ify that the forego(rig Is true and correct to the best of my knowledge. Signed:;~JX ~ ~1~~_. ' ' Title:. '~-,.~t..5..t, ~ ~II~~~-~ BOP sketch: X Suspended: Date: ; 10-22-97 FOR COMMISSION USE ONLY Conditlo~s of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test,,"""' Location clearance Mechanical Integrity Test Subsequent form required 10- /.{ O ?_ dr~gina~ Approved by order o[ the C, ommi~slonec O~vid W. Johnston ! 13 .I/' Commissioner IApproval No. Form 10-403 Rev 06115188 SUBMIT IN TRIP[JCATE TO: Forcenergy Inc 310 K Street, Suite 700 Anchorage, Alaska 99501 {907! 258-8600 258-8601: FAX FAX TRANSMITTAL SHEET DATE: ..JC)/~c~ / ~ "7 PAGES TO FoLLow FAX: Phone: rCONFIDENTIALITY NOTE= The information In this facsimile transmittal is legally privileged and c~nfide..nJial. Information Intended only_ for the uae of the individual o~ entity named above. If the reader of this message is not the intended recipient, you are he-~y notified that any dissemination, ~atn-butio~ or oopy of the transm~al Is strictly prohib~ted. If you receive this transmittal In error, please Immediately no,fy ua by telephone, and return the original transmittal to us at the above address v~a the United States Postal Service. Thank you, t~AXAL~OO~ ~Jl 1/~? . MESSAGE: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X 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) Forcenergy Inc. Development: x 163' KB feet 3. Address Exploratory: 7. Unit or Property name 310 K Street, Suite 700 Stratigraphic: West McArthur River Unit Anchorage, Alaska 99501 Service: 4. Location of well at surface 8. Well number 2381' FNL, 1323' FWL, Sec. 16, T8N, R14W, SM WMRU #3 At top of productive interval 9. Permit number 838' FNL, 1125' FFL, Sec. 10, T8N, R14W, SM 94-113 At effective depth 10. APl number 727' FNL, 989' FEL, Sec. 10, T8N, R14W, SM 50- 133-20461 At total depth 11. Field/Pool West McArthur River Field 623' FNL, 857' FEL, Sec. 10, TSN, R14W, SM West McAdhur River Pool 12. Present well condition summary Total depth: measured 15338' feet Plugs (measured) Cement Retainer @ 15,070' true vertical 9824' feet Effective depth: measured 15070' feet Junk(measured)ORIGINAL true vertical 9615' feet Casing Length Size Cemented Measured depth True vertical depth Structural 117' 20" Driven 117' 117' Conductor Surface 2361' 16" 2027 cuff G blend 2361' 2278' Intermediate 7343' 10 3/4" 511 cuff G blend 7343' 5234' Production (Liner) 7344' 7 5~8" 286 cuff G blend 14161' 8993' Liner 1460' 5 1/2" 174 cuft G blend 15338' 9824' PeRoration depth: measured bench # 1 14,805' - 14836', bench #2 14,852' - 15,060', Squeeze Perf. 15,074' - 15,076' true vertical bench # 1 9,417' - 9,439', bench #2 9,451' - 9,607' Tubing (size, grade, and measured depth) 2 7/8", L-80, 6.5#, 8 rnd AB - 14,790' ~ ' Packers and SSSV (type and measured depth) 5 1/2" BWD 14,738' 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch:: X 14. Estimated date for commencing operation 15. Status of well classification as: October 21, 1997 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name ¢.~pprover Date approved Service: 17. I hereb c ify that the foregoing is true and correct to the best of my knowledge. Signe~:~'"~~V,~, ~'~~ Title: "~)*,~t.%._~¢,..~ ~(~,~hJ~...~-.~ Date: ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No59q Plug integrity c,-""- BOP Test z-,'"'- Location clearance " Mechanical Integrity Test Subsequent form required 10- .'/.~ 0 "~ A 0O~'''j /'-~,~ Original Signed By David W, Johnston/ Approved by order of the Commissioner Commissioner Date _ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Fo *Cer,a, rgy Inc Attachments . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. Outline Procedure Abandonment schematic Sidetrack schematic Unit Maps Drilling Fluids Program Pressure Information Casing Design Cement Calculations Directional Information Nabors BOP schematic Nabors BOP equipment list Nabors Drilling Fluid System Description HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 A nr-hnr~n,-, TELEPHONE 907/258-8600 FAX CIFI7/9t:q~_P. RD 1 orcer;ergy Inc . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. WMRU #3st OUTLINE PROCEDURE Reverse out jet pump. Kill well with produced water. Install BPV Move in and Rig up Nabors Rig 160 Nipple down tree. Nipple up and test 5000 psi BOPE Ensure well is dead. Recover BPV. Engage tubing hanger and recover 2 7/8" tubing from BWD packer at 14,738'. Mill out BWD packer Recover BWD packer and TCP guns Balance 18.5 bbl cement plug from PBTD @ 15,070', PU to 14,000', circulate clean Hesitation squeeze cement, leaving at least 150' cement above top perforations. WOC and tag TOC. Change over to milling fluid. Balance 20 bbl second cement abandonment plug from 14,000' to 13,500' Polish off cement to 13,700' Test casing to 2000 psi RIH with 10 SA" test packer to 6500' with 1000' air cushion Set test packer and open test valve performing negative test on liner lap. Make gauge ring and junk basket run to 13,700' Set and orient Whipstock at 13,700' Mill window in 7 5/8" casing Change over to drilling fluid. Perform Leak Off Test. Directionally drill 6 sA" hole to 15,303' MD (9963'TVD) Run electric logs Condition hole Run and cement 5 lA" liner from 13,650' to TD. Set Liner top/production packer Run completion string HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 305/856-8500 310 K Street Suite 800 FAX Suite 700 TELEPHONE 907/258-8600 FAX Force ergy Inc BLOWOUT PREVENTION EQUIPMENT NABORS RIG No. 160 13-5/8" BOP Equipment 3 ea 13-5/8" x 5000 psi wp ram type preventers (Hydril) 1 ea 13-5/8" x 5000 psi wp annular preventer (Hydril) 1 ea 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. 1 ea BOP accumulator, Valvcon, 300 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. 1 ea Valvcon, 6 station, remote control panel 1 ea Thornhill Craver, automatic choke 3"- 10,000 psi with control choke panel 1 lot Hydraulic pipe and fittings from manifold to BOP stack. DRILLING FLUID SYSTEM DESCRIPTION Mud Pumps 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 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum I with 50 HP AC motor. Mud Tank System (1035 bbls Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three 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. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank #3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbls; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 REGIONAL OFFICE TELEPHONE TELEPHONE 305/856-8500 310 K Street 907/258-8600 FAX Suite 700 FAX 'Force ,ergy inc Mud System Equipment iea 1 ea 1 ea 1 ea 4 ca 4 ea 1 ca 6 ea Derrick dual tandem shale shaker Drilco degasser Picenco 16 cone desilter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electric Motors Pioneer desander, 2 cone, Model S-2-12 , Dahlory 3" mud guns HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 305/856-8500 310 K Street Suite 800 FAX Suite 700 TELEPHONE 907/258-8600 FAX ~/~0 WMRU #3 Abandonment 16" 75~, K-55 BT&C · 10-3/4' 45.5~, K-55, BTC .~ Cement Abandonment Plug #2 from 14,000' to 13,700' Top of 5-1/2' Liner {~ 13,878' MD~I ~'~~-----~ ~ ~{'~~=-'~ ~ 7-5/8" 29.04~, L-80, STL ~,. @ 2361' MD, 2278' 'I'VD with cement to surface Top of 7-5/8' liner @ 6817' MD 7343' MD, 5234' 'I'VD @ 14,161' MD, 8993' TVD Cement Abandollment Plug #1 from 15,070' to 14,705' 5-1/2" 17#, L-80, FL-4S L 8.4 ppg produced water between plugs Perforations 14,805'-14,836' MD 9417'-9439' TVD 14,852'-15,060' MD 9451'-9607' T VD Retainer @ 15,070' MD Squeeze Perfs @ 15,074'-15,076' Tag Cmt inside liner @ 15,185' MD 15,338' MD, 9824' TVD WMR J #3st 16' 75~. K-55 BT&C ~ 10-3/4" 45.5~, K-55, BTC. ~ @ 2361' MD, 2278' TVD with cement to surface Top of 7-5/8' liner ~ 6817' MD ~ 7343' MD, 5234' TVD 5 1/2' Liner Top @ 13,650' Whipstock set at 13,700' Cement Abandonment Plug · from 14,000' to 13,700' Top of 5-1/2' Liner {~ 13,878' MD 7-5/8' 29.04#, L-80, STL 8,4 ppg produced water between plugs Cement Abandol~ment Plug #1 from 15,070' to t4,705' 14,805'-14,836' MD 9417'-9439' 14,852'-15,060' MD g451'-9607' Retainer ~ 15,070' MD Squeeze Perfs @ t5,.074'-t 5.076' L 14,161' MD, 8993' TVD 15.338' MD, 9824' TVD 5 1/2" 17# L-80 FL.45 Liner 15~303' MD 1 9963' TVD Forcer, rgy inc WEST MCARTHUR RIVER UNIT #3ST DRILLING FLUID PROGRAM Interval Hole size = Casing Size = Mud type = 13,700' to 15,070' cased 5 1/2"/7 5/8" Gel/Gelex Milling Fluid Parameters: Weight: 8.8-9.2 ppg Viscosity: 42-50 sec/qt PH: 8.0-9.0 PV: 1 0 YP: 40 Fluid Loss: 15ml/min Build a simple gel/gelex system with sufficient viscosity and yield point to remove metal shavings and cement. It is anticipated that approximately 20 ppb of bentonite with about. 1 to. 15 ppb gelex will be required for this system. Caustic for alkalinity control may be needed, and barite will be utilized for dry jobs. Interval Hole size = Casing Size = Mud type = 13,700' to 15,303' 63A,, 51/I,, low solids, non-dispersed polymer Drilling Fluid Parameters: Weight: 8.8-9.2 ppg Viscosity: 42-50 sec/qt PH: 8.0-9.0 PV: 5-10 YP: 23-35 AP1 Fluid Loss: < 6 HPHT Fluid Loss < 12 After cleaning out the metal cuttings and drilling beyond any cement behind the 7-5/8" casing and into new formation, build a low solids, non-dispersed polymer system. The polymer products are Flovis and Drispac with a maximum concentration of 3 ppb. HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE TELEPHONE 2730 SW 3rd Avenue 305/856-8500 310 K Street 907/258-8600 Suite 800 FAX Suite 700 FAX Forcer, ergy Inc Soltex is recommended for control of sloughing shales and coals up to a maximum ppb. Barite for weight control as needed. Mud weights should be kept low by running all solids control equipment to their maximum efficiency. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. A low gravity solids of less than 7% is required for optimum performance of this system. Dilution or complete displacement should be considered if higher LGS contents persist. Maintain rheological properties on the high side to prevent particle settlement and pump regular high viscosity/low viscosity sweeps. Keep the mud weight as low as possible because unnecessary solids have detrimental effects on the polymers. HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE TELEPHONE 2730 SW 3rd Avenue 305/856-8500 310 K Street 907/258-8600 Suite 800 FAX Suite 700 FAX Forcehergy Inc WEST MCARTHUR RIVER UNIT #3ST PRESSURE INFORMATION The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the West McArthur River Unit #3st. The pore pressure gradient information was obtained from the original bottom hole pressure surveys and RFT surveys on West McArthur River Unit #1,#2A and #3. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit # 1, #2A and #3. WMRU #2A, P= 4304 psi 9567' TVD from DST (as per 407 Comp Report, 11/93) WMRU #1, P= 4362 psi @ 9724' TVD from RFT (as per 407 Comp Report, 2/92) WMRU #3, P - 3680 psi @ 9400 from static BHP survey 7/2/95 The most conservative (highest) formation pressure gradient of 8.65 ppg or .45 psi/ft was used in these calculations. Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less half the casing hydrostatic column of a 9.0 ppg mud and the remainder, a gas gradient to the surface. It is assumed that full evacuation of the casing is highly unlikely in a developed field with a normal gradient, low GOR (235 cuft / bbl) and no known gas cap. 1) ASP = ((FG x .052) - 0.115) x D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.115 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR 2) ASP= FPP-(0.115 x lAD) - (9.0 x .052 x lAD) where' FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 305/856-8500 310 K Street Suite 800 FAX Suite 700 TELEPHONE 907/258-8600 FAX Forcer,ergy i nc ASP Calculations Drilling below liner (7-5/8") ASP = ((FG x .0520.115) x D = ((14.5 x .052) - 0.115) x 9963' = 6366 psi OR ASP = (9963' x .45) - (.115 x .5 x 9963') - = 4483 - 573 - 2331 = 1579 psi (9.0 x .052 x .5 x 9963') HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 305/856-8500 310 K Street Suite 800 FAX Suite 700 Miami VlnriHn R.qlpCI_ppR7 qnq/nqn_z~qnn A,~,--k ..... ^~.,.-,~.,-, nn~n. TELEPHONE 907/258-8600 FAX nn-z/n~o oen-~ Forcer-'-e lnc WMRU #3ST CEMENTING PROGRAM Cement Abandonment Plug #1 - Volume Calculation Balanced plug from 15,070' CapaCity of 5 IA" 17# liner = Minimum required coverage = 365' x .0232 bbls/ft = .0232 bbls/ft 15,070'- 14,705' 8.5 bbls = 365' Squeeze quantity = 10 bbls Total cement = 8.5bbls + 10bbls = 18.5 bbls 18.5 bbls/.0232 bbls/ft = 797' plug length or 15,070' to 14,273' prior to squeeze Cement Abandonment Plug #2 - Volume Calculation Balanced Plug from 14,000' to 13,500' Capacity of 5 1/5" 17# liner = Capacity of 7 5/8" 29.04 # liner .0232 bbls/ft .0459 bbls/ft 5 %" 14,000' to 13,878 - 122' x .0232 - 2.83 bbls 7 5/8" 13,878' to 13,500 = 378' x .0459 = 17.35 bbls Total cement = 2.83 bbls + 17.35 bbls = 20.2 bbls 5 ~/~" Liner Cement- Volume Calculation Liner Top @ 13,650' Window @ 13,700' TD @ 15,074' Capacity - Liner = 5 ~A" 17.0# FL4S = Annulus Volume - 6 ~A" gauge hole x 5 %" Liner - 5 ~A" x 7 5/8" liner lap = Capacity- 7 5/8" #29.04 = .0232 bbls/ft .0149 bbls/ft .0165 bbls/ft .0459 bbls/ft Shoe Track- 120' x .0232 bbls/ft = Liner to Open hole - 15,074'-13,700' = 1,374' 1,374' x .0149 bbls/ft= 20.47 bbls + 30% excess = Liner Lap 50' x .0165 bbls/ft = Excess above liner top = 2.78 bbls 26.61 bbls 0.82 bbls 10.00 bbls Total Cement = 40.21 bbls HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX Forcer,ergy lnc Current Casing WEST MCARTHUR RIVER UNIT #3ST CASING DESIGN Setting Depth Size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD Driven 20" 133 NT-80 BT&C 117' Surf. Surf. 117' 117' 18 1/2" 16" 75 K-55 BT&C 2361' Surf. Surf. 2361' 2278' 13 1/2" 10 3/4" 45.5 K-55 BT&C 7343' Surf. Surf. 7343' 5234' 9 7/8" 7 5/8" 29 L-80 STL 7344' 6817' 4925' 14161' 8993' 6 3/4" 5 1/2" 17 L-80 STL 1460' 13878' 8834' 15338' 9824' Proposed Liner Casing program Setting Depth size Specifications Top Bottom Hole Casing Weight Grade CouplingI Length MD TVD MD -I-VD I 6 3/4" 5 1/2" 17 lb. L-80 AB FL4S 1654' 13650' 8706' 15303' 9963' 10-3/4" Intermediate Casing. 45.5# K-55 BT&C ~.. 7343' MD/5234' TVD Tension = 7343' x 45.5# = 334K Rated = 715K for body Safety Factor = 2.1 Burst = (9963' x .45) - (.115 x .5 x 9963') - (9.0 x .052 x .5 x 9963') -1579 psi f/drlg to TD half colunm of 9.0 ppg Rated 2864 psi (80% of 3580) Safety Factor = 1.81 Collapse = (5234' x .45) - (.115 x .5 x 5234') - (9.0 x .052 x .5 x 5234') = 830 psi for half evacuation Rated = 1672 psi (80% of 2090 psi) Safety Factor - 2.01 HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 305/856-8500' 310 K Street Suite 800 FAX Suite 700 TELEPHONE 907/258-8600 FAX Forcer,ergy inc 7-5/8" 29.0#. L-80 STL liner @14,161' MD/8,993' TVD Tension = (14163'-6817') x 29.0# = 213K Rated = 444K for joint Safety Factor = 2.08 Burst = (9963' x .45) - (.115 x .5 x 9963') - (9.0 x .052 x .5 x 9963') = 1579 psi f/drlg to TD half column of 9.0 ppg Rated 5512 psi (80% of 6890) Safety Factor = 3.49 Collapse = (8993' x .45) - (.5 x 8993' x .115) - (9.0 x .052 x .5 x 8993') 1425 psi for half evacuation Rated = 3832 (80% of 4790 psi) Safety Factor = 2.69 5-1/2"17# L-80 STL liner 15 303' MD/9963' TVD Tension = (15,303'-13,650') x 17# = 28.1K Rated = 210K for joint Safety Factor = 7.47 Burst = (9963'x.45)-(.115x.5x9963')- (9.0 x .052 x .5 x 9963') -1579 psi f/drlg to TD half column of 9.0 ppg Rated = 7740 psi Safety Factor - 4.90 Collapse = (9963' x .45)- (9963' x .115) = 3337 psi for full evacuation Rated = 6280 psi Safety Factor = 1.88 HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 · ~. . ~, . , ~ ~ TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX An&drill Schlumberger 12ll East 80th Avenue Anchorage, AK 99518 DIP~CTIGMAL ~ELL PLAN for FORCENERGY INC. Welt ......... : ~MR-$A (P08] Field ........ : Cook Inlet com~utation..: Mini~%n~ Curvature surface Lat.,: 60.78482702 N Surface bong.= 15~.75Q22727 W ~TIO~S - ~ Zone: L~al Description X-Coord Ta~et ....... = 823 ~ 94~ FEL $10 TOMN RI~ SM 4 Y-Coord 18724~.$3 2482962.33 ~94846.87 2489034.55 195711.?1 2459580.12 195711.7~ 2489580.12 ANADRtLL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION Prepared ..... : 89 Oct 1997 Vert sect az.: K~ elevation.: 163.00 MagDe~ic Dcln: ~21,763 Scale Fae~or,~ i. OOOOll3O OonYerge~ce..~ -1,52~69959 ~DE~TIFICATION D~[~"H A.NGi,~ TI~-IN S~Y ~3697.~0 fi6.20 ~ 5.50/100 13700.00 56.~9 TOP OF ~RI~S~C~ 13700.00 56.L9 ~ 5.50/~0Q ~R~ 13750.00 57.59 13~.0~ 52.63 DIRECTION ~RTICAL-DEPT~ $~"TIOi',] (XX)RD~NAT~-~ROM AhASEA Zor~e 4 TOOL AZIMUTH T~D SUB-SF.A DBPART W~LLH~J~D X Y FACE 100 50.40 8732.L$ 8569.18 9655.99 6272.59 N ?433.37 ~ 1~4846.87 2489034.55 ~48E 50.41 8733.85 ~570.85 9655.47 6274.18 N 7435.29 E ~94848.83 2489036.09 60R 5~.42 6735.85 8570.85 965S.47 6274.~ N 7435.29 E 194~48.83 2489036.09 60R 0.51 53.23 8~61.16 8598.16 9500.19 6300.06 N 7468.21 E 194882.43 2459061.0~ Z74R 5.50 53.92 878].76 ~626.76 97(1.~ 6324.40 ~ 7501.20 ~ ~94916.D5 2489084.54 173R lO.Q0 CORV~ I0. O0/'m O0 :Ei'~TI:, 10.00/100 C~ TOP OF I{~MLOCK 13850.00 47.66 54.72 8821,79 8658.79 9779.46 13900.00 42.71 55.65 8857.02 8694.02 9814.9L ~3948.S7 37.90 56.73 8894.05 8731.05 9846.32 13948.57 57.9~ $6.73 8894.05 8731.05 9845.~2 14542.~ 37.90 56.73 9363.00 9200.00 10211.39 15305.26 ~7.90 56.73 9963.00 9800.00 10678.49 6346.79 N 7532.36 B 194947.80 2459~06.Q9 L?3R 10.00 6367.05 N 756L.46 E 194937.43 2489125.56 172R 6384.54 ~ 7587.5~ E 295003.98 2489142.35 KS ~0.00 6384.54 N 7587.55 8 ~95003.98 2489L42.35 HS 6584.80 N 7892.80 E 195314.46 2489334.40 KS 6~41.02 N 8283.36 E /95711.?1 2489580.12 0,00 93 3> ITl FORCENER6Y Marker IOentification MD BKB SECTN ~NCLN A) Tie-in 13697 8732 g656 56,20 BI CURVE §.§0/100 23700 8734 9658 56.t9 C) TOP OF WHIPSTOCK t3700 8734 9§58 ~6,t9 O) END B.50/t00 CURVE 13750 87§t 9700 ~7.5§ E) CuRvE 10.00/i00 i3949 8894 9846 37.90 F) ENO ~0.00/100 CURVE t3949 8894 9846 37,90 i ii I C'. WMR-3A (P08) VERTICAL SECTION VIEW Section at: 56.73 TVD Scale · ~ inch = 1800 feet O3 __i. · i , 15303 9963 10678 37.90 Dep Sca]e' t inch ~ ~800 feet t ' I .... Ana/l'r.i]] $ch]u¢l)en.qer 'T~-or ~ ~- "~ - ~ .... ~- - , .... ~e T~ G ~..~ .... , ---... ,--~ ,-- ..A.~ ~DRILL AKA- )PC :EASIBILTY [~LAbl NOT/~PPF:OVED E~)R E;~ECtJTICN ..... , ...... .,... ~ I 0 900 ~eoo 2700 3600 4500 5400 ~300 7~00 ~100 9000 9~00 ~0~00 Section Departure (A~adrl~] {c)~7 ~tk~13A~08 3.~ 3: 8~ ~ P} _ I oint AN~DRILL DPO FORCENFRO~ ..... ~NC. PAGE IIIr Ii' .. T Ill Ill m i IIII Marker Identification A) Tie-in B) CURVES.50/]00 ~3700 8734 955855&9. :VERTICAL SECTIONVIEH C) TOP 0F ~H~PSTOCK ~3700 8734 9558 5~.~9 ....... D) END 5.50/~00 CURVE E) CURYE ~0.00/~0 ~3949 8Bg4 98~6 37,90 F) END ~O.00/J00 CURVE B6~ . ~°° 8800 .... '"' D I FLI~ 89oo'- ~.- ~ooo ~ .... ~ EXE'CU-'-" '- - ~ON 9t00 9~00 - ~300.... -~-~ ~ ~--~ ............. ~ ........ - ~SO0 ..... ~ ~ .. 9600 '" , B70O ..... "=~ ~900 ~ T~rget(Point) XO000- ' ~0200 ~ ~00 ~700 ~800 ~00 ~0000 ~Om~ ~0~00 ~0300 ~OqO0 ~0500 IOSO0 ~0700 a0800 ~OSO0 [AnsdPi]] (¢)97 ~.R3APOB .-'].OE 2:43 PH P} ; i 04 m tOOC 10/09/1997 15:24 907-34'*-'"~"t60 ~NADRILL DPC --, PAGE 85 FORCENEROY I IH 11 I Marker 'Ident ~ f ~cot~on MO N/$ Al Tie-in 136g? 6273 N 7433 E 8) 6UAVE 5.50/i00 13700 6274 N 7435 E TOP OF WHIPSTOCK ~3700 8274 N 7,35 E INC. ~R-3A (PO8) PLAN VIEW ~ , , ,, ,,.i . . CLOSURE · J0743 feet at Azimuth 5o.4i DECLINATION.' +2~.763 (E) SCALE ' ~ inch : 1400 feet DRAWN ' 09 Oct ~997 /nadrl ]] SchJumberger / F',~ASI 3tLI~W PI_AN NC)T A ~PRC)VEE~ FOF' ....................... ~ EXECU'TIOFI PLAIN ~B~ .............................................. .-. ...........- 700 0 700 1400 2100 2800 3500 4200 4900 5600 6300 7000 7700 8400 <- WEST - EAST -> I1OO AN~DRILL DPO FORCEN NMR-3A (POB) ' PLAN VIEW CLOSURE ..... : 10743 feet at Azimuth 50,45 BECLINATION.: +2],763 (E) SCALE ....... : 1 inch = 200 feet BRAWN ....... : 0§ Oct ~897 ,4nadr'i l] Sch]umberger ,,,,- -'RGY :I:Iq'C':- .... .. Marker IdenLJficatton MD N/S E/H A) Tie~in ~3697 8273 N 7433 E B) CURVE 5.50/~00 J3700 6274 N 7435 E C) TOP OF WHIPSTOCK ~3700 8274 N 7435 E 0) END 5.50/t00 CURVE ~3750 6300 N 7488 E E) CURVE lO,O0/JO0 J3949 6385 N 7588 E F) END JO,O0/~O0 CURVE ~3949 6385 N 7588 E G) TD ~5303 6841N 8253 E PAGE EiC, ) ............. / Target (Poi ~t) I t _ _ ~ /,.NADR LL AK A-DPC / ,FE/~,SIBi~i-i~, PL/xN .... ,NQ] API)ROx /ED_._ EXE<~UTION ..... P_AN~ ., ....... 7200 7300 7400 7500 7500 7700 7800 7900 8000 8100 8200 8300 8400 8500 EAST -> 600 Nabors Rig #160 13-5/8' 5000 psi BOP Stack 5000 psi =Annular Preventer I = HCR Valve 2 = Gate Valve I 5000 psi Pipe Rams I I 3-1/8' Kill Line 5000 psi Blind Rams Drilling Spool 5000 psi Pipe Rams 13-5/8"x 11' I v~ell;h5eaMd ~ 4-1/16' Choke Line · . 9h,-1 13 I 0-.-!+07 ~ CC, MF'L. ETIC, N DATE ?/"~s'/"~/-/" DAILY WELL .nF'S'~c..¢~/3/"A7,.'"~,'' TC, "- ' Wail dr'y d'¥tci'~ sarnp'ies wal'l cot. ed? we'il 't:e.s't:s r"equ'¥r'.ed? i Yes X n { 't 'i a i C: O k'i kl E N T S Stewart petroleum Company Denali Towers North, Suite 1300 2550 Denali Street, Anchorage, Alaska 99503 (907) 277.4004 ° FAX (907) 274-0424 August 22, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Log Data West McArthur River Unit #3 Attn: Mr. Larry Grant Mr. Grant: Enclosed is the return of the 8 mm digital tape for all logs ran in the West McArthur River Unit VVell No. 3. Mr. Ted Bornemann with Schlumberger contacted you regarding the information contained on this tape. in summary, the enclosed 8 mm tape contains all of the logging information contained on the nine track tape which you have already received plus the information from the FMS and CET/CBT logs. This additional information could not be contained on a reasonable number of nine track tapes. Therefore, it is recommended that the enclosed 8 mm tape be retained by the AOGCC to ensure that all available log information on the WMRU #3 well is on file. If there are any questions, please contact me at 277-4004. Tim Billingsle~ Petroleum Engineer Stewart Petroleum Company cc: William R. Stewart, President- Stewart Petroleum Company Paul D. White, Operations Manager- Stewart Petroleum Company Sf. ate of Alaska . Oil Gas Conservation Commission 3001 Porcupine Drive Anrt. hnrnn~ ,A, In~k-n .cI.clR01 ..~1 · %IIVIIVI~41~V, II~ii~Vl'I,~i~I VVVI v Irk 907-279-1433 Tim Billingsley Stewart Petroleum Co. ,~-.-~,,./VV i,.~gi !~.411 VI.. U&g VVV Anchorage, AK 99503-2737 The following daw is hereby acknowledged as being received. The Commission however requests the 'data resUbmitted On nine track tape With an L!S verificati°n iisting l We are unable to use 8mm digital tape. Well Name Description Mc Arthur River #3 Field Tape: 8mm ~.pe; FMS/,~DT/CNUCET/CBT AP!PTD50' # 94-1133-2046113 --~ -00 ' ~:~ ~;~,~,/~...,,,~ -- , :: : - . . . "' (~~ J Received Date: C°py ;e;t~pe "' n0.. ~,&~ .. :': :.. ~,.;~ .; .... : , - ...........- ., . Stewart petroleum Company Denali Towers North, Suite 1300 2550 Dena]i Street, Anchorage, Alaska 99503 (907) 277.4004 · FAX (907) 274-0424 July 18, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Re: Well Completion Report and Log (Form 10-407) West McArthur River Unit #3 Greetings: Enclosed is the Well Completion Report for the West McArthur River Unit Well No. 3. The following items are enclosed for your files: 1) 2) 3) 4) 5) 6) 7) Completion Report (Form 10-407) in duplicate Daily Ddtling Reports (9 pages) Directional Survey Report from Anaddll Schlumberger Completion Schematic Completion Detail Halliburton BHP Survey Report Welt Logs: (Sepia and Blue line copy) a) Array Inducfion/SP b) Litho Density/Compensated Neutron c) Litho Density/GR d) Formation Micro Scanner Run 1 e) Formation Micro Scanner Run 2 f), Cement Evaluation Log g) Cement Bond Log h) Gamma Ray up to intermediate casing at 7200' i) Measured Depth Composite Log j) True Vedical Depth Composite Log 8) Tale and disk with ve~cation listing of digitized data from al! togs. We~ McArthur River UNt ", . #3 Completion R~ort The approved penmit to ddt! (Approval #94-113) did not require a mud log or samples and the formation log requirements on the surface and intermediate hole sections down to 7343' MD were waived. Please keep all of the m~efia! subm~ed with this repod confidential for 24 months with the exception of the welt !c-~tion and depth as per AS Sec. 31.05.025(c). If there are any questions, please co~a~ me ~ 277-4004. Petroleum Engineer Stewa~ Petroleum Company William R. Stewart, President - Stewad Petroleum Company Paul D. White, Operations Manager- Stewart Petroleum Company STATE OF ALASKA ALASKA O,L AND GAS CONSERVATION CO~,,;~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL 5~ GAS :~] SUSPENDED {-] ABANDONED ~ SERVICE [] 2. Name of Operator Stewart Petroleum Company 3. Address 2550 Denali St., Suite 1300 Anchorage, Ak 99503 4. Location of well at surface 2381' FNL, 1323' FWL, Sec. 16, T8N, R14W, At Top Producing Interval 838' FNL, 1125' FEL, Sec. 10, T8N, R14W, At Total Depth 623' FNL, 857' FEL, Sec. 10, T8N, RZ4W, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 163' KB J ADL 35911'1 12. Date Spudded 3/29/95 17. Total Depth (MD+TVD) 15338 ' MD/9824 ' TVD 7. Permit Number 94-113 8. APl Number 50- 133-20461 9. Unit or Lease Name West McArthur River Unit 10. Well Number No. 3 11. Field and Pool West McArthur River Field West McArthur River Pool 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 6/15/95 J 7/5/95 J N/A feet MSL One 18. Plug Back Depth (MID+'FVD)119. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 15070' MD/9615' TVDI YES ~ NO [] I N/A feet MD I N/A 22. Type Electric or Other Logs Run Array Induction Tool/SP~ LDT/CNL, LDT/GR, FMS, CET 23. CASING, LINER ANDCEMENTIN( RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133 NT-80 117 ' 20" Driven 0 ' 16" 10-3/4' 7-5/8' 5-1/2', 75 45.5 29.04 K-55 K-55 L-80 SETTING DEPTH MD TOP I BOTTOM °'t O' O' 6817' 14161' 13878'~ CBL, GR 2361' 18.5" 2027 cuft G blended 0' 7343' 13.5" 511 cuft G blended 0' ' 17 L-80 15338' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Hemlock Bench 1 MD TVD 14,805'-14,836' 14,852'-15,060' Bench 2 All intervals 6spf, 9.875 6.75" 286 cuft G blended 174 cuft G blended ! ! 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" . 14,790' 14,738' 9417'-9439' 9451'-9607' .49" dia holes 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. Date First Production 7/5/95 Date of Test 7/10/95 Hours Tested 24 Flow Tubing Casing Pressure Press. N/A I 50 28. PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) Hydraulic Jet Pump PRODUCTION FOR OIL-BBL JGAS-MCF TEST PERIOD ~ 2,821 I 663 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE ~1~ 2,821 663 CORE DATA WATER-BBL 1,232 WATER-BBL 1,232 fCHOKESIZE GAS-OIL RATIO NA, 2.35 OIL GRAVITY-APl (corr) 28 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, None Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME Tyonek G Hemlock Bench 1 Bench 2 Bench 3 G EOLOG lC M~-~'~E RS MEAS. DEPTH 14,649' 14,800' 14,862' 15,026' TRUE VERT. DEPTH 9458' 9581' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 7/2/95 Static BHP Survey with Hemlock Bench 1, Bench 2 and Bench 3 perforations open: 3680 psi @ -9400' ss 31. LISTOFATTACHMENTS Daily drilling reports, Directional Survey, Comp. Schematic/Detail, BHP report, Well logs. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Petroleum Engr. Stewart Pet. Co. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23': Attached supplemental records for this well should show the details, of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 West McArthur River Unit #3 Daily Drilling Reports Day 3127195 Activity Summary Mud Weight: N/A, Depth = 117' MD. Drove 20" 133# NT-80 conductor to 117' RKB. RKB = 163' above sea level. 3~28~95 i Mud Weight = N/A, Depth = 117' MD. !Rigging up mud logging unit, MWD unit, mix mud. 3/29/95 3/30195 Mud Weight = 9.2 ppg, Depth = 117' MD. Finished dgging up mudlogging unit, continued dgging up Nabors #160. Mud Weight = 9.2 ppg, Depth = 377' MD, Days Since Spud = 1. Finished dgging up Nabors Rig #160. Spud well with 18.5" bit at 19:30 hrs on 3/29/95. Ddtled from from 117' to 377'. i3/31/95 · Mud Weight = 9.5 ppg, Depth = 722' MD, Days Since Spud = 2. i Ddlled from 377' to 722'. Tdpped for ddlling motor. RIH with motor assembly. MWD failure. I POOH and lay down MWD. 4/1/95 !Mud Weicjht = 9.5 ppg, Depth = 1423' MD, Days Since Spud = 3. !RIH with new MWD. Ddlted from 722' to 891'. POOH and change out MWD. RIH with new MWD. i Ddlled from 891' to 1423'. i i 4~2~95 , Mud Weight = 9.3 ppg, Depth = 1952' MD, Days Since Spud = 4. i Ddlled from 1423' to 1578'. POH to 1470' and ream to 1578'. Ddlled from 1578' to 1701'. POOH and changed bits and stabilizer blades. RIH and drilled from 1701' to 1952'. 4/3/95 i Mud Weight = 9.5 ppg, Depth = 2362' MD, Days Since Spud = 5. i Ddlled from 1952' to 2357'. POOH and laid down motor, MWD and lead collar. RIH with clean-out assembly. Tight hole at 1270', washed from 2326' to 2357'. Ddiled from 2357' to 2362'. , Circ hole clean in prep for casing. 4/4/95 i Mud Weight = 9.3 ppg, Depth = 2362' MD, Days Since Spud = 6. i Finished circulating hole clean. POOH, RU casing tools. Started running 16" casing. 4/5/95 Mud Weight = 9.3 ppg, Depth = 2362' MD, Days Since Spud = 7. !Ran 16" 75#, K-55, BTC casing. Worked thru tight spots from 800' to bottom at 2361'. Circ casing on bottom. RIH with stab-in toot on 5' ddlt pipe. Pumped 10 bbi water, 283 bbi lead cement @ 12.5 ppg, i(770 sx Class G cement with 2% A-2, 0.4% CD-31, 0.5% A-7 and 1 gphs FP-6L), 78 bbl tail cement @ 15.7 ppg (375 sx class G cement with 0.25% CD-31, 1.5% A-7, lgphs FP-6L). ~Dropped wiper plug, displaced DP to within 3 bbl of float collar. Cmt retums (~ end of displacement. i Unsting and pull 1 stand. Pumped wiper plug dear of drill pipe, POOH. ND dser. 416t95 i Mud Weight = 9.3 ppg, Depth = 236_1' MD, Days Since Spud = 8 i Cut and removed 20" and 16" dsers. Cut 16" casing and weld on wellhead. Pressure test wellhead. i NU 20-3/4" 3000 psi BOPE. 4/7/95 i Mud Weight = 8.8 ppg, Depth = 2361' MD, Days Since Spud = 9 !Test BOPE, witnessed by John Spaulding-AOGCC. Disposed spud mud, build new mud volume. 418/95 !Mud Weight = 8.8 ppg, Depth = 2530' MD, Days Since Spud = 10 , iRIH with 13.5" bit, tagged float collar at 2314'. Tested casing OK to 1500 psi. Drilled out to 2371~ Performed formation integrity test to 11.5 ppg EMW. Drilled from 2371' to 2511'. ~.~.:~ Tdpped to 2402' and reamed back to bottom. Ddlled from 2511' to 2530'. ~;~'~ ,,, '\ Page 1 . West McArthur River Unit #3 Daily Drilling Reports 4/9/95 4110~95 Mud Weight = 9.1 ppg, Depth = 3438' MD, Days Since Spud = 11 Drilled .from 2530' to 3438'. Lost 270 bbt mud to sands from 3140' to 33.10'. Stabilized after that point. POOH to change to rotary assembly. Mud Weight = 9.1 ppg, Depth = 3937' MD, Days Since Spud = 12 RIH with rotary assembly. Worked thru tight hole from 3100' to 3370'. Reamed bottom 60'. iDdlled from 3438' to 3815'. Building too much angle. POOH. PU motor and new bit. iRIH with no problems. Ddlled from 3815' to 3937'. 4/11/95 !Mud Weight = 9.1 ppg, Depth = 4928' MD, Days Since Spud = 13 Drilled ~rom 3937' to 4620'. Short ~p to 3485', one tight spot at 4108'. Ddlled from 4620' to 4i12/95 ,Mud Weight = 9.3 ppg, Depth = 5485' MD, Days Since Spud = 14 ',Ddlled from 4928' to 5299'. Short trip to 3952L 'Dght from bottom to 4700'. !No problems going back to bottom. Ddlled from 5299' to 5485'. Circ for bit trip. ,, 4/13/95 i Mud Weight = 9.2 ppg, Dopth = 5~76' MD, Days Since Spud = 15 iCirc high density sweep. POOH with suspected keyseat at 5165'. RIH with new bit, ~slight bddge at 4210'. Reamed out of gauge hole from 5380' to 5485'. Drilled from 5485' to 5676'. 4/14/95 i Mud Weight = 9.5 p~, Depth = 5694' MD, Days Since Spud = 16 Ddlled from 5485' to 5694'. POOH for MWD failure. Hole tight at 5535' and 5165'. RIH to 4978'. !Tight hole conditions, pumped nut plug and SAPP sweep, raised mud weight to 9.4 ppg. i POOH to 4130', improper hole flit volume, raised mud weight to 9.6 ppg. POOH to shoe. i Check for flow, no flow. Circ BU, no gas, no flow, POOH. 4/15/95 'Mud Weight = 9.7 ppg, Depth = 5491' MD, Days Since Spud = 17 PU new MWD and RIH. Reamed from 4928' to 5026', tight hole. Circ out gas (max gas units= 850). Reamed from 5010' to bddge at 5068'. Ddlled out bridge from 5068' to 5180'. Surveys indicate unintentional sidetrack from odginal weilbore. Ddlled from 5180' to 5491'. 1 4/16/95 Mud Weight = 9.8 ppg, Depth = 5992' MD, Days Since Spud = 18 ! Ddiled from 5304' to 5522'. CBU. Short tdp to 4917', no drag, no swabbing, no bddges. i Ddlled from 5522' to 5992', circ for short trip. 4/17/95 !Mud Weight = 9.8 ppg, Depth = 6286' MD, Days Since Spud = 19 !Circ for short trip. Tdpped to 4917'. Drilled from 5992' to 6286'. CBU and trip for bit. Tight at 4940' !and 4763', extremely fight at 4525'. 4/18/95 i Mud Weight = 9.9 ppg, Depth = 6286' MD, Days Since Spud = 20 i POOH. Tested BOPE. RIH to 2202'. Rig up TESCO rental top drive equipment. 4/19/95 Mud Weight = 9.9 ppg, Depth = 6327' MD, Days Since Spud = 21 Finished dgging up top ddve. RIH to 4294', upreamed fight spot, reamed down from 4309' to 4403'. Bddges at 4317' and 4383'. RtH to 6136', reamed from 6136' to 6286'. Drilled from 6286' to 6327'. 4/20/95 Mud Weight = 9.9 ppg, Depth = 6824' MD, Days Since Spud = 22 Ddlled from 6327' to 6656'. CBU and short trip to 3502' with no hole problems. Ddlled from 6656' to 6700'. Circ out trip gas, 578 units. Ddlled from 6700' to '6824'. 4/21/95 'Mud Weight = 9.9 ppg, Depth = 6929' MD, Days Since Spud = 23 I Drilled from 6824' to 6929'. CBU and POOH for BHA change to motor. Minor tight spot at 4750'. i RIH with no problems. , Page 2 compsum.doc West McArthur River Unit #3 Daily Drilling Reports 4/22/95 Mud Weight = 10.0 ppg, Depth = 7148' MD, Days Since Spud: 24 Ddlled from 6929' to 7148' with motor. Circ cuttings sweep, trip for BHA. LD motor and RIH i with rotary BHA. 4~23~95 Mud Weight = 10.0 ppg, Depth = 7343' MD, Days Since Spud = 25 !RIH, reamed from tight spot at 7074' to bottom. Drilled from 7148' to 7194'. 4/24/95 iTdpped for washout in ddll pipe at 4300'. Ddlled from 7194' to casing point at 7343'. i Mud Weight: 10.0 ppg, Depth = 7343' MD, Days Since Spud = 26 i Pumped hi-vis sweep, short trip to shoe, RIH to TD with no fill. Circ sweep, POOH to run 10-3/4" csg. 4/25/95 Mud Weight = 10.1 ppg, Depth: 7343' MD, Days Since Spud: 27 · RU casing tools. Ran 167joints 10-3i4" 45.5#, K-55, BTC casing. Circ with casing on bottom. ~ Pumped 50 bbl water spacer, dropped bottom plug, 450 sx (91 bbl) class G cement @ ~15.8 ppg with 0.25% CD-31, 0.25% A-7, I gphs FP-6L. Dropped top plug. Displaced with 10 bbl water, and 687 bbi mud with good returns. Bumped plug to 1000 psi. Bled pressure, floats held. i ND BOPE. 4/26,'95 Mud Weight = 10.1 ppg, Depth = 7343' MD, Days Since Spud = 28 ,PU BOP stack, set slips with 200,000 tb tension on 10-3/4" casing. Cut 10-3/4" casig, install and test itubing spool to 1600 psi. NU BOPE and install new mud shakers. 4/27/95 iMud Weight = 10.1 ppg, Depth = 7343' MD, Days Since Spud = 29 NU ELOPE, fabricate choke and kill lines, continue installing new shakers. i 1 4/28195 iMud Weight = 10.1 ppg, Depth = 7343' MD, Days Since Spud = 30 I Finished NU 13-5/8" 5000 psi BOPE. Test BOPE. MU BHA. !4/29195 I Mud Weight = 9.4 ppg, Depth = 7348' MD, Days Since Spud = 31 RIH to 7248'. Test casing to 2000 psi, OK. Ddil float collar, cement, shoe and new formation to 7348'. iCirc hole until mud in balance. Perform EMW to 15.0 ppg. Build PHPA mud volume. 4/30/95 !Mud Weight = 9.5 ppg, Depth = 7715' MD, Days Since Spud = 32 I Displaced hole with PHPA mud. Ddlled 9-7/8" hole from 7348' to 7715'. CBU, POOH for motor BHA. I i 5/1/95 iMud Weight: 9.6 ppg, Depth: 8187' MD, Days Since Spud: 33 Finished POOH and PU motor BHA. RIH with no problems. Ddiled from 7715' to 8187'. i 5/2/95 I Mud' Weight = 10.0 ppg, Depth = 8722' MD, Days Since Spud = 34 i Drilled from 7715' to 8255'. CBU, short trip to shoe, pulled tight from 7881' to 7819'. t Ddlled from 8255' to 8722'. CBU for trip. Pulled tight at 8,412' and 8318'. Pumped out of hole to shoe. i Swabbed welt while pulling BHA in casing. Pumped out of hole in casing. 5/3/95 !Mud Weight = 10.2 ppg, !~pth = 8040' MD, Days Sirme Spud = 35 ~Finished pumping out of hole, well swabbed when pump was not running. RIH, circ casing dean. i(abundant coal piec.~.q in c~sing). RIH, washed and rmamed 45' to tx~ttom. i - i Ddlled from 8722' to 8946'. 5/4/95 i Mud Weight = 10.2 ppg, Depth = 9274' MD, Days Since Spud = 36 iDdlled from 8946' to 8999'. CBU, shod trip to shoe with no problems. Drilled from 8999' to 9164'. !CBU, short trip to shoe with no problems. Ddlled from 9164' to 9274'. Page 3 compsum.doc West McArthur River Unit #3 Daily Drilling Reports 5t5195 Mud Weight = 10.2 ppg, Depth = 9368' MD, Days Since Spud = 37 Ddlted from 9274' to 9368'. CBU for bit trip. POOH, tight from 9191' to 9099'. i Tested BOPE, witnessed by Doug Amos-AOGCC. RIH with new bit. 516195 i Mud Weight = 10.2 ppg, Depth = 9746' MD, Days Since Spud = 38 RIH, drilled from 9368' to 9542'. CBU, short tdp to shoe, ddiled from 9542' to 9746'. 5/7/95 Mud Weight = 10.2 ppg, Depth = 10152' MD, Days Since Spud = 39 Ddlled from 9746' to 9813'. CBU, short trip to shoe. Ddlled from 9813' to 9989'. CBU, short trip to 9470'. Ddlled from 9989' to 10152'. No hole problems. 5/8/95 Mud Weight = 10.2 ppg, Depth = 10331' MD, Days Since Spud = 40 !Ddlled from 10152' to 10216'. CBU, trip for bit. RIH, ddlled from 10216' to 10331'. 5/9/95 Mud Weight = I0.2 ppg, Depth = 10706' MD, Days Since Spud = 41 Ddlled from 10331' to 10540'. Circ for samples. Short tdp to 9661'. Tight hole at 10308'-10123'. Back ream from 10212 to 10123'. RIH, ddiled from 10540' to 10706'. CBU, short trip. . 5/10/95 iMud Weight = 10.3 ppg, Depth = 11030' MD, Days Since Spud = 42 !Short tdp to shoe, tight at 10600' and 8570'. RIH, ddiled from 10706' to 10908'. CBU, !short tdp to 9988'. Ddlled from 10908' to 11030'. I 5/11t95 Mud Weight= 10.3 ppg, Depth = 11100' MD, Days Since Spud =43 iDdlled from 11030' to 11055'. CBU for bit trip. Backreamed from 8,.-.-.-.-.-.-.-.-.~0' to 8560'. POOH, changed bits. iRIH, wash and ream 150' to bottom. Drilled from 11055' to 11100'. 5/t2/95 Mud Weight: 10.4 ppg, Depth = 11485' MD, Days Since Spud = 44 iDrilled from 11100' to 11170'. Repair Top Drive unit, blown O-ring. Ddlled from 11170' to 11276'. IShort trip of 10 stands, no problems. Ddlled from 11276' to 11485'. 5/13/95 iMud Weight = 10.3 ppg, Depth = 11863' MD, Days Since Spud = 45 j Drilled from 11485' to 11502'. Circ, short trip to 10125', 30-40k more drag than previous trip. Drilled from 11502' to 11863'. Reduced mud weight to 10.25 ppg. PU wieght reduced by 25-35k. i CBU, POOH for MWD failure and bit hours. 15/14/95 iMud Weight = 10.3 ppg, Depth = 11900' MD, Days Since Spud = 46 !CBU, POOH, trouble pulling into shoe. Test BOPE. RIH, ream 100' to bottom. ! Ddlled from 11863' to 11900'. 5/15t95 iMud Weight = 10.2 ppg, Dep~ = 12183' MD, Days Since Spud = 47 ~ Ddlled from 11900' to 12090'. CBU, short trip to 11124'. Ddlled from 12090' to 12183'. 5ti6t95 Mud Weight = 10.1 ppg, Depth = 12450' MD, Days Since Spud = 48 Ddlled fi'om 12183' to 12344'. Reamed tight hole from 12313' !2355'. Unable to survey due to surface MWD problems. Drilled from 12344' to 12450'. CBU, [Tip for bit. 5/17/95 Mud Weight = 10.2 ppg, Depth = 12610' MD, Days Since Spud = 49 POOH for bit. RIH, bddge at 11640', reamed 90' to bottom. Lost 87 bbls on trip. Ddiled from 12450' to 12610'. 5/18/95 Mud Weight = 10.2 ppg, Depth = 12958' MD, Days Since Spud = 50 iDrilled from 12610' to 12767'. Circ samples, short trip to 11819'. Ddlled from 12767' to 12958'. Page 4 compsum.doc West McArthur River Unit #3 Daily Drilling Reports 5tl 9/95 Mud Weight = 10.2 ppg, Depth. = 13011' MD, Days Since Spud = 51 Drilled from 12958' to 13011'. CBU, trip for bit. 5~20~95 Mud Weight: 10.3 ppg, Depth = 13222' MD, Days Since Spud: 52 5/21/95 RIH, reamed 90' to bottom. Ddlled from 13011' to 13048'. Repaired top drive hose connections. Ddlled from 13048' to 13159'. Short trip 5 stands. Ddlled from 13159' to 13222'. Mud Weight = 10.2 ppg, Depth = 13369' MD, Days Since Spud = 53 Drilled from 13222' to 13288'. Short trip to 11505'. Drilled from 13288' to 13369'. CBU, trip for bit. 5/22/95 Mud Weight = 10.2 ppg, Depth = 13433' MD, Days Since Spud = 54 POOH, tight hole at 9264'. Test BOPE, repair top ddve. RIH, ddlled from 13369' to 13433'. !Replaced hoses on top drive. 5/23/95 iMud Weight: 10.2 ppg, Depth = 13667' MD, Days Since Spud = 55 iDdlled from 13433' to 13640'. CBU, short tdp to 12600'. Ddlled from 13630' to 13667'. 5/24/95i iMud Weight = 10.2 ppg, Depth = 13869' MD, Days Since Spud = 56 i Ddlled from 13667' to 13869'. CBU, trip for bit. i 5/25/95 i Mud Weight = 10.3 ppg, Depth: 14115' MD, Days Since Spud = 57 RIH, wash and ream 90' to bottom. Ddlted from 13869' to 14115'. 5/26195 iMud Weight= 10.2 ppg, Depth = 14161' MD, Days Since Spud = 58 .Ddlled from 14115' to 14161'. Circand condition mud. Short tdp to 12318'. Circ, POOH to log. Differential sticking at 10515', jarred down to free pipe, back, ream from 10420' to 10400'. I 5/27/95 Mud Weight = 10.1 ppg, Depth = 14161' MD, Days Since Spud = 59 Finished POOH for logs. Rig up Schlumberger TLC tools to ddll pipe. RIH to 11000'. PU side entry i sub and RIH with wet connect. Attempt to latch into control sub, no connection to surface. !POOH with wet connect, latch ring had sheared. RIH with new wet connect. Unable to latch in. ~POOH with ddll pipe. LD side entry sub. 5/28/95 !Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 60 !POOH and check Schlumberger tools. Wet conect receptacle was bent over, change out same. !RIH with logging tools on ddll pipe. Circ at shoe and every 20 stands thereafter. RIH to 11000'. . PU side entry sub. RIH with wireline and latch in successfully. Log from 11000' to 13678'. iCable crushed downhole. POOH with wireline and LD side entry sub. RIH with DP to 12,660'. i Changeout electric line, rehead line. 5/29t95 Mud Weight = 10.1 ppg, Depth = 14161' MD, Days Since Spud = 61 Circ and work pipe while new cable and wet connect dgged up. PU side entry sub. RIH with wiretine and latch wet connect. Log down from 12,676' to 14,130' with triple combo: AIT/CNL/LDT. Log up from 14,060' to 12670' with FMS. Pull wet connect loose and POOH with wireline. POOH with drit! pipe. RD loggers, PU casing scraper and RIH to 7293'. CBU. 5/30t95 ~Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 62 i POOH with 10-314" casing scraper. RU Dia-log and run casing caliper log. RD Dialog. i RIH with 9-7/8" bit for dean out run. 5/31195 !Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 63 iRIH and ream bridge @ 13,730' and 14,040', no fill. Circ, short trip to 13,260'. Circ, POOH for liner. Pulled tight @ 12,267' and 12,212'. Slow pro~lress upreamin¢ at 12,212'. Page 5 compsum.doc West McArthur River Unit #3 Daily Drilling Reports 6tlt95 Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 64 Worked up through tight hole at 12,267'. More tight hole at 12,206'. 6t2/95 Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 65 Backreamed tight hole from 12,200' to 12,175'. POH to more tight hole at 9546'. Backreamed i9546' to 9238'. POOH. 6/3/95 Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 66 POOH with bit. RIH with string mill, reamed from 7456' to 8075', no fill on bottom. i Circ hi-vis sweep, POOH. 6/4/95 Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 67 POOH with mill, worked thru tight spots at 12,297' to 12,257' and 12,051' to 12,041'. Upreamed 11,050' to 11,014'. POH to shoe, RIH with no problems, no fill. Circ and spot CaCO3 pill. POOH with no problems. 6/5/95 Mud Weight = 10.2 ppg, Depth = 14161' MD, Days Since Spud = 68 Finished POOH. RU to run liner. Ran 171 joints of 7-5/8" 29~, L-80, STL liner with insert float shoe, float collar and landing collar. MU Baker hydraulic liner hanger and mechanical liner top packer. RIH with liner on ddli pipe. Worked through tight hole at 13,000' to 14,161'. Liner on bottom. 6/6/95 ;Mud Weight = 10.3 ppg, Depth = 14161' MD, Days Since Spud = 69 'Circ liner on bottom, well packed off, worked pipe and regained circulation. i Pumped 50 bbi water spacer, 250 sx (51 bbt) Class G cement with 0.6% FL-20, 0.2% CD-31, 0.1% A-2, and 1 gphs FP-6L Dropped drill pipe wiper plug, displaced with 4.5 bbi water and 450 bbl mud. Unable to reciprocate while pumping cement. Bumped plug to 3000 psi to set hah( i Bled pressure, checked floats. Released liner running tool with 12 turns to the right PU 8' and set i liner top packer by slacking off 50,000~. PU 2 stands and reverse circ to dear ddll pipe. i Pressure test casing and liner top packer to 1000 psi. POOH with ddll pipe. Change pipe rams to 13-1/2" and test BOPE. 6/7/95 iMud Weight = 10.3 ppg, Depth = 14161' MD, Days Since Spud = 70 !Finished testing BOPE. RIH with 6-3/4" bit and 3-1/2" x 5" tapered ddll pipe stdng. Mud Weight = 10.3 ppg, Depth = 14171' MD, Days Since Spud = 71 Finished RIH with 6-3/4" bit. Ddiled landing collar and cement to 14089'. Pressure tested casing to 925 psi. Drilled cement, float collar and shoe, ddlled new formation to 14171'. Circ hole clean. Performed teakoff test to tl .9 ppg EMW. 6/9/95 6/10195 Mud Weight = 10.2 ppg, Depth = 14281' MD, Days Since Spud = 72 Drilled from 14172' to 14255'. POOH ~r bit. RIH to 14161', reamed out of gauge hole from 14161' to i !4255'. Ddlled from 14255' to 14281'. Mud Weight = 10.2 ppg, Depth = 14450' MD, Days Since Spud = 73 Drilled from 14281' to 14283'. Repaired standpipe valve. Ddlled from 14283' to 14450'. Tdp for bit. 6/11/95 Mud Weight = 10.2 ppg, Depth = 14674' MD, Days Since Spud = 74 RIH. Torque check at shoe= 17,500 ft-lbs @ 40 rpm. i Ddlled from 14450' to 14674'_ CBU for bit trip. 6/12/95 iMud Weight = 10.2 ppg, Depth = 14704' MD, Days Since Spud = 75 i POOH, changed out mud motor, repaired top ddve. RIH, reamed 80' to bottom. i Ddlled from 14674' to 14704'. Page 6 compsum.doc 6tl West McArthur River Unit #3 Daily Drilling Reports 3/95 !Mud Weight = 10.2 ppg, Depth = 14853' MD, Days Since Spud = 76 i Ddlled from 14704' to 14853'. Circ for samples. POOH for bit. Backreamed at 14677' and 14523'. Replaced top stabilizer with stdng mill. 6114t95 !Mud Weight = 9.9 ppg, Depth = 15091' MD, Days Since Spud: 77 .RIH to shoe, decreased mud weight from 10.2 to 10.1 ppg. RIH to bottom. Drilled from 14853' to 114989'. Decreased mud weight to 9.9 ppg. CBU, short trip to shoe. Ddlled from 14989' to 15091'. I CBU for bit tdp. 6115195 iMud Weiqht = 9.9 ppg, Depth = 15156' MD, Days Since Spud = 78 !POOH. Tested BOPE- witnessed by Lou Gdmaldi with AOGCC. RIH, reamed 60' to bottom. ! Ddlled from 15091' to 15156'. 6116/95 iMud Weight = 9.8 ppg, Depth = 15338' MD, Days Since Spud = 79 'Dnlled from 15156' to 15338' TD. CBU, short trip to shoe, backreamed tight spot at 15018'. iCBU, POOH for togs with no hole problems. 6t17/95 iMud Weight = 9.8 ppg, Depth = 15338" MD, Days Since Spud = 80 RU Schlumberger wiretine unit. Log first pass on wireline with triple combo: AIT/CNL/LDT. ILog second pass with FMS. RIH with casing scraper to 14098'. CBU. .i 6t18t95 Mud Weight = 9.8 ppg, Depth = 1~' MD, Days Since Spud = 81 . POOH with scraper, RtH with clean out assembly. Reamed 10' to bottom. CBU, short tdp to shoe. ~Circ hole clean, POOH to run liner, no hole problems. 6119195 Mud Weight = 9.8 ppg, Depth = 15338' MD, Days Since Spud = 82 POH to shoe, dropped rabbitt for 3-1/2" ddll pipe. POOH. RU casing tools and run 33 joints of 5-I/2" L-80, 17#, FL-4S liner. RIH with liner on ddli pipe, check torque at 7-5/8" shoe at 11,500 ft-lbs l at 20 RPM and 4.2 BPM. PU weight = 220,000 lbs. RIH with liner on bottom. Circ liner at 5 BPM and 1700 psi. Reciprocate and rotate on down stroke. PU weight = 250,000 lbs, torque = 13,000 fi-lb. 6/20/95 1 Mud Weight = 9.8 ppg, Depth = 15338' MD, Days Since Spud = 83 Stop pipe movement to RU cement lines for appx 10 minutes. Liner was stuck, could not move Pumped 100 bbl water spacer, 150 sx (31 bbl) Class G cement at 15.6 ppg with 0.85% FL-28, 0.2% CD-31, 0.15% A-2, I gphs FP-6L. Displaced with 1 bbl water, dropped wiper plug, i pumped 4 bbl water and 196.5 bbi mud. Full returns while cementing. Bumped plug to 3000 psi to !set Baker liner top packer. Bled pressure to 0 psi and checked floats. Pumped up pressure to 3500 !psi to set hanger. Slacked off and pressured up to 4000 psi to release running tool. PU 10' and I reverse circ, received 6 bbt of cement contaminated mud and water spacer. iRD cement lines, RIH with 7-5t8" casing scraper to top of line, rat 13878'. CBU, POOH. 6/21/95. Mud Weight = 9.8 ppg, Depth = 1533~' MD, Days Since Spud = 84 j POOH with 7-5/8" scraper. RtH with 4-3/4" mitt and 5-1/2" casing scraper to 15,200'. CBU. . Test casing to 850 psi, OK. POOH. 6/22/95 iMud Weight = 9.8 ppg, Depth = 15184' PBTD, Days Since Spud = 85 IRU Schlumberger logging unit. Ran CET/CBL log in 5-1/2" liner, tag bottom at 15184' WLM. i Log indicated channel below proposed perfs. i Tested BOPE. RIH with Schlumberger 3-3/8" wireline perf guns. Shot squeeze perfs at 15074'-15076'. i6 spf 60 degree phasing, 13 shots total. RIH with19 joints 2-7/8" tubing tail below RTTS for bradenhead squeeze attempt. Page 7 compsum.doc West McArthur River Unit #3 Daily Drilling Reports 16/23/95 Mud Weight = 9.8 ppg, Depth = 15184' PBTD, Days Since Spud = 86 Finished RIH with RTTS. Circ on bottom and ddll pipe backed off at appx 4800'. Screwed into fish. POOH slowly, 5" x 3-1/2" drill pipe crossover had damaged pin and was where back-off had occurred. Check every cnxn and continued POOH. 6/24/95 Mud Weight = 9.8 ppg, Depth = 15184' PBTD, Days Since Spud = 87 i Finish POOH with RTTS, left junk in hole off RTTS: 7"x 2/16" x 1/2" steel bar from hoiddown buttons, i4 stainless steel spdngs, 4 stainless steel bolt heads and one rubber packer element. iRU APRS wireline fishing unit. Ran 4" magnet to 15,198' with no recovery. Ran 4-1/2" magnet to 15,198' with no recovery. Ran 6" magnet to top of 5-1/2" liner at 13,878' with no recovery. RIH with 4-3/4" mill and junk basket. 6/25/95 Mud Weight = 9.8 ppg, Depth = 15185' PBTD, Days Since Spud = 88 !Washed from 13680' to 15193' with mill and junk basket. Ddll from 15193' to 15194'. CBU and i recovered packer rubber on shaker screens. POOH, recovered 2 bolt heads and 2 spdngs. with squeeze assembly including CHAMP packer. 6/26/95 i Mud Weight = 9.8 ppg, Depth = 15070' PBTD, Days Since Spud = 89 ICirc on bottom. Spot 10 bbl water across and above squeeze perfs. Set CHAMP packer, attempt i injectivity test. No injection at 3500 psi. Bled pressure, unseat packer and POOH. Abort squeeze {due to lack of injectivity. RU Schltm~berger, set EZSV retainer on wiretine at 15070' WLM. POOH !with wiretine. RIH with mill and tag retainer at 15085' DPM. 6/27/95 Mud Weight = 8.5 ppg, Depth = 15070' PBTD, Days Since Spud = 90 i Attempt to displace hole with produced water by reverse circulating but pressure too high. Circ 100 bbi water down ddli pipe with 50 bbl XC polymer pill followed by 100 bbi dirt magnet pill. i Displace down ddll pipe with produced water but returns still dirty. Switch to reverse circulating with { 100 bbl New Ddli polymer piti followed by produced water and 2% KCL water as produced water supply j became depleted. Returns clean. Dropped 1-7/8" rabbitt and POOH with ddil pipe. i RU Halliburton TCP guns and perm packer on ddll pipe. 6/28/95 iMud Weight = 8.5 ppg, Depth = 15070' PBTD, Days Since Spud = 91 i RIH w/per guns, Model "BWD" perm pkr. Run Schlumberger GR tie-in log through DP for depth I ~correlation to set pkr @ 14738' WLM. POOH with wireline logs. Drop ball and set pkr with 1800 psi i !slack-off weight of 40,000#. PU and shear out running tool. Shear out ball at 4900 psi. !POOH laying down ddli pipe. 6/29/95 [Mud Weight = 8.5 ppg, Depth = 15070' PBTD, Days Since Spud = 92 !Lay down ddii pipe, dg down top ddve. 6/30195 Mud Weight = 8.5 ppg, Depth = 15070' PBTD, Days Since Spud = 93 Run 2-7/8" completion tubing with seal assembly and jet pump cavity. Hydrotest tubing to 5000 psi. 7t1195 Mud Weight = 8.5 ppg, Depth.. = 15070' PBTD, Days Since Spud = 94 Finished running 2-7/8"tubing incl seal assy, 1 jt tbg, pump cavity, 456 jts tbg, 3 pups, hanger. Drifted all tubing to 2.347". Land hanger with seals stabbed into packer. Install BPV. Run in lock down screws and ND BOPE. 7/2/95 i Mud Weight = 7.4 ppg, Depth = 15070' PBTD, Days Since Spud = 95 NU tree and test to 5000 psi. Pull BPV. i Release Nabors Rig #160 at 12:00 hfs 7/1/95. !Displace well with crude oil down annulus, through pump cavity ports and up tubing. i RU Halliburton slick line and set islolation sleeve in pump cavity. Page 8 compsum.doc 7/3/95 West McA hur River Unit #3 Daily Drilling Reports !Mud Weight = 7.4 ppg, Depth = 15070' PBTD, Days Since Spud = 96 i Pressure test sleeve. Bled compressed crude to heater treater. Pressure up tubing and fire guns. I Perfed 14805'-14836' and 14852'-15060' MD at 6spf, 3-3/8" gun 22 gm charges. i Run Amerada pressure gauge on slick;line with stops at 10227' MD = -6647'ss, 14442' MD = -9000ss iand 14591' MD = -9100'ss. Puli isolation sleeve from pump cavity. Run standing valve on slickJine. 714/95 j Mud Weight = 7.4 ppg, Depth = 15070' PBTD, Days Since Spud = 97 Drop jet pump in tubing and pump to bottom. Pumped well for 2 hfs, plugged pump. Reverse out ipump and unplug pump. Reverse circ 1-1/2 tubing volumes. Return pump to bottom. Pump well. I 7/5/95 1 Mud Weight = 7.4 ppg, Depth = 15070' PBTD, Days Since Spud = 98 iWell on production. Page 9 compsum.doc Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 lell ......... : WMR-3 ~ield ........ : WEST MCARTHUR RIVER UNIT ~omputation..: MINIMUM CURVATURE Jnits ........ : FEET ;ur )e Lat..: 60.78482702 N ~urface Long.: 151.75022727 W DIRECTIONAL WELLi~LAN for STEWART PETROLEUM COMPANY · LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord ~urface ...... : 2899 FSL 3957 FEL S16 T08N R14W SM 187248.83 2482962.33 ?op Target...: 4442 FSL 1125 FEL Sl0 T08N R14W SM. 195528.56 2489569.50 ~ottom Target: 4549 FSL 994 FEL S10 T08N R14W SM 195662.29 2489673.54 ~HL .......... : 4657 FSL 857 FEL Sl0 T08N R14W SM 195802.01 2489777 78 PROPOSED WELL pRO~I~ MEAS INCLN DIRECTION VERT-DEPTHS SECT RE DEPTH ANGLE AZ IMUTH BKB SUB- S DIST FROM- THE- WELLHEAD S TAT I ON IDENTIFICATION 0 0.00 0.00 0 -163 0 0.00 N 285 0.50 56.00 285 122 1 0.70 N 537 1.50 32.00 537 374 5 4.11 N 693 1.90 49.60 693 530 10 7.52 N 724 1.90 45.40 724 561 11 8.21 N Prepared ..... : 06/29/95 Section at...: 50.35 KB elevation.: 163.00 ft Magnetic Dcln: 22.660 E Scale Factor.: 1.00001130 Convergence..: -1.52769959 STATE-PLANE TOOL DL/ X Y FACE 100 0.00 E 187248.83 2482962.33 HS 0.00 1.03 E-8301409.82-9390943.84 35L 3.69 E-8301409.82-9390943.84 62R 6.74 E-8301409.82-9390943.84 92L 7.50 E-8301409.82-9390943.84 5R 755 2.10 45.90 755 592 12 8.97 N 787 2.50 40.40 787 624 13 9.90 N 838 2.80 55.70 838 675 16 11.45 N 863 3.10 47.70 863 700 17 12.25 N 895 3.40 50.70 895 732 19 13.44 N 8.27 E 187248.83 2482962.33 32L 0.00 9.15 E 187248.83 2482962.33 75R 0.00 10.90 E 187260.03 2482973.49 58L 1.50 11.90 E 187261.05 2482974.26 31R 2.03 13.27 E 187262.46 2482975.41 19R 1.08 925 3.60 51.80 925 762 21 14.58 N 957 3.70 50.40 957 794 23 15.86 N 988 4.20 49.50 987 824 25 17.24 N 1019 4.60 50.40 1018 855 27 18.77 N 14.70 E 187263.92 2482976.51 42L 0.70 16.29 E 187265.54 2482977.75 8L 0.42 17.92 E 187267.21 2482979.08 10R 1.63 19.74 E 187269.07 2482980.56 4R 1.31 WMR- 3 STATION IDENTIFICATION 06/29/95 Page 2 PROPOSED WELL PROFILE MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES DEPTH ANGLE AZIMUTH BKB SUB-S DIST FROM-THE-WELLHEAD 1050 5.00 1081 5.70 1113 6.10 1144 6.80 1175 7.40 50.70 1049 886 30 49.80 1080 917 33 51.30 1112 949 36 48.50 1143 980 39 50.60 1174 1011 43 STATE-PLANE TOOL DL/ X Y FACE 100 20.41 N 21.75 E 187271.11 2482982.16 7L 1.29 22.26 N 23.97 E 187273.38 2482983.95 22R 2.27 24.35 N 26.51 E 187275.98 24829~5.97 26L 1.34 26.60 N 29.17 E 187278.70 2482988.14 24R 2.47 29.08 N 32.09 E 187281.68 2482990.55 12L 2.11 1207 7.90 1238 8.90 1269 9.70 1301 10.10 1332 10.90 49.80 1205 1042 48 49.60 1236 1073 52 51.00 1267 1104 57 49.10 1298 1135 63 51.30 1329 1166 68 31.81 N 34.74 N 37.94 N 41.47 N 45.08 N 35.36 E 187285.02 2482993.18 2L 1.60 38.81 E 187288.55 2482996.02 16R 3.23 42.67 E 187292.49 2482999.11 40L 2.68 46.88 E 187296.80 2483002.54 28R 1.61 51.23 E 187301.24 2483006.03 13L 2.89 1363 11.40 1394 12.20 1425 12.90 1457 13.50 1488 14.30 50.70 1359 1196 74 49.60 1389 1226 81 51.30 1420 1257 87 49.00 1451 1288 95 50.10 1481 1318 102 48.85 N 55.88 E 187306.00 2483009.68 16L 1.66 52.92 N . 60.75 E 187310.97 2483013.61 29R 2.68 57.20 N 65.94 E 187316.28 2483017.76 42L 2.55 61.89 N 71.55 E 187322.01 2483022.29 19R 2.49 66.72 N 77.22 E 187327.80 2483026.97 HS 2.72 1518 15.20 1548 15.80 1579 16.60 1610 17.10 1641 17.80 50.10 1510 1347 110 50.00 1539 1376 118 49.80 1568 1405 126 50.80 1598 1435 135 50.70 1628 1465 145 71.62 N 83.08 E 187333.79 2483031.71 3L 3.00 76.77 N 89.22 E 187340.07 2483036.69 4L 2.00 82.34 N 95.84 E 187346.83 2483042.08 31R 2.59 88.08 N 102.75 E 187353.90 2483047.64 3L 1.86 93.96 N 109.95 E 187361.25 2483053.32 20L 2.26 1673 18.70 1705 19.00 1735 19.50 1767 20.00 1798 20.60 49.70 1658 1495 155 50.30 1688 1525 165 49.60 1717 1554 175 49.80 1747 1584 186 49.70 1776 1613 196 100.37 N 117.65 E 187369.12 2483059.53 33R 2.98 107.02 N 125.57 E 187377.21 2483065.96 25L 1.12 113.38 N 133.14 E 187384.95 2483072.12 8R 1.84 120.38 N 141.39 E 187393.38 2483078.90 3L 1.58 127.33 N 149.60 E 187401.77 2483085.62 3L 1.94 1829 21.20 1860 21.80 1892 22.60 1923 23.00 1954 23.80 49.60 1805 1642 207 50.50 1834 1671 219 49.40 1863 1700 231 50.30 1892 1729 243 49.70 1920 1757 255 134.49 N 158.02 E 187410.39 2483092.56 29R 1.94 141.78 N 166.73 E 187419.29 2483099.62 28L 2.21 149.56 N 175.99 E 187428.74 2483107.15 42R 2.82 157.31 N 185.17 E 187438.13 2483114.65 17L 1.71 165.22 N 194.60 E 187447.77 2483122.31 19L 2.69 1986 24.40 49.20 1950 1787 268 173.72 N 204.53 E 187457.92 2483130.53 3L 1.98 WMR- 3 STATION IDENTIFICATION 06/29/95 Page 3 PROPOSED WELL PROFILE MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES DEPTH ANGLE AZIMUTH BKB SUB-S DIST 2017 25.20 2048 25.90 2080 26.70 2111 27.50 2142 28.30 STATE-PLANE TOOL DL/ FROM-THE-WELLHEAD X Y FACE 100 182.22 N 214.36 E 187467.98 2483138.77 21L 2.58 191.03 N 224.42 E 187478.27 2483147.31 29L 2.41 200.52 N 234.96 E 187489.05 2483156.51 22R 2.86 209.99 N 245.43 E 187499.77 2483165.71 17L 2.78 219.71 N 256.20 E 187510.80 2483175.13 HS 2.69 49.10 1978 1815 281 48.50 2006 1843 295 47.50 2034 1871 309 48.20 2062 1899 323 47.70 2089 1926 337 2174 29.10 2204 29.90 2242 31.00 2274 32.00 2306 32.20 47.70 2117 1954 353 48.20 2144 1981 368 48.40 2176 2013 387 48.30 2204 2041 404 48.20 2231 2068 421 230.05 N 267.57 E 187522.44 2483185.17 17R 2.50 239.94 N 278.54 E 187533.67 2483194.77 5R 2.79 252.76 N 292.91 E 187548.38 2483207.19 3L 2.91 263.87 N 305.41 E 187561.17 2483217.96 15L 3.13 275.19 N 318.09 E 187574.15 2483228.94 6R 0.65 2416 33.80 2447 34.90 2478 35.50 2509 36.70 2540 37.70 48.50 2323 2160 480 48.70 2349 2186 498 49.80 2374 2211 516 48.70 2399 2236 534 49.10 2424 2261 553 315.00 N 362.86 E 187619.96 2483267.55 6R 1.46 326.57 N 375.98 E 187633.39 2483278.76 47R 3.57 338.23 N 389.52 E 187647.23 2483290.06 29L 2.82 350.16 N 403.35 E 187661.38 2483301.61 14R 4.40 362.48 N 417.48 E 187675.83 2483313.55 llR 3.32 2571 38.70 2602 39.50 2633 40.00 2664 40.10 2696 40.40 49.40 2448 2285 572 49.30 2472 2309 591 49.30 2496 2333 611 49.50 2520 2357 631 49.10 2544 2381 652 374.99 N 432.00 E 187690.68 2483325.67 5L 3.28 387.72 N 446.83 E 187705.85 2483338.01 HS 2.59 400.65 N 461.86 E 187721.21 2483350.53 52R 1.61 413.63 N 477.01 E 187736.70 2483363.10 41L 0.53 427.11 N 492.68 E 187752.73 2483376.16 59R 1.24 2727 40.80 2757 41.20 2788 41.70 2820 42.20 2850 43.00 50.10 2568 2405 672 50.40 2590 2427 692 50.60 2613 2450 712 50.70 2637 2474 734 51.00 2659 2496 754 440.19 N 508.05 E 187768.44 2483388.82 26R 2.46 452.77 N 523.18 E 187783.90 2483401.00 15R 1.49 465.83 N 539.01 E 187800.08 2483413.63 8R 1.67 479.39 N 555.55 E 187816.97 2483426.74 14R 1.58 492.21 N 571.30 E 187833.06 2483439.14 17R 2.75 2882 43.70 2912 44.10 2942 44.30 2973 44.80 3004 45.50 51.30 2683 2520 776 51.60 2704 2541 797 51.80 2726 2563 818 51.40 2748 2585 839 50.90 2770 2607 861 505.99 N 588.41 E 187850.53 2483452.46 28R 2.28 518.95 N 604.68 E 187867.13 2483464.98 35R 1.50 531.92 N 621.09 E 187883.89 2483477.50 29L 0.81 545.42 N 638.13 E 187901.29 2483490.55 27L 1.85 559.21 N 655.25 E 187918.76 2483503.88 28L 2.53 3035 45.90 50.60 2791 2628 884 573.25 N 672.43 E 187936.31 2483517.45 20L 1.46 WMR-3 06/29/95 Page 4 PROPOSED WELL PROFILE STATION IDENTIFICATION MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES DEPTH ANGLE AZIMUTH BKB SUB-S DIST FROM-THE-WELLHEAD STATE-PLANE TOOL DL/ X Y FACE 100 3067 46.70 3097 47.20 3128 48.10 3158 49.10 3189 49.90 50.20 2813 2650 907 49.40 2834 2671 929 49.50 2855 26~2 951 49.20 2875 2712 974 49.20 2895 2732 998 587.99 N 690.26 E 187954.52 2483531.72 50L 2.66 602.15 N 707.00 E 187971.64 2483545.42 5R 2.56 617.04 N 724.41 E 187989.44 2483559.84 13L 2.91 631.70 N 741.48 E 188006.90 2483574.04 HS 3.42 647.10 N 759.32 E 188025.14 2483588.96 llL 2.58 3220 50.30 3251 50.80 3282 51.00 3312 51.50 3343 52.40 49.10 2915 2752 1021 48.80 2934 2771 1045 48.20 2954 2791 1069 47.70 2973 2810 1093 48.00 2992 2829 1117 662.66 N 777.31 E 188043.54 2483604.03 25L 1.31 678.38 N 795.37 E 188062.01 2483619.27 67L 1.78 694.32 N 813.38 E 188080.44 2483634.72 38L 1.63 709.99 N 830.76 E 188098.23 2483649.93 15R 2.11 726.37 N 848.85 E 188116.76 2483665.82 4L 3.00 3381 53.70 3467 56.80 3559 57.50 3651 58.00 3744 58.60 47.90 3015 2852 1147 46.70 3064 2901 1218 46.90 3114 2951 1295 46.80 3163 3000 1373 46.70 3212 3049 1452 746.71 N 871.40 E 188139.84 2483685.55 18L 3.43 794.63 N 923.32 E 188193.01 2483732.07 14R 3.78 847.54 N 979.66 E 188250.75 2483783.46 10L 0.78 900.75 N 1036.42 E 188308.91 2483835.14 8L 0.55 954.97 N 1094.06 E 188367.97 2483887.80 82L 0.65 3841 58.70 3935 58.70 4028 59.10 4122 58.60 4214 58.20 45.90 3262 3099 1534 1012.20 N 1153.94 E 188429.36 2483943.42 90R 0.71 46.30 3311 3148 1614 1067.89 N 1211.82 E 188488.70 2483997.55 47R 0.36 46.80 3359 3196 1694 1122.66 N 1269.63 E 188547.95 2484050.75 161R 0.63 47.00 3407 3244 1774 1177.62 N 1328.37 E 188608.14 2484104.13 157R 0.56 47.20 3456 3293 1852 1230.96 N 1385.77 E 188666.94 2484155.92 90L 0.47 4307 58.20 4401 57.40 4493 56.80 4587 56.30 4679 55.70 47.00 3505 3342 1931 1284.77 N 1443.67 E 188726.25 2484208.17 144R 0.18 47.70 3555 3392 2011 1338.66 N 1502.17 E 188786.17 2484260.48 164L 1.06 47.50 3605 3442 2088 1390.75 N 1559.21 E 188844.58 2484311.03 127R 0.68 48.30 3657 3494 2166 1443.33 N 1617.40 E 188904.16 2484362.04 165L 0.89 48.10 3708 3545 2243 1494.17 N 1674.26 E 188962.35 2484411.34 171R 0.68 4772 55.20 4864 55.00 4957 54.70 5050 54.70 5141 54.50 48.20 3761 3598 2319 1545.27 N 1731.32 E 189020.75 2484460.91 158R 0.54 48.30 3813 3650 2394 1595.51 N 1787.61 E 189078.36 2484509.63 165R 0.23 48.40 3867 3704 2470 1646.05 N 1844.43 E 189136.51 2484558.64 90R 0.33 49.00 3921 3758 2546 1696.14 N 1901.45 E 189194.85 2484607.19 104L 0.53 48.00 3973 3810 2620 1745.29 N 1957.01 E 189251.69 2484654.84 132R 0.92 5234 54.00 48.70 4028 3865 2696 1795.45 N 2013.40 E 189309.41 2484703.48 90L 0.81 WMR- 3 S TAT I ON IDENTIFICATION 06/29/95 Page 5 PROPOSED WELL PROFILE MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES DEPTH ANGLE 5327 54.00 5421 53.80 5514 54.20 5608 54.20 5702 54.80 STATE-PLANE TOOL DL/ AZIMUTH BKB SUB-S DIST FROM-THE-WELLHEAD X Y FACE 100 48.40 4082 3919 2771 1845.26 N 2069.80 E 189367.11 2484751.77 104L 0.26 47.40 4138 3975 2847 1896.18 N 2126.15 E 189424.80 2484801.17 31R 0.89 47.70 4192 4029 2922 1946.96 ~ 2181.67 E 189481.65 2484850.45 90L 0.50 47.60 4247 4084 2998 1998 32 N 2238.01 E 189539.35 2484900.29 15L 0.09 47.40 4302 4139 3075 2050.02 N 2294.43 E 189597.13 2484950.47 39L 0.66 5797 55.00 5891 55.30 5984 55.80 6077 56.00 6169 56.80 47.20 4357 4194 3152 2102.73 N 2351.55 E 189655.63 2485001.64 39R 0.27 47.50 4410 4247 3229 2154.99 N 2408.29 E 189713.74 2485052.37 59L 0.41 46.50 4463 4300 3306 2207.29 N 2464.37 E 189771.20 2485103.16 83R 1.04 48.40 4515 4352 3383 2259.37 N 2521.10 E 189829.30 2485153.70 6L 1.71 48.30 4566 4403 3459 2310.29 N 2578.36 E 189887.90 2485203.08 32L 0.87 6286 57.20 6379 56.90 6472 56.80 6565 56.50 6660 55.60 48.00 4630 4467 3557 2375.76 N 2651.45 E 189962.71 2485266.58 104R 0.40 49.50 4680 4517 3635 2427.21 N 2710.12 E 190022.73 2485316.45 104L 1.39 49.00 4731 4568 3713 2478.04 N 2769.11 E 190083.05 2485365.68 121R 0.46 49.60 4782 4619 3791 2528.70 N 2828.00 E 190143.28 2485414.76 160L 0.63 49.20 4835 4672 3870 2579.98 N 2887.84 E 190204.46 2485464.42 141L 1.01 6754 55.20 6849 54.70 6945 53.70 7032 53.50 7125 52.70 48.80 4889 4726 3947 2630.74 N 2946.23 E 190264.19 2485513.61 162L 0.55 48.60 4943 4780 4025 2682.07 N 3004.66 E 190323.96 2485563.37 162R 0.55 49.00 4999 4836 4103 2733.36 N 3063.24 E 190383.89 2485613.07 LS 1.10 49.00 5051 4888 4173 2779.30 N 3116.09 E 190437.95 2485657.59 142R 0.23 49.80 5107 4944 4247 2827.70 N 3172.56 E 190495.68 2485704.47 37R 1.10 7218 54.00 7265 55.40 7356 56.00 7450 55.60 7546 55.10 51.00 5162 4999 4322 2875.25 N 3230.05 E 190554.42 2485750.47 13R 1.74 51.40 5190 5027 4360 2899.29 N 3259.94 E 190584.95 2485773.70 29R 3.06 51.80 5241 5078 4435 2945.98 N 3318.86 E 190645.09 2485818.81 134R 0.75 52.30 5294 5131 4513 2993.79 N 3380.16 E 190707.64 2485864.97 LS 0.61 52.30 5348 5185 4592 3042.08 N 3442.65 E 190771.40 2485911.58 161L 0.52 7640 53.90 7730 53.90 7824 55.60 7918 55.80 8012 56.00 51.80 5403 5240 4668 3089.14 N 3502.99 E 190832.97 2485957.01 90R 1.35 52.90 5456 5293 4741 3133.56 N 3560.57 E 190891.71 2485999.88 32L 0.99 51.60 5510 5347 4818 3180.56 N 3621.25 E 190953.63 2486045.24 75R 2.13 52.50 5563 5400 4895 3228.32 N 3682.49 E 191016.12 2486091.35 64L 0.82 52.00 5616 5453 4973 3275.97 N 3744.03 E 191078.91 2486137.35 68R 0.49 8103 56.10 52.30 5667 5504 5049 3322.29 N 3803.64 E 191139.73 2486182.06 52L 0.29 WMR-3 06/29/95 Page 6 PROPOSED WELL PROFILE STATION IDENTIFICATION MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES STATE-PLANE TOOL DL/ DEPTH ANGLE AZIMUTH BKB SI3B-S DIST FROM-THE-WELLHEAD X Y FACE 100 8198 56.70 51.40 5719 5556 5128 3371.17 N 3865.86 E 191203.24 2486229.26 157R 1.01 8292 56.50 51.50 5771 5608 5206 3420.07 N 3927.23 E 191265.89 2486276.51 32R 0.23 8386 56.90 51.80 5823' 5660 5285 3468.82 N 3988.85 E 191328.~8 2486323.60 121L 0.50 8480 56.70 51.40 5874 5711 5363 3517.68 N 4050.49 E 191391.71 2486370.80 90L 0.41 8573 56.70 51.20 5925 5762 5441 3566.28 N 4111.15 E 191453.64 2486417.76 40R 0.18 8667 57.20 8759 56.90 8854 57.10 8948 57.80 9042 58.40 51.70 5976 5813 5520 3615.38 N 4172.77 E 191516.55 2486465.20 164R 0.69 51.80 6026 5863 5597 3663.17 N 4233.40 E 191578.43 2486511.37 HS 0.34 51.80 6078 5915 5677 3712.44 N 4296.01 E 191642.34 2486558.95 26R 0.21 52.20 6129 5966 5756 3761.22 N 4358.45 E 191706.05 2486606.05 23R 0.83 52.50 6178 6015 5836 3809.97 N 4421.63 E 191770.52 2486653.09 90L 0.69 9134 58.40 9230 58.70 9321 58.70 9415 58.20 9508 58.30 52.10 6227 6064 5914 3857.89 N 4483.63 E 191833.77 2486699.34 30R 0.37 52.30 6277 6114 5996 3908.08 N 4548.34 E 191899.80 2486747.79 90R 0.36 52.60 6324 6161 6073 3955.47 N 4609.99 E 191962.69 2486793.52 146R 0.28 53.00 6373 6210 6153 4003.90 N 4673.80 E 192027.76 2486840.24 60R 0.64 53.20 6422 6259 6232 4051.39 N 4737.04 E 192092.25 2486886.02 106L 0.21 9602 58.20 9696 57.80 9785 57.30 9881 57.40 9972 56.80 52.80 6472 6309 6312 4099.49 N 4800.88 E 192157.34 2486932.40 157R 0.38 53.00 6521 6358 6392 4147.58 N 4864.46 E 192222.18 2486978.78 135R 0.46 53.60 6569 6406 6467 4192.46 N 4924.67 E 192283.58 2487022.04 85L 0.80 52.30 6621 6458 6548 4241.16 N 4989.18 E 192349.36 2487069.00 164R 1.14 52.50 6670 6507 6624 4287.78 N 5049.71 E 192411.12 2487113.99 99L 0.68 10066 56.70 10160 56.90 10252 56.80 10342 57.10 10437 57.00 51.70 6722 6559 6703 4336.07 N 5111.74 E 192474.41 2487160.61 59R 0.72 52.10 6773 6610 6781 4384.60 N 5173.64 E 192537.58 2487207.47 140L 0.41 52.00 6824 6661 6858 4431.97 N 5234.38 E 192599.56 2487253.21 16R 0.14 52.10 6873 6710 6934 4478.36 N 5293.87 E 192660.27 2487298.00 107L 0.35 51.70 6924 6761 7013 4527.55 N 5356.60 E 192724.29 2487345.50 90L 0.37 10530 57.00 10621 56.40 10714 56.50 10807 56.70 10899 56.40 50.40 6975 6812 7091 4576.58 N 5417.25 E 192786.23 2487392.89 157L 1.17 50.10 7025 6862 7167 4625.21 N 5475.73 E 192845.98 2487439.95 68R 0.71 50.40 7076 6913 7245 4674.78 N 5535.32 E 192906.87 2487487.90 74R 0.29 51.20 7128 6965 7323 4723.85 N 5595.49 E 192968.33 2487535.35 126L 0.75 50.70 7178 7015 7399 4772.20 N 5655.10 E 193029.21 2487582.10 144L 0.56 10993 55.60 50.00 7231 7068 7477 4821.93 N 5715.10 E 193090.52 2487630.21 109R 1.05 h~4R-3 06/29/95 Page 7 STATION IDENTIFICATION START CORRECTION CNE ? CORRECTION PROPOSED WELL PROFILE STATE-PLANE TOOL DL/ X Y FACE 100 50.70 7284 7121 7555 4871.36 N 5774.75 E 193151.46 2487678.04 46L 0.65 50.20 7337 7174 7632 4920.75 N 5834.55 E 193212.56 2487725.81 6L 0.61 · 50.10 7388 7225 7708 4969 20 N 5892.61 E 193271.89 2487772.70 67L 0.88 49.00 7438 7275 7784 5018.60 N 5950.55 E 193331.13 2487820.54 60R 1.10 50.20 7488 7325 7862 5069.32 N 6010.15 E 193392.06 2487869.65 173R 1.26 MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES DEPTH ANGLE AZIMUTH BKB SUB-S DIST FROM-THE-WELLHEAD 11087 55.40 11181 55.80 11272 56.60 11363 57.00 11456 57.60 11546 56.90 11639 56.50 11731 56.70 11823 57.30 11916 57.20 50.30 7537 7374 7938 5117.72 N 6068.34 E 193451.52 2487916.49 l16L 0.78 49.30 7588 7425 8016 5167.89 N 6127.71 E 193512.21 2487965.05 75R 1.00 50.20 7638 7475 8092 5217,52 N 6186.33 E 193572.13 2488013.10 23L 0.85 49.90 7688 7525 8170 5267.06 N 6245.48 E 193632.58 2488061.05 l12R 0.71 50.20 7739 7576 8248 5317.29 N 6305.44 E 193693.86 2488109.66 173L 0.29 12009 55.80 12103 55.80 12196 55.40 12288 55.80 12381 55.80 50.00 7790 7627 8325 5367.03 N 6364.94 E 193754.66 2488157.80 90L 1.52 49.50 7843 7680 8403 5417.26 N 6424.28 E 193815.32 2488206.43 158R 0.44 49.70 7895 7732 8480 5467.00 N 6482.71 E 193875.06 2488254.59 12L 0.47 49.60 7947 7784 8556 5516.15 N 6540.56 E 193934.20 2488302.18 90R 0.44 49.70 8000 7837 8633 5565.95 N 6599.18 E 193994.13 2488350.40 LS 0.09 12472 55.40 12564 55.70 12657 55.70 12751 55.80 12833 56.51 49.70 8051 7888 8708 5614.51 N 6656.45 E 194052.67 2488397.42 29L 0.44 49.50 8103 7940 8784 5663.68 N 6714.22 E 194111.73 2488445.03 0.37 49.50 8156 7993 8860 5713.58 N 6772.64 E 194171.46 2488493.35 59R 0.00 49.70 8208 8045 8938 5763.93 N 6831.81 E 194231.96 2488542.11 28L 0.21 49.26 8254 8091 9006 5808.18 N 6883.58 E 194284.89 2488584.97 27L 0.97 12844 56.60 12938 56.70 13030 56.90 13136 56.60 13230 56.10 49.20 8260 8097 9015 5814.18 N 6890.53 E 194291.99 2488590.77 HS 0.97 49.20 8312 8149 9094 5865.48 N 6949.97 E 194352.78 2488640.48 59R 0.11 49.60 8362 8199 9171 5915.58 N 7008.42 E 194412.55 2488689.00 164R 0.42 49.70 8420 8257 9260 5972.98 N 7075.98 E 194481.61 2488744.57 140R 0.29 50.20 8472 8309 9338 6023.33 N 7135.88 E 194542.83 2488793.31 107L 0.69 13323 56.00 13416 56.10 13510 56.60 13604 56.20 13697 56.20 49.80 8524 8361 9415 6072.91 N 7194.98 E 194603.23 2488841.30 HS 0.37 49.80 8576 8413 9492 6122.71 N 7253.90 E 194663.46 2488889.51 40R 0.11 50.30 8628 8465 9570 6172.95 N 7313.89 E 194724.77 2488938.13 148L 0.69 50.00 8680 8517 9649 6223.12 N 7373.99 E 194786.19 2488986.68 90R 0.50 50.40 8732 8569 9726 6272.59 N 7433.37 E 194846.86 2489034.55 148R 0.36 13790 55.80 50.70 8784 8621 9803 6321.58 N 7492.90 E 194907.68 2489081.94 167L 0.51 ~MR-3 06/29/95 Page 8 PROPOSED WELL PROFILE STATION IDENTIFICATION POP TARGET BOTTOM TARGET FD MEAS INCLN DIRECTION VERT- DEPTHS SECT RELATIVE- COORDINATES DEPTH ANGLE AZIMUTH BKB SUB- S DIST FROM- THE-WELLHEAD 13882 55.10 13975 55.90 14068 56.20 14099 56.10 14238 54.60 STATE-PLANE TOOL DL/ X Y FACE 100 50.50 8836 8673 9879 6369.68 N 7551.46 E 194967.50 2489128.45 6R 0.78 50.60 8889 8726 9955 6418.38 N 7610.64 E 195027.96 2489175.56 15R 0.86 50.70 8941 8778 10033 6467.29 N 7670.29 E 195~88.90 2489222.87 140R 0.33 50.80 8958 8795 10058 6483.58 N 7690.23 E 195109.26 2489238.62 157L 0.42 50.00 9037 8874 10173 6556.46 N 7778.34 E 195199.28 2489309.12 167R 1.18 14331 51.80 14426 50.10 14518 48.00 14610 45.90 14703 43.50 50.80 9093 8930 10247 6603.93 N 7835.70 E 195257.89 2489355.04 154R 3.09 51.90 9153 8990 10321 6650.01 N 7893.31 E 195316.71 2489399.57 148L 2.00 50.10 9213 9050 10390 6693.72 N 7947.32 E 195371.86 2489441.83 167L 2.72 49.40 9276 9113 10458 6737.15 N 7998.63 E 195424.32 2489483.88 169L 2.35 48.70 9342 9179 10523 6780.01 N 8048.04 E 195474.85 2489525.41 155R 2.63 14795 42.50 14805 42.45 14889 42.00 14982 41.30 15060 40.71 49.40 9409 9246 10586 6821.14 N 8095.42 E 195523.32 2489565.25 llSR 1.20 49.55 9417 9254 10592 6825.52 N 8100.56 E 195528.56 2489569.50 llSR 1.13 50.80 9479 9316 10649 6861.68 N 8143.91 E 195572.86 2489604.49 LS 1.13 50.80 9548 9385 10711 6900.74 N 8191.80 E 195621.78 2489642.26 LS 0.75 50.80 9607 9444 10762 6933.09 N 8231.46 E 195662.29 2489673.54 LS 0.76 15074 40.60 15167 39.30 15260 37.90 15289 37.60 15338 37.10 50.80 9618 9455 10771 6938.85 N 8238.53 E 195669.51 2489679.11 156R 0.76 51.70 9689 9526 10831 6976.23 N 8285.10 E 195717.05 2489715.24 168R 1.53 52.20 9762 9599 10889 7012.00 N 8330.78 E 195763.68 2489749.77 169R 1.54 52.30 9785 9622 10906 7022.87 N 8344.82 E 195778.00 2489760.26 173R 1.06 52.40 9824 9661 10936 7041.02 N 8368.36 E 195802.01 2489777.78 1.03 WMR- 3 DATA INTERPOLATED FOR 100 SUBSEA MEAS INCLN DIRECTION DEPTH DEPTH ANGLE AZIMUTH 0 100 200 300 400 500 600 700 800 900 163 0.29 56.00 263 0.46 56.00 363 0.79 42.21 463 1.20 34.86 563 1.55 35.54 663 1.81 46.85 763 2.20 44.31 863 3.10 47.73 963 3.80 50.19 1064 5.31 50.27 1000 1164 7.19 49.92 1100 1265 9.61 50.85 1200 1367 11.51 50.54 1300 1470 13.83 49.46 1400 1573 16.45 49.84 1500 1678 18.75 49.80 1600 1784 20.33 49.74 1700 1892 22.59 49.41 1800 2001 24.78 49.15 1900 -.2112 27.53 48.18 2000 2227 30.55 48.32 2100 2344 32.76 48.31 2200 2465 35.24 49.33 2300 2590 39.20 49.34 2400 2721 40.72 49.91 2500 2855 43.11 51.05 2600 2995 45.29 51.05 2700 3140 48.51 49.38 Page FOOT SUBSEA INTERVAL 1 06/29/95 TVD MD-TVD VERT BKB DIFF CRRT RELATIVE COORDINATES FROM WELL HEAD 163 0 6 0.23 N 0.34 E 263 0 0 0 . 59 N 0 . 88 E 363 0 0 1.29 N 1.68 E 463 0 0 2.65 N 2.74 E 563 0 0 4.68 N 4.08 E 663 0 0 763 0 0 863 0 0 963 0 0 1063 1 0 6.87 N 6.02 E 9.18 N 8.49 E 12.26 N 11.91 E 16.13 N 16.61 E 21.20 N 22.70 E 1163 1 1 1263 2 1 1363 4 2 1463 7 3 1563 10 4 28.22 N 31.05 E 37.56 N 42.20 E 49.38 N 56.52 E 63.84 N 73.81 E 81.29 N 94.60 E 1663 15 5 1763 21 6 1863 29 7 1963 38 9 2063 49 11 101.44 N 118.91 E 124.21 N 145.92 E 149.47 N 175.88 E 177.73 N 209.17 E 210.35 N 245.82 E 2163 64 14 2263 81 18 2363 102 20 2463 127 26 2563 158 31 247.49 N 286.99 E 288.88 N 333.43 E 333.22 N 383.64 E 382.89 N 441.21 E 437.66 N 505.03 E 2663 192 34 2763 232 39 2863 277 46 494.37 N 573.97 E 554.95 N 650.00 E 623.03 N 731.41 E WMR- 3 Page 2 06/29/95 DATA INTERPOLATED FOR 100 FOOT SUBSEA INTERVAL SUBSEA DEPTH 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 MEAS INCLN DIRECTION TVD MD-TVD VERT RELATIVE COORDINATES DEPTH ANGLE AZIMUTH BKB DIFF CRRT FROM WELL HEAD 3297 51.24 47.9~ 2963 334 56 701.86 N ~21.78 E 3466 56.76 46.72 3063 403 69 793.96 N 922.61 E 3652 58.00 46.80 3163 489 86 901.15 N 1036.85 E 3843 58.70 45.91 3263 580 91 1013.38 N 1155.16 E 4036 59.06 46.82 3363 673 93 1127.41 N 1274.69 E 4228 58.20 47.17 3463 765 92 1238.99 N 1394.44 E 4416 57.30 47.67 3563 853 88 1347.31 N 1511.67 E 4599 56.22 48.27 3663 936 82 1449.75 N 1624.60 E 4776 55.19 48.20 3763 1013 77 1547.43 N 1733.74 E 4950 54.72 48.39 3863 1087 74 1642.37 N 1840.28 E 5123 54.54 48.20 3963 1160 73 1735.57 N 1946.17 E 5294 54.00 48.51 4063 1231 71 1827.57 N 2049.83 E 5464 53.98 47.54 4163 1301 70 1919.56 N 2151.64 E 5635 54.37 47.54 4263 1372 71 2012.94 N 2254.01 E 5808 55.04 47.24 4363 1445 73 2108.91 N 2358.24 E 5984 55.80 46.50 4463 1521 76 2207.34 N 2464.43 E 6164 56.75 48.31 4563 1601 79 2307.24 N 2574.93 E 6347 57.00 48.99 4663 1684 84 2409.84 N 2689.97 E 6530 56.61 49.37 4763 1767 83 2509.72 N 2805.79 E -.6709 55.39 48.99 4863 1846 79 2606.32 N 2918.24 E 6883 54.35 48.74 4963 1920 74 2700.34 N 3025.43 E 7052 53.33 49.17 5063 1989 69 2789.83 N 3128.24 E 7219 54.03 51.01 5163 2056 67 2875.75 N 3230.67 E 7396 55.83 52.01 5263 2133 77 2966.16 N 3344.61 E 7572 54.77 52.17 5363 2209 76 3054.93 N 3459.23 E 7742 54.12 52.73 5463 2279 70 3139.48 N 3568.36 E 7918 55.80 52.50 5563 2355 76 3228.21 N 3682.35 E 8096 56.09 52.28 5663 2433 79 3318.98 N 3799.36 E WMR- 3 SUBSEA DEPTH DATA INTERPOLATED FOR 100 MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 5600 8278 56.53 51.48 5700 8460 56.74 51.49 5800 8642 57.07 51.57 5900 8826 57.04 51.80 6000 9013 58.21 52.41 6100 9204 58.62 52.25 6200 9396 58.30 52.92 6300 9586 58.22 52.87 6400 9774 57.36 53.52 6500 9959 56.89 52.47 6600 10141 56.86 52.02 6700 10324 57.04 52.08 6800 10508 57.00 50.71 6900 10690 56.47 50.32 7000 10871 56.49 50.85 7100 11050 55.48 50.42 7200 11227 56.20 50.15 7300 11410 57.30 49.60 7400 11594 56.69 49.78 7500 11776 56.99 50.05 7600 11960 56.53 50.11 7700 12139 55.65 49.58 7800 12316 55.80 49.63 7900 12493 55.47 49.65 8000 12670 55.71 49.53 8100 12849 56.61 49.20 8200 13031 56.90 49.60 8300 13213 56.19 50.11 Page 3 06/29/95 FOOT SUBSEA INTERVAL TVD MD-TVD VERT RELATIVE COORDINATES BKB DIFF CRRT FROM WELL HEAD 5763 2515 81 3412.58 N 3917.82 E 5863 2597 82 3507.20 N 4037.34 E 5963 2679 82 3602.54 N 4156.56 E 6063 2763 84 3697.99 N 4277.64 E 6163 2850 87 3794.78 N 4401.88 E 6263 2941 91 3894.33 N 4530.57 E 6363 3033 92 3994.03 N 4660.71 E 6463 3123 90 4091.16 N 4789.89 E 6563 3211 88 4186.80 N 4917.00 E 6663 3296 85 4280.94 N 5040.81 E 6763 3378 82 4374.85 N 5161.13 E 6863 3461 83 4469.12 N 5282.00 E 6963 3545 84 4564.78 N 5402.91 E 7063 3627 82 4661.85 N 5519.71 E 7163 3708 82 4757.59 N 5637.20 E 7263 3787 78 4851.87 N 5751.05 E 7363 3864 77 4945.21 N 5863.88 E 7463 3947 83 5044.16 N 5980.26 E 7563 4031 85 5143.61 N 6099.23 E 7663 4113 82 5241.73 N 6215.32 E 7763 4197 84 5341.09 N 6333.97 E 7863 4276 78 5436.39 N 6446.70 E 7963 4353 77 5530.99 N 6558.01 E 8063 4430 77 5625.67 N 6669.60 E 8163 4507 77 5720.65 N 6780.93 E 8263 4586 79 5816.95 N 6893.74 E 8363 4668 82 5916.32 N 7009.29 E 8463 4750 82 6014.29 N 7125.05 E {Anadril (c)95 WMR3D2 B1.52 5:16 PM 2~ WMR-3 SUBSEA DEPTH 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 Page 4 06/29/95 DATA INTERPOLATED FOR 100 FOOT SUBSEA INTERVAL MEAS INCLN DIRECTION TVD MD-TVD VERT RELATIVE COORDINATES DEPTH ANGLE AZIMUTH BKB DIFF CRRT FROM WELL HEAD 13392 56.07 4'9.80 8563 4829 79 6109.90 N' 7238.74 E 13573 56.33 50.10 8663 4910 80 6206.35 N 7353.96 E 13752 55.96 50.58 8763 4989 80 6301.75 N 7468.73 E 13929 55.50 50.55 8863 5066 77 6394.13 N 7581.15 E 14108 56.01 50.75 8963 5145 79 6488.05 N 7695.71 E 14282 53.28 50.37 9063 5219 74 6579.09 N 7805.48 E 14442 49.74 51.60 9163 5279 60 6657.50 N 7902.81 E 14591 46.33 49.55 9263 5328 50 6728.42 N 7988.42 E 14732 43.19 48.92 9363 5369 40 6793.05 N 8062.94 E 14868 42.11 50.48 9463 5405 36 6852.59 N 8132.83 E 15001 41.15 50.80 9563 5438 34 6908.84 N 8201.73 E 15133 39.77 51.37 9663 5470 32 6962.80 N 8268.19 E 15261 37.88 52.21 9763 5498 28 7012.55 N 8331.50 E (Anadril (c)95 WMR3D2 BI .52 5:16 PM 2) WMR #3 Completion 16" 75~, K-55 BT&C ~ 10-3/4" 45.5~, K-55, BTC ~ 7-5/8" 29.04~, L-80, STL ,~ 2-718" 6.5#, L-80, 8rd AB tubing w/3-3/8" spent perf guns attached 5-112" 17#, L-80, FL-4S ~ X @ 2361' MD, 2278' TVD with cement to surface Top of 7-5/8" liner @ 6817' MD 7343' MD, 5234' TVD Top of 5-1t2' Liner @ 13,878' MD 14,161' MD, 8993' TVD "BWD" packer @ 14,738' MD Perforations 14,805'-14,836' MD 9417'-9439' TVD 14,852'-15,060' MD 9451'-9607' TVD Retainer @ 15,070' MD Squeeze Perfs @ 15,074'-15,076' Tag Cmt inside liner @ 15,185' MD 15,338' MD, 9824' TVD WMRU #3 Completion Detail JCasing: 10-3/4" 45.5, K-55 with 1000 psi limit on burst pressure to 6817' MD i 7-5/8" 29~, L-80 STL liner from 6817' to 13,878' MD i 5-1/2" 17#, L-80, FL4S with PBTD 15,244'. {Tubing: 2-7/8" L-80, 6.5#, 8rd AB modified i , ID i OD Item Length I Depth I 2.441" 3.500" appx 14,690' 1 i2-7/8" L-80, 6.5~, 8rd AB modified, 456 jts, 3 pups 2 TRICO jet pump cavity, 2-7~8" 8rd pinxpin x/o sleeve ! 2.250" ~ 4.53" ! 5.438 I 14693.99 l w/isolation sleeve ~ 1.190" 3 '1 joint 2-7~8" tubing i I 4.53" , 5.438 ! ' ', 30 14699.43 4 i Halliburton Seal Ass.: Locater sub 2-7/8" 8rd AB mod box, 2.240" ~ 9 14729.43 !Seal, spacer, 2 Seals, Spacer, (2) , iSeals and Guide I 5 !Halliburton 5-1/2" 13-20~ Hydraulic Set "BVVD" 2.990 4.53 i 3.45 14738.43 permanent packer 6 I Seal Bore Extension I 2.99 3.478 7.47 14741.88 7 X-over, 3-7/16"-10 UNS Box x 2-7/8" 8rd pinI 2.435 4.35 0.74 14749.35 2.441 3.500" 6.09 14750.09 8 2-7/8" 8rd Pup joint tubing 9 2-7/8 .... R"nipple I 2.188 3.68 I 1.36 14756.18 1012-7/8" 8rd joint tubingI 2.441 3.500"I 32.3 14757.54 I 11 i Balanced isolation tool 12iTime Delayed Fidng Head I 1.995 3.375" ' 1.81 I 14791.57 131Vann Gun adapter I 3.375" 0.71I 14793.38 14 Blank Gun (top shot @ 14,805') i 3.375 10.91 14794.09 15~3-3/8 x 6 spf Vann Gunns 3.375" 31 14805 17 3-3/8" x 6 spf Vann Gunns 18!Blank Gun I 3.375 i 0.85 I 15060 19 Vann Gun adapter I 3.375"i 0.71 15060.85 20 Time Delayed Fidng HeadI 1.995" ! 3.375" ~ 1.81 15061.56 21 ,Ported Bull Plug I 3.375" ! 0.5 15063.37 Top of Retainer i i i 15070 .7/13/95 Page I _J Z Stewart Petroleum Company - WMR #3 4000 3500 ................................. '3000 ; .......... 2500 Ext[apD]atcd k', Nlk] POll'- 2000 1500 1000 - 500 . 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Depth (Sub Surface) 'Depth ...... 6647: 9000 9!00 9400 .................. Pressure 2594. 3499 3545 3680 ~ ~ . I ....... i~radien, t __ , ._..385.453 D;~.te ot Survey: 7/2/95 Gauge #: 26659 12hr single pitch clock Prep by: J. Mills NMR- 3 Page 1 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 06/29/95 MEAS INCLN DEPTH ANGLE 0 0.00 1000 4.35 2000 24.76 3000 45.41 4000 58.98 5000 54.70 6000 55.83 7000 53.57 8000 55.97 9000 58.13 DIRECTION VERT-DEPTHS SECT AZIMUTH BKB SUB-S DIST 0.00 0 -163 0 49.87 999 836 26 49.15 1962 1799 274 50.96 2767 2604 858 46.65 3344 3181 1670 48.68 3892 3729 2506 46.83 4472 4309 3319 49.00 5032 4869 4147 52.06 5609 5446 4963 52.37 6156 5993 5800 10000 56.77 52.26 11000 55.58 50.05 12000 55.94 50.02 13000 56.83 49.47 14000 55.98 50.63 15000 41.16 50.80 6686 6523 6647 7235 7072 7483 7785 7622 8318 8346 8183 9146 8903 8740 9976 9562 9399 10723 REL-COORDINATES CLOSURE FROM-WElLHEAD DIST AZIMUTH 0 N 0 E 0 0.00 18 N 19 E 26 46.24 178 N 209 E 274 49.65 557 N 653 E 859 49.52 1106 N 1252 E 1671 48.54 1669 N 1871 E 2507 48.26 2216 N 2474 E 3322 48.14 2762 N 3097 E 4150 48.27 3270 N 3736 E 4965 48.81 3788 N 4393 E 5801 49.23 4302 N 5068 E 6648 49.67 4826 N 5720 E 7483 49.85 5362 N 6359 E 8318 49.86 5899 N 6989 E 9146 49.83 6432 N 7627 E 9976 49.86 6908 N 8201 E 10723 49.89 DL/ 100 0.0 1.3 2.6 2.5 0.6 0.5 1.7 0.2 0.5 0.7 0.7 0.6 1.5 0.4 0.3 0.8 (Anadril (c)95 WMR3D2 B1.52 5:16 PM 2) ~adrill Schlumberger 06/29/95 ]lient .... : STEWART PETROLEUM COMPANY ~ield ..... : WEST MCARTHUR RIVER UNIT fell ...... : WMR-3 ~ection at: 50.35 ~ngineer..: GARY PAUL Jnits ..... : FEET Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic Dcln.: MINIMUM CURVATURE 06/29/95 163.00 ft JOB#35901 22. 660 E RECORD OF SURVEY Pg: 1 MEAS INCLN DIRECTION VERTICAL-DEPTHS SECTION DEPTH ANGLE AZ IMUTH BKB SUB - SEA DI STNCE RELATIVE-COORDINATES FROM-WELL-HEAD 0 0.00 0.00 0.0 -163.0 0.0 0.0 N 0.0 E 285 0.50 56.00 285.0 122.0 1.2 0.7 N 1.0 E 537 1.50 32.00 537.0 374.0 5.5 4.1 N 3.7 E 693 1.90 49.60 692.9 529.9 10.0 7.5 N 6.7 E 724 1.90 45.40 723.9 560.9 11.0 8.2 N 7.5 E CLOSURE DISTNCE AZIMUTH DL /loo 0.0 0.00 0.00 1.2 56.00 0.18 5.5 41.94 0.42 10.1 41.90 0.42 11.1 42.41 0.45 755 2.10 45.90 754.9 591.9 12.1 9.0 N 8.3 E 787 2.50 40.40 786.8 623.8 13.4 9.9 N 9.1 E 838 2.80 55.70 837.8 674.8 15.7 11.5 N 10.9 E 863 3.10 47.70 862.7 699.7 17.0 12.3 N 11.9 E 895 3.40 50.70 894.7 731.7 18.8 13.4 N 13.3 E 12.2 42.70 0.65 13.5 42.72 1.43 15.8 43.57 1.50 17.1 44.16 2.03 18.9 44.65 1.08 925 3.60 51.80 924.6 761.6 20.6 14.6 N 14.7 E 957 3.70 50.40 956.6 793.6 22.7 15.9 N 16.3 E 988 4.20 - 49.50 987.5 824.5 24.8 17.2 N 17.9 E 1019 4.60 50.40 1018.4 855.4 27.2 18.8 N 19.7 E 1050 5.00 50.70 1049.3 886.3 29.8 20.4 N 21.7 E 20.7 45.24 0.70 22.7 45.76 0.42 24.9 46.12 1.63 27.2 46.45 1.31 29.8 46.81 1.29 1081 5.70 49.80 1080.2 917.2 32.7 22.3 N 24.0 E 1113 6.10 51.30 1112.0 949.0 35.9 24.4 N 26.5 E 1144 6.80 48.50 1142.8 979.8 39.4 26.6 N 29.2 E 1175 7.40 50.60 1173.6 1010.6 43.3 29.1 N 32.1 E 1207 7.90 49.80 1205.3 1042.3 47.5 31.8 N 35.4 E 32.7 47.11 2.27 36.0 47.43 1.34 39.5 47.64 2.47 43.3 47.81 2.11 47.6 48.02 1.60 'Station Types: 1/SINGLE SHOT 3/MWD ~**Grid and magnetic corrections have been applied to these surveys*** '~Anadril (c)95 WMR3D2 B1.52 5:16 PM 2) NMR-3 Page 2 06/29/95 RECORD OF SURVEY MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 1238 8.90 49.60 1269 9.70 51.00 1301 10.10 49.10 1332 10.90 51.30 1363 11.40 50.70 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 1235.9 1072.9 52.0 34.7 N 38.8 ~ 1266.5 1103.5 57.1 37.9 N 42.7 E 1298.1 1135.1 62.6 41.5 N 46.9 E 1328.5 1165.5 68.2 45.1 N 51.2 E 1358.9 1195.9 74.2 48.9 N 55.9 E 1394 12.20 49.60 1389.3 1226.3 80.5 52.9 N 60.7 E 1425 12.90 51.30 1419.6 1256.6 87.3 57.2 N 65.9 E 1457 13.50 49.00 1450.7 1287.7 94.6 61.9 N 71.6 E 1488 14.30 50.10 1480.8 1317.8 102.0 66.7 N 77.2 E 1518 15.20 50.10 1509.8 1346.8 109.7 71.6 N 83.1 E 3 1548 15.80 50.00 1538.7 1375.7 117.7 76.8 N 89.2 E 3 1579 16.60 49.80 1568.5 1405.5 126.3 82.3 N 95.8 E 3 1610 17.10 50.80 1598.2 1435.2 135.3 88.1 N 102.8 E 3 1641 17.80 50.70 1627.7 1464.7 144.6 94.0 N 110.0 E 3 1673 18.70 49.70 1658.1 1495.1 154.6 100.4 N 117.6 E 3 1705 19.00 50.30 1688.4 1525.4 165.0 107.0 N 125.6 E 3 1735 19.50 49.60 1716.7 1553.7 174.9 113.4 N 133.1 E 3 1767 20.00 49.80 1746.8 1583.8 185.7 120.4 N 141.4 E 3 1798 20.60 49.70 1775.9 1612.9 196.4 127.3 N 149.6 E 3 1829 21.20- 49.60 1804.9 1641.9 207.5 134.5 N 158.0 E 3 1860 21.80 50.50 1833.7 1670.7 218.8 141.8 N 166.7 E 3 1892 22.60 49.40 1863.3 1700.3 230.9 149.6 N 176.0 E 3 1923 23.00 50.30 1891.9 1728.9 243.0 157.3 N 185.2 E 3 1954 23.80 49.70 1920.4 1757.4 255.3 165.2 N 194.6 E 3 1986 24.40 49.20 1949.6 1786.6 268.3 173.7 N 204.5 E 3 2017 25.20 49.10 1977.7 1814.7 281.3 182.2 N 214.4 E 3 2048 25.90 48.50 2005.7 1842.7 294.7 191.0 N 224.4 E 3 2080 26.70 47.50 2034.4 1871.4 308.9 200.5 N 235.0 E ^Station Types: 3/MWD ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH DL /lOO 80.6 48.94 2.68 87.3 49.06 2.55 94.6 49.14 2.49 102.0 49.17 2.72 109.7 49.24 3.00 117.7 49.29 2.00 126.4 49.33 2.59 135.3 49.40 1.86 144.6 49.49 2.26 154.6 49.53 2.98 165.0 49.56 1.12 174.9 49.58 1.84 185.7 49.59 1.58 196.4 49.60 1.94 207.5 49.60 1.94 218.9 49.62 2.21 231.0 49.64 2.82 243.0 49.65 1.71 255.3 49.67 2.69 268.3 49.66 1.98 281.3 49.63 2.58 294.7 49.60 2.41 308.9 49.52 2.86 52.1 48.17 3.23 57.1 48.36 2.68 62.6 48.51 1.61 68.2 48.65 2.89 74.2 48.84 1.66 ;MR-3 Page 3 06/29/95 RECORD OF SURVEY MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 2111 27.50 48.20 2142 28.30 47.70 2174 29.10 47.70 2204 29.90 48.20 2242 31.00 48.40 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 2062.0 1899.0 323.0 210.0 N 245.4 E 2089.4 1926.4 337.5 219.7 N 256.2 E 2117.4 1954.4 352.8 230.1 N 267.6 E 2143.6 1980.6 367.6 239.9 N 278.5 E 2176.3 2013.3 386.8 252.8 N 292.9 E 2274 32.00 48.30 2203.6 2040.6 403.5 263.9 N 305.4 E 2306 32.20 48.20 2230.7 2067.7 420.5 275.2 N 318.1 E 2416 33.80 48.50 2323.0 2160.0 480.4 315.0 N 362.9 E 2447 34.90 48.70 2348.5 2185.5 497.9 326.6 N 376.0 E 2478 35.50 49.80 2373.9 2210.9 515.7 338.2 N 389.5 E 2509 36.70 48.70 2398.9 2235.9 534.0 350.2 N 403.4 E 2540 37.70 49.10 2423.6 2260.6 552.7 362.5 N 417.5 E 2571 38.70 49.40 2448.0 2285.0 571.9 375.0 N 432.0 E 2602 39.50 49.30 2472.0 2309.0 591.4 387.7 N 446.8 E 2633 40.00 49.30 2495.9 2332.9 611.3 400.7 N 461.9 E 2664 40.10 49.50 2519.6 2356.6 631.2 413.6 N 477.0 E 2696 40.40 49.10 2544.0 2381.0 651.9 427.1 N 492.7 E 2727 40.80 50.10 2567.6 2404.6 672.1 440.2 N 508.0 E 2757 41.20 50.40 2590.2 2427.2 691.7 452.8 N 523.2 E 2788 41.70- 50.60 2613.4 2450.4 712.3 465.8 N 539.0 E 2820 42.20 50.70 2637.2 2474.2 733.6 479.4 N 555.6 E 2850 43.00 51.00 2659.3 2496.3 754.0 492.2 N 571.3 E 2882 43.70 51.30 2682.6 2519.6 775.9 506.0 N 588.4 E 2912 44.10 51.60 2704.2 2541.2 796.7 519.0 N 604.7 E 2942 44.30 51.80 2725.7 2562.7 817.6 531.9 N 621.1 E 2973 44.80 51.40 2747.8 2584.8 839.4 545.4 N 638.1 E 3004 45.50 50.90 2769.7 2606.7 861.3 559.2 N 655.2 E 3035 45.90 50.60 2791.3 2628.3 883.5 573.2 N 672.4 E 'Station Types: 3/MWD ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH 323.0 49.45 337.5 49.38 352.9 49.31 367.6 49.26 386.9 49.21 403.6 49.17 420.6 49.14 480.5 49.04 498.0 49.02 515.9 49.03 534.1 49.04 552.9 49.03 572.0 49.04 591.6 49.05 611.4 49.06 631.4 49.07 652.0 49.08 672.2 49.09 691.9 49.13 712.4 49.17 733.8 49.21 754.1 49.25 776.0 49.31 796.8 49.36 817.7 49.42 839.5 49.48 861.4 49.52 883.6 49.55 DL /100 2.78 2.69 2.50 2.79 2.91 3.13 0.65 1.46 3.57 2.82 4.40 3.32 3.28 2.59 1.61 0.53 1.24 2.46 1.49 1.67 1.58 2.75 2.28 1.50 0.81 1.85 2.53 1.46 ~MR-3 Page 4 06/29/95 RECORD OF SURVEY MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 3067 46.70 50.20 3097 47.20 49.40 3128 48.10 49.50 3158 49.10 49.20 3189 49.90 49.20 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 2813'.4 2650.4 906.7 588.0 N 696.3 E 2833.9 2670.9 928.6 602.1 N 707.0 E 2854.8 2691.8 951.5 617.0 N 724.4 E 2874.6 2711.6 974.0 631.7 N 741.5 E 2894.8 2731.8 997.6 647.1 N 759.3 E 3220 50.30 49.10 2914.6 2751.6 1021.3 662.7 N 777.3 E 3251 50.80 48.80 2934.3 2771.3 1045.3 678.4 N 795.4 E 3282 51.00 48.20 2953.9 2790.9 1069.3 694.3 N 813.4 E 3312 51.50 47.70 2972.7 2809.7 1092.7 710.0 N 830.8 E 3343 52.40 48.00 2991.8 2828.8 1117.1 726.4 N 848.9 E 3381 53.70 47.90 3014.6 2851.6 1147.4 746.7 N 871.4 E 3467 56.80 46.70 3063.6 2900.6 1218.0 794.6 N 923.3 E 3559 57.50 46.90 3113.5 2950.5 1295.1 847.5 N 979.7 E 3651 58.00 46.80 3162.6 2999.6 1372.8 900.8 N 1036.4 E 3744 58.60 46.70 3211.5 3048.5 1451.7 955.0 N 1094.1 E 3841 58.70 45.90 3262.0 3099.0 1534.4 1012.2 N 1153.9 E 3935 58.70 46.30 3310.8 3147.8 1614.5 1067.9 N 1211.8 E 4028 59.10 46.80 3358.8 3195.8 1693.9 1122.7 N 1269.6 E 4122 58.60 47.00 3407.5 3244.5 1774.2 1177.6 N 1328.4 E 4214 58.20. 47.20 3455.7 3292.7 1852.5 1231.0 N 1385.8 E 4307 58.20 47.00 3504.7 3341.7 1931.4 1284.8 N 1443.7 E 4401 57.40 47.70 3554.8 3391.8 2010.8 1338.7 N 1502.2 E 4493 56.80 47.50 3604.7 3441.7 2087.9 1390.7 N 1559.2 E 4587 56.30 48.30 3656.6 3493.6 2166.3 1443.3 N 1617.4 E 4679 55.70 48.10 3708.0 3545.0 2242.5 1494.2 N 1674.3 E 4772 55.20 48.20 3760.7 3597.7 2319.1 1545.3 N 1731.3 E 4864 55.00 48.30 3813.4 3650.4 2394.5 1595.5 N 1787.6 E 4957 54.70 48.40 3866.9 3703.9 2470.5 1646.0 N 1844.4 E ^Station Types: 3/MWD ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH DL /lOO 906.7 49.57 2.66 928.7 49.58 2.56 951.6 49.58 2.91 974.1 49.57 3.42 997.7 49.56 2.58 1021.4 49.55 1.31 1045.4 49.54 1.78 1069.4 49.52 1.63 1092.8 49.48 2.11 1117.2 49.45 3.00 1147.6 49.41 3.43 1218.2 49.28 3.78 1295.4 49.14 0.78 1373.1 49.01 0.55 1452.2 48.88 0.65 1535.0 48.74 0.71 1615.2 48.61 0.36 1694 . 8 48 . 52 0 · 63 1775.2 48.44 0.56 1853.5 48.39 0.47 1932.6 48.33 0.18 2012.1 48.29 1.06 2089.3 48.27 0.68 2167.8 48.26 0.89 2244.0 48.25 0.68 2320.6 48.25 2396.1 48.25 2472.1 48.25 0.54 0.23 0.33 WMR-3 Page 5 06/29/95 RECORD OF SURVEY S MEAS INCLN DIRECTION C DEPTH ANGLE AZIMUTH · 3 5050 54 70 49.00 3 5141 54.50 48.00 3 5234 54.00 48.70 3 5327 54.00 48.40 3 5421 53.80 47.40 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 3920.7 3757.7 25~6.3 1696.1 N 1901.5 E 3973.4 3810.4 2620.5 1745.3 N 1957.0 E 4027.7 3864.7 2695.9 1795.5 N 2013.4 E 4082.4 3919.4 2771.1 1845.3 N 2069.8 E 4137.8 3974.8 2847.0 1896.2 N 2126.1 E 3 5514 54.20 47.70 4192.4 4029.4 2922.1 1947.0 N 2181.7 E 3 5608 54.20 47.60 4247.4 4084.4 2998.3 1998.3 N 2238.0 E 3 5702 54.80 47.40 4302.0 4139.0 3074.7 2050.0 N 2294.4 E 3 5797 55.00 47.20 4356.6 4193.6 3152.3 2102.7 N 2351.6 E 3 5891 55.30 47.50 4410.3 4247.3 3229.4 2155.0 N 2408.3 E 3 5984 55.80 46.50 4463.0 4300.0 3305.9 2207.3 N 2464.4 E 3 6077 56.00 48.40 4515.1 4352.1 3382.8 2259.4 N 2521.1 E 3 6169 56.80 48.30 4566.0 4403.0 3459.4 2310.3 N 2578.4 E 3 6286 57.20 48.00 4629.7 4466.7 3557.5 2375.8 N 2651.5 E 3 6379 56.90 49.50 4680.3 4517.3 3635.5 2427.2 N 2710.1 E 3 6472 56.80 49.00 4731.2 4568.2 3713.3 2478.0 N 2769.1 E 3 6565 56.50 49.60 4782.3 4619.3 3791.0 2528.7 N 2828.0 E 3 6660 55.60 49.20 4835.4 4672.4 3869.8 2580.0 N 2887.8 E 3 6754 55.20 48.80 4888.7 4725.7 3947.1 2630.7 N 2946.2 E 3 6849 54.70: 48.60 4943.3 4780.3 4024.9 2682.1 N 3004.7 E 3 6945 53.70 49.00 4999.4 4836.4 4102.7 2733.4 N 3063.2 E 3 7032 53.50 49.00 5051.1 4888.1 4172.7 2779.3 N 3116.1 E 3 7125 52.70 49.80 5106.9 4943.9 4247.1 2827.7 N 3172.6 E 3 7218 54.00 51.00 5162.4 4999.4 4321.7 2875.3 N 3230.0 E 3 7265 55.40 51.40 5189.6 5026.6 4360.0 2899.3 N 3259.9 E 3 7356 56.00 51.80 5240.9 5077.9 4435.2 2946.0 N 3318.9 E 3 7450 55.60 52.30 5293.7 5130.7 4512.9 2993.8 N 3380.2 E 3 7546 55.10 52.30 5348.3 5185.3 4591.8 3042.1 N 3442.6 E ^Station Types: 3/MWD ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH 2548.0 48.27 2622.2 48.27 2697.7 48.27 2772.9 48.28 2848.9 48.27 2924.1 48.25 3000.3 48.24 3076.8 48.22 3154.6 48.20 3231.7 48.18 3308.4 48.15 3385.4 48.13 3462.0 48.14 3560.1 48.14 3638.1 48.15 3716.0 48.18 3793.7 48.20 3872.5 48.22 3949.8 48.24 4027.6 48.25 4105.4 48.26 4175.5 48.27 4249.8 48.29 4324.4 48.33 4362.7 48.35 DL /lOO 0.53 0.92 0.81 0.26 0.89 0.50 0.09 0.66 0.27 0.41 1.04 1.71 0.87 0.40 1.39 0.46 0.63 1.01 0.55 0.55 1.10 0.23 1.10 1.74 3.06 4437.7 48.41 0.75 4515.3 48.47 0.61 4594.1 48.53 0.52 ~MR-3 Page 6 06/29/95 RECORD OF SURVEY MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 7640 53.90 51.80 7730 53.90 52.90 7824 55.60 51.60 7918 55.80 52.50 8012 56.00 52.00 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DISTNCE ~402.9 5239.9 4668.3 3089.1 N '3503.0 E 4670.5 5455.9 5292.9 4741.0 3133.6 N 3560.6 E 4743.1 5510.1 5347.1 4817.7 3180.6 N 3621.3 E 4819.7 5563.1 5400.1 4895.3 3228.3 N 3682.5 E 4897.2 5615.8 5452.8 4973.1 3276.0 N 3744.0 E 4974.9 8103 56.10 52.30 5666.6 5503.6 5048.6 3322.3 N 8198 56.70 51.40 5719.2 5556.2 5127.7 3371.2 N 8292 56.50 51.50 5771.0 5608.0 5206.1 3420.1 N 8386 56.90 51.80 5822.6 5659.6 5284.7 3468.8 N 8480 56.70 51.40 5874.0 5711.0 5363.3 3517.7 N 3803.6 E 3865.9 E 3927.2 E 3988.8 E 4050.5 E 8573 56.70 51.20 5925.1 5762.1 5441.0 3566.3 N 8667 57.20 51.70 5976.4 5813.4 5519.8 3615.4 N 8759 56.90 51.80 6026.4 5863.4 5597.0 3663.2 N 8854 57.10 51.80 6078.1 5915.1 5676.6 3712.4 N 8948 57.80 52.20 6128.7 5965.7 5755.8 3761.2 N 4111.2 E 4172.8 E 4233.4 E 4296.0 E 4358.4 E 9042 58.40 52.50 6178.4 6015.4 5835.6 3810.0 N 9134 58.40 52.10 6226.6 6063.6 5913.9 3857.9 N 9230 58.70 52.30 6276.7 6113.7 5995.8 3908.1 N 9321 58.70 52.60 6324.0 6161.0 6073.5 3955.5 N 9415 58.20. 53.00 6373.1 6210.1 6153.5 4003.9 N 4421.6 E 4483.6 E 4548.3 E 4610.0 E 4673.8 E 9508 58.30 53.20 6422.1 6259.1 6232.5 4051.4 N 9602 58.20 52.80 6471.5 6308.5 6312.3 4099.5 N 9696 57.80 53.00 6521.4 6358.4 6392.0 4147.6 N 9785 57.30 53.60 6569.1 6406.1 6467.0 4192.5 N 9881 57.40 52.30 6620.9 6457.9 6547.7 4241.2 N 4737.0 E 4800.9 E 4864.5 E 4924.7 E 4989.2 E 9972 56.80 52.50 6670.3 6507.3 6624.1 4287.8 N 10066 56.70 51.70 6721.9 6558.9 6702.6 4336.1 N 10160 56.90 52.10 6773.3 6610.3 6781.3 4384.6 N 5049.7 E 5111.7 E 5173.6 E ^Station Types: 3/MWD ***Grid and magnetic corrections have been applied to these surveys*** AZIMUTH 48.59 48.65 48.71 48.76 48.81 5050.3 5129.3 5207.7 5286.2 5364.7 48 48 48 48 49 .86 .91 .95 .99 .03 5442.4 5521.1 5598.3 5677.8 5757.0 49 49 49 49 49 .06 .09 .13 .17 .21 5836.7 5914.9 5996.7 6074.4 6154.3 49 49 49 49 49 .25 .29 .33 .37 .41 6233.2 6313.0 6392.6 6467.5 6548.2 49 49 49 49 49 .46 .51 .55 .59 .63 6624.5 6703.1 6781.7 49 49 49 .66 .69 .72 DL /loo 1.35 0.99 2.13 0.82 0.49 0.29 1.01 0.23 0.50 0.41 0.18 0.69 0.34 0.21 0.83 0.69 0.37 0.36 0.28 0.64 0.21 0.38 0.46 0.80 1.14 0.68 0.72 0.41 ~MR-3 Page 7 06/29/95 RECORD OF SURVEY MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 10252 56.80 52.00 10342 57.10 52.10 10437 57.00 51.70 10530 57.00 50.40 10621 56.40 50.10 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 6823.7 6660.7 6858.3 4432.0 N 5234.4 E 6872.7 6709.7 6933.7 4478.4 N 5293.9 E 6924.4 6761.4 7013.4 4527.6 N 5356.6 E 6975.1 6812.1 7091.3 4576.6 N 5417.3 E 7025.0 6862.0 7167.4 4625.2 N 5475.7 E 10714 56.50 50.40 7076.4 6913.4 7244.9 4674.8 N 5535.3 E 10807 56.70 51.20 7127.6 6964.6 7322.5 4723.8 N 5595.5 E 10899 56.40 50.70 7178.3 7015.3 7399.3 4772.2 N 5655.1 E 10993 55.60 50.00 7230.9 7067.9 7477.2 4821.9 N 5715.1 E 11087 55.40 50.70 7284.1 7121.1 7554.7 4871.4 N 5774.8 E 11181 55.80 50.20 7337.2 7174.2 7632.3 4920.7 N 5834.6 E 11272 56.60 50.10 7387.9 7224.9 7707.9 4969.2 N 5892.6 E 11363 57.00 49.00 7437.7 7274.7 7784.0 5018.6 N 5950.6 E 11456 57.60 50.20 7487.9 7324.9 7862.3 5069.3 N 6010.1 E 11546 56.90 50.30 7536.6 7373.6 7938.0 5117.7 N 6068.3 E 11639 56.50 49.30 7587.7 7424.7 8015.7 5167.9 N 6127.7 E 11731 56.70 50.20 7638.3 7475.3 8092.5 5217.5 N 6186.3 E 11823 57.30 49.90 7688.4 7525.4 8169.6 5267.1 N 6245.5 E 11916 57.20 50.20 7738.7 7575.7 8247.9 5317.3 N 6305.4 E 12009 55.80- 50.00 7790.1 7627.1 8325.4 5367.0 N 6364.9 E 12103 55.80 49.50 7842.9 7679.9 8403.1 5417.3 N 6424.3 E 12196 55.40 49.70 7895.5 7732.5 8479.9 5467.0 N 6482.7 E 12288 55.80 49.60 7947.4 7784.4 8555.8 5516.1 N 6540.6 E 12381 55.80 49.70 7999.7 7836.7 8632.7 5565.9 N 6599.2 E 12472 55.40 49.70 8051.1 7888.1 8707.8 5614.5 N 6656.4 E 12564 55.70 49.50 8103.2 7940.2 8783.6 5663.7 N 6714.2 E 12657 55.70 49.50 8155.6 7992.6 8860.4 5713.6 N 6772.6 E 12751 55.80 49.70 8208.5 8045.5 8938.1 5763.9 N 6831.8 E ~Station Types: 3/MWD ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH 6858.~ 49.75 6934.0 49.77 7013.7 49.79 7091.7 49.81 7167.7 49.81 7245.2 49.82 7322.9 49.83 7399.6 49.84 7477.5 49.85 7555.0 49.85 7632.5 49.86 7708.2 49.86 7784.3 49.86 7862.6 49.85 7938.3 49.86 8016.0 49.86 8092.8 49.86 8169.9 49.86 8248.2 49.86 8325.7 49.86 8403.5 49.86 8480.2 49.86 8556.1 49.86 8633.0 49.85 8708.1 49.85 8784.0 49.85 8860.8 49.85 8938.5 49.85 /lOO 0.14 0.35 0.37 1.17 0.71 0.29 0.75 0.56 1.05 0.65 0.61 0.88 1.10 1.26 0.78 1.00 0.85 0.71 0.29 1.52 0.44 0.47 0.44 0.09 0.44 0.37 0.00 0.21 ~MR-3 Page 8 06/29/95 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 12844 56.60 12938 56.70 13030 56.90 13136 56.60 13230 56.10 DIRECTION AZIMUTH VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 49.20 8260.2 8097.2 9015.4 5814.2 ~ 6890.5 E 49.20 8311.9 8148.9 9093.9 5865.5 N 6950.0 E 49.60 8362.3 8199.3 9170.9 5915.6 N 7008.4 E 49.70 8420.4 8257.4 9259.5 5973.0 N 7076.0 E 50.20 8472.5 8309.5 9337.8 6023.3 N 7135.9 E 13323 56.00 49.80 8524.4 8361.4 9414.9 6072.9 N 7195.0 E 13416 56.10 49.80 8576.3 8413.3 9492.1 6122.7 N 7253.9 E 13510 56.60 50.30 8628.4 8465.4 9570.3 6173.0 N 7313.9 E 13604 56.20 50.00 8680.4 8517.4 9648.6 6223.1 N 7374.0 E 13697 56.20 50.40 8732.2 8569.2 9725.9 6272.6 N 7433.4 E 13790 55.80 50.70 8784.2 8621.2 9803.0 6321.6 N 7492.9 E 13882 55.10 50.50 8836.4 8673.4 9878.8 6369.7 N 7551.5 E 13975 55.90 50.60 8889.0 8726.0 9955.4 6418.4 N 7610.6 E 14068 56.20 50.70 8941.0 8778.0 10032.5 6467.3 N 7670.3 E 14099 56.10 50.80 8958.2 8795.2 10058.3 6483.6 N 7690.2 E 14238 54.60 50.00 9037.3 8874.3 10172.6 6556.5 N 7778.3 E 14331 51.80 50.80 9093.0 8930.0 10247.1 6603.9 N 7835.7 E 14426 50.10 51.90 9152.8 8989.8 10320.8 6650.0 N 7893.3 E 14518 48.00 50.10 9213.1 9050.1 10390.3 6693.7 N 7947.3 E 14610 45.90. 49.40 9275.9 9112.9 10457.5 6737.1 N 7998.6 E 14703 43.50 48.70 9342.0 9179.0 10522.9 6780.0 N 8048.0 E 14795 42.50 49.40 9409.3 9246.3 10585.7 6821.1 N 8095.4 E 14805 42.45 49.55 9416.7 9253.7 10592.4 6825.5 N 8100.6 E 14889 42.00 50.80 9478.9 9315.9 10648.9 6861.7 N 8143.9 E 14982 41.30 50.80 9548.4 9385.4 10710.7 6900.7 N 8191.8 E 15060 40.71 50.80 9607.2 9444.2 10761.8 6933.1 N 8231.5 E 15074 40.60 50.80 9617.9 9454.9 10771.0 6938.9 N 8238.5 E 15167 39.30 51.70 9689.2 9526.2 10830.7 6976.2 N 8285.1 E ^Station Types: 3/MWD N/INTERPOLATED ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH 9015.8 49.84 9094.3 49.84 9171.3 49.83 9259.9 49.83 9338.2 49.83 9415.3 49.83 9492.5 49.83 9570.7 49.84 9649.0 49.84 9726.3 49.84 9803.4 49.85 9879.1 49.85 9955.8 49.86 10032.9 49.86 10058.7 49.87 10173.0 49.87 10247.4 49.88 10321.2 49.89 10390.7 49.89 10457.9 49.89 10523.3 49.89 10586.0 49.88 10592.8 49.88 10649.2 49.88 10711.0 49.89 10762.2 49.89 10771.3 49.89 10831.0 49.90 /lOO 0.99 0.11 0.42 0.29 0.69 0.37 0.11 0.69 0.50 0.36 0.51 0.78 0.86 0.33 0.42 1.18 3.09 2.00 2.72 2.35 2.63 1.20 1.13 1.13 O.75 0.76 0.76 1.53 WMR-3 RECORD OF SURVEY Page 9 06/29/95 S MEAS INCLN DIRECTION C DEPTH ANGLE AZIMUTH 3 152'60 37.90 52.20 3 15289 37.60 52.30 J 15338 37.10 52.40 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 9761.8 9598.8 10888.7 9784.8 9621.8 10906.4 9823.7 9660.7 10936.1 RELATIVE-COORDINATES FROM-WELL-HEAD __ 7012.0 N 8330.8 E 7022.9 N 8344.8 E 7041.0 N 8368.4 E ^Station Types: 3/MWD J/PROJECTED ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH 108'89.0 49.91 10906.7 49.92 10936.4 49.92 DL /lOO 1.54 1.06 1.03 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh.~n~-~,/~ Chairma'r~..~'~ DATE: June 14, 1995 THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Gnmald~,)~ SUBJECT: Petroleum Inspector FILE NO: A6TJFNCD.DOC BOP test Nabors rig #160 Stewart Petr. #3 W McArthur river Field PTD #94-113 Wednesday, June 14, 1995: I witnessed the weekly BOP test on Nabors rig #160 which is presently drilling Stewart petroleums well #3 in the West McArthur river field. The test went very well with all components functioning and holding their pressure test properly. The rigs new gas detection system was in place but non- operational due to incompability between components. Paul Smith (Nabors Toolpusher informed me that repair parts were ordered and would be installed in approximately 10 days. This well should be completed before then and as the rig is protected by the mud-loggers gas detection system I approved the continuance of operations after discussing the importance of the mud-loggers vigilance and reporting sequence with Paul. ! required that the rigs gas detection system be fully operational by the next rig move or 14 days whichever is first. This rig has had some good modifications since it was purchased by Nabors and ! observed good maintenence practiced during my visit. .SUMMARY: i witnessed the weekly BOP test on Nabors rig #160. Rig Gas detection system non operational. Test time 3 hours. One failure. Attachments: A6TJFNCD.XLS A Iai cl o lEI F IGI . I I iKILIMINIOIPIQIRIS 1 STATE OF ALASKA 2 OIL AND GAS CONSERVATION COMMISSION 3 BOPE Test Report 4 5 OPERATION: Drlg: X Workover: DATE: 6/14/95 6 Drlg Contractor: Nabors Rig No. 160 PTD # 94-113 Rig Ph.# 776-5580 7 Operator: Stewart Petroleum Rep.' Mike Murray 8 Well Name: #3 Rig Rep.: Paul Smith 9 Casing Size: 7 5/8 Set @ 14161 Location: Sec. 16 T. 8N R. 14W Meridian Seward 10 Test: Initial Weekly X Other 11 12 i !:~!i:.ii! : .......... i TE,ST D~..TAi,,,~i ........ ,i.i!~i~i? :~ ...... , ...... : i :~i~. ii'.:: 13 Test 14 MlSC, INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F 15 Location Gen.: OK Well Sign OK Upper Kelly/IBOP 1 250/5000 P 16 Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly/IBOP 1 250/5000 P 17 P.T.D, on location: N/A Hazard Sec. Ball Type 1 250/5000 P 18 Standing Orders: Inside BOP 1 I 250/5000 P 19 20 Test 21 BOP STACK: Quan. Pressure P/F Test 22 Annular Preventer 1 250/3500 P CHOKE MANIFOLD: Pressure P/F 23 Pipe Rams 1 ; 250/5000 P No. Valves 12 250/5000 P 24 Pipe Rams I i 250/5000 P No. Flanges 38 250/5000 P 25 Blind Rams 1 250/5000 P Manual Chokes 2 P 26 Choke Ln. Valves 1 250/5000 P Hydraulic Chokes 1 P 27 HCRValves 1 250/5000 ! P 28 Kill LineValves 2 250/5000 I P ACCUMULATOR SYSTEM: 29 Check Valve N/A N/A N/AI System Pressure 2,900 I P 30 Pressure After Closure 1,600J P 31 MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 31 sec. 32 Trip Tank P P System Pressure Attained 3 minutes 24 sec. 33 Pit Level Indicators P P Blind Switch Covers: Master: P Remote: P 34 Flow Indicator P P Nitgn. Btl's: Four Bottles 35 Gas Detectors F* 2400 average Psig. 36 H2S Detectors F* 37 38 i ~iii i : ~ :::TESTRESULTS ~ ,, , i,.i:iii,i, ;i 39 Number of Failures: 1 ,TestTime: 3.00 Hours. Number of valves tested 25 Repair or Replacement of Failed 40 Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to 41 the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 42 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 43 44 45 REMARKS: Rig is using Mud Loggers gas detection system due to problems with their new installation. Problems are to 46 be repaired by rig move or 14 days. Otherwise Good Test! 47 48 49 50 Distribution: STATE WITNESS REQUIRED? Waived By: 51 orig-Well File YES X NO 52 c- Oper./Rig Witnessed By: Louis R Grimaldi 53 c - Database 24 HOUR NOTICE GIVEN 54 c - Trip Rpt File YES X NO 55 c-Inspector FI-O21L (Rev. 2/93) A6TJFNCD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John.~~n, Chairmar¥,'~ DATE: May 5, 1995 THRU: FROM: Blair Wondzell,~ P. I. Supervisor Doug Amos, Petroleum Inspector FILE NO' a6theecd.doc SUBJECT: ' -BOPE Test Nabors 160 W. McAdhur Ry. #3 W. McArthur Rv. Field PTD No. 94-113 Thursday, May 4, 1995: I traveled to Stewart Petroleum's W. McArthur Rv. #3 well, to witness the BOPE test at Nabors Rig No. 160. As the attached AOGCC BOPE Test Report indicates, there were no failures. During the course of the test I conducted an inspection of the rig and location. I discovered that the rig had only one methane gas detector and no H2S detectors. The single methane detector, located at the shell shaker, was provided by the mud loggers, however there were no alarms or lights for the driller on the rig floor. ! did not write the rig up for this noncompliance because of the late hour of the test and not being able to contact Blair to discuss the problem. Friday, May 5, 1995: I discussed the lack of gas detectors on the rig with~Blair. Blair contacted Paul White Stewart Petroleum representative and discus~the problem. Paul is currently investigating the possibility of having the mud loggers add additional sensors and lights to the rig to bring them in to ce~liance. SUMMARY: I witnessed the successful BOPE test at St~oleum W. ~. Well No. 3. Test Time 3.5 hours . ~,~. ~-- 19 Valves Tested No Failures Attachments: A6THEECD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Alaska Drillin, g Rig No. Operator: Stewart Petroleum Well Name: W. McArthur Rv. No. 3 Casing Size: I0 3/4" Set @ 7,343 Test: Initial Weekly X Other 160 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 5/4/95 94-113 Rig Ph.# 776-5580 Mike Murray Paul Smith 16 T. 8 N R. 14W Meridian SM MISC. INSPECTIONS: Location Gen.: OK Housekeeping' OK (Gen) PTD On Location OK Standing Order Posted Yes Well Sign Yes Drl. Rig OK Hazard Sec. Yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP ,, Quan. 1 Test Pressure P/F 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F i 300/3,000 P 1 500/5,000 P 1 500/5,000 P 500/5,000 P P 500/5,000 500/5,000 P P 500/5,000 N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector See Remarks H2S Gas Detector N/A N/A CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 500/5,000 P 32 500/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 ~ 2300 3,000 P 1,700 P minutes 24 sec. minutes 48 sec. Yes Remote: Yes Psig. Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I REMARKS: Other than the mud loqgers methane gas detection sensor at the shakers there are no other methane gas detectors on the dg. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: Doug Amos F1-021L (Rev. 12/94) A6TH EECD.XLS ..! MEMORANDUM TO: David Joh .pe~ Chairman'" State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 7, 1995 THRU: Blair Wondzell, P. !. Supervisor FILE NO: A6TLDGCD.doc FROM: John Spaulding,~,~ SUBJECT: Petroleum Insp BOP Test Nabors-160 Stewart Petroleum Co. W. Mc Arthur River #3 Mc Arthur River Unit Friday April 7, 1995: ! traveled to Stewart Petroleum's West Mc Arthur River Unit well #3 to witness a BOPE test on Nabors rig 160. The AOGCC BOPE test report is attached for reference. The rig has been stacked for quite some time and this was an initial test. As noted on the B©PE test report 3 flange leaks were observed, these were repaired and testing was resumed. The rest of the test went very well. Shut - in standing orders were not posted on the rig or in the tool- pushers office. Paul Smith Nabors tool- pusher informed that he obtain a set of standing orders from Nabors office in Anch. and have them posted immediately. The rig is well laid out with good access for any emergency needs. The area is quite muddy and cramped for space as spring break-up is in full swing. Summary: I witnessed the BOPE test on Nabors rig 160 with 3 failures, 4 hour test time. Attachments: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 16" Test: Initial X Workover: Nabors Rig No. 160 PTD# Stewart Petroleum Co. Rep.: WMRv #3 Rig Rep.: Set @ 2361' Location: Sec. Weekly Other DATE: 4/7/95 94-113 Rig Ph.# 776-5580 Paul A. Smith Mike Murray 16 T. 8N R. 14W Meridian Seward Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location yes Standing Order Posted (Gen) no Well Sign yes Drl. Rig ok Hazard Sec. yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 250/3000 P 250/3000 P 250/3000 P 250/3000 P BOP STACK: Annular Preventer 1 Pipe Rams NA Lower Pipe Rams 1 Blind Rams Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves Check Valve Quan. Test Press. P/F P 150/1,500 250/3,000 P 1 250/3,000 P P 250/3,000 250/3,000 1 250/3,000 P NA MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector na na CHOKE MANIFOLD: No. Valves 12 No. Flanges Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 250/3000 P 32 250/3000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 4 ea. avg. 2350 2,975 P 1,600 P minutes 25 sec. minutes 55 sec. yes Remote: yes Psig. Number of Failures: 3 ,Test Time: 4.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: 3 Flange leaks - repaired and continued testing. No shut in standing orders were on the rig floor, Nabors will post the standing orders as soon as they are recieved from the Anch. office. Distribution: odg-Well File c- Oper./Rig c- Database c - Trip Rpt File c- InsP~l~[L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: 3GCD.XLT John H. Spaulding Stewart P ompany 2550 Denali ~., ~or~e, ~aska ~503 ;,907) 27~4004 ' F~ (S07) ~74-0424 March 30, 19l)5 Alaska Oil an~l Gas Conservation Commiasion 3001 Porcupil~e Drive Anchorage, ^laska 9950'! Facsimile: 276-7842 Attn: Mr. B~llrWondzell Re: Notice of Spud West I~icArthur River Unit #3 (Permit to Drill #94-113) AP! # 50-133-2046t Mr, Wondzell: This correspondence officially notifies you that the West McArthur River Unit Well No. 3 wes spudded at 19;30 hr$ on 3129195 aha ¢lrilling operations are proceeding. A cliverter was not required by the approved Permit to D~. An inspector from AOGCC will be notified 24 h{3urs prior to the testing of BOP equipment after surface casing is run which is estimated t,) be 4/7195, A copy of thi~ not~on is being sent to the Alaska Department of Natural Resources because of le ass-holding requirements. if there are ar ~y questions, please contact me at 277-4004. Paul O. White Operations Manager Stewart Petroleum Company RECEIVED (..,!AR 5 0 1.895 ^iaska Oil & Gas Cons. CommL%to)~ Anchorag~ Mr. Michael Kotowski, Alaska Dept. of Natural Resources Mr. W. FI, Stewart, Stewart PetFoteum Company Mr, Tim BiJlingsley, Stewart Petroleum Company fax 562-3852 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR ~.. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 2, 1994 Tim Billingsley Consulting Engineer Stewart Petroleum Company 2550 Denali St., Ste 1300 Anchorage, AK 99503 Re: West McArthur River Unit No. 3 Stewart Petroleum Company Permit No: 94-113 Sur. Loc. 2381'FNL, 1323'FWL, Sec. 16, T8N, R14W, SM Btmhole Loc. 600'FNL, 700'FEL, Sec. 10, T8N, R14W, SM Dear Mr. Billingsley: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all'other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Not~ntacting the Commission at 279-1433. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION (. IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill _-x Redrill --1 lb. Type of well. Exploratory ,~ Stratigraphic Test ~ Development Oil ~x Re-Entry -- DeepenFI Service -- Developement Gas ~ Single Zone - Multiple Zone..E] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Stewart Petroleum Company 163' KB feet West McArthur River 3. Address 2550 Denali St. Suite 1300 6. ProPerty Designation ~ Field and Pool Anchorage, Ak 99503 ADL 359~t (BHL) 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2381' FNL,' 1323' FWL, Sec. 16, T8N, R14W, SM West McArthur River Unit Blanket At top of productive interval 8. Well number Number 1278657 93t' FNL, 1100' FEL, Sec. 10, T8N, R14W, SM No. 3 Amwest Security Ins. At total depth 9. Approximate spud date Amount 600' FNL, 700' FEL', Sec. 10, T8N, R14W, SM Oct. 1, 1994 $200,000 12. Distance to nearest 13, Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 40' @ surf. Lease 4175 acres 15,347' 700' @ BHL feet 2332' @ TD feet Unit 6330 acres 9,663' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 800 feet Maximum hole angle 56 0 Maximum surface 32~4 psig At total depth CrVD) 4346 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) . Driven 20" 133 NT-8( BT&C 120 Surf 120.~ 120 ' Driven 18-1/2 16" 75 K-55 BT&C 2286 Surf 2286' 2216" 2160 cuft to surf. 13-1/2' 10-3/4 45.5 K-55 BT&C 7368 Surf 7368' 5200'. 420 cuft (11000.7 f/shoe 9-7/8' 7-5/8 29. q L-80 STL 6994 7168' 5088' 14162 9000' 250 cuft (1000' f/shoe b-3/4' b-±/2 £'/ L-80 STL 1385 13962' 8888' 15347 9663' 135 cuft ,_ 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface IntermediateRECEIVED Production Liner ~,U(~ ~ A, ]99~r Perforation depth: measured /~!~,$t{~. 0ii & Gas Cons. Commission true vertical Anchora~je 20. Attachments Filing fee E~ Property plat I~ BOP Sketch ~x Diverter Sketch ~ Drilling program Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report ,~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Consulting Engineer Signed ~ ~ Title Stewart Petroleum Company Commission Use Only Permit Number I API number [ Appry~;;~ate J See cover letter ~"-//~.~ 50--/,~_,~-, -2._<D z_./~ / . .. ~;~' for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required L-] Yes j~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE 1-12M; J~ 3M; J~ 5M; [] 10M; [] 15M Other: by order of Approved by Commissioner the commission Date ?'/-z_/'-) y Form 10-401 Rev. 12-1-85 Submit in triplicate Stewart Pec - ompany Denali ~o~ers North, Sui~,e 1300 2550 Denali StretSt, Anchorage, Alaska 99503 (907) 277-,4004 · FAX (907) 274-0424 August 24, 1994 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Ddll (Form 10-401) West McArthur River Unit #3 Gentlemen: Enclosed is the Application for Permit to Drill the McArthur River Unit #3 including two copies. A waiver is requested to drill the surface hole without a diverter. A waiver is also requested to eliminate the open hole wireline logging runs at the surface casing point and at the intermediate casing point. If there are any questions, please contact me at 277-4004. Tim Billingsle~ Consulting Engineer Stewart Petroleum Company Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for STEWART PETROLEUM COMPANY Well ......... : WMR-3 (P6) Field ........ : WEST MCARTHUR RIVER UNIT Computation..: MINIMUM CURVATURE Units ........ : FEET Surface Lat..: 60.78482702 N Surface Long.: 151.75022727 W Legal Description RECEIVED AUG 2 4 994 ~'laSka, .Oil .&. Gas Cons. Commission LOCATIONS - ALAS'~U%.~,~:8 4 X-Coord Y-Coord Surface ...... : 2899 FSL 3957 FEL S16 T08N R14W SM 187248.83 2482962.33 Target ....... : 4349 FSL 1100 FEL S10 T08N R14W SM 195551.25 2489476.31 BHL .......... : 4680 FSL 700 FEL Sl0 T08N R14W SM 195959.35 2489796.49 Prepared ..... : 08/24/94 Section at...: 50.35 KB elevation.: 163.00 ft Magnetic Dcln: 22.660 E Scale Factor.: 1.0000113r Convergence..: -1.52769959 PROPOSED WELL PROFILE STATION IDENTIFICATION 20" 133# CONDUCTOR KOP BUILD 1/100 BUILD 1.5/100 MEAS INCLN ' DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES DEPTH J~GLE AZIM~FI'H BKB SIJB-S DIST FROM-THE-WELLHEAD 0 0.00 0.00 0 -163 0 0.00 N 120 0.00 50.35 120 -43 0 0.00 N 500 0.00 50.35 500 337 0 0.00 N 800 0.00 50.35 800 637 0 0.00 N 900 1.00 50.35 900 737 1 0.56 N STATE-PLASTE TOOL DL/ X Y FACE 100 0.00 E 187248.83 2482962.33 0.00 E 187248.83 2482962.33 0.00 E 187248.83 2482962.33 0.00 0.00 0.00 0.00 E 187248.83 2482962.33 HS 0.0, 0.67 E 187249.52 2482962.87 HS 1.00 BUILD 2/100 BUILD 2.5/100 1000 2.50 50.35 1000 837 4 2.51 N 1100 4.00 50.35 1100 937 10 6.12 N 1200 6.00 50.35 1199 1036 18 11.68 N 1300 8.00 50.35 1299 1136 30 19.46 N 1400 10.50 50.35 1397 1234 47 29.71 N 3.02 E 187251.92 2482964.75 HS 1.50 7.39 E 187256.38 2482968.25 HS 1.50 14.10 E 187263.24 2482973.63 HS 2.00 23.48 E 187272.82 2482981.16 HS 2.00 35.86 E 187285.47 2482991.08 HS 2.50 1500 13.00 50.35 1495 1332 67 1600 15.50 50.35 1592 1429 92 1700 18.00 50.35 1688 1525 120 1800 20.50 50.35 1782 1619 153 1900 23.00 50.35 1875 1712 190 42.70 N 51.54 E 187301.49 2483003.65 HS 2.50 58.41 N 70.49 E 187320.85 2483018.84 HS 2.50 76.80 N 92.68 E 187343.53 2483036.63 HS 2.50 97.83 N 118.07 E 187369.46 2483056.98 RS 2.50 121.47 N 146.60 E 187398.61 2483079.85 HS 2.50 {Anadr]l (c)g4 WMR3P{ B1.52 ]0:]g AM 1) WMR-3 08/24/94 Page 2 PROPOSED WELL PROFILE 16" 75~ CASING STATION IDENTIFICATION DEPTH ANGLE '2000 25.50 2100 28.00 2200 30.50 2286 32.65 2300 33.00 MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES AZII~JTH BKB SUB-S DIST FROM-THE-WELLHE/LD STATE-PLANE TOOL DL/ X Y FACE 100 50.35 1966 1803 231 50.35 2056 1893 276 50.35 2143 1980 325 50.35 2216 2053 370 50.35 2228 2065 378 147.67 N 178.22 E 187430.93 2483105.20 HS 2.50 176.39 N 212.88 E 187466.33 2483132.98 HS 2.50 207.56 N 250.50 E 187504.77 2483163.14 HS 2.50 236.23 N 285.10 E 187540.13 2483190.88 HS 2.50 241.13 N 291.01 E 187546.17 2483195.62 HS 2.50 2400 35.50 2500 38.00 2600 40.50 2700 43.00 2800 45.50 50.35 2311 2148 434 50.35 2391 2228 494 50.35 2468 2305 557 50.35 2543 2380 624 50.35 2614 2451 694 277 04 N 334.35 E 187590.45 2483230.36 HS 2.5C 315.21 N 380.41 E 187637.52. 2483267.29 HS 2.50 355.58 N 429.13 E 187687.29 2483306.34 HS 2.50 398.06 N 480.40 E 187739.68 2483347.44 HS 2.50 442.58 N 534.12 E 187794.57 2483390.51 HS 2.50 2900 48.00 3000 50.50 3100 53.00 3200 55.50 END OF 2.5/100 BUILD 3220 55.99 50.35 2683 2520 766 50.35 2748 2585 842 50.35 2810 2647 921 50.35 2868 2705 1002 50.35 2879 2716 1018 489.04 N 590.21 E 187851.87 2483435.47 HS 2.50 537.38 N 648.53 E 187911.47 2483482.23 HS 2.50 587.48 N 709.00 E 187973.25 2483530.70 HS 2.50 639.25 N 771.49 E 188037.09 2483580.79 HS 2.50 649.60 N 783.97 E 188049.85 2483590.80 2.50 3500 55.99 4000 55.99 4500 55.99 5000 55.99 5500 55.99 6000 55.99 6500 55.99 7000 55.99 10-3/4" 45.5# CASING 7368 55.99 7500 55.99 8000 55.99 8500 55.99 9000 55.99 9500 55.99 10000 55.99 10500 55.99 50.35 3036 2873 1251 797.89 N 962.94 E 188232.71 2483734.27 50.35 3316 3153 1665 1062.34 N 1282.09 E 188558.80 2483990.12 50.35 3596 3433 2079 1326.78 N 1601.23 E 188884.89 2484245.96 50.35 3875 3712 2494 1591.23 N 1920.38 E 189210.97 2484501.81 50.35 41'55 3992 2908 1855.67 N 2239.53 E 189537.06 2484757.65 50.35 4435 4272 3323 2120.12 N 2558.68 E 189863.15 2485013.50 50.35 4714 4551 3737 2384.56 N 2877.83 E 190189.24 2485269.34 50.35 4994 4831 4152 2649.01 N · 3196.97 E 190515.33 2485525.19 50.35 5200 5037 4457 2843.82 N 3'432.08 E 190755.55 2485713.66 50.35 5274 5111 4566 2913.45 N 3516.12 E 190841.41 2485781.03 50.35 5553 5390 4981 3177.90 N 3835.27 E 191167.50 2486036.88 50.35 5833 5670 5395 3442.35 N 4154.42 E 191493.59 2486292.72 50.35 6113 5950 5810 3706.79 N 4473.56 E 191819.68 2486548.57 50.35 6392 6229 6224 3971.24 N 4792.71 E 192145.76 2486804.41 50.35 6672 6509 6639 4235.68 N 5111.86 E 192471.85 2487060.25 50.35 6952 6'789 7053 4500.13 N 5431.01 E 192797.94 2487316.10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IAnadri] (c)94 WMR3P6 B1.52 10:18 AM 1) WMR-3 (P6) 08/24/94 Page 3 PROPOSED WELL PROFILE STATION IDENTIFICATION MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES STATE-PLANE DEPTH ANGLE AZIMUTH BKB SUB-S DIST FROM-THE-WELLHEAD X Y 11000 55.99 11500 55.99 12000 55.99 12500 55.99 13000 55.99 50.35 7231 7068 7468 4764.57 N 5750.15 E 193124.03 2487571.94 50.35 7511 7348 7882 5029.02 N 6069.30 E 193450.11 ~487827.79 50.35 7791 7628 8297 5293.46 N 6388.45 E 193776.20 2488083.63 50.35 8070 7907 8711 5557.91 N 6707.60 E 194102.29 2488339.47 50.35 8350 8187 9126 5822.36 N 7026.75 E 194428.38 2488595.32 TOOL DL/ FACE 100 0.00 0.00 0.00 0.00 0.00 7-5/8" 29~ CASING TARGET 13500 55.99 14000 55.99 14162 55.99 14500 55.99 14722 55.99 50.35 8630 8467 9540 6086.80 N 7345.89 E 194754.46 2488851.16 50.35 8909 8746 9954 6351.25 N 7665.04 E 195080.55 2489107.00 50.35 9000 8837 10089 6437.00 N 7768.54 E 195186.30 2489189.97 50.35 9189 9026 10369 6615.69 N 7984.19 E 195406.64 2489362.85 50.35 9313 9150 10553 6732.97 N 8125.72 E 195551.25 2489476.31 0.0(' 0.00 0.00 0.00 0.00 15000 55.99 15347 55.99 50.35 9469 9306 10783 6880.14 N 8303.34 E 195732.73 2489618.69 50.35 9663 9500 11071 7063.92 N 8525.13 E 195959.35 2489796.49 0.00 0.00 (Anadril (c)94 WMR3P6 B1.52 10:18 AM 1) "STEWART IIII I I I I II II I i I I I 'P'E?ROLEUM C'OivlPANy" III Section at: TVD Scale · Oep Scale ' Dnaun ..... · ,,i lnadrj ]] Schlumberger WMR-3 (P6) VERTICAL SECTION VIEW i I Ill II 50.35 :1 inch = 2000 feet 1 inch = 2000 feet 08/24/94 .__ , .... MarKer toent]tlcat]on MU UKU 5bUIN INCLI Al KB 0 0 0 0.0t B] 20" 133# CONDUCTOR 120 120 0 § -- ,. ............. C) KOP BUILD 1/100 BO0 800 0 0.01 E ',-- D) BUILD 1.5/100 go0 900 ',~ E) BUILD 2/100 1100 t100 F) BUILD 2.5/100 1300 t299 30 8.0~ ....... G) t6" 75# CASING 22136 22t6 370 32.6! ~lc H) END OF 2.5/100 BUILD 3220 2879 10t8 55.9 I) 10-3/4" 45,5# CASING 7368 5200 4457 55.9 J] 7-5/8" 29# CASING 14162 9000 1008§ 55,9 ' ~ K) ..... TARGET 14722 9313 10553 55.9 L) TD 15347 9663 11071 55.9 ~ .. , . '--,., k-~- (Anadr~]] (c)93 NMR3P6 B~.52 ~0:58 AM ~) -2000 -1000 0 ~000 2000 3000 4000 5000 6000 7000 13000 g000 10000 ~ 1000 12000 13000 14000 15000 16000 Section Beparture STEWART PETROLEJN COMPANY A)Harker ~dentificatiOnKB MDO ""o lR-3 (PG) .~ ~o' ,~, co.ouc~o. ~o o o ~ PLAN VIEW c~ ~o~ ~o ~,oo ,oo o o D) BUILD ~.5/~00 900 E) BUILD ~/100 ~00 6 7 CLOSURE · ~07~ feet at Azimuth 50.35 F) 8UILO ~.5/~00 ~300 ~9 23 6) ~6' 75~ CAS~N~ ~6 ~36 ~85 DECLINATION.: 22.660 E H) END OF ~.5/t00 BUILD 3~0 650 78~ SCALE ....... : ~ inch = ~500 feet I) ~0-3/~' ~5.5~ CAS~N~ 7a68 ~8~4 d) 7-5/8' ~9~ CASIN~ ~4)6~ 6437 7769 DRAHN ' 08/~4/94 K) TARGET ~4722 6733 8J26 L) TD ~5347 7064 8525 /nad~ ]] Schlumberger 8250-- 7500- / TA~BET ~00 :T RAD~U~ 6750- - 6000 5250- - 4500- ~ 750-- 750 750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 B~50 9000 9750 <- HEST: EAST -> ,~"--. (~nadri]! (c)93 t~l~,,q3PB Bi.52 ~]: ~2 ~ l) Great Land Directional Drilling, Inc. Collision Avoidance Analysis Client.: STEWART PETROLEUM COMPANY Field..: COOKINLT Pad .... : WEST MCARTHUR RIVER Well...: WMR3P6 · Comment: WMR-3 (P6) Wells with minimum separation greater than 500 ft not reported. All depths are relative to the planned well. Existing Well Band Closest Point WMR1DOHD WMR1DD WMR2D WMR2AOHD WMR2AD WMRD1D Occurs at Depths BKD MD 38 557 557 38 557 557 133 492 492 133 492 492 133 492 492 173 1175 1176 Method..: Normal Plane Date .... : 08/24/94 WellHd X: 187248.88 WellHd Y: 2482962.23 .... 100' ........ 25' ...... Warning-Band Serious-Band Enter Leave Enter Leave MD MD MD MD 0 1189 0 1189 WMR #3 Casing Design 16" 75~, K-55 BT&C ~ 10-3/4' 45.5#, K-55 7-5/8" 29.04#, L-80 ,~ 5-1/2" 17#, L-80 .,~ 2286' MD, 2216' TVD ~. @ 7368' MD, 5200' TVD ~. @ 14,162' MD, 9000' TVD 5,347' MD, 9663' TVD West McArthur River #3 Casing Design 20" Conductor, 133¢#, NT-80, BT&C @ 120' MD !6" Surface, 75#, K-55, BT&C ¢, 2286' MD, 2216' TVD Tension = 2286' x 75~ = 171K Rated = 1178K for body Safety Factor = 6.9 OK Burst (5200' x .45) - (.115 x 5200') 1742 psi fl drlg to next csg pt. w/full column of gas Rated = 2630 psi for burst Safety Factor = 1.5 OK Collapse : (2216'x .45) - (.115 x2216') : 742 psi for full evacuation Rated = 1020 psi Safety Factor = 1.4 OK 10-3/4" Intermediate Casing, 45.5#, K-55, BT&C ¢, 7368' MD, 5200' TVD Tension = 7368' x 45.,5¢ = 335K Rated = 715K for body Safety Factor = 2.1 OK Burst = (9663' x .45) - (.115 x 9663') = 3237 psi f/drlg to TD w/full column of gas Rated 3580 psi for burst Safety Factor = 1.1 OK Collapse = (5200' x .45) - (.115x5200') = 1742 psi for full evacuation Rated: 2090 psi Safety Factor = 1.2 OK 7-5/8' 29.0#, L-80, STL liner ~ 14,162' MD, 9000' TVD Tension = (14162'-7168') x 29.0~ = 203K Rated = 444K for joint Safety Factor = 2.2 OK Burst = (9663' x .45) - (. 115 x 9663') = 3237 psi fl drlg to TD w/full column of gas Rated 6890 psi for burst Safety Factor = 2.1 OK N/A for liner Collapse = (9000' x .45) - (9000' x .115) = 3015 psi for full evacuation rated = 4790 psi Safety Factor = 1.6 OK 5-1/2' 17#, L-80, STL liner ¢,, 15,347' MD, 9663' TVD Tension = (15,347'-13,962') x 17#= 24K Rated = 210K for joint Safety Factor = 8.9 OK Burst = (9663' x .45) - (.115 x 9663') = 3237 psi Rated = 7740 psi Safety Factor = 2.4 OK N/A for liner Collapse = (9663' x .45) - (9663' x.115) = 3237 psi Rated = 6280 psi Safety Factor = 1.9 OK West McArthur River Unit #3 'Casing Specifications Joint Bo.dy ........................ Strength Strength Burst Co!lapse ID Drift ID 'Min ~orq Opt Torq MaxTorq K lbs K lbs psi psi fi-lbs fi-lbs fi-lbs Conductor !20" 133#, NT-80, BT&C 2123 2125 3060 1500 18.730 18.542 Surface ;16" 75#, K-55, BT&C 1331 1178 2630 1020 15.124' 14.936 , Intermediate 10-3/4" 45.5#, K-55, BT&C 931 715 3580 2090-': 9.950 9.875 4480 5970 746-~ ._ Liner 7-5~8" 29..04~, L-80, STL 444 555 6890 4790 6.875 6.750 4600 5300 6000 ;Liner 5-1/2" 17#, L-80, STL 210 397 7740 6280 4.892 4.767 2400 2800 3200 ,, csgspec2.xls ' -' ~ ~ONIM1661ON' ALA .A QI~ANDGAS ~ONSERV~ BOND aONV NUMa~R___ __1_278~57 .... - ...... _PENAI. SUM $. ~ 200.000 .oo.. . DUPLICATE ORIGINAL KN~ AL~ MSN BY THeE : ~ '. , T~T w. ......... ~~g..~~~~g ................................................... . ANCHO~GE -a ~AS~ .............. of ~ ~ity or,,, .... ~.,, .................... ~...,,,.., $~to ~, ..... , ....... --...- .......... ; .................. ............ TY INSURANCE COMPANY ........... ~ ~..~, ~ .... ~sLS.,..m=~__~_._-...,,,,,,.,,,,,,,,,. .............................................. · %%~1¢rtM U.. tl~ ~r~len i~rirmip41 i~'olw, sa~ t~ ~ i. d~e drifting, pzcK:k~m~ and c)~.r.ting of · or prol)04~s ~o .drill l~z f~r llT4ti~'iphl~ Inferrhlrr~n in a)d upon :h4 fa.-di ~eunt4~i. within tho ~rJte ~f AJe3ke. ~t 4 loc. it SING~J[ Wti. k BOND-.m~rdmum ~rtal ~um UMt or I.Mj4 Nm~ Wel! HumMP Surfae~ W~U I.ocatton-.~m.. TwI).. Rng. and ~ro . Any lfld ill we/il dril~d lnd ol~mlted ~ tl~ I~fAGJpli In t~ 3,~ cf Ai~. . -- NOW, ~EREFORE, ~ I~ ~~ ~~ ~I ~mply ~ ~i of the ~ffM~ ~ ~l fa~ of ~ ~m nf ~ ~ ru~. ~u~na ~d ~ ~ ~ ~ OU ~ Gu ~~~ ~~, ~ tim wl~ ~ AJMkl Oil l~ ~ ~n.~ ~mm~cfl dl ~as Ind r~ r~r~ by NM ~ ~iipl~ thaq r~ In full f~ ~ eft~ ~l ~~ ~ ~ ~ Oil ~ Gas ~rvat~ ~mm~ a first . ..~a- ~C . 0ctobe~ 1o ~ (P~flo~l] ~'. ............................................ ~/~¢~ P~~~ / ~. ',ober ,~.~,..,.,,'~ S~ S~_~ ~SU~S ~~~---7-~: ........ ~7~ ........... "'~'"" ...... ' ..... ~ Dianne'Hansen, Cour~~: NA · · West McArthur River Unit No. 3 Proposed Surface and BHL Property Plat T6N, R14W, Seward Meridian i Bottomhole ~ Location ADL 35911 Sec. 3 ~ Sec. 2 Stewart Pet. Co. ~ ~ ~ ~ ~) ADL 17602 Sec. 9 ~' Sec. 10 Sec. 1 1 Sec. 16 ~' Sec. 15 1323' ~rface I ~cation I Sec. 21 Sec. 22 ADL 35912 I Stewart Pet. Co. I Cook Inlet Bluff West McArthur River Unit No. 3 Proposed Surface and BHL Unit Boundary Plat T8N, R14W, Seward Meridian W. McArthur River Unit ADL 17602 Stewart Pet. Co. Unocal 4 3 2 1 Bottomhole ~ Location 8 9 .~' 10 11 Surface t Location ..... .~ ~ 17 15 14 3 20 21 ~ 23 24 I 29 28 I 26 25 I Cook Inlet Bluff 32 33 35 36 SCALE 1500 FT I WMR-5 BHL 15547 MD 9665 TVD 4680 FSL 700 FEL S10 TOSN R14W SM 7064 N 8525 E ASP ZONE 04 X=195,959..35 Y=2,489,796.49 TARGET 14722 MD 9515 TVD 4549 FSL 1100 FEL S10 TOSN R14W SM 6755 N 8126 E ASP ZONE 04 X=195,551.25 Y=2,489,476.51 -IARGET RADIUS I O0 IrT 10 WMR-5 WMR-2A 16 10 15 KBE 163' MSL WMR-2 D~ISPOSAL :D 1 WELL LOCATION PLAT WEST MCARTHUR RIVER UNIT NABORS 160 COOK INLET, ALASKA WMR-5 SURFACE LOCATION APl - 50-7.35- -00 2899 FSL 5957 FFL SEC 16 TOBN R14W SEWARD ASP ZONE 04' : - X=187,248.83 Y=2,48:2,962.35 Stew ny ^UGUST 12, Igg4 Request for Diverter Waiver Stewart Petroleum Company requests that the diverter requirements in 20 AAC 25.035 be waived for West McArthur River Unit No. 3 because West McAdhur River Unit No. 1, No. 2 and No. D-1 were all ddlled from the same surface location without encountering any shallow gas. Previous waivers were granted for WMRU No. 2 and No. D-I. Mud weights planned for the surface interval are 8.5 ppg at spud building to 9.4 ppg at 2216' TVD due to ddlled solids. These mud densities are consistent with the 3 pdor wells. Request to Eliminate Logging Runs at Surface and Intermediate Casing Points Stewart Petroleum Company requests a waiver for the open hole wireline logging required by 20 AAC 25.071 at the surface casing point of 2216' TVD and at the intermediate casing point of 5200' TVD. West McArthur River Unit Wells No. 1, No. 2 and No. D-1 have previously logged these intervals and it does not seem necessary to incur the added expense for more logs in this area over these shallow intervals. West McArthur River Unit #3 Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling of the West McArthur River Unit #3. The pore pressure gradient information was obtained from the odginal bottom hole pressure surveys and RFT surveys on West McArthur River Unit #1 and #2A. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit # 1 and #2A. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (TVD fi) ('lbs/~al) (Ibs/.clal) ('psi) ('psi) 20 120 8.4 52 16 2216 11.5 8.4 968 10-3/4 5200 15.0 8.6 2325 7-5/8 9000 14.5 8.6 4025 5-1/2 9663 8.65* 4346 1070 3234 3234 * WMRU #2A, P= 4304 psi @ 9567' TVD from DST (as per 407 Comp Report, 11/93) WMRU #1, P= 4362 psi @ 9724' TVD from RFT (as per 407 Comp Report, 2/92) Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = ((FG x .052) - 0.115) x D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.115 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR 2) ASP = FPP - (0.115 x D) whem: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) West McArthur River Unit .. ,~11 #3 Pressure Information ASP Calculations 1. Ddlling below surface casing (16") ASP = ((FG x .052)-0.115) x D = ((11.5 x .052) - 0.115) x 2216 = 1070 psi OR ASP = FPP - (0.115 x D) = 2325 - (0.115 x 5200) = 1727 psi 2. Drilling below intermediate casing (10-3/4") ASP = ((FG x .052)-0.115) x D = ((15.0 x .052) - 0.115) x 5200 = 3458 psi OR ASP = FPP - (0.115 x D) = 4346 - (0.115 x 9663) = 3234 psi 3. Drilling below liner (7-5/8") ASP = ((FG x .052)-0.115) x D = ((14.5 x .052) - 0.115) x 9000 = 5751 psi OR ASP = FPP - (0.115 x D) = 4346 - (0.115 x 9663) = 3234 psi . . . . o . . . . 10. McArthur River Unit #3 Drilling Program Rig up Nabors Rig #160. Ddve 20" conductor to 130' RKB. Directionally ddll 18-1/2" hole to surface casing point @ 2286' MD. Note: A waiver is being requested to eliminate the diverter on the surface hole section. Note: A waiver is being requested to eliminate a logging run at the surface casing point. Run and cement 16" casing to surface. If slurry will not circulate to surface, pump top job. Cut off 16" casing. Install 16-3/4" 3000 psi SOW casinghead and 16-3/4" 3000 psi x 20-3/4" 3000 psi adapter. NU 20-3/4" 3000 psi BOP stack. Notify AOGCC representative 24 hours in advance to witness BOPE test. Drill cement and 10' of new formation with 13-1/2' bit. Perform pressure integrity formation pressure test to 11.5 ppg EMW. Drill 13-1/2" hole to intermediate casing point @ 7368' MD. Note: A waiver is being requested to eliminate a logging run at the intermediate casing point. Run and cement 10-3/4" casing. Land casing in 16-3/4" casing head. Install 11" 5000 psi tubinghead and 11" 5000 x 13-5/8" 5000 psi adapter. NU and test 13-5/8" 5000 psi BOPE. Ddil cement and 10' of new formation with 9-7/8" bit. Perform leak-off pressure test. 11. Drill 9-7/8" hole to ddlling liner depth @ 14,162' MD. 12. Run wireline logs: DIL/LSS/GR/SP. 13. Run and cement 7-5/8" liner. 14. Ddll 6-3/4" hole to TD @ 15,347' MD. 15. Run wireline logs: Run #1 = DIL/SP/BHC/NGT Run #2 = FMS West McArthur River U~ Drilling Program .Veil #3 Run #3 = CNL/LDT/GR 16. Run and cement 5-1/2" liner dependent on log results. 17. Run cased hole logs as required: CET/CBT 18. Run completion equipment. Completion equipment will be contingent on logs. Blowout Prevention Equipment Nabors Rig No. 160 13-5/8' BOP Equipment 3 ea 13-5/8' x 5000 psi wp ram type preventers (Hyddl) 1 ea 13-5/8" x 5000 psi wp annular preventer (Hyddl) 1 ea 13-5/8" x 5000 psi wp ddlling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 20-3/4" BOP Equipment Iea 20-3/4" x 2000 psi annular preventer (Hyddl) 1 ea 20-3/4" x 3000 psi double ram preventer (Cameron) 1 ea 20-3/4" x 3000 psi wp ddlling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. Iea Iea 1 ea 1 lot BOP accumulator, Valvcon, 300 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 psi with control choke panel Hydraulic pipe and rittings from manifold to BOP stack. Nabors Rig #160 20-3/4" BOP Stack 3" Kill Line 1 = HCR Valve 2 = Gate Valve 2000 psi Annular Preventer 3000 psi Pipe Rams I I 3000 psi Blind Rams Drilling Spool 16-3/4' 3M Wellhead 16" Casing 3" Choke Line 20-3/4'x 16-3/4" RECEIVED AUC., 2 4 1994 z\!aska Oil & Gas Cons. Commission Nabors Rig #160 13-5/8" 5000 psi BOP Stack 3" Kill Line I = HCR Valve 2 - Gate Valve 5000 psi Annular Preventer i 5000 psi Pipe Rams ! I 5000 psi Blind Rams Drilling Spool Choke Line 5000 psi Pipe Rams 3-5/8~x 11" 11" 5M Wellhead 10-3/4" Casing West McArthur River Unit #3 Cementing Program 20" Conductor- Driven 16" Surface Casing 18.5" hole at 2300' MD 2286' x 0.4704 cuft/ft (18.5" x 16") x 2.0 (100% excess) = 2160 cuff Cement = 520 cuff Class G w/CaCI @ 15.7 ppg 1640 cuff Class G w/2% gel @ 12.5 ppg If no returns to surface after pumping 100% excess, perform top job. 10-3/4" Intermediate Casing 13.5" hole @ 7368' MD Cement volume for 1000' of fill-up above shoe: 1000' x 0.3637 cuff/ff (12-1/4" x 10-3/4") x 1.15 excess = 420 cuff Cement = 15.8 ppg Class G 7-5/8" Drillinq Liner 9-718' hole @ 14,162' MD, top of liner at 7168' MD Cement volume for liner based on 1000' of fill-up above shoe: 1000' x 0.2148 cuft/ft (9-7/8' x 7-5/8") x 1.15 excess = 250 cuff Cement = 15.8 ppg Class G 5-1/2' Drillinq Liner 6-3/4" hole @ 15,347' MD, top of liner at 13,962' MD Cement volume for liner based on caliper hole volume plus 15% and liner lap, estimated volume is: 1185' (15,347'- 14,162') x 0.0835 cuft/ft (6-3/4' x 5-1/2") x 1.15 = 115 cuff plus 200' liner lap @ 0.0928 cuft/ft x 200' = 20 cuff 115 + 20 = 135 cuff Class G cement Drilling Fluid System Description Nabors Rig No. 160 Mud Pumps 2 ea Continental Emsco F-1300 tdplex mud pumps 7"x 12", 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum I with 50 HP AC motor. Mud Tank System (1035 Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three 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. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank #3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbls; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment Iea 1 ea 1 ea 1 ea 4 ea 4 ea 1 ea 6 ea Brandt dual tandem shale shaker Ddlco degasser Picenco 16 cone desiiter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electric Motors Pioneer desander, 2 cone, Model S-2-12 Dahlory 3" mud guns McArthur River Unit #3 Drilling Fluid Program Surface Hole Spud - 2286' Hole size = 18-1/2" Casing Size = 16" Mud type = Spud Mud Mud Parameters: Weight: 8.5-9.4 ppg Viscosity: 90-150 sec/qt pH: 8.5-9.5 PV: 14-24 YP: 25-50 Fluid Loss: <30 cc/30 min The surface interval will be drilled with a bentonite/acrylic polymer surface mud. Fill pits with fresh water. Treat excessive hardness with soda ash (1/2 to 3/4 ppb) until 40 ppm hardness remains. Prior to spud, mix the surface system to maximum capacity, adding bentonite (20- 25 ppb) to yield a viscosity of 90 sec/qt. Maintain viscosity while drilling ahead at 120-150 sec/qt through any gravel sections. Keep mud weights as Iow as possible with water additions and solids control equipment. Keep sand content below 1%. Acrylic polymer (Ben-Ex) may be added at a 5:1 ratio with bentonite as a bentonite extender. West McArthur River Un~, ~/ell #3 Drilling Fluid Program Intermediate Hole 2286' - 7368' MD or 2216' - 5200' 'rVD Hole size = 13-1/2" Casing Size = 10-3/4" Mud type = LSND Mud Parameters: Weight: 8.8-9.4 ppg Viscosity: 50-90 sec/qt pH: 8.5-9.5 PV: 8-18 YP: 15-25 Fluid Loss: <12 cc/30 min The intermediate interval will continue with a Iow solids, non-dispersed mud system. Before drilling out cement, evaluate the spud mud from the previous interval for Iow gravity solids and active bentonitic clays. If the mud is clean, the 16" shoe can be drilled with the old mud and this would eliminate building a new mud system from scratch. If the Iow gravity solids are too high, dump and dilute with fresh water to bring LGS into line. Prior to drilling new formation, increase the yield point to ensure good hole cleaning. Because this well has a high angle, cuttings bed formation could be a problem. Therefore, keep the yield point high (20-25) and initial gel strenghts at 10-15. Rheologicai properties can be regulated using Sodium Pyrophosphate (SAPP) in small quantities. If it is necessary to reduce the fluid loss to the 6-8 cc range, Drispac can be used at Iow concentrations. Keep mud weight as Iow as possible with water additions and solids control equipment. Keep sand content below 1%. West McArthur River U~ Drilling Fluid Program Veil #3 Ddlling Liner Hole Section 7368'-14,162' MD or 5200'-9000' TVD Hole size = 9-7~8" Casing Size = 7-5/8" Mud type - PHPA polymer Mud Parameters: Weight: 9.4-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min Bump the plug on the 10-3/4" casing with the old mud, then build the new PHPA polymer system. Fill one suction pit with fresh water for drill out of the cement. Avoid drilling cement with the new PHPA system. Clean the remaining pits and fill with fresh water. Treat the fresh water with Soda Ash as required for hardness. Add 10-12 ppb bentonite and allow to properly hydrate. Add 0.75 ppb PHPA and do not add barite at this time. After drilling the cement, discard as much of the old mud as possible. Continue PHPA additions until the complete system is treated with 0.75 ppb PHPA. Add sufficient polymer (0.5 ppb) until the Clapper Polymer test on the whole mud yields 0.4-0.6 ppb of available polymer. Because of potential cuttings bed problems, 10 minute gel stegths should be at 15-22 and 30 minute gels should be 25-30 which will indicate non-progressive gel structure. There may be siginificant viscosity increases as the polymer reacts initially with the native solids but additions should continue until you are over the "hump". Slight additions of Desco or Ligco will reduce the viscosity somewhat. Inspect the ddli cuttings to help determine the proper polymer concentration. Sticky or visibly hydrated cuttings indicate Iow polymer concentration. The Clapper Polymer Test is the most accurate method to determine proper polymer concentration and should be run at least every 2 days. If more viscosity is desired to clean the hole, Biozan can supplement the system. Utilize Iow viscosity-high viscosity sweeps to reduce cuttings bed formation. West McArthur River Ur, . ~ell #3 Drilling Fluid Program To reduce fluid loss, add starch at 3-4 ppb while adding PAC polymer at 1-1.5 ppb. This will assist the bentonite and native clays in suspending solids when not circulating. Monitor the HTHP filtration for an indication of cake formation and compressibility. Adding an acrylamide and alkali salt will help stabilize the APl filtrate and improve the HTHP values to less than 12 cc/30 min. Supplementing the PHPA polymer with a 4 ppb blend of Bore-Plate will provide maximum shale stabilization especially as the Cook Inlet coal intervals are encountered. To smooth out rheological properties, add a Iow moecular weight polyacrylate thinner works which will not disperse the solids. Mud weights should be. kept Iow by running all solids control equipment to their maximum efficiency. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. A Iow gravity solids of less than 7% is required for optimum performance of this system. Dilution or complete displacement should be considered if higher LGS contents persist. West McArthur River U~ ,Veil #3 Drilling Fluid Program Production Liner Hole Section 14,162'-15,347' MD or 9000'-9663' TVD Hole size = 6-3/4' Casing Size = 5-1/2" Mud type -- PHPA polymer Mud Parameters: Weight: 9.4-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 Pr: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min Bump the plug on the 7-518" liner with the PHPA mud treated with Bicarb to offset cement contamination. The fluid system will already be established from the previous hole section. Eliminate the PAC polymer for filtration control and use starch and acrylamide/alkali salt. This will also enhance the lubricity of the fluid along with a glycol lubricant. After drilling out the cement, have the PHPA concentration at .6-.75 ppb and Bore-plate at 4.0 ppg. The APl filtrate should be less than 6.0 cc. The glycol lubricant should be kept at 3% to provide lubricity for the high angle wellbore. Maintain rheological properties on the high side to prevent particle settlement and pump regular high viscosity/Iow viscosity sweeps. Keep the mud weight as Iow as possible because, unnecessary solids have detrimental effects on the polymers. West McArthur River Unit #3 -8000 Set 10-3/4" -10000 -12000 -14000 -16000 Log, Set 7-5/8" 10 20 30 40 50 60 70 80 Log, Set 5-1/2", Complete ~.::.i::::,;;~:~ 90 1 O0 110 120 Days NELL PERMIT CHECKLIST ,~ELD ~ POO~, ~300c~c WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] /.~O/C3 ON/OFF SHORE o~%J ~MINISTRATION 1. Permit fee attached ................... N 2. Lease number appropriate ................ N 3. Unique well name and number ............... N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ........ ~~ ......... 26. BOPE press rating adequate; tes~to ~'--O~'~ psig.~ 27. Choke manifold complies w/API RP-53 ~May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis 9f shallow gas zones .......... y N 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports . . . ./~ Y N [exploratory only] ./ GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED ~,' - - I995 Aurd ~ o Alaska fiji_. & ,.,~.o .... Cons. Commission Anchorage * ALASKA COMPUTING CENTER * * ....... SCHLUMBERGER ....... * COMPANY NAME : STEWART PETROLEUM COMPANY WELL NAME : WMR #3 FIELD NAME : WEST McARTHUR RIVER BOROUGH : KENAI STATE : ALASKA API NUMBER : 50-133-20461-00 REFERENCE NO : 95230 d.. L~.. g.,,/ MICROFILMED LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 **** REEL HEADER **** SERVICE NAME : MEST DATE : 95/05/30 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** TAPE HEADER SERVICE NAME : FMEST DATE : 95/05/30 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY PAGE: **** FILE HEADER FILE NAME : MEST .026 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/30 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 20308 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .lIN 11 66 1 12 68 -999. 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: ** SET TYPE - CHAN ** ID ORDER if LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS MEST IN O0 282 01 0 21 1 I 4 68 0000000000 CS MEST F/HR O0 636 21 0 21 CVEL MEST F/MN O0 636 O0 0 21 TENS MEST LBF O0 635 21 0 21 ETIM MEST S O0 636 21 0 21 MARK MEST F O0 150'01 0 21 AREA MEST FT2 O0 280 04 0 21 AFCD MEST FT2 O0 282 01 0 21 ABS MEST FT2 O0 282 01 0 21 FCD MEST IN O0 282 01 0 21 IHV MEST F3 O0 282 01 0 21 ICV MEST F3 O0 282 01 0 21 STIA MEST F O0 000 O0 0 21 STIT MEST F O0 000 O0 0 21 SPCF MEST O0 611 01 0 21 DPTR MEST DEG O0 611 01 0 21 DPAZ MEST DEG O0 611 01 0 21 QUAF MEST O0 611 01 0 21 DDIP MEST DEG O0 611 01 0 21 DDA MEST DEG O0 611 01 0 21 DEVI MEST DEG O0 620 01 0 21 FNOR MEST OER O0 631 01 0 21 FINC MEST DEG O0 631 01 0 21 HAZI MEST DEG O0 630 01 0 21 PIAZ MEST DEG O0 630 01 0 21 RB HEST DEG O0 631 01 0 21 SDEV MEST DEG O0 620 01 0 21 HV MEST V O0 000 O0 0 21 HTEN MEST LBF O0 000 O0 0 21 MRES MEST OHMM O0 000 O0 0 21 RGR MEST GAPI O0 000 O0 0 21 TIME MEST MS O0 636 21 0 21 ANOR MEST F/S2 O0 631 01 0 21 GAT MEST DEGF O0 000 O0 0 21 GMT MEST DEGF O0 000 O0 0 21 CTEM MEST DEGF O0 000 O0 0 21 RMTE MEST DEGF O0 000 O0 0 21 MTEM MEST DEGF O0 000 O0 0 21 AMTE MEST DEGF O0 000 O0 0 21 DTEM MEST DFHF O0 000 O0 0 21 GR MEST GAPI O0 000 O0 0 21 6A MEST MS O0 636 21 0 21 EV MEST V O0 000 O0 0 21 BA28 MEST O0 610 O0 0 21 BA17 MEST O0 610 O0 0 21 BB17 MEST O0 610 O0 0 21 BC13 MEST O0 610 O0 0 21 BD13 MEST O0 610 O0 0 21 BB28 MEST O0 610 O0 0 21 BA13 MEST O0 610 O0 0 21 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 60 60 6O 60 60 60 60 60 60 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 240 240 240 240 240 240 240 240 240 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: ID ORDER # 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LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BD22 MEST O0 610 O0 0 21 60 1 240 68 0000000000 BD23 MEST O0 610 O0 0 21 60 1 240 68 0000000000 BD24 MEST O0 610 O0 0 21 60 i 240 68 0000000000 BD25 MEST O0 610 O0 0 21 60 I 240 68 0000000000 BD26 MEST O0 610 O0 0 21 60 1 240 68 0000000000 BD27 MEST O0 610 O0 0 21 60 1 240 68 0000000000 SB1 MEST O0 610 O0 0 21 60 I 240 68 0000000000 DB1 MEST O0 610 O0 0 21 60 i 240 68 0000000000 DB2 MEST O0 610 O0 0 21 60 i 240 68 0000000000 DB3A MEST O0 610 O0 0 21 60 1 240 68 0000000000 DB4A MEST O0 610 O0 0 21 60 i 240 68 0000000000 SB2 MEST O0 610 O0 0 21 60 I 240 68 0000000000 DBiA MEST O0 610 O0 0 21 60 i 240 68 0000000000 DB2A MEST O0 610 O0 0 21 60 i 240 68 0000000000 DB3 MEST O0 610 O0 0 21 60 I 240 68 0000000000 DB4 MEST O0 610 O0 0 21 60 1 240 68 0000000000 FCAX MEST M/S2 O0 000 O0 0 21 60 i 240 68 0000000000 FCAY MEST M/S2 O0 000 O0 0 21 60 i 240 68 0000000000 FCAZ MEST M/S2 O0 000 O0 0 21 60 i 240 68 0000000000 FTIM MEST MS O0 000 O0 0 21 60 I 240 68 0000000000 7A MEST O0 000 O0 0 21 60 1 240 68 0000000000 8A MEST M/S2 O0 000 O0 0 21 60 1 240 68 0000000000 9A MEST M/S2 O0 000 O0 0 21 60 I 240 68 0000000000 iOA MEST MS O0 636 21 0 21 4 1 16 68 0000000000 ¢1 MEST IN O0 280 41 0 21 4 I 16 68 0000000000 C2 MEST IN O0 280 42 0 21 4 I 16 68 0000000000 RCl MEST IN O0 280 41 0 21 4 i 16 68 0000000000 R¢2 MEST IN O0 280 42 0 21 4 I 16 68 0000000000 PP MEST O0 000 O0 0 21 4 i 16 68 0000000000 CP MEST O0 000 O0 0 21 4 i 16 68 0000000000 AX MEST M/S2 O0 615 02 0 21 4 1 16 68 0000000000 AY MEST M/S2 O0 615 03 0 21 4 i 16 68 0000000000 AZ MEST M/S2 O0 615 01 0 21 4 1 16 68 0000000000 FX MEST OER O0 000 O0 0 21 4 i 16 68 0000000000 FY MEST OER O0 000 O0 0 21 4 i 16 68 0000000000 EI MEST MA O0 000 O0 0 21 4 1 16 68 0000000000 FZ MEST OER O0 000 O0 0 21 4 1 16 68 0000000000 ** DATA DEPTH = 14427.000 FEET BS.MEST 6.750 CS.MEST 865.801 CVEL.MEST -14.430 TENS.MEST ETIM.MEST 0.000 MARK.MEST 64.000 AREA.MEST 0.110 AFCD.MEST ABS.MEST 0.249 FCD.MEST 5.500 IHV.MEST 0.055 ICV.MEST STIA.MEST 1.982 STIT.MEST 1.982 SPCF.MEST 0.000 DPTR.MEST DPAZ.MEST -999.250 QUAF.MEST 0.000 DDIP.MEST -999.250 DDA.MEST DEVI.MEST 50.973 FNOR.MEST 0.563 FINC.MEST 72.117 HAZI.MEST P1AZ.MEST 342.878 RB.MEST 305.612 SDEV.MEST 50.973 HV.MEST 2105.000 0.165 -0.028 -999.250 -999.250 48.602 249.450 .dpe Verification Listing ocnlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: HTEN.MEST 311.229 ANOR.MEST 32.554 RMTE.MEST 167.445 GR.MEST 26.817 BA17.MEST -999.250 BB28.MEST -999.250 BD17.MEST -999.250 BC28.MEST -999.250 BA11.MEST -999.250 BA16.MEST -999.250 BC12.MEST -999.250 BC18.MEST -999.250 BC24.MEST -999.250 BB22.MEST -999.250 BB25.MEST -999.250 BB12.MEST -999.250 BB18.MEST -999.250 BD14.MEST -999.250 BD21.MEST -999.250 BD25.MEST -999.250 DB1.MEST -999.250 SB2.MEST -999.250 DB4.MEST -999.250 FTIM.MEST -999.250 IOA.MEST -999.250 RC2.MEST -999.250 AY.MEST -999.250 EI.MEST -999.250 ** DEPTH : BS.MEST 6.750 ETIM.MEST 727.046 ABS.MEST 0.249 STIA.MEST 0.000 DPAZ.MEST -999.250 DEVI.MEST 54.613 P1AZ.MEST 44.972 HTEN.MEST 692.969 ANOR.MEST 30.940 RMTE.MEST 166.744 GR.MEST 46.377 BA17.MEST 0.000 BB28.MEST 0.000 BD17.MEST 0.000 B¢28.MEST 0.000 BA11.MEST 0.000 BA16.MEST 0.000 BC12.MEST 0.000 BC18.MEST 0.000 BC24.MEST 0.000 BB22.MEST 0.000 BB25.MEST 0.000 BB12.MEST 0.000 BB18.MEST 0.000 MRES.MEST GAT.MEST MTEM.MEST 6A.MEST BB17.MEST BA13.MEST BA22.MEST BA25.MEST BA12.MEST BA18.MEST BC14.MEST BC21.MEST BC25.MEST BB23.MEST BB26.MEST BB14.MEST BB21.MEST BD15.MEST BD22.MEST BD26.MEST DB2.MEST DB1A.MEST FCAX.MEST 7A.MEST Cl. 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LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS MEST IN O0 282 01 0 22 1 1 4 68--6666666666- CS MEST F/HR O0 636 21 0 22 1 1 4 CVEL MEST F/MN O0 636 O0 0 22 I 1 4 TENS MEST LBF O0 635 21 0 22 i I 4 ETIM MEST S O0 636 21 0 22 1 1 4 MARK MEST F O0 150 01 0 22 I I 4 AREA MEST FT2 O0 280 04 0 22 1 1 4 AFCD MEST FT2 O0 282 01 0 22 i 1 4 ABS MEST FT2 O0 282 01 0 22 1 1 4 FCD MEST IN O0 282 01 0 22 i 1 4 IHV MEST F3 O0 282 01 0 22 i 1 4 ICV MEST F3 O0 282 01 0 22 I 1 4 STIA MEST F O0 000 O0 0 22 i 1 4 STIT MEST F O0 000 O0 0 22 1 1 4 SPCF MEST O0 611 01 0 22 i 1 4 DPTR MEST DEG O0 611 01 0 22 i i 4 DPAZ MEST DEG O0 611 01 0 22 1 1 4 QUAF MEST O0 611 01 0 22 1 1 4 DDIP HEST DEG O0 611 01 0 22 1 1 4 DDA MEST DEG O0 611 01 0 22 I I 4 DEVI MEST DEG O0 620 01 0 22 1 1 4 FNOR MEST OER O0 631 01 0 22 1 1 4 FINC MEST DEG O0 631 01 0 22 1 1 4 HAZI MEST DEG O0 630 01 0 22 i 1 4 P1AZ MEST DEG O0 630 01 0 22 i 1 4 RB MEST DEG O0 631 01 0 22 i I 4 SDEV MEST DEG O0 620 01 0 22 i 1 4 HV MEST V O0 000 O0 0 22 i i 4 HTEN MEST LBF O0 000 O0 0 22 I 1 4 MRES MEST OHMM O0 000 O0 0 22 1 i 4 RGR MEST GAPI O0 000 O0 0 22 i I 4 TIME MEST MS O0 636 21 0 22 I I 4 ANOR MEST F/S2 O0 631 01 0 22 I I 4 GAT MEST DEGF O0 000 O0 0 22 i i 4 GMT MEST DEGF O0 000 O0 0 22 1 I 4 CTEM MEST DEGF O0 000 O0 0 22 i 1 4 RMTE MEST DEGF O0 000 O0 0 22 I I 4 MTEM MEST DEGF O0 000 O0 0 22 I I 4 AMTE MEST DEGF O0 000 O0 0 22 I I 4 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,ape Verification Listing ~chlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: ID ORDER if LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GR MEST GAPI O0 000 O0 0 22 1 1 6A MEST MS O0 636 21 0 22 60 1 EV MEST V O0 000 O0 0 22 60 1 BA28 MEST O0 610 O0 0 22 60 1 BA17 MEST O0 610 O0 0 22 60 1 BB17 MEST O0 610:00 0 22 60 1 BC13 MEST O0 610 O0 0 22 60 1 BD13 MEST O0 610 O0 0 22 60 1 BB28 MEST O0 610 O0 0 22 60 1 BA13 MEST O0 610 O0 0 22 60 1 BB13 MEST O0 610 O0 0 22 60 1 BC17 MEST O0 610 O0 0 22 60 1 BD17 MEST O0 610 O0 0 22 60 1 BA22 MEST O0 610 O0 0 22 60 1 BA23 MEST O0 610 O0 0 22 60 1 BA24 MEST O0 610 O0 0 22 60 1 BC28 MEST O0 610 O0 0 22 60 1 BA25 MEST O0 610 O0 0 22 60 1 BA26 MEST O0 610 O0 0 22 60 1 BA27 MEST O0 610 O0 0 22 60 1 BAll MEST O0 610 O0 0 22 60 1 BA12 MEST O0 610 O0 0 22 60 1 BA14 MEST O0 610 O0 0 22 60 1 BA15 MEST O0 610 O0 0 22 60 1 BA16 MEST O0 610 O0 0 22 60 1 BA18 MEST O0 610 O0 0 22 60 1 BA21MEST O0 610 O0 0 22 60 1 BC11MEST O0 610 O0 0 22 60 1 BC12 HEST O0 610 O0 0 22 60 1 BC14 MEST O0 610 O0 0 22 60 1 BC15 MEST O0 610 O0 0 22 60 1 BC16 MEST O0 610 O0 0 22 60 1 BC18 MEST O0 610 O0 0 22 60 1 BC21HEST O0 610 O0 0 22 60 1 BC22 MEST O0 610 O0 0 22 60 1 BC23 MEST O0 610 O0 0 22 60 1 BC24 MEST O0 610 O0 0 22 60 1 BC25 MEST O0 610 O0 0 22 60 1 BC26 MEST O0 610 O0 0 22 60 1 BC27 MEST O0 610 O0 0 22 60 1 BB22 MEST O0 610 O0 0 22 60 1 BB23 MEST O0 610 O0 0 22 60 1 BB24 MEST O0 610 O0 0 22 60 1 BD28 MEST O0 610 O0 0 22 60 1 BB25 HEST O0 610 O0 0 22 60 1 BB26 MEST O0 610 O0 0 22 60 1 BB27 MEST O0 610 O0 0 22 60 1 BB11MEST O0 610 O0 0 22 60 1 BB12 MEST O0 610 O0 0 22 60 1 BB14 MEST O0 610 O0 0 22 60 i 4 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 68 68 68 68 68 68 68 68 68 68 68 68 .68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~ape verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ................. .... .... i ..... .... O0 610 O0 0 22 60 1 240 68 0000000000 BB16 MEST BB18 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BB21 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BD11 MEST O0 610 O0 0 22 60 I 240 68 0000000000 BD12 MEST O0 610 O0 0 22 60 I 240 68 0000000000 BD14 MEST O0 610'00 0 22 60 i 240 68 0000000000 BD15 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BD16 MEST O0 610 O0 0 22 60 I 240 68 0000000000 BD18 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BD21 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BD22 MEST O0 610 O0 0 22 60 I 240 68 0000000000 BD23 MEST O0 610 O0 0 22 60 i 240 68 0000000000 BD24 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BD25 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BD26 MEST O0 610 O0 0 22 60 1 240 68 0000000000 BD27 MEST O0 610 O0 0 22 60 1 240 68 0000000000 SB1 MEST O0 610 O0 0 22 60 i 240 68 0000000000 DB1 MEST O0 610 O0 0 22 60 1 240 68 0000000000 DB2 MEST O0 610 O0 0 22 60 1 240 68 0000000000 DB3A MEST O0 610 O0 0 22 60 I 240 68 0000000000 DB4A MEST O0 610 O0 0 22 60 1 240 68 0000000000 SB2 MEST O0 610 O0 0 22 60 1 240 68 0000000000 DB1A MEST O0 610 O0 0 22 60 1 240 68 0000000000 DB2A MEST O0 610 O0 0 22 60 1 240 68 0000000000 DB3 MEST O0 610 O0 0 22 60 1 240 68 0000000000 DB4 MEST O0 610 O0 0 22 60 I 240 68 0000000000 FCAX MEST M/S2 O0 000 O0 0 22 60 1 240 68 0000000000 FCAY MEST M/S2 O0 000 O0 0 22 60 I 240 68 0000000000 FCAZ MEST M/S2 O0 000 O0 0 22 60 1 240 68 0000000000 FTIM MEST MS O0 000 O0 0 22 60 1 240 68 0000000000 7A MEST O0 000 O0 0 22 60 1 240 68 0000000000 8A MEST M/S2 O0 000 O0 0 22 60 1 240 68 0000000000 9A MEST M/S2 O0 000 O0 0 22 60 1 240 68 0000000000 iOA MEST MS O0 636 21 0 22 4 1 16 68 0000000000 C1 MEST IN O0 280 41 0 22 4 I 16 68 0000000000 C2 MEST IN O0 280 42 0 22 4 1 16 68 0000000000 RCl MEST IN O0 280 41 0 22 4 I 16 68 0000000000 RC2 MEST IN O0 280 42 0 22 4 1 16 68 0000000000 PP MEST O0 000 O0 0 22 4 1 16 68 0000000000 CP MEST O0 000 O0 0 22 4 I 16 68 0000000000 AX MEST M/S2 O0 615 02 0 22 4 1 16 68 0000000000 AY MEST M/S2 O0 615 03 0 22 4 1 16 68 0000000000 AZ MEST M/S2 O0 615 01 0 22 4 1 16 68 0000000000 F× MEST OER O0 000 O0 0 22 4 I 16 68 0000000000 FY MEST OER O0 000 O0 0 22 4 1 16 68 0000000000 EI MEST MA O0 000 O0 0 22 4 1 16 68 0000000000 FZ MEST OER O0 000 O0 0 22 4 1 16 68 0000000000 ~ Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ** ** DEPTH = 15375.000 FEET BS.MEST 6.750 CS.MEST ETIM.MEST 0.000 MARK.MEST ABS.MEST 0.249 FCD.MEST STIA.HEST 1.955 STIT.MEST DPAZ.MEST -999.250 QUAF.MEST DEVI.MEST 37.609 FNOR.MEST P1AZ.MEST 354.815 RB.MEST HTEN.MEST 2.623 MRES.MEST ANOR.HEST 32.416 GAT.MEST RMTE.MEST 174.539 MTEM.MEST GR.MEST 47.282 6A.MEST BA17.MEST -999.250 BB17.MEST BB28.MEST -999.250 BA13.MEST BD17.MEST -999.250 BA22.MEST BC28.MEST -999.250 BA25.MEST BA11.MEST -999.250 BA12.MEST BA16.MEST -999.250 BA18.MEST BC12.MEST -999.250 BC14.MEST BC18.MEST -999.250 BC21.MEST BC24.MEST -999.250 B¢25.MEST BB22.MEST -999.250 BB23.MEST BB25,MEST -999.250 BB26.MEST BB12.MEST -999.250 BB14.MEST BB18.MEST -999.250 BB21.MEST BD14.MEST -999.250 BD15.MEST BD21.MEST -999.250 BD22.MEST BD25.MEST -999.250 BD26.MEST DB1.MEST -999.250 DB2.MEST SB2.MEST -999.250 DB1A.MEST DB4.MEST -999.250 FCAX.MEST FTIM.MEST -999.250 7A.MEST IOA.HEST -999.250 Cl.MEST RC2.MEST -999.250 PP.MEST AY.MEST -999.250 AZ.MEST EI.MEST -999.250 FZ.MEST ** DEPTH = 14095.500 FEET BS.MEST 6.750 CS.MEST ETIM.MEST 3039.019 MARK.MEST ABS.MEST 0.249 FCD.MEST STIA.MEST 0.000 STIT.MEST DPAZ.MEST -999.250 QUAF.MEST DEVI.MEST 39.166 FNOR.MEST PiAZ.MEST 273.235 RB.MEST HTEN.MEST 687.541 MRES.MEST ANOR.MEST 23.255 GAT.MEST RMTE.MEST 166.744 MTEM.MEST GR.HEST 39.317 6A.MEST BA17.MEST 950304.143 BB17.MEST BB28.MEST 950304.143 BA13.MEST 17-JUL-1995 12:00 904.977 CVEL.MEST 59.000 AREA.MEST 5.500 IHV.MEST 1.955 SPCF.MEST 0.000 DDIP.MEST 0.568 FINC.MEST 312.556 SDEV.MEST 0.422 RGR.MEST 147.248 GMT.MEST 174.539 AMTE.MEST -999.250 EV.MEST -999.250 BC13.MEST -999.250 BB13.MEST -999.250 BA23.MEST -999.250 BA26.MEST -999.250 BA14.MEST -999.250 BA21.MEST -999.250 BC15.MEST -999.250 BC22.MEST -999.250 BC26.MEST -999.250 BB24.MEST -999.250 BB27.MEST -999.250 BB15.MEST -999.250 BD11.MEST -999.250 BD16.MEST -999.250 BD23.MEST -999.250 BD27.MEST -999.250 DB3A.MEST -999.250 DB2A.MEST -999.250 FCAY.MEST -999.250 8A.MEST -999.250 C2.MEST -999.250 CP.MEST -999.250 FX.MEST -999.250 1632.630 CVEL.MEST 64.000 AREA.MEST 5.500 IHV.MEST 0.000 SPCF.MEST -999.250 DDIP.MEST 0.379 FINC.MEST 240.075 SDEV.MEST 0.441 RGR.MEST 168.390 GMT.MEST 166.744 AMTE.MEST 37.000 EV.MEST 950304.143 BC13.MEST 950304.143 BB13.MEST -15.083 0.093 0.000 0.000 -999.250 72.527 37.609 37.895 188.721 174.539 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -27.211 0.267 314.584 0.000 -999.250 64.195 39.166 24.316 205.414 166.740 0.072 950304.143 950304.143 TENS. AFCD. ICV. DPTR. DDA. HAZI. HV. TIME. CTEM. DTEM. BA28. BD13. BC17. BA24. BA27. BA15. BC11. BC16. BC23. BC27. BD28. BBll. BB16. BD12. BD18. BD24. SB1. DB4A. DB3. FCAZ. 9A. RC1. AX. FY. TENS. AFCD. ICV. DPTR. DDA. HAZI. HV. TIME. CTEM. DTEM. BA28. BD13. BC17. MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST MEST PAGE: 2425. O. O. -999. -999. 48. 247. O. 188. O. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 5780. O. 120. -999. -999. 27. 247. 1107. 193. O. 950304. 950304. 950304. 000 165 000 250 250 786 110 000 600 000 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 000 165 318 250 250 285 110 000 lO0 000 143 143 143 10 _~ Tape Verification Listing Schlumberger Alaska Computing Center BD17.MEST 950304.143 BA22.MEST BC28.MEST 950304.143 BA25.MEST BA11.MEST 950304.143 BA12.MEST BA16.MEST 950304.143 BA18.MEST BC12.MEST 950304.143 BC14.MEST BC18.MEST 950304.143 BC21.MEST BC24.MEST 950304.143 BC25.MEST BB22.MEST 950304.143 BB23.MEST BB25.MEST 950304.143 BB26.MEST BB12.MEST 950304.143 BB14.MEST BB18.MEST 950304.143 BB21.MEST BD14.MEST 950304.143 BD15.MEST BD21.MEST 950304.143 BD22.MEST BD25.MEST 950304.143 BD26.MEST DBi.HEST 950304.143 DB2.MEST SB2.MEST 950304.143 DBIA.MEST DB4.MEST 950304.143 FCAX.MEST FTIM.MEST 25.431 7A.MEST IOA.MEST 553.500 ¢I.MEST RC2.MEST 7.959 PP.MEST AY.MEST 3.832 AZ.MEST EI.MEST 444.878 FZ.MEST 17-JUL-1995 12:00 950304.143 BA23.MEST 950304.143 BA26.MEST 950304.143 BA14.MEST 950304.143 BA21.MEST 950304.143 BC15.MEST 950304.143 BC22.MEST 950304.143 BC26.MEST 950304.143 BB24.HEST 950304.143 BB27.MEST 950304.143 BB15.MEST 950304.143 BD11.MEST 950304.143 BD16.MEST 950304.143 BD23.MEST 950304.143 BD27.MEST 950304.143 DB3A.MEST 950304.143 DB2A.MEST -7.314 FCAY.MEST 0.000 8A.MEST 7.016 C2.MEST 33.523 CP.MEST 5.446 FX.MEST 0.180 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 3.817 0.000 6.972 33.944 -0.102 BA24.MEST BA27.MEST BA15.MEST BC11.MEST BC16.MEST BC23.MEST BC27.MEST BD28.MEST BB11.MEST BB16.MEST BD12.MEST BD18.MEST BD24.MEST SB1.MEST DB4A.MEST DB3.MEST FCAZ.MEST 9A.MEST RCl.MEST AX.MEST FY.MEST PAGE: 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 950304.143 5.547 0.000 7.861 -7.302 0.038 11 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : MEST .027 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/30 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : SPEA .014 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/30 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : .~ Fape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE --i .......... .......... .... 2 66 0 3 79 2306 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .lIN 11 66 3 12 68 -999. 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS SPEA IN 99 282 01 0 10 i 1 4 68 0000000000 CS SPEA F/HR 99 636 21 0 10 1 1 4 68 CVEL SPEA F/MN 99 636 O0 0 10 i 1 4 68 TENS SPEA LBF 99 635 21 0 10 I 1 4 68 ETIM SPEA S 99 636 21 0 10 1 1 4 68 MARK SPEA F 99 150 01 0 10 i 1 4 68 SP SPEA MV 99 010 01 0 10 I I 4 68 SPAR SPEA MV 99 010 01 0 10 I 1 4 68 RSP SPEA MV 99 010 01 0 10 i 1 4 68 RSPA SPEA MV 99 010 01 0 10 1 1 4 68 RT SPEA OHHM 99 935 01 0 10 1 1 4 68 HV SPEA V 99 000 O0 0 10 i i 4 68 HTEN SPEA LBF 99 000 O0 0 10 I i 4 68 MRES SPEA OHMM 99 000 O0 0 10 i 1 4 68 AREA SPEA FT2 99 280 04 0 10 i i 4 68 AFCD SPEA FT2 99 282 01 0 10 1 1 4 68 ABS SPEA FT2 99 282 01 0 10 i 1 4 68 FCD SPEA IN 99 282 01 0 10 i 1 4 68 IHV SPEA F3 99 282 01 0 10 1 1 4 68 ICV SPEA F3 99 282 01 0 10 1 1 4 68 STIA SPEA F 99 000 O0 0 10 1 1 4 68 STIT SPEA F 99 000 O0 0 10 1 1 4 68 ASCA SPEA MV 99 000 O0 0 10 1 1 4 68 ASFI SPEA MV 99 000 O0 0 10 i 1 4 68 BDQC SPEA 99 000 O0 0 10 1 I 4 68 DRHO SPEA G/C3 99 356 01 0 10 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000020000 0000020000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 12 Verification Listing v,~lumDerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DALP SPEA 99 356 01 0 10 1 1 4 68 0000000000 LSRH SPEA G/¢3 99 350 02 0 t0 1 1 LURH SPEA G/C3 99 350 02 0 10 1 1 PEF SPEA 99 358 01 0 10 i 1 QRLS SPEA G/C3 99 354 01 0 10 1 1 QLS SPEA G/C3 99 354 01 0 10 i 1 QRSS SPEA G/C3 99 354 01 0 10 i 1 QSS SPEA G/C3 99 354 01 0 10 1 1 RHOB SPEA G/C3 99 350 02 0 10 i 1 SiRH SPEA G/C3 99 350 02 0 10 i 1 NRHO SPEA G/C3 99 350 01 0 10 1 1 RLL SPEA CPS 99 354 02 0 10 1 1 RLU SPEA CPS 99 354 02 0 10 I 1 RLS SPEA CPS 99 354 02 0 10 1 1 RLIT SPEA CPS 99 354 02 0 10 i 1 LSHV SPEA V 99 354 O0 0 10 i 1 FFLS SPEA 99 354 O0 0 10 I 1 RSS1 SPEA CPS 99 354 01 0 10 I 1 RSS2 SPEA CPS 99 354 01 0 10 i 1 SSHV SPEA V 99 354 O0 0 10 1 1 FFSS SPEA 99 354 O0 0 10 1 1 RCAL SPEA IN 99 280 01 0 10 i 1 LL SPEA CPS 99 354 01 0 10 1 1 LU SPEA CPS 99 354 01 0 10 I 1 LS SPEA CPS 99 354 01 0 10 i 1 LITH SPEA CPS 99 354 01 0 10 1 1 SS1 SPEA CPS 99 354 02 0 10 i 1 SS2 SPEA CPS 99 354 02 0 10 I 1 CALI SPEA IN 99 280 01 0 10 1 1 RGCN SPEA CPS 99 000 O0 0 10 I 1 DRTA SPEA 99 000 O0 0 10 1 1 TALP SPEA 99 000 O0 0 10 1 1 RTNR SPEA 99 000 O0 0 10 1 1 RCNT SPEA CPS 99 000 O0 0 10 1 1 RCFT SPEA CPS 99 000 O0 0 10 i 1 CNTC SPEA CPS 99 000 O0 0 10 i 1 TNRA SPEA 99 000 O0 0 10 I 1 CFTC SPEA CPS 99 000 O0 0 10 I 1 RGR SPEA GAPI 99 000 O0 0 10 1 1 TIHE SPEA MS 99 636 21 0 10 i 1 CTEM SPEA DEGF 99 000 O0 0 10 I 1 RMTE SPEA DEGF 99 000 O0 0 10 i 1 MTEM SPEA DEGF 99 000 O0 0 10 1 1 AMTE SPEA DEGF 99 000 O0 0 10 i 1 ATCA SPEA DEGF 99 000 O0 0 10 1 1 DTEM SPEA DFHF 99 000 O0 0 10 I 1 DPHI SPEA PU 99 890 01 0 10 1 1 PHND SPEA PU 99 890 01 0 10 1 1 TNPH SPEA PU 99 000 O0 0 10 i 1 NPHI SPEA PU 99 000 O0 0 10 i 1 NPL SPEA PU 99 000 O0 0 10 i i 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000020000 0000020000 0000020000 000O02O000 0000020000 0000020000 0000020000 OO00020000 0000000000 0000020000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0O40000000 0000000000 0000000000 0000000000 0442000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0242000400 0242000000 0000000000 13 Verification Listing ~nlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 14 ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NPOR SPEA PU 99 000 O0 0 10 1 1 4 68 0000000000 SCNL SPEA 99 000 O0 0 10 1 1 2 79 0000000000 GR SPEA GAPI 99 000 O0 0 10 1 i 4 68 0000000000 lA SPEA MS 99 636 21 0 10 12 1 48 68 0000000000 AIBP SPEA PSI 99 000 00 0 10 2 1 8 68 0000000000 AIBD SPEA IN 99 000 00 0 10 2 1 8 68 0000000000 AIMR SPEA 0HMM 99 000 00 0 10 2 1 8 68 0000000000 AIFF SPEA 99 000 00 0 10 2 I 8 68 0000000000 ACBS SPEA 99 000 O0 0 10 2 1 8 68 0000000000 ACED SPEA IN 99 000 00 0 10 2 1 8 68 0000000000 ACCB SPEA MM/M 99 000 00 0 10 2 1 8 68 0000000000 ACRB SPEA OHMM 99 000 00 0 10 2 1 8 68 0000000000 ACCF SPEA MM/M 99 000 00 0 10 2 1 8 68 0000000000 ACRF SPEA OHMM 99 000 O0 0 10 2 1 8 68 0000000000 ABFR SPEA 99 000 00 0 10 2 i 8 68 0000000000 2A SPEA MM/M 99 000 00 0 10 2 1 8 68 0000000000 3A SPEA MM/M 99 000 O0 0 10 2 I 8 68 0000000000 4A SPEA MM/M 99 000 O0 0 10 2 i 8 68 0000000000 5A SPEA MM/M 99 000 O0 0 10 2 1 8 68 0000000000 6A SPEA MM/M 99 000 O0 0 10 2 I 8 68 0000000000 7A SPEA MM/M 99 000 00 0 10 2 1 8 68 0000000000 8A SPEA MM/M 99 000 O0 0 10 2 1 8 68 0000000000 9A SPEA MM/M 99 000 00 0 10 2 1 8 68 0000000000 10A SPEA MH/M 99 000 00 0 10 2 1 8 68 0000000000 11A SPEA MM/M 99 000 00 0 10 2 I 8 68 0000000000 AT10 SPEA 0HMM 99 000 00 0 10 2 I 8 68 0000000000 AT20 SPEA OHMM 99 000 00 0 10 2 1 8 68 0000000000 AT30 SPEA OHMM 99 000 O0 0 10 2 I 8 68 0000000000 AT60 SPEA OHMM 99 000 00 0 10 2 1 8 68 0000000000 AT90 SPEA OHMM 99 000 00 0 10 2 I 8 68 0000000000 12A SPEA MS 99 636 21 0 10 2 i 8 68 0000000000 AIEC SPEA MM/M 99 000 00 0 10 2 28 224 68 0000020000 13A SPEA MM/M 99 000 O0 0 10 2 28 224 68 0000020000 AIBT SPEA DEGF 99 000 00 0 10 2 1 8 68 0000000000 AIPO SPEA PU 99 000 00 0 10 2 1 8 68 0000000000 AIFC SPEA MM/M 99 000 00 0 10 2 28 224 68 0000000000 AISE SPEA MM/M 99 000 O0 0 10 2 28 224 68 0000020000 AIBC SPEA MM/M 99 000 O0 0 10 2 28 224 68 0000000000 AQAB SPEA MM/M 99 000 O0 0 10 2 8 64 68 0000000000 AQAF SPEA MM/M 99 000 00 0 10 2 8 64 68 0000000000 ATCO SPEA MM/M 99 000 O0 0 10 2 5 40 68 0000000000 ATCB SPEA MM/M 99 000 O0 0 10 2 5 40 68 0000000000 ATPR SPEA 0HMM 99 000 00 0 10 2 45 360 68 0000000000 ACRS SPEA 0HMM 99 000 O0 0 10 2 1 8 68 0000000000 14A SPEA MS 99 636 21 0 10 I i 4 68 0000000000 15A SPEA MS 99 636 21 0 10 1 1 4 68 0000000000 16A SPEA MS 99 636 21 0 10 I 1 4 68 0000000000 Verification Listing ~,~umoerger Alaska Computing Center ** DATA ** DEPTH = 15367.000 FEET 17-JUL-1995 BS.SPEA 6.750 CS.SPEA 1918.977 ETIM.SPEA 0.000 MARK.SPEA 35.000 RSP.SPEA -81.000 RSPA.SPEA 1.000 HTEN.SPEA 205.486 MRES.SPEA 0.390 ABS.SPEA 0.249 FCD.SPEA 7.625 STIA.SPEA 0.532 STIT.SPEA 0.532 BDQC.SPEA 0.000 DRHO.SPEA 0.252 LURH.SPEA 2.012 PEF.SPEA 6.382 QRSS.SPEA 0.811 QSS.SPEA 0.110 NRHO.SPEA 2.296 RLL.SPEA 315.532 RLIT.SPEA 118.324 LSHV.SPEA 1364.829 RSS2.SPEA 457.367 SSHV.SPEA 1416.719 LL.SPEA 315.532 LU.SPEA 670.505 SS1.SPEA 357.482 SS2.SPEA 457.367 DRTA.SPEA 0.000 TALP.SPEA 1.267 RCFT.SPEA 3480.985 CNTC.SPEA 5628.981 RGR.SPEA 37.895 TIME.SPEA 0.000 MTEM.SPEA 174.338 AMTE.SPEA 174.338 DPHI.SPEA 21.448 PHND.SPEA 21.448 NPL.SPEA 12.306 NPOR.SPEA 13.167 1A.SPEA -999.250 AIBP.SPEA -999.250 AIFF.SPEA -999.250 ACBS.SPEA -999.250 ACRB.SPEA -999.250 ACCF.SPEA -999.250 2A.SPEA -999.250 3A.SPEA -999.250 6A.SPEA -999.250 7A.SPEA -999.250 IOA.SPEA -999.250 11A.SPEA -999.250 AT30.SPEA -999.250 AT60.SPEA -999.250 AIEC.SPEA -999.250 13A.SPEA -999.250 AIF¢.SPEA -999.250 AISE.SPEA -999.250 AQAF.SPEA -999.250 ATCO.SPEA -999.250 ACRS.SPEA -999.250 14A.SPEA 0.000 ** DEPTH = 14965.000 FEET BS.SPEA 6.750 CS.SPEA 1805.238 ETIM.SPEA 809.088 MARK.SPEA 34.000 RSP.SPEA 112.750 RSPA.SPEA 0.875 HTEN.SPEA 1136.245 MRES.SPEA 0.412 ABS.SPEA 0.249 FCD.SPEA 7.625 STIA.SPEA 0.000 STIT.SPEA 0.000 BDQC.SPEA 0.000 DRHO.SPEA 0.067 LURH.SPEA 2.436 PEF.SPEA 3.364 QRSS.SPEA 0.747 QSS.SPEA 0.046 NRHO.SPEA 2.468 RLL.SPEA 175.147 RLIT.SPEA 86.146 LSHV.SPEA 1368.629 RSS2.SPEA 347.151 SSHV.SPEA 1419.979 LL.SPEA 173.882 LU.SPEA 321.604 SS1.SPEA 265.788 SS2.SPEA 352.234 DRTA.SPEA 0.002 TALP.SPEA 1.351 RCFT.SPEA 4226.524 CNTC.SPEA 6331.659 RGR.SPEA 43.006 TIME.SPEA 988.000 CVEL. SP. RT. AREA. IHV. ASCA. DALP. QRLS. RHOB. RLU. FFLS. FFSS. LS. CALI. RTNR. TNRA. CTEM. ATCA. TNPH. SCNL. AIBD. ACED. ACRF. 4A. 8A. ATIO. ATgO. AIBT. AIBC. ATCB. 15A. CVEL. SP. RT. AREA. IHV. ASCA. DALP. QRLS. RHOB. RLU. FFLS. FFSS. LS. CALI. RTNR. TNRA. CTEM. 12:00 SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA SPEA -31.983 0.000 28.226 0.054 0.000 -8.703 0.719 0.489 2.296 670.505 -0.017 0.005 650.784 3.153 1.571 1.496 179.600 164.011 13.167 2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 -30.087 193.750 40.783 0.222 67.659 172.544 0.192 0.629 2.495 328.390 0.074 0.075 334,684 6.375 1.445 1.421 184.100 TENS.SPEA SPAR.SPEA HV.SPEA AFCD.SPEA ICV.SPEA ASFI.SPEA LSRH.SPEA QLS.SPEA S1RH.SPEA RLS.SPEA RSS1.SPEA RCAL.SPEA LITH.SPEA RGCN.SPEA RCNT.SPEA CFTC.SPEA RMTE.SPEA DTEM.SPEA NPHI.SPEA GR.SPEA AIMR.SPEA ACCB.SPEA ABFR.SPEA 5A.SPEA 9A.SPEA AT20.SPEA 12A.SPEA AIPO.SPEA AQAB.SPEA ATPR.SPEA 16A.SPEA TENS.SPEA SPAR.SPEA HV.SPEA AFCD.SPEA ICV.SPEA ASFI.SPEA LSRH.SPEA QLS.SPEA S1RH.SPEA RLS.SPEA RSS1.SPEA RCAL.SPEA LITH.SPEA RGCN.SPEA RCNT.SPEA CFTC.SPEA RMTE.SPEA PAGE: 15 3480.000 0.000 245.940 0.317 0.000 0.023 2.048 -0.159 1.621 650.784 357.482 2.218 118.324 5628.981 5545.682 3806.728 174.338 0.000 16.405 47.487 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 6525.000 193.750 248.280 0.317 -50.776 197.798 2.433 -0.020 2.283 339.342 264.631 5.544 86.297 6492.216 6396.143 4545.393 172.316 AVe Verification Listing lumberger Alaska Computing Center MTEM.SPEA 172.316 AMTE.SPEA DPHI.SPEA 9.410 PHND.SPEA NPL.SPEA 8.317 NPOR.SPEA 1A.SPEA 82.313 AIBP.SPEA AIFF.SPEA 102.074 ACBS.SPEA ACRB.SPEA 0.293 ACCF.SPEA 2A.SPEA 36.598 3A.SPEA 6A.SPEA 26.690 7A.SPEA iOA.SPEA 46.659 11A.SPEA AT30.SPEA 38.745 AT60.SPEA AIEC.SPEA 198.090 13A.SPEA AIFC.SPEA 207.927 AISE.SPEA AQAF.SPEA 215.819 ATCO.SPEA ACRS.SPEA 0.321 14A.SPEA 17-JUL-1995 12:00 172.350 ATCA.SPEA 11.000 TNPH.SPEA 11.348 SCNL.SPEA 170.243 AIBD.SPEA 3.000 ACED.SPEA 28.704 ACRF.SPEA 19.889 4A.SPEA 46.659 8A.SPEA 46.659 ATiO.SPEA 40.783 AT90.SPEA 198.050 AIBT.SPEA 4.532 AIBC.SPEA 36.598 ATCB.SPEA -999.250 15A.SPEA 168.340 11.916 2 6.377 -999.250 34.839 25.810 46.659 27.324 37.467 172.350 25.857 46.659 -999.250 DTEM.SPEA NPHI.SPEA GR.SPEA AIMR.SPEA ACCB.SPEA ABFR.SPEA 5A.SPEA 9A.SPEA AT20.SPEA 12A.SPEA AIP0.SPEA AQAB.SPEA ATPR.SPEA 16A.SPEA PAGE: 16 0.000 12.384 50.584 0.646 3409.466 6.332 24.520 46.659 50.280 494.000 9.898 82.256 28.326 -999.250 END OF DATA ** **** FILE TRAILER **** FILE NAME : SPEA .014 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/30 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER FILE NAME : SPEA .016 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/30 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** coo 1 66 0 2 66 0 3 79 2306 4 66 1 5 66 1 6 73 0 7 65 IN ,ape Verification Listing ochlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 17 9 65 .lIN 11 66 3 12 68 -999. 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 ** SET TYPE - CHAN ** ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS SPEA IN 99 282 01 0 12 i i 4 68 0000000000 CS SPEA F/HR 99 636 21 0 12 I I 4 68 0000000000 CVEL SPEA F/MN 99 636 O0 0 12 1 I 4 68 0000000000 TENS SPEA LBF 99 635 21 0 12 I i 4 68 0000000000 ETIM SPEA S 99 636 21 0 12 I I 4 68 0000000000 MARK SPEA F 99 150 01 0 12 1 1 4 68 0000000000 SP SPEA MV 99 010 0t 0 12 i I 4 68 0000000000 SPAR SPEA MV 99 010 01 0 12 i I 4 68 0000000000 RSP SPEA MV 99 010 01 0 12 I 1 4 68 0000020000 RSPA SPEA MV 99 010 01 0 12 i 1 4 68 0000020000 RT SPEA OHMM 99 935 01 0 12 1 1 4 68 0000000000 HV SPEA V 99 000 O0 0 12 1 1 4 68 0000000000 HTEN SPEA LBF 99 000 O0 0 12 I 1 4 68 0000000000 MRES SPEA OHMM 99 000 O0 0 12 1 I 4 68 0000000000 AREA SPEA FT2 99 280 04 0 12 I I 4 68 0000000000 AFCD SPEA FT2 99 282 01 0 12 i i 4 68 0000000000 ABS SPEA FT2 99 282 01 0 12 I I 4 68 0000000000 FCD SPEA IN 99 282 01 0 12 I I 4 68 0000000000 IHV SPEA F3 99 282 01 0 12 I i 4 68 0000000000 ICV SPEA F3 99 282 01 0 12 1 1 4 68 0000000000 STIA SPEA F 99 000 O0 0 12 I i 4 68 0000000000 STIT SPEA F 99 000 O0 0 12 I I 4 68 0000000000 ASCA SPEA MV 99 000 O0 0 12 1 I 4 68 0000000000 ASFI SPEA MV 99 000 O0 0 12 i i 4 68 0000000000 BDQC SPEA 99 000 O0 0 12 1 1 4 68 0000000000 DRHO SPEA G/C3 99 356 01 0 12 1 1 4 68 0000000000 DALP SPEA 99 356 01 0 12 i I 4 68 0000000000 LSRH SPEA G/C3 99 350 02 0 12 1 1 4 68 0000000000 LURH SPEA G/C3 99 350 02 0 12 I I 4 68 0000000000 PEF SPEA 99 358 01 0 12 I I 4 68 0000000000 QRLS SPEA G/C3 99 354 01 0 12 i I 4 68 0000000000 QLS SPEA G/C3 99 354 01 0 12 1 i 4 68 0000000000 QRSS SPEA G/C3 99 354 01 0 12 i i 4 68 0000000000 QSS SPEA G/C3 99 354 01 0 12 I i 4 68 0000000000 RHOB SPEA G/C3 99 350 02 0 12 1 i 4 68 0000000000 S1RH SPEA G/C3 99 350 02 0 12 1 i 4 68 0000000000 Verification Listing ~cnlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NRHO SPEA G/C3 99 350 01 0 12 i I 4 68 0000000000 RLL SPEA CPS 99 354 02 0 12 I 1 4 68 0000020000 RLU SPEA CPS 99 354 02 0 12 1 RLS SPEA CPS 99 354 02 0 12 1 RLIT SPEA CPS 99 354 02 0 12 1 LSHV SPEA V 99 354 O0 0 12 1 FFLS SPEA 99 354 O0 0 12 1 RSS1 SPEA CPS 99 354 01 0 12 1 RSS2 SPEA CPS 99 354 01 0 12 1 SSHV SPEA V 99 354 O0 0 12 1 FFSS SPEA 99 354 O0 0 12 1 RCAL SPEA IN 99 280 01 0 12 1 LL SPEA CPS 99 354 01 0 12 1 LU SPEA CPS 99 354 01 0 12 1 LS SPEA CPS 99 354 01 0 12 1 LITH SPEA CPS 99 354 01 0 12 1 SS1 SPEA CPS 99 354 02 0 12 1 SS2 SPEA CPS 99 354 02 0 12 1 CALI SPEA IN 99 280 01 0 12 1 RGCN SPEA CPS 99 000 O0 0 12 1 DRTA SPEA 99 000 O0 0 12 1 TALP SPEA 99 000 O0 0 12 1 RTNR SPEA 99 000 O0 0 12 1 RCNT SPEA CPS 99 000 O0 0 12 1 RCFT SPEA CPS 99 000 O0 0 12 1 CNTC SPEA CPS 99 000 O0 0 12 1 TNRA SPEA 99 000 O0 0 12 1 CFTC SPEA CPS 99 000 O0 0 12 1 RGR SPEA GAPI 99 000 O0 0 12 1 TIME SPEA MS 99 636 21 0 12 1 CTEM SPEA DEGF 99 000 O0 0 12 1 RMTE SPEA DEGF 99 000 O0 0 12 1 MTEM SPEA DEGF 99 000 O0 0 12 1 AMTE SPEA DEGF 99 000 O0 0 12 1 ATCA SPEA DEGF 99 000 O0 0 12 1 DTEM SPEA DFHF 99 000 O0 0 12 1 DPHI SPEA PU 99 890 01 0 12 1 PHND SPEA PU 99 890 01 0 12 1 TNPH SPEA PU 99 000 O0 0 12 1 NPHI SPEA PU 99 000 O0 0 12 1 NPL SPEA PU 99 000 O0 0 12 1 NPOR SPEA PU 99 000 O0 0 12 1 SCNL SPEA 99 000 O0 0 12 1 GR SPEA GAPI 99 000 O0 0 12 1 lA SPEA MS 99 636 21 0 12 12 AIBP SPEA PSI 99 000 O0 0 12 2 AIBD SPEA IN 99 000 O0 0 12 2 AIHR SPEA OHMM 99 000 O0 0 12 2 AIFF SPEA 99 000 O0 0 12 2 ACBS SPEA 99 000 O0 0 12 2 ACED SPEA IN 99 000 O0 0 12 2 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 2 4 48 8 8 8 8 8 8 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 79 68 68 68 68 68 68 68 68 0000020000 0000020000 0000020000 0000020000 O0OO020000 0000020000 0O00020OOO 0000000000 O0O002000O 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0040000000 0000000000 0000000000 0000000000 0442000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0242000400 0242000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 18 ~ape Verification Listing Sc~lumoerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM ACCB SPEA MM/M 99 000 O0 0 12 2 1 8 ACRB SPEA ACCF SPEA ACRF SPEA ABFR SPEA 2A SPEA 3A SPEA 4A SPEA 5A SPEA 6A SPEA 7A SPEA 8A SPEA 9A SPEA IOA SPEA 11A SPEA ATIO SPEA AT20 SPEA AT30 SPEA AT60 SPEA ATgO SPEA 12A SPEA AIEC SPEA 13A SPEA AIBT SPEA AIPO SPEA AIFC SPEA AISE SPEA AIBC SPEA AQAB SPEA AQAF SPEA ATCO SPEA ATCB SPEA ATPR SPEA ACRS SPEA 14A SPEA 15A SPEA 16A SPEA OHMM MM/M OHMM MM/M MM/M MM/M MM/M MM/M MM/M MM/M MM/M MM/M MM/M OHMM OHMM OHMM OHMM OHMM MS MM/M MM/M DEGF PU MM/M MM/M MM/M MM/M MM/M MM/M MM/M OHMM OHMM MS MS MS REPR PROCESS CODE (HEX) 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 I 8 68 0000000000 99 000 O0 0 12 2 I 8 68 0000000000 99 000 O0 0 12 2 i 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 000 O0 0 12 2 i 8 68 0000000000 99 636 21 0 12 2 I 8 68 0000000000 99 000 O0 0 12 2 28 224 68 0000020000 99 000 O0 0 12 2 28 224 68 0000020000 99 ' 000 O0 0 12 2 I 8 68 0000000000 99 000 O0 0 12 2 I 8 68 0000000000 99 000 O0 0 12 2 28 224 68 0000000000 99 000 O0 0 12 2 28 224 68 0000020000 99 000 O0 0 12 2 28 224 68 0000000000 99 000 O0 0 12 2 8 64 68 0000000000 99 000 O0 0 12 2 8 64 68 0000000000 99 000 O0 0 12 2 5 40 68 0000000000 99 000 O0 0 12 2 5 40 68 0000000000 99 000 O0 0 12 2 45 360 68 0000000000 99 000 O0 0 12 2 1 8 68 0000000000 99 636 21 0 12 I I 4 68 0000000000 99 636 21 0 12 I 1 4 68 0000000000 99 636 21 0 12 i 1 4 68 0000000000 19 ** DATA ** ** DEPTH = 15371.000 FEET ** BS.SPEA 6.750 CS.SPEA 1884.817 CVEL.SPEA -31.414 TENS.SPEA ETIM.SPEA 0.000 MARK.SPEA 34.000 SP.SPEA 0.000 SPAR.SPEA RSP.SPEA -79.500 RSPA.SPEA 0.938 RT.SPEA 6.663 HV.SPEA HTEN.SPEA 203.361 MRES.SPEA 0.398 AREA.SPEA 0.053 AFCD.SPEA ABS.SPEA 0.249 FCD.SPEA 7.625 IHV.SPEA 0.000 ICV.SPEA STIA.SPEA 0.000 STIT.SPEA 0.000 ASCA.SPEA -14.023 ASFI.SPEA BDQC.SPEA 0.000 DRHO.SPEA 0.119 DALP.SPEA 0.487 LSRH.SPEA 3710.000 0,000 245.940 0,317 0,000 0.107 2,077 ~ape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 20 LURH.SPEA 2.052 PEF.SPEA QRSS.SPEA 0.748 QSS.SPEA NRHO.SPEA 2.192 RLL. SPEA RLIT.SPEA 112.924 LSHV.SPEA RSS2.SPEA 438.000 SSHV.SPEA LL.SPEA 305.314 LU.SPEA SS1.SPEA 311.467 SS2.SPEA DRTA.SPEA 0.000 TALP.SPEA RCFT.SPEA 3454.146 CNT¢.SPEA RGR.SPEA 26.866 TIME.SPEA MTEM.SPEA 173.880 AMTE.SPEA DPHI.SPEA 27.743 PHND.SPEA NPL.SPEA 12.341 NPOR.SPEA 1A.SPEA -999.250 AIBP.SPEA AIFF.SPEA -999.250 ACBS.SPEA ACRB.SPEA -999.250 ACCF.SPEA 2A.SPEA -999.250 3A.SPEA 6A.SPEA -999.250 7A.SPEA iOA.SPEA -999.250 11A.SPEA AT30.SPEA -999.250 AT60.SPEA AIE¢.SPEA -999.250 13A.SPEA AIFC.SPEA -999.250 AISE.SPEA AQAF.SPEA -999.250 ATCO.SPEA ACRS.SPEA -999.250 14A.SPEA 6.290 QRLS.SPEA 0.510 0.047 RHOB.SPEA 2.192 305.314 RLU.SPEA 623.175 1367.728 FFLS.SPEA 0.037 1418.970 FFSS.SPEA 0.014 623.175 LS.SPEA 616.902 438.000 CALI.SPEA 3.114 1.257 RTNR.SPEA 1.571 5584.987 TNRA.SPEA 1.496 0.000 CTEM.SPEA 184.100 173.880 ATCA.SPEA 170.156 27.743 TNPH.SPEA 13.165 13.165 SCNL.SPEA 2 -999.250 AIBD.SPEA -999.250 -999.250 ACED.SPEA -999.250 -999.250 ACRF.SPEA -999.250 -999.250 4A.SPEA -999.250 -999.250 8A.SPEA -999.250 -999.250 ATIO.SPEA -999.250 -999.250 AT90.SPEA -999.250 -999.250 AIBT.SPEA -999.250 -999.250 AIBC.SPEA -999.250 -999.250 ATCB.SPEA -999.250 0.000 15A.SPEA 0.000 ** DEPTH = 13834.500 FEET BS.SPEA 6.750 CS.SPEA ETIM.SPEA 3095.014 MARK.SPEA RSP.SPEA 178.063 RSPA.SPEA HTEN.SPEA 1209.860 MRES.SPEA ABS.SPEA 0.249 FCD.SPEA STIA.SPEA 0.000 STIT.SPEA BDQC.SPEA 0.000 DRHO.SPEA LURH.SPEA 2.624 PEF.SPEA QRSS.SPEA 0.573 QSS.SPEA NRHO.SPEA 1.972 RLL.SPEA RLIT.SPEA 24.720 LSHV.SPEA RSS2.SPEA 155.605 SSHV.SPEA LL.SPEA 109.533 LU.SPEA SS1.SPEA 90.157 SS2.SPEA DRTA.SPEA 0.030 TALP.SPEA RCFT.SPEA 1436.455 CNTC.SPEA RGR.SPEA 23.284 TIME.SPEA HTEM.SPEA 163.881 AMTE.SPEA DPHI.SPEA 42.906 PHND.SPEA NPL.SPEA 11.649 NPOR.SPEA 1A.SPEA 82.500 AIBP.SPEA AIFF.SPEA 2.940 ACBS.SPEA ACRB.SPEA 5.010 ACCF.SPEA 2A.SPEA 0.451 3A.SPEA 6A.SPEA 11.680 7A.SPEA iOA.SPEA -35.575 11A.SPEA AT30.SPEA 1950.000 AT60.SPEA AIEC.SPEA -3093.179 13A.SPEA 1801.866 CVEL.SPEA -30.031 34.000 SP.SPEA 257.563 0.938 RT. SPEA 28.195 0.456 AREA.SPEA 0.256 7.625 IHV.SPEA 355.589 0.000 ASCA.SPEA 193.846 -0.653 DALP.SPEA -1.816 23.441 QRLS.SPEA 0.583 -0.128 RHOB.SPEA 1.942 106.841 RLU.SPEA 225.151 1368.422 FFLS.SPEA 0.022 1421.945 FFSS.SPEA -0.014 224.889 LS.SPEA 221.978 157.192 CALI.SPEA 6.854 0.626 RTNR.SPEA 1.843 2496.006 TNRA.SPEA 1.674 989.000 CTEM.SPEA 179.600 163.882 ATCA.SPEA 170.393 41.100 TNPH.SPEA 15.872 14.065 SCNL.SPEA 2 157.333 AIBD.SPEA 6.847 1.000 ACED.SPEA -999.250 98.421 ACRF.SPEA 10.160 0.475 4A.SPEA 0.500 -35.575 8A.SPEA -35.575 -35.575 ATiO.SPEA 1950.000 28.195 ATgO.SPEA 85.620 -3088.681 AIBT.SPEA 163.883 QLS.SPEA SiRH.SPEA RLS.SPEA RSS1.SPEA RCAL.SPEA LITH.SPEA RGCN.SPEA RCNT.SPEA CFTC.SPEA RMTE.SPEA DTEM.SPEA NPHI.SPEA GR.SPEA AIMR.SPEA ACCB.SPEA ABFR.SPEA 5A. SPEA 9A.SPEA AT20.SPEA 12A.SPEA AIPO.SPEA AQAB.SPEA ATPR.SPEA 16A.SPEA TENS.SPEA SPAR.SPEA HV.SPEA AFCD.SPEA ICV.SPEA ASFI.SPEA LSRH.SPEA QLS.SPEA SiRH.SPEA RLS.SPEA RSS1.SPEA RCAL.SPEA LITH.SPEA RGCN.SPEA RCNT.SPEA CFTC.SPEA RMTE.SPEA DTEM.SPEA NPHI.SPEA GR.SPEA AIMR.SPEA A¢CB.SPEA ABFR.SPEA 5A.SPEA 9A.SPEA AT20.SPEA 12A.SPEA AIPO.SPEA -0.138 1.838 616.902 311.467 2.178 112.924 5584.987 5502.339 3777.377 173.880 0.000 16.440 33.666 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 6215.000 257.563 248.280 0.317 -20.010 254.914 2.597 -0.066 4.032 219.417 90.363 6.039 22.761 2679.953 2640.294 1496.506 163.881 0.000 15.742 28.581 0.678 199.598 4353.728 35.468 -35.575 1950.000 494.500 58.317 ,ape Verification Listing Sclilumberger Alaska Computing Center 17-JUL-1995 12:00 AIFC.SPEA -3232.903 AISE.SPEA 4.635 AIBC.SPEA AQAF.SPEA -3761.455 ATCO.SPEA 0.451 ATCB.SPEA ACRS.SPEA 9.961 14A.SPEA -999.250 15A.SPEA ** END OF DATA ** -3260.108 -35.575 -999.250 AQAB.SPEA ATPR.SPEA 16A.SPEA PAGE: 21 -3326.110 1950.000 -999.250 **** FILE TRAILER FILE NAME : SPEA .016 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/30 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : MEST .017 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/28 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 79 22146 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .tIN 11 66 1 12 68 -999. 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 Tape Verification Listing Schlumoerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) oo o -i ..... ..... .... CS NEST F/HR O0 636 21 0 13 1 CVEL NEST F/MN O0 636 O0 0 13 1 TENS NEST LBF O0 635 21 0 13 1 ETIM MEST S O0 636 21 0 13 1 MARK MEST F O0 150 01 0 13 1 DEVI MEST DEG O0 620 01 0 13 1 FNOR MEST OER O0 631 01 0 13 1 FINC MEST DEG O0 631 01 0 13 1 HAZI NEST DEG O0 630 01 0 13 1 PIAZ MEST DEG O0 630 01 0 13 1 RB MEST DEG O0 631 01 0 13 1 SDEV MEST DEG O0 620 01 0 13 1 RT NEST OHMM O0 935 01 0 13 1 HV MEST V O0 000 O0 0 13 1 HTEN NEST LBF O0 000 O0 0 13 1 MRES MEST OHMM O0 000 O0 0 13 1 SP MEST MV O0 010 01 0 13 1 SPAR NEST MV O0 010 01 0 13 1 RSP MEST MV O0 010 01 0 13 1 RSPA NEST MV O0 010 01 0 13 1 SPCF MEST O0 611 01 0 13 1 DPTR MEST DEG O0 611 01 0 13 1 DPAZ MEST DEG O0 611 01 0 13 1 QUAF MEST O0 611 01 0 13 1 DDIP NEST DEG O0 611 01 0 13 1 DDA MEST DEG O0 611 01 0 13 1 AREA NEST FT2 O0 280 04 0 13 1 AFCD MEST FT2 O0 282 01 0 13 1 ABS NEST FT2 O0 282 01 0 13 1 FCD MEST IN O0 282 01 0 13 1 IHV NEST F3 O0 282 01 0 13 1 ICV MEST F3 O0 282 01 0 13 1 ASCA NEST NV O0 000 O0 0 13 1 ASFI NEST MV O0 000 O0 0 13 1 BDQC NEST O0 000 O0 0 13 1 DRHO NEST G/C3 O0 356 01 0 13 1 DALP NEST O0 356 01 0 13 1 LSRH MEST G/C3 O0 350 02 0 13 1 LURH NEST G/C3 O0 350 02 0 13 1 PEF MEST O0 358 01 0 13 1 QRLS NEST G/C3 O0 354 01 0 13 1 QLS NEST G/C3 O0 354 01 0 13 1 QRSS NEST G/C3 O0 354 01 0 13 1 QSS NEST G/C3 O0 354 01 0 13 1 RHOB MEST G/C3 O0 350 02 0 13 1 SiRH NEST G/C3 O0 350 02 0 13 1 NRHO NEST G/C3 O0 350 01 0 13 1 RLL NEST CPS O0 354 02 0 13 1 RLU NEST CPS O0 354 02 0 13 i 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000020000 0000020000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000020000 0000020000 22 Tape Verification Listing Schlumoerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API AP! FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RLS MEST CPS O0 354 02 0 13 I I 4 68 0000020000 RLIT MEST CPS O0 354 02 0 13 I 1 LSHV MEST V O0 354 O0 0 13 1 1 FFLS MEST O0 354 O0 0 13 1 1 RSS1 MEST CPS O0 354 01 0 13 I 1 RSS2 MEST CPS O0 354 01 0 13 1 1 SSHV MEST V O0 354~00 0 13 i 1 FFSS MEST O0 354 O0 0 13 i 1 RCAL MEST IN O0 280 01 0 13 I 1 LL MEST CPS O0 354 01 0 13 1 1 LU MEST CPS O0 354 01 0 13 I 1 LS MEST CPS O0 354 01 0 13 1 1 LITH MEST CPS O0 354 01 0 13 I 1 SS1 MEST CPS O0 354 02 0 13 I 1 SS2 MEST CPS O0 354 02 0 13 I 1 CALI MEST IN O0 280 01 0 13 i 1 RGCN MEST CPS O0 000 O0 0 13 1 1 DRTA MEST O0 000 O0 0 13 i 1 TALP MEST O0 000 O0 0 13 I 1 RTNR MEST O0 000 O0 0 13 1 1 RCNT MEST CPS O0 000 O0 0 13 1 1 RCFT HEST CPS O0 000 O0 0 13 i 1 CNTC MEST CPS O0 000 O0 0 13 1 1 TNRA MEST O0 000 O0 0 13 1 1 CFTC HEST CPS O0 000 O0 0 13 i 1 RGR MEST GAPI O0 000 O0 0 13 1 1 TIME MEST MS O0 636 21 0 13 I 1 ANOR MEST F/S2 O0 631 01 0 13 I 1 GAT MEST DEGF O0 000 O0 0 13 i 1 GMT MEST DEGF O0 000 O0 0 13 1 1 CTEM MEST DEGF O0 000 O0 0 13 I 1 RMTE MEST DEGF O0 000 O0 0 13 1 1 MTEM MEST DEGF O0 000 O0 0 13 1 1 AMTE MEST DEGF O0 000 O0 0 13 i 1 ATCA MEST DEGF O0 000 O0 0 13 i 1 DTEM MEST DFHF O0 000 O0 0 13 I 1 DPHI MEST PU O0 890 01 0 13 1 1 PHND MEST PU O0 890 01 0 13 I 1 TNPH HEST PU O0 000 O0 0 13 i 1 NPHI MEST PU O0 000 O0 0 13 1 1 NPL MEST PU O0 000 O0 0 13 I 1 NPOR MEST PU O0 000 O0 0 13 I 1 SCNL MEST O0 000 O0 0 13 1 1 GR MEST GAPI O0 000 O0 0 13 i 1 6A MEST MS O0 636 21 0 13 60 1 EV MEST V O0 000 O0 0 13 60 1 BA28 MEST O0 610 O0 0 13 60 1 BA17 MEST O0 610 O0 0 13 60 1 BB17 MEST O0 610 O0 0 13 60 1 BC13 HEST O0 610 O0 0 13 60 1 BD13 MEST O0 610 O0 0 13 60 1 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 2 4 240 240 240 240 240 24O 240 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 79 68 68 68 68 68 68 68 68 0000020000 0000020000 0000020000 0000020000 0000020000 0000000000 0000020000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0O4000OO00 0000000000 0000000000 0000000000 0442000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0242000400 0242000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 23 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: ID ORDER # LOg TYPE CLASS ,OD NUMB SAMP eleM CODE (HEX) ee2s.[st co co o 6o -i ..... .... 666666666;- BA13 MEST O0 610 O0 0 13 60 1 BE13 MEST O0 610 O0 0 13 60 1 BC17 MEST O0 610 O0 0 13 60 1 ED17 MEST O0 610 O0 0 13 60 1 BA22 MEST O0 610 O0 0 13 60 1 BA23 MEST O0 610; O0 0 13 60 1 BA24 MEST O0 610 O0 0 13 60 1 BC28 MEST O0 610 O0 0 13 60 1 BA25 MEST O0 610 O0 0 13 60 1 BA26 MEST O0 610 O0 0 13 60 1 BA27 MEST O0 610 O0 0 13 60 1 BAll MEST O0 610 O0 0 13 60 1 BA12 MEST O0 610 O0 0 13 60 1 BA14 MEST O0 610 O0 0 13 60 1 BA15 MEST O0 610 O0 0 13 60 1 BA16 MEST O0 610 O0 0 13 60 1 BA18 MEST O0 610 O0 0 13 60 1 BA21MEST O0 610 O0 0 13 60 1 ECl1MEST O0 610 O0 0 13 60 1 B¢12 MEST O0 610 O0 0 13 60 1 BC14 MEST O0 610 O0 0 13 60 1 ECl5 MEST O0 610 O0 0 13 60 1 BC16 MEST O0 610 O0 0 13 60 1 BC18 MEST O0 610 O0 0 13 60 1 BC21MEST O0 610 O0 0 13 60 1 BC22 MEST O0 610 O0 0 13 60 1 BC23 MEST O0 610 O0 0 13 60 1 BC24 MEST O0 610 O0 0 13 60 1 BC25 MEST O0 610 O0 0 13 60 1 BC26 MEST O0 610 O0 0 13 60 1 BC27 MEST O0 610 O0 0 13 60 1 BE22 MEST O0 610 O0 0 13 60 1 BE23 MEST O0 610 O0 0 13 60 1 BE24 MEST O0 610 O0 0 13 60 1 ED28 MEST O0 610 O0 0 13 60 1 BE25 MEST O0 610 O0 0 13 60 1 BE26 MEST O0 610 O0 0 13 60 1 BE27 MEST O0 610 O0 0 13 60 1 BEll MEST O0 610 O0 0 13 60 1 BE12 MEST O0 610 O0 0 13 60 1 BE14 MEST O0 610 O0 0 13 60 1 BE15 MEST O0 610 O0 0 13 60 1 BE16 MEST O0 610 O0 0 13 60 1 BE18 MEST O0 610 O0 0 13 60 1 BE21MEST O0 610 O0 0 13 60 1 ED11MEST O0 610 O0 0 13 60 1 ED12 MEST O0 610 O0 0 13 60 1 ED14 MEST O0 610 O0 0 13 60 1 ED15 MEST O0 610 O0 0 13 60 1 ED16 MEST O0 610 O0 0 13 60 I 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 24 _~ Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BD18 MEST O0 610 O0 0 13 60 1 240 68 0000000000 BD21 MEST O0 610 O0 0 13 60 1 BD22 MEST O0 610 O0 0 13 60 1 BD23 MEST O0 610 O0 0 13 60 1 BD24 MEST O0 610 O0 0 13 60 1 BD25 MEST O0 610 O0 0 13 60 1 BD26 MEST O0 610 O0 0 13 60 1 BD27 MEST O0 610 O0 0 13 60 1 SB1 MEST O0 610 O0 0 13 60 1 DB1 MEST O0 610 O0 0 13 60 1 DB2 MEST O0 610 O0 0 13 60 1 DB3A MEST O0 610 O0 0 13 60 1 DB4A MEST O0 610 O0 0 13 60 1 SB2 MEST O0 610 O0 0 13 60 1 DB1A MEST O0 610 O0 0 13 60 1 DB2A MEST O0 610 O0 0 13 60 1 DB3 MEST O0 610 O0 0 13 60 1 DB4 MEST O0 610 O0 0 13 60 1 FCA× MEST M/S2 O0 000 O0 0 13 60 1 FCAY MEST M/S2 O0 000 O0 0 13 60 1 FCAZ MEST M/S2 O0 000 O0 0 13 60 1 FTIM MEST MS O0 000 O0 0 13 60 1 7A MEST O0 000 O0 0 13 60 1 8A MEST M/S2 O0 000 O0 0 13 60 1 9A MEST M/S2 O0 000 O0 0 13 60 1 iOA MEST MS O0 636 21 0 13 4 1 Cl MEST IN O0 280 41 0 13 4 1 C2 MEST IN O0 280 42 0 13 4 1 RCl MEST IN O0 280 41 0 13 4 1 RC2 MEST IN O0 280 42 0 13 4 1 PP MEST O0 000 O0 0 13 4 1 CP MEST O0 000 O0 0 13 4 1 AX MEST M/S2 O0 615 02 0 13 4 1 AY MEST M/S2 O0 615 03 0 13 4 1 AZ MEST M/S2 O0 615 01 0 13 4 1 F× MEST OER O0 000 O0 0 13 4 1 FY MEST OER O0 000 O0 0 13 4 1 EI MEST MA O0 000 O0 0 13 4 1 FZ MEST OER O0 000 O0 0 13 4 1 11A MEST MS O0 636 21 0 13 12 1 AIBP MEST PSI O0 000 O0 0 13 2 1 AIBD MEST IN O0 000 O0 0 13 2 1 AIMR MEST OHMM O0 000 O0 0 13 2 1 AIFF MEST O0 000 O0 0 13 2 1 ACBS MEST O0 000 O0 0 13 2 1 ACED MEST IN O0 000 O0 0 13 2 1 ACCB HEST MH/M O0 000 O0 0 13 2 1 ACRB MEST OHMM O0 000 O0 0 13 2 1 ACCF MEST MM/M O0 000 O0 0 13 2 1 ACRF MEST OHMM O0 000 O0 0 13 2 1 ABFR MEST O0 000 O0 0 13 2 I 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 240 16 16 16 16 16 16 16 16 16 16 16 16 16 16 48 8 8 8 8 8 8 8 8 8 8 8 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 25 ~S Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) MM/M MM/M MM/M MM/M MM/M MM/M MM/M MH/M MM/M MM~M OHMM OHMM OHMM OHHM OHMM MS MM/M MM/M DEGF PU MM/M MM/M MM/M MM/M MM/M MM/M MM/M OHMM MS MS MS 12A MEST 13A MEST 14A MEST 15A MEST 16A MEST 17A MEST 18A MEST 19A MEST 20A MEST 21A MEST ATIO MEST AT20 MEST AT30 MEST AT60 MEST AT90 HEST 22A MEST AIE¢ MEST 23A MEST AIBT MEST AIPO MEST AIFC MEST AISE MEST AIBC MEST AQAB MEST AQAF MEST ATCO MEST ATCB MEST ACRS MEST 24A MEST 25A MEST 26A MEST O0 000 O0 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 I 8 68 0000000000 O0 000 O0 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 I 8 68 0000000000 O0 000 O0 0 13 2 i 8 68 0000000000 O0 000 O0 0 13 2 I 8 68 0000000000 O0 000 O0 0 13 2 i 8 68 0000000000 O0 000 O0 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 i 8 68 0000000000 O0 000 O0 0 13 2 I 8 68 0000000000 O0 000 O0 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 i 8 68 0000000000 O0 000 O0 0 13 2 I 8 68 0000000000 O0 636 21 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 28 224 68 0000020000 O0 000 O0 0 13 2 28 224 68 0000020000 O0 000 O0 0 13 2 I 8 68 0000000000 O0 000 O0 0 13 2 1 8 68 0000000000 O0 000 O0 0 13 2 28 224 68 0000000000 O0 000 O0 0 13 2 28 224 68 0000020000 O0 000 O0 0 13 2 28 224 68 0000000000 O0 000 O0 0 13 2 8 64 68 0000000000 O0 000 O0 0 13 2 8 64 68 0000000000 O0 000 O0 0 13 2 5 40 68 0000000000 O0 000 O0 0 13 2 5 40 68 0000000000 O0 000 O0 0 13 2 i 8 68 0000000000 O0 636 21 0 13 i 1 4 68 0000000000 O0 636 21 0 13 1 I 4 68 0000000000 O0 636 21 0 13 1 i 4 68 0000000000 26 ** DATA ** ** DEPTH = 12954.000 FEET ** BS.MEST 9.875 CS.MEST 39.533 CVEL.MEST -0.659 TENS.MEST ETIM.MEST 0.000 MARK.MEST 0.000 DEVI.MEST 56.465 FNOR.MEST FINC.MEST 73.234 HAZI.MEST 49.674 PiAZ.MEST 207.022 RB.MEST SDEV.MEST 56.465 RT.MEST 12.147 HV.MEST 243.600 HTEN.MEST MRES.MEST 0.584 SP.MEST -30.000 SPAR.MEST -30.000 RSP.MEST RSPA.HEST 0.813 SPCF.MEST 0.000 DPTR.MEST -999.250 DPAZ.MEST QUAF.MEST 0.000 DDIP.MEST -999.250 DDA.MEST -999.250 AREA.MEST AFCD.MEST 0.317 ABS.MEST 0.532 FCD.MEST 7.625 IHV.MEST ICV.HEST -0.097 ASCA.MEST 40.836 ASFI.HEST -0.006 BDQC.MEST DRHO.MEST 0.126 DALP.MEST 0.261 LSRH.MEST 2.540 LURH.MEST PEF.MEST 3.869 QRLS.MEST 0.699 QLS.MEST 0.051 QRSS.MEST QSS.MEST 0.084 RHOB.MEST 2.673 SiRH.MEST 2.288 NRHO.MEST RLL.MEST 148.108 RLU.MEST 261.726 RLS.MEST 278.971 RLIT.MEST 1305.000 0.570 167.017 -171.791 -97.438 -999.250 0.123 0.062 0.000 2.570 0.784 2.673 65.939 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 27 LSHV.MEST 1364.407 SSHV.MEST 1412.939 LU.MEST 261.726 SS2.MEST 337.280 TALP.MEST 1.707 CNTC.MEST 3005.205 TIME.MEST 0.000 CTEM.MEST 184.100 ATCA.MEST 161.309 TNPH.MEST 46.391 SCNL.MEST 2 BA28.MEST -999.250 BD13.MEST -999.250 BC17.MEST -999.250 BA24.MEST -999.250 BA27.MEST -999.250 BA15.MEST -999.250 BC11.MEST -999.250 BC16.MEST -999.250 BC23.MEST -999.250 BC27.MEST -999.250 BD28.MEST -999.250 BB11.MEST -999.250 BB16.MEST -999.250 BD12.HEST -999.250 BD18.MEST -999.250 BD24.HEST -999.250 SB1.MEST -999.250 DB4A.MEST -999.250 DB3.HEST -999.250 FCAZ.MEST -999.250 9A.MEST -999.250 RCI.MEST -999.250 AX.MEST -999.250 FY.MEST -999.250 AIBP.MEST -999.250 ACBS.MEST -999.250 ACCF.MEST -999.250 13A.MEST -999.250 17A.MEST -999.250 21A.MEST -999.250 AT60.MEST -999.250 23A.MEST -999.250 AISE.MEST -999.250 ATCO.MEST -999.250 25A.MEST 0.000 ** DEPTH : FFLS.MEST FFSS.MEST LS.MEST CALI.MEST RTNR.MEST TNRA.MEST ANOR.MEST RMTE.MEST DTEM.MEST NPHI.MEST GR.MEST BA17.MEST BB28.MEST BD17.MEST BC28.MEST BA11.MEST BA16.MEST BC12.MEST BC18.MEST BC24.MEST BB22.MEST BB25.MEST BB12.MEST BB18.MEST BD14.MEST BD21.MEST BD25.MEST DB1.MEST SB2.MEST DB4.MEST FTIM.MEST iOA.MEST RC2.MEST AY.MEST EI.MEST AIBD.MEST ACED.MEST ACRF.MEST 14A.MEST 18A.MEST ATIO.MEST AT90.MEST AIBT.MEST AIBC.MEST ATCB.MEST 26A.MEST 12675.000 FEET 0.118 -0.070 278.971 3.153 4.000 3.808 32.534 155.983 0.000 53.400 109.065 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 BS.MEST 9.875 CS.MEST 1037.569 ETIM.MEST 1217.723 MARK.MEST 0.000 FINC.MEST 73.248 HAZI.MEST 49.867 SDEV.MEST 56.554 RT.MEST 11.969 MRES.MEST 0.583 SP.MEST -27.125 RSPA.MEST 0.875 SPCF.MEST 0.000 RSS1.MEST RCAL.MEST LITH.MEST RGCN.MEST RCNT.MEST CFTC.MEST GAT.MEST MTEM.MEST DPHI.MEST NPL.MEST 6A.MEST BB17.MEST BA13.MEST BA22.MEST BA25.MEST BA12.MEST BA18.MEST BC14.MEST BC21.MEST BC25.MEST BB23.MEST BB26.MEST BB14.MEST BB21.MEST BD15.MEST BD22.MEST BD26.MEST DB2.MEST DBIA.MEST FCAX.MEST 7A.MEST C1.MEST PP.MEST AZ.MEST FZ.MEST AIMR.MEST ACCB.MEST ABFR.MEST 15A.MEST 19A.MEST AT20.MEST 22A.MEST AIPO.MEST AQAB.MEST ACRS.MEST CVEL.MEST DEVI.MEST PiAZ.MEST HV.MEST SPAR.MEST DPTR.MEST 275.903 2.142 65.939 3005.205 2960.733 794.857 158.887 155.983 -1.410 45.887 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -17.293 56.554 207.934 248.280 -27.125 -999.250 RSS2.MEST LL.MEST SSl.MEST DRTA.MEST RCFT.MEST RGR.MEST GMT.MEST AMTE.MEST PHND.MEST NPOR.MEST EV.MEST BC13.MEST BB13.MEST BA23.MEST BA26.MEST BA14.MEST BA21.MEST BC15.MEST BC22.MEST BC26.MEST BB24.MEST BB27.MEST BB15.MEST BD11.MEST BD16.MEST BD23.MEST BD27.MEST DB3A.MEST DB2A.MEST FCAY.MEST 8A.MEST C2.MEST CP.MEST FX.MEST 11A.MEST AIFF.MEST ACRB.MEST 12A.MEST 16A.MEST 20A.MEST AT30.MEST AIEC.MEST AIFC.MEST AQAF.MEST 24A.MEST TENS.MEST FNOR.MEST RB.MEST HTEN.MEST RSP.MEST DPAZ.MEST 337.280 148.108 275.903 0.000 726.841 92.030 193.109 155.983 -1.410 46.391 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 840.OOO 0.570 167.487 684.462 -94.563 -999.250 _~ Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 28 QUAF.MEST AFCD.MEST ICV.MEST DRHO.MEST PEF.MEST QSS.MEST RLL.MEST LSHV.MEST SSHV.MEST LU.MEST SS2.MEST TALP.MEST CNTC.MEST TIME.MEST CTEM.MEST ATCA.MEST TNPH.HEST SCNL.MEST BA28.MEST BD13.MEST BC17.MEST BA24.MEST BA27.MEST BA15.MEST B¢11.MEST BC16.MEST BC23.MEST BC27.MEST BD28.MEST BB11.MEST BB16.MEST BD12.MEST BD18.MEST BD24.MEST SB1.MEST DB4A.MEST DB3.MEST FCAZ.MEST 9A.MEST RC1.MEST A×.MEST FY.MEST AIBP.MEST ACBS.MEST ACCF.MEST 13A.MEST 17A.MEST 21A.MEST AT60.MEST 23A.MEST AISE.MEST AT¢O.MEST 25A.MEST -999.250 0.317 55.852 0.014 2.665 0.075 180.189 1363.458 1413.416 347.584 326.223 1.237 4862.549 2600.000 184.100 161.061 16.249 2 -1.500 -1.500 -1 500 -1 500 -1 500 -1 500 -1 500 -1 500 -1 500 -1 500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 5.706 174.287 10.576 8.095 0.154 148.635 2.000 57.708 62.428 86.779 86.779 11.969 295.964 4.197 35.895 -999.250 DDIP.MEST -999.250 DDA.MEST -999.250 ABS.MEST 0.532 FCD.MEST 7.625 ASCA.MEST 23.308 ASFI.MEST 11.582 DALP.MEST -0.076 LSRH.MEST 2.397 QRLS.MEST 0.586 QLS.MEST -0.063 RHOB.MEST 2.417 SIRH.MEST 2.340 RLU.MEST 335.245 RLS.MEST 347.812 FFLS.MEST 0.040 RSS1.MEST 239.713 FFSS.MEST -0.039 RCAL.MEST 9.550 LS.MEST 355.810 LITH.MEST 109.855 CALI.MEST 10.175 RGCN.MEST 4902.770 RTNR.MEST 1.858 RCNT.MEST 4830.217 TNRA.MEST 1.822 CFTC.MEST 2646.470 ANOR.MEST 32.537 GAT.MEST 159.309 RMTE.MEST 155.719 MTEM.MEST 155.719 DTEM.MEST 0.000 DPHI.MEST 14.111 NPHI.MEST 14.444 NPL.MEST 10.361 GR.MEST 40.858 6A.MEST 86.750 BA17.MEST -1.500 BB17.MEST -1.500 BB28.MEST -1.500 BA13.MEST -1.500 BD17.MEST -1.500 BA22.MEST -1.500 BC28.MEST -1.500 BA25.MEST -1.500 BA11.MEST -1.500 BA12.MEST -1.500 BA16.MEST -1.500 BA18.MEST -1.500 BC12.MEST -1.500 BC14.MEST -1.500 BC18.MEST -1.500 BC21.MEST -1.500 BC24.MEST -1.500 BC25.MEST -1.500 BB22.MEST -1.500 BB23.MEST -1.500 BB25.MEST -1.500 BB26.MEST -1.500 BB12.MEST -1.500 BB14.MEST -1.500 BB18.MEST -1.500 BB21.MEST -1.500 BD14.MEST -1.500 BD15.MEST -1.500 BD21.MEST -1.500 BD22.MEST -1.500 BD25.MEST -1.500 BD26.MEST -1.500 DB1.MEST -1.500 DB2.MEST -1.500 SB2.MEST -1.500 DBiA.MEST -1.500 DB4.MEST -1.500 FCAX.MEST 8.096 FTIM.MEST 33.456 7A.MEST 8.000 IOA.MEST 1300.000 ¢i.MEST 9.970 RC2.MEST 10.474 PP.MEST 43.967 AY.MEST 1.764 AZ.MEST 5.565 EI.MEST 1746.960 FZ.MEST 0.421 AIBD.MEST 9.989 AIMR.MEST 0.824 ACED.MEST -999.250 ACCB.MEST 1186.053 ACRF.MEST 17.328 ABFR.MEST 3.425 14A.MEST 69.555 15A.MEST 83.547 18A.MEST 86.779 19A.MEST 86.779 ATiO.MEST 27.859 AT20.MEST 16.018 ATgO.MEST 11.416 22A.MEST 1300.000 AIBT.MEST 155.719 AIPO.MEST 12.349 AIB¢.MEST 59.085 AQAB.MEST 73.346 ATCB.MEST 86.779 ACRS.MEST 0.846 26A.MEST -999.250 AREA.MEST IHV.MEST BDQC.MEST LURH.MEST QRSS.MEST NRHO.MEST RLIT.MEST RSS2.MEST LL.MEST SS1.MEST DRTA.MEST RCFT.MEST RGR.MEST GMT.MEST AMTE.MEST PHND.MEST NPOR.MEST EV.MEST BC13.MEST BB13 MEST BA23 MEST BA26 MEST BA14 MEST BA21MEST BC15 MEST BC22 MEST B¢26.MEST BB24.MEST BB27.MEST BB15.MEST BD11.MEST BD16.MEST BD23.HEST BD27.MEST DB3A.MEST DB2A.MEST FCAY.MEST 8A.MEST C2.MEST CP.MEST FX.MEST 11A.MEST AIFF.MEST ACRB.MEST 12A.MEST 16A.MEST 20A.MEST AT30.MEST AIEC.MEST AIFC.HEST AQAF.MEST 24A.MEST 0.536 144.321 0.000 2.379 0.776 2.435 113.646 333.907 182.018 252.189 0.039 2364.977 32.262 195.069 155.719 13.016 16.106 2.835 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 -1.500 1.747 43.945 9.876 44.304 0.351 216.625 65.572 0.843 35.895 87.600 86.779 14.377 296.001 294.904 294.213 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 29 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : MEST .017 SERVICE : PLAYBA _VERSION : 7C0-427 DATE : 95/05/28 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : MEST .018 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/28 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 22146 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .lIN 11 66 1 12 68 -999. 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: ** SET TYPE - CHAN ** ............ .... ..... ..... 2 ..... .... 6666666666- CS "EST F/HR O0 636 21 0 14 i i 4 68 0000000000 CVEL MEST F/MN O0 636 O0 0 14 1 TENS MEST LBF O0 635 21 0 14 1 ETIM MEST S O0 636 21 0 14 1 MARK MEST F O0 150 01 0 14 1 DEVI MEST DEG O0 620 01 0 14 1 FNOR MEST OER O0 631 01 0 14 1 FINC MEST DEG O0 631 01 0 14 1 HAZI MEST DEG O0 630 01 0 14 1 P1AZ MEST DEG O0 630 01 0 14 1 RB MEST DEG O0 631 01 0 14 1 SDEV MEST DEG O0 620 01 0 14 1 RT MEST OHMM O0 935 01 0 14 1 HV MEST V O0 000 O0 0 14 1 HTEN MEST LBF O0 000 O0 0 14 1 MRES MEST OHMM O0 000 O0 0 14 1 SP MEST MV O0 010 01 0 14 1 SPAR MEST MV O0 010 01 0 14 1 RSP MEST MY O0 010 01 0 14 1 RSPA MEST MV O0 010 01 0 14 1 SPCF MEST O0 611 01 0 14 1 DPTR MEST DEG O0 611 01 0 14 1 DPAZ MEST DEG O0 611 01 0 14 1 QUAF MEST O0 611 01 0 14 1 DDIP MEST DEG O0 611 01 0 14 1 DDA MEST DEG O0 611 01 0 14 1 AREA MEST FT2 O0 280 04 0 14 1 AFCD MEST FT2 O0 282 01 0 14 1 ABS MEST FT2 O0 282 01 0 14 1 FCD MEST IN O0 282 01 0 14 1 IHV MEST F3 O0 282 01 0 14 1 ICV MEST F3 O0 282 01 0 14 1 ASCA MEST MV O0 000 O0 0 14 1 ASFI MEST MV O0 000 O0 0 14 1 BDQC MEST O0 000 O0 0 14 1 DRHO MEST G/C3 O0 356 01 0 14 1 DALP MEST O0 356 01 0 14 1 LSRH MEST G/C3 O0 350 02 0 14 1 LURH MEST G/C3 O0 350 02 0 14 1 PEF HEST O0 358 01 0 14 1 QRLS MEST G/C3 O0 354 01 0 14 1 QLS MEST G/C3 O0 354 01 0 14 1 QRSS MEST G/C3 O0 354 01 0 14 1 QSS MEST G/C3 O0 354 01 0 14 1 RHOB MEST G/C3 O0 350 02 0 14 1 S1RH MEST G/C3 O0 350 02 0 14 1 NRHO MEST G/C3 O0 350 01 0 14 1 RLL MEST CPS O0 354 02 0 14 1 RLU MEST CPS O0 354 02 0 14 1 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000020000 0000020000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0OO0020000 00O0020000 30 -IS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 31 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) oo o RLIT MEST CPS O0 354 02 0 14 I 1 LSHV MEST V O0 354 O0 0 14 I 1 FFLS MEST O0 354 O0 0 14 I 1 RSS1 MEST CPS O0 354 01 0 14 i 1 RSS2 MEST CPS O0 354 01 0 14 I 1 SSHV MEST V O0 354'00 0 14 i 1 FFSS MEST O0 354 O0 0 14 i 1 RCAL MEST IN O0 280 01 0 14 i 1 LL MEST CPS O0 354 01 0 14 I 1 LU MEST CPS O0 354 01 0 14 I 1 LS MEST CPS O0 354 01 0 14 1 1 LITH MEST CPS O0 354 01 0 14 1 1 SS1 MEST CPS O0 354 02 0 14 I 1 SS2 MEST CPS O0 354 02 0 14 1 1 CALI MEST IN O0 280 01 0 14 i 1 RGCN MEST CPS O0 000 O0 0 14 i 1 DRTA MEST O0 000 O0 0 14 1 1 TALP MEST O0 000 O0 0 14 i 1 RTNR MEST O0 000 O0 0 14 i 1 RCNT MEST CPS O0 000 O0 0 14 I 1 RCFT MEST CPS O0 000 O0 0 14 I 1 CNTC MEST CPS O0 000 O0 0 14 1 1 TNRA MEST O0 000 O0 0 14 i 1 CFTC MEST CPS O0 000 O0 0 14 I 1 RGR MEST GAPI O0 000 O0 0 14 I 1 TIME MEST MS O0 636 21 0 14 i 1 ANOR MEST F/S2 O0 631 01 0 14 I 1 GAT MEST DEGF O0 000 O0 0 14 I 1 GMT MEST DEGF O0 000 O0 0 14 I 1 CTEM MEST DEGF O0 000 O0 0 14 1 1 RMTE MEST DEGF O0 000 O0 0 14 i 1 MTEM MEST DEGF O0 000 O0 0 14 1 1 AMTE MEST DEGF O0 000 O0 0 14 I 1 ATCA MEST DEGF O0 000 O0 0 14 i 1 DTEM MEST DFHF O0 000 O0 0 14 1 1 DPHI MEST PU O0 890 01 0 14 1 1 PHND MEST PU O0 890 01 0 14 i 1 TNPH MEST PU O0 000 O0 0 14 1 1 NPHI MEST PU O0 000 O0 0 14 i 1 NPL MEST PU O0 000 O0 0 14 I 1 NPOR MEST PU O0 000 O0 0 14 1 1 SCNL MEST O0 000 O0 0 14 1 1 GR MEST GAPI O0 000 O0 0 14 I 1 6A MEST MS O0 636 21 0 14 60 1 EV MEST V O0 000 O0 0 14 60 1 BA28 MEST O0 610 O0 0 14 60 1 BA17 MEST O0 610 O0 0 14 60 1 BB17 MEST O0 610 O0 0 14 60 1 BC13 MEST O0 610 O0 0 14 60 1 BD13 MEST O0 610 O0 0 14 60 1 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 2 4 240 240 240 240 240 240 240 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 79 68 68 68 68 68 68 68 68 0000020000 0000020000 0000020000 0000020000 00O00200O0 0000000000 000002O000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0040O00O00 0000000000 0000000000 0000000000 0442000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0242000400 0242000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR--~6~--' ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BB28 MEST O0 610 O0 0 14 60 1 240 68 0000000000 BA13 MEST O0 610 O0 0 14 60 1 240 BB13 MEST O0 610 O0 0 14 60 1 240 BC17 MEST O0 610 O0 0 14 60 1 240 BD17 MEST O0 610 O0 0 14 60 1 240 BA22 MEST O0 610 O0 0 14 60 1 240 BA23 MEST O0 610'00 0 14 60 1 240 BA24 MEST O0 610 O0 0 14 60 1 240 BC28 MEST O0 610 O0 0 14 60 I 240 BA25 MEST O0 610 O0 0 14 60 1 240 BA26 MEST O0 610 O0 0 14 60 1 240 BA27 MEST O0 610 O0 0 14 60 1 240 BAll MEST O0 610 O0 0 14 60 1 240 BA12 MEST O0 610 O0 0 14 60 1 240 BA14 MEST O0 610 O0 0 14 60 I 240 BA15 MEST O0 610 O0 0 14 60 I 240 BA16 MEST O0 610 O0 0 14 60 1 240 BA18 MEST O0 610 O0 0 14 60 1 240 BA21 MEST O0 610 O0 0 14 60 1 240 BC11 MEST O0 610 O0 0 14 60 i 240 BC12 MEST O0 610 O0 0 14 60 1 240 BC14 MEST O0 610 O0 0 14 60 1 240 BC15 MEST O0 610 O0 0 14 60 1 240 BC16 MEST O0 610 O0 0 14 60 1 240 BC18 MEST O0 610 O0 0 14 60 i 240 BC21 MEST O0 610 O0 0 14 60 1 240 BC22 MEST O0 610 O0 0 14 60 1 240 BC23 MEST O0 610 O0 0 14 60 1 240 BC24 MEST O0 610 O0 0 14 60 1 240 BC25 MEST O0 610 O0 0 14 60 1 240 BC26 MEST O0 610 O0 0 14 60 1 240 BC27 MEST O0 610 O0 0 14 60 1 240 BB22 MEST O0 610 O0 0 14 60 1 240 BB23 MEST O0 610 O0 0 14 60 i 240 BB24 MEST O0 610 O0 0 14 60 i 240 BD28 MEST O0 610 O0 0 14 60 i 240 BB25 MEST O0 610 O0 0 14 60 i 240 BB26 MEST O0 610 O0 0 14 60 I 240 BB27 MEST O0 610 O0 0 14 60 1 240 BB11 MEST O0 610 O0 0 14 60 1 240 BB12 MEST O0 610 O0 0 14 60 1 240 BB14 MEST O0 610 O0 0 14 60 i 240 BB15 MEST O0 610 O0 0 14 60 1 240 BB16 MEST O0 610 O0 0 14 60 1 240 BB18 MEST O0 610 O0 0 14 60 1 240 BB21 MEST O0 610 O0 0 14 60 1 240 BDll MEST O0 610 O0 0 14 60 1 240 BD12 MEST O0 610 O0 0 14 60 1 240 BD14 MEST O0 610 O0 0 14 60 1 240 BD15 MEST O0 610 O0 0 14 60 1 240 BD16 MEST O0 610 O0 0 14 60 i 240 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 32 ~S Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 33 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BD18 MEST O0 610 O0 0 14 60 i 240 68 0000000000 BD21 NEST O0 610 O0 0 14 60 i 240 68 0000000000 BD22 NEST O0 610 O0 0 14 60 1 240 68 0000000000 BD23 NEST O0 610 O0 0 14 60 i 240 68 0000000000 BD24 NEST O0 610 O0 0 14 60 i 240 68 0000000000 BD25 NEST O0 610 O0 0 14 60 i 240 68 0000000000 BD26 NEST O0 610 O0 0 14 60 I 240 68 0000000000 BD27 NEST O0 610 O0 0 14 60 1 240 68 0000000000 SB1 NEST O0 610 O0 0 14 60 I 240 68 0000000000 DB1 NEST O0 610 O0 0 14 60 i 240 68 0000000000 DB2 NEST O0 610 O0 0 14 60 1 240 68 0000000000 DB3A NEST O0 610 O0 0 14 60 1 240 68 0000000000 DB4A NEST O0 610 O0 0 14 60 1 240 68 0000000000 SB2 NEST O0 610 O0 0 14 60 i 240 68 0000000000 DBiA MEST O0 610 O0 0 14 60 i 240 68 0000000000 DB2A NEST O0 610 O0 0 14 60 1 240 68 0000000000 DB3 NEST O0 610 O0 0 14 60 1 240 68 0000000000 DB4 NEST O0 610 O0 0 14 60 i 240 68 0000000000 FCAX NEST M/S2 O0 000 O0 0 14 60 i 240 68 0000000000 FCAY NEST M/S2 O0 000 O0 0 14 60 1 240 68 0000000000 FCAZ NEST N/S2 O0 000 O0 0 14 60 I 240 68 0000000000 FTIM NEST MS O0 000 O0 0 14 60 1 240 68 0000000000 7A NEST O0 000 O0 0 14 60 1 240 68 0000000000 8A NEST M/S2 O0 000 O0 0 14 60 I 240 68 0000000000 9A NEST M/S2 O0 000 O0 0 14 60 1 240 68 0000000000 IOA MEST MS O0 636 21 0 14 4 i 16 68 0000000000 Cl NEST IN O0 280 41 0 14 4 i 16 68 0000000000 C2 NEST IN O0 280 42 0 14 4 i 16 68 0000000000 RC1 MEST IN O0 280 41 0 14 4 i 16 68 0000000000 RC2 NEST IN O0 280 42 0 14 4 I 16 68 0000000000 PP NEST O0 000 O0 0 14 4 I 16 68 0000000000 CP NEST O0 000 O0 0 14 4 1 16 68 0000000000 AX NEST M/S2 O0 615 02 0 14 4 I 16 68 0000000000 AY MEST M/S2 O0 615 03 0 14 4 i 16 68 0000000000 AZ NEST M/S2 O0 615 01 0 14 4 I 16 68 0000000000 FX NEST OER O0 000 O0 0 14 4 1 16 68 0000000000 FY MEST OER O0 000 O0 0 14 4 I 16 68 0000000000 EI NEST MA O0 000 O0 0 14 4 1 16 68 0000000000 FZ NEST OER O0 000 O0 0 14 4 1 16 68 0000000000 11A NEST NS O0 636 21 0 14 12 i 48 68 0000000000 AIBP NEST PSI O0 000 O0 0 14 2 I 8 68 0000000000 AIBD MEST IN O0 000 O0 0 14 2 1 8 68 0000000000 AINR NEST OHMM O0 000 O0 0 14 2 1 8 68 0000000000 AIFF NEST O0 000 O0 0 14 2 1 8 68 0000000000 ACBS NEST O0 000 O0 0 14 2 I 8 68 0000000000 ACED NEST IN O0 000 O0 0 14 2 i 8 68 0000000000 ACCB NEST NM/M O0 000 O0 0 14 2 I 8 68 0000000000 ACRB NEST OHMM O0 000 O0 0 14 2 I 8 68 0000000000 ACCF NEST MM/M O0 000 O0 0 14 2 1 8 68 0000000000 ACRF NEST OHMN O0 000 O0 0 14 2 i 8 68 0000000000 ABFR MEST O0 000 O0 0 14 2 1 8 68 0000000000 ~S Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) 12A MEST MM/M O0 000 O0 0 14 2 1 8 68 0000000000 13A MEST MM/M O0 000 O0 0 14 2 i 8 68 0000000000 14A MEST MM/M O0 000 O0 0 14 2 1 8 68 0000000000 15A MEST MM/M O0 000 O0 0 14 2 1 8 68 0000000000 16A MEST MM/M O0 000 O0 0 14 2 I 8 68 0000000000 17A MEST MM/M O0 000 O0 0 14 2 1 8 68 0000000000 18A MEST MM/M O0 000 O0 0 14 2 1 8 68 0000000000 19A MEST MM/M O0 000 O0 0 14 2 1 8 68 0000000000 20A MEST MM/M O0 000 O0 0 14 2 I 8 68 0000000000 21A MEST MH/M O0 000 O0 0 14 2 1 8 68 0000000000 ATiO MEST OHMM O0 000 O0 0 14 2 1 8 68 0000000000 AT20 MEST OHMM O0 000 O0 0 14 2 1 8 68 0000000000 AT30 MEST OHMM O0 000 O0 0 14 2 1 8 68 0000000000 AT60 MEST OHMM O0 000 O0 0 14 2 i 8 68 0000000000 ATgO MEST OHMM O0 000 O0 0 14 2 i 8 68 0000000000 22A MEST MS O0 636 21 0 14 2 i 8 68 0000000000 AIEC MEST MM/M O0 000 O0 0 14 2 28 224 68 0000020000 23A MEST MM/M O0 000 O0 0 14 2 28 224 68 0000020000 AIBT MEST DEGF O0 000 O0 0 14 2 I 8 68 0000000000 AIPO MEST PU O0 000 O0 0 14 2 i 8 68 0000000000 AIFC MEST MM/M O0 000 O0 0 14 2 28 224 68 0000000000 AISE MEST MM/M O0 000 O0 0 14 2 28 224 68 0000020000 AIBC MEST MM/M O0 000 O0 0 14 2 28 224 68 0000000000 AQAB MEST MM/M O0 000 O0 0 14 2 8 64 68 0000000000 AQAF MEST MM/M O0 000 O0 0 14 2 8 64 68 0000000000 ATCO MEST MM/M O0 000 O0 0 14 2 5 40 68 0000000000 ATCB MEST MM/M O0 000 O0 0 14 2 5 40 68 0000000000 ACRS MEST OHMM O0 000 O0 0 14 2 1 8 68 0000000000 24A MEST MS O0 636 21 0 14 1 1 4 68 0000000000 25A MEST MS O0 636 21 0 14 I i 4 68 0000000000 26A MEST MS O0 636 21 0 14 1 i 4 68 0000000000 34 ** DATA ** ** DEPTH = 14136.000 FEET ** BS.MEST 9.875 CS.MEST 853.687 CVEL.MEST -14.228 TENS.MEST ETIM.MEST 0.000 MARK.MEST 0.000 DEVI.MEST 56.969 FNOR.MEST FINC.MEST 73.232 HAZI.MEST 50.739 PIAZ.MEST 193.293 RB.MEST SDEV.MEST 56.969 RT.MEST 11.969 HV.MEST 241.260 NTEN.MEST MRES.MEST 0.498 SP.MEST -30.000 SPAR.MEST -30.000 RSP.MEST RSPA.MEST 0.813 SPCF.MEST 0.000 DPTR.MEST -999.250 DPAZ.MEST QUAF.MEST 0.000 DDIP.MEST -999.250 DDA.MEST -999.250 AREA.MEST AFCD.MEST 0.317 ABS.MEST 0.532 FCD.MEST 7.625 IHV.MEST ICV.HEST -0.109 ASCA.MEST 28.608 ASFI.MEST -0.002 BDQC.MEST DRHO.MEST 0.004 DALP.MEST -0.187 LSRH.MEST 2.325 LURH.MEST PEF.MEST 4.605 QRLS.MEST 0.612 QLS.MEST -0.037 QRSS.MEST QSS.MEST 0.091 RHOB.MEST 2.334 SIRH.MEST 2.309 NRHO.MEST RLL.MEST 208.772 RLU.MEST 381.328 RLS.MEST 399.436 RLIT.MEST 1565.000 0.570 157.342 131.818 -29.000 -999.250 0.098 0.049 0.000 2.331 0.792 2.334 88.409 ~S Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 35 LSHV.MEST 1366.260 SSHV.MEST 1417.447 LU.MEST 381.328 SS2.MEST 322.476 TALP.MEST 0.925 CNTC.MEST 3780.572 TIME.MEST 0.000 CTEM.MEST 197.600 ATCA.MEST 169.729 TNPH.MEST 15.232 SCNL.MEST 2 BA28.MEST -999.250 BD13.MEST -999.250 BC17.MEST -999.250 BA24.HEST -999.250 BA27.MEST -999.250 BA15.MEST -999.250 B¢11.MEST -999.250 BC16.MEST -999.250 BC23.MEST -999.250 BC27.MEST -999.250 BD28.MEST -999.250 BB11.MEST -999.250 BB16.MEST -999.250 BD12.MEST -999.250 BD18.MEST -999.250 BD24.MEST -999.250 SB1.MEST -999.250 DB4A.MEST -999.250 DB3.MEST -999.250 FCAZ.MEST -999.250 9A.MEST -999.250 RCl.MEST -999.250 AX.MEST -999.250 FY.MEST -999.250 AIBP.MEST -999.250 ACBS.MEST -999.250 ACCF.MEST -999.250 13A.MEST -999.250 17A.MEST -999.250 21A.MEST -999.250 AT60.MEST -999.250 23A.MEST -999.250 AISE.MEST -999.250 ATCO.MEST -999.250 25A.MEST 0.000 FFLS.MEST FFSS.MEST LS.HEST CALI.MEST RTNR.MEST TNRA.MEST ANOR.MEST RMTE.MEST DTEM.MEST NPHI.MEST GR.MEST BA17.MEST BB28.MEST BD17.MEST BC28.MEST BA11.MEST BA16.MEST BC12.MEST BC18.MEST BC24.MEST BB22.MEST BB25.MEST BB12.MEST BB18.MEST BD14.MEST BD21.MEST BD25.MEST DB1.MEST SB2.MEST DB4.MEST FTIM.MEST iOA.MEST RC2.MEST AY.MEST EI.MEST AIBD.MEST ACED.MEST ACRF.MEST 14A.MEST 18A.MEST ATIO.MEST ATgO.MEST AIBT.MEST AIBC.MEST ATCB.MEST 26A.MEST 0.017 0.063 399.436 3.189 1.875 1.785 32.542 169.005 0.000 19.856 64.156 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 RSS1.MEST RCAL.MEST LITH.MEST RGCN.MEST RCNT.MEST CFTC.MEST GAT.MEST MTEM.MEST DPHI.MEST NPL.MEST 6A.MEST BB17.MEST BA13.MEST BA22.MEST BA25.HEST BA12.MEST BA18.MEST BC14.MEST BC21.MEST BC25.MEST BB23.MEST BB26.MEST BB14.MEST BB21.MEST BD15.MEST BD22.MEST BD26.MEST DB2.MEST DBIA.MEST FCAX.MEST 7A.MEST Cl.MEST PP.MEST AZ.MEST FZ.MEST AIMR.MEST ACCB.HEST ABFR.MEST 15A.MEST 19A.MEST AT20.MEST 22A.MEST AIPO.MEST AQAB.MEST ACRS.MEST 250.361 2.180 88.409 3780.572 3724.625 2144.559 168.554 169.005 19.174 15.731 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 RSS2.MEST LL.MEST SS1.MEST DRTA.MEST RCFT.MEST RGR.MEST GMT.MEST AMTE.MEST PHND.MEST NPOR.MEST EV.MEST BC13.MEST BB13.MEST BA23.MEST BA26.MEST BA14.MEST BA21.MEST BC15.MEST BC22.MEST BC26.MEST BB24.MEST BB27.MEST BB15.MEST BD11.MEST BD16.MEST BD23.MEST BD27.MEST DB3A.MEST DB2A.MEST FCAY.MEST 8A.MEST C2.MEST CP.MEST FX.MEST 11A.MEST AIFF.MEST ACRB.MEST 12A.MEST 16A.MEST 20A.MEST AT30.MEST AIEC.MEST AIFC.MEST AQAF.MEST 24A.MEST 322.476 208.772 250.361 0.000 1961.049 54.135 203.381 169.005 19.174 15.232 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 ** DEPTH = 12676.000 FEET BS.MEST 9.875 CS.MEST 1124.171 ETIM.MEST 7065.825 MARK.MEST 0.000 FIN¢.MEST 72.919 HAZI.MEST 49.613 SDEV.MEST 56.642 RT.MEST 12.321 MRES.MEST 0.574 SP.MEST -59.063 RSPA.MEST 0.875 SPCF.MEST 0.000 CVEL.MEST DEVI.MEST PiAZ.MEST HV.MEST SPAR.MEST DPTR.MEST -18.736 56.642 206.486 249.450 -59.063 -999.250 TENS.HEST FNOR.MEST RB.MEST HTEN.MEST RSP.MEST DPAZ.MEST 305.000 0.568 166.784 684.452 -58.063 -999.250 _~ Tape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 36 QUAF.MEST -999.250 DDIP.MEST AFCD.MEST 0.317 ABS.MEST ICV.MEST 416.690 ASCA.MEST DRHO.MEST 0.010 DALP.MEST PEF.MEST 2.636 QRLS.MEST QSS.MEST 0.042 RHOB.MEST RLL.MEST 180.178 RLU.MEST LSHV.MEST 1364.973 FFLS.MEST SSHV.MEST 1414.509 FFSS.MEST LU.MEST 324.485 LS.MEST SS2.MEST 332.612 CALI.MEST TALP.MEST 1.236 RTNR.MEST CNTC.MEST 4861.833 TNRA.MEST TIME.MEST 1617.000 ANOR.MEST CTEM.MEST 188.600 RMTE.MEST ATCA.HEST 165.156 DTEM.MEST TNPH.MEST 16.247 NPHI.MEST SCNL.MEST 2 GR.MEST BA28.MEST *********** BA17.MEST BD13.MEST *********** BB28.MEST BC17.MEST *********** BD17.MEST BA24.MEST *********** BC28.MEST BA27.MEST *********** BA11.MEST BA15.MEST *********** BA16.MEST BC11.MEST *********** BC12.MEST BC16.MEST *********** BC18.MEST BC23.MEST *********** BC24.MEST BC27.MEST *********** BB22.MEST BD28.MEST *********** BB25.MEST BB11.MEST *********** BB12.MEST BB16.MEST *********** BB18.MEST BD12.MEST *********** BD14.MEST BD18.MEST *********** BD21.MEST BD24.MEST *********** BD25.MEST SB1.MEST *********** DB1.MEST DB4A.MEST *********** SB2.MEST DB3.MEST *********** DB4.MEST FCAZ.MEST 5.449 FTIM.MEST 9A.MEST 174.108 iOA.MEST RC1.MEST 10.852 RC2.MEST AX.MEST 8.121 AY.MEST FY.MEST 0.149 EI.MEST AIBP.MEST 148.646 AIBD.MEST ACBS.MEST 3.000 ACED.MEST ACCF.MEST 55.413 ACRF.MEST 13A.MEST 61.228 14A.MEST 17A.MEST 87.147 18A.MEST 21A.MEST 87.147 ATIO.MEST AT60.MEST 12.321 AT90.MEST 23A.MEST 293.470 AIBT.MEST AISE.MEST 4.393 AIBC.MEST ATCO.MEST 33.361 ATCB.MEST 25A.MEST -999.250 26A.MEST -999.250 0.532 12.764 -0.011 0.626 2.435 321.168 -0.057 0.054 340.199 10.268 1.978 1.849 32.505 158.792 0.000 14.487 39.251 24.987 809.000 10.613 1.652 1729.599 10.264 -999.250 18.046 70.323 87.147 29.975 11.523 158.817 57.534 87.147 -999.250 DDA.MEST -999.250 FCD.MEST 7.625 ASFI.MEST 2.804 LSRH.MEST 2.420 QLS.MEST -0.023 SIRH.MEST 2.382 RLS.MEST 340.762 RSSl.MEST 244.616 RCAL.MEST 9.647 LITH.MEST 108.359 RGCN.MEST 4816.468 RCNT.MEST 4745.191 CFTC.MEST 2629.405 GAT.MEST 164.005 MTEM.MEST 158.792 DPHI.MEST 13.012 NPL.MEST 10.404 6A.MEST 54.000 BB17.MEST *********** BA13.MEST *********** BA22.MEST *********** BA25.MEST *********** BA12.MEST *********** BA18.MEST *********** BC14.MEST *********** BC21.MEST *********** BC25.MEST *********** BB23.MEST *********** BB26.MEST *********** BB14.MEST *********** BB21.MEST *********** BD15.MEST *********** BD22.MEST *********** BD26.MEST *********** DB2.MEST *********** DBIA.MEST *********** FCAX.MEST 8.115 7A.MEST 8.000 C1.MEST 10.264 PP.MEST 69.011 AZ.MEST 5.440 FZ.MEST 0.422 AIMR.MEST 0.809 ACCB.MEST 1178.766 ABFR.MEST 3.471 15A.MEST 81.159 19A.MEST 87.147 AT20.MEST 16.332 22A.MEST 808.500 AIPO.MEST 13.502 AQAB.MEST 74.607 ACRS.MEST 0.856 AREA. IHV. BDQC. LURH. QRSS. NRHO. RLIT. RSS2. LL. SS1. DRTA. RCFT. RGR. GMT. AMTE. PHND. NPOR. EV. BC13. B313. BA23. BA26. BA14. BA21. BC15. BC22. BC26. B324. B327. B315. BD11. BD16. BD23. BD27. MEST 0.561 MEST 879.649 MEST 0.000 MEST 2.417 MEST 0.742 MEST 2.480 MEST 109.008 MEST 335.741 MEST 177.955 MEST 247.294 MEST 0.010 MEST 2393.126 MEST 36.322 MEST 199.601 MEST 158.817 MEST 10.332 MEST 16.186 MEST 2.769 MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST *********** MEST MEST *********** DB3A.MEST *********** DB2A.MEST *********** FCAY.MEST 1.641 8A.MEST 43.515 C2.MEST 10.023 CP.MEST 69.236 FX.MEST 0.350 11A.MEST 135.000 AIFF.HEST 54.854 ACRB.MEST 0.848 12A.MEST 33.361 16A.MEST 86.784 20A.MEST 87.147 AT30.MEST 14.220 AIEC.MEST 293.889 AIFC.MEST 297.985 AQAF.MEST 292.058 24A.MEST -999.250 LiS Tape Verification Listing Schlumoerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 37 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : MEST .018 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/05/28 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : TCH .004 SERVICE : LOG VERSION : 40.2 DATE : 95/06/21 MAX REC SIZE : 8192 FILE TYPE : PR LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 79 3884 4 66 1 5 66 1 6 73 36 7 65 INCH 8 73 60 9 65 .lIN 11 66 2 12 68 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 I Tape verification Listing Schlumoerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 38 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TOD TCH S 61 000 O0 0 4 1 ..... i ..... ~ ..... ~ .... ~~$~- TIME TCH MS 61 636 21 0 4 ETIM TCH S 61 636 21 0 4 CS TCH F/HR 61 636 21 0 4 DIFF TCH F 61 636 21 0 4 TENS TCH LBF 61 635 21 0 4 MARK TCH F 61 150 01 0 4 DEVI TCH DEG 61 620 11 0 4 RB TCH DEG 61 631 11 0 4 WiT1 TCH 61 000 O0 0 4 W2T1 TCH 61 000 O0 0 4 W3T1 TCH 61 000 O0 0 4 AGT1 TCH DB 61 000 O0 0 4 DTT1 TCH US 61 000 O0 0 4 W1T2 TCH 61 000 O0 0 4 W2T2 TCH 61 000 O0 0 4 W3T2 TCH 61 000 O0 0 4 AGT2 TCH DB 61 000 O0 0 4 DTT2 TCH US 61 000 O0 0 4 WiT3 TCH 61 000 O0 0 4 W2T3 TCH 61 000 O0 0 4 W3T3 TCH 61 000 O0 0 4 AGT3 TCH DB 61 000 O0 0 4 DTT3 TCH US 61 000 O0 0 4 W1T4 TCH 61 000 O0 0 4 W2T4 TCH 61 000 O0 0 4 W3T4 TCH 61 000 O0 0 4 AGT4 TCH DB 61 000 O0 0 4 DTT4 TCH US 61 000 O0 0 4 WiT5 TCH 61 000 O0 0 4 W2T5 TCH 61 000 O0 0 4 W3T5 TCH 61 000 O0 0 4 AGT5 TCH DB 61 000 O0 0 4 DTT5 TCH US 61 000 O0 0 4 W1T6 TCH 61 000 O0 0 4 W2T6 TCH 61 000 O0 0 4 W3T6 TCH 61 000 O0 0 4 AGT6 TCH DB 61 000 O0 0 4 DTT6 TCH US 61 000 O0 0 4 W1T7 TCH 61 000 O0 0 4 W2T7 TCH 61 000 O0 0 4 W3T7 TCH 61 000 O0 0 4 AGT7 TCH DB 61 000 O0 0 4 DTT7 TCH US 61 000 O0 0 4 WIT8 TCH 61 000 O0 0 4 W2T8 TCH 61 000 O0 0 4 W3T8 TCH 61 000 O0 0 4 AGT8 TCH DB 61 000 O0 0 4 DTT8 TCH US 61 000 O0 0 4 W1T9 TCH 61 000 O0 0 4 68 68 49 68 68 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 8000000000 8000000000 8200000000 8000020000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 ~ape Verification Listing Schlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 39 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) W2T9 TCH W3T9 TCH AGT9 TCH DB DTT9 TCH US WWM TCH ECCE TCH IN CALU TCH IN FVEL TCH US/F W2F9 TCH W3F9 TCH ¢SMN TCH CSMX TCH AW2 TCH AW3 TCH AAG1TCH AWl1TCH AW21TCH AAG2 TCH AW12 TCH AW22 TCH AAG3 TCH AW13 TCH AW23 TCH AAG4 TCH AW14 TCH AW24 TCH AAG5 TCH AW15 TCH AW25 TGH AAG6 TCH AW16 TCH AW26 TCH AAG7 TCH AW17 TCH AW27 TCH AAG8 TCH AW18 TCH AW28 TCH AAG9 TCH AW19 TCH AW29 TCH AW31TCH AW32 TCH AW33 TCH AW34 TCH AW35 TCH AW36 TCH AW37 TCH AW38 TCH AW39 TCH RGR TCH GAPI 61 000 O0 0 4 3 1 6 49 8000000000 61 000 O0 0 4 3 1 6 49 8000000000 61 000 O0 0 4 3 1 6 49 8000000000 61 000 O0 0 4 3 I 6 49 8000000000 61 000 O0 0 4 3 1 6 49 8200000000 61 000 O0 0 4 3 1 6 49 8200000000 61 280'50 0 4 3 1 6 49 8200000000 61 000 O0 0 4 3 1 6 49 8200000000 61 000 O0 0 4 3 1 6 49 8000000000 61 000 O0 0 4 3 1 6 49 8000000000 61 000 O0 0 4 i 1 2 49 8200000000 61 000 O0 0 4 I I 2 49 8200000000 61 000 O0 0 4 I 1 2 49 8000000000 61 000 O0 0 4 I 1 2 49 8000000000 61 000 O0 0 4 ! 1 2 49 9000000000 61 000 O0 0 4 I 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 I 1 2 49 9000000000 61 000 O0 0 4 1 I 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 i 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 i 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 I 2 49 9000000000 61 000 O0 0 4 I 1 2 49 9000000000 61 000 O0 0 4 i 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 I 2 49 9000000000 61 000 O0 0 4 I 1 2 49 9000000000 61 000 O0 0 4 I I 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 I 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 000 O0 0 4 1 1 2 49 9000000000 61 310 01 0 4 1 1 2 49 8000020000 ,ape Verification Listing ochlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 4O ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GR TCH GAPI 61 310 01 0 4 1 1 2 49---~~6- STSG TCH 61 000 O0 0 4 1 1 WFI3 TCH 61 000 O0 0 4 1 512 WFI2 TCH 61 000 O0 0 4 1 512 WFI1TCH 61 000 O0 0 4 1 512 WF7 TCH 61 580 56 0 4 1 120 WF7D TCH F 61 581~ 56 0 4 1 1 WFiN TCH 61 582 56 0 4 i 1 WF2N TCH 61 582 56 0 4 1 1 WF3N TCH 61 582 56 0 4 1 1 WF4N TCH 61 582 56 0 4 1 1 WF5N TCH 61 582 56 0 4 1 1 WF6N TCH 61 582 56 0 4 i 1 WF7N TCH 61 582 56 0 4 i 1 DTMD TCH US/F 61 000 O0 0 4 1 1 SA1 TCH MV 61 000 O0 0 4 I 1 SA2 TCH MV 61 000 O0 0 4 1 1 SA3 TCH MV 61 000 O0 0 4 1 1 SA4 TCH MV 61 000 O0 0 4 1 1 SA5 TCH MV 61 000 O0 0 4 1 1 SA6 TCH MV 61 000 O0 0 4 1 1 SAIM TCH MV 61 000 O0 0 4 i 1 SA2M TCH MV 61 000 O0 0 4 1 1 SA3M TCH MV 61 000 O0 0 4 I 1 SA4M TCH MV 61 000 O0 0 4 i 1 SA5M TCH MV 61 000 O0 0 4 I 1 SA6M TCH MV 61 000 O0 0 4 i 1 TT1 TCH US 61 000 O0 0 4 i 1 TT2 TCH US 61 000 O0 0 4 I 1 TT3 TCH US 61 000 O0 0 4 1 1 TT4 TCH US 61 000 O0 0 4 1 1 TT5 TCH US 61 000 O0 0 4 i 1 TT6 TCH US 61 000 O0 0 4 i 1 TTiM TCH US 61 000 O0 0 4 I 1 TT2M TCH US 61 000 O0 0 4 I 1 TT3M TCH US 61 000 O0 0 4 I 1 TT4M TCH US 61 000 O0 0 4 1 1 TT5M TCH US 61 000 O0 0 4 i 1 TT6M TCH US 61 000 O0 0 4 I 1 RUAT TCH DB/F 61 000 O0 0 4 I 1 RLAT TCH DB/F 61 000 O0 0 4 i 1 RUAM TCH DB/F 61 000 O0 0 4 i 1 RLAM TCH DB/F 61 000 O0 0 4 i 1 CCCL TCH 61 150 01 0 4 6 1 BATT TCH DB/F 61 000 O0 0 4 i 1 BATM TCH DB/F 61 000 O0 0 4 i 1 FLSA TCH 61 000 O0 0 4 1 1 FLTT TCH 61 000 O0 0 4 I 1 DATN TCH DB/F 61 000 O0 0 4 I 1 NATN TCH DB/F 61 000 O0 0 4 i 1 SATN TCH DB/F 61 000 O0 0 4 i 1 2 1024 1024 1024 240 4 4 4 4 4 4 4 4 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 12 2 2 2 2 2 2 2 79 79 79 79 79 68 68 68 68 68 68 68 68 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 8000000000 8000000000 8000000000 8000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 8200000000 8000O20O00 8000020000 9000020000 9000020000 9000020000 8000020000 8000020000 8000020000 9000020000 9000020000 9000020000 8000O200O0 8000020000 800O020O00 9000020000 9000020000 9000020000 8000020000 800O020000 8000O2O000 9000020000 9000020000 9000020000 800OO20000 8200020000 8200020000 8200020000 8200020000 8400000000 8200000000 8200000000 820O00O000 8200000000 8240000000 8200000000 820OO000O0 ,ape Verification Listing ochlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 41 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DT TCH US/F 61 000 O0 0 4 1 1 2 49 8200000000 DTUT TCH US/F 61 000 O0 0 4 i i 2 49 8200000000 DTLT TCH US/F 61 000 O0 0 4 I 1 2 49 8200000000 DTUM TCH US/F 61 000 O0 0 4 1 1 2 49 8200000000 DTLM TCH US/F 61 000 O0 0 4 1 1 2 49 8200000000 DCBL TCH MV 61 000 O0 0 4 i 1 2 49 8200000000 RCCL TCH 61 150 ~ 01 0 4 6 1 12 49 8000020000 CCL TCH 61 150 01 0 4 6 1 12 49 8400000000 ** DATA ** ** DEPTH = 15225.500 FEET TOD.TCH 488196673 TIME.TCH 7669.000 ETIM.TCH 7.669 CS.TCH DIFF.TCH -0.400 TENS.TCH 2145.000 MARK.TCH 13.797 DEVI.TCH RB.TCH 127,688 WIT1.TCH 1648.000 W2T1.TCH 1648.000 W3T1.TCH AGT1.TCH 1648.000 DTT1.TCH 1648.000 WIT2.TCH 1666.000 W2T2.TCH W3T2.TCH 1666.000 AGT2.TCH 1666.000 DTT2.TCH 1666.000 W1T3.TCH W2T3.TCH 1860.000 W3T3.TCH 1860.000 AGT3.TCH 1860.000 DTT3.TCH W1T4.TCH 1763.000 W2T4.TCH 1763.000 W3T4.TCH 1763.000 AGT4.TCH DTT4.TCH 1763.000 WIT5.TCH 1978.000 W2T5.TCH 1978.000 W3T5.TCH AGTS.TCH 1978.000 DTT5.TCH 1978.000 WIT6.TCH 1585.000 W2T6.TCH W3T6.TCH 1585.000 AGT6.TCH 1585.000 DTT6.TCH 1585.000 WIT7.TCH W2T7.TCH 1736.000 W3T7.TCH 1736.000 AGT7.TCH 1736.000 DTT7.TCH W1T8.TCH 1629.000 W2T8.TCH 1629.000 W3T8.TCH 1629.000 AGT8.TCH DTTS.TCH 1629.000 WITg. TCH 1880.000 W2Tg. TCH 1880.000 W3T9.TCH AGTg. TCH 1880.000 DTT9.TCH 1880.000 WWM.TCH 1.351 ECCE.TCH CALU.TCH 4.207 FVEL.TCH 6620.000 W2Fg. TCH 1,000 W3Fg. TCH CSMN.TCH 0.000 CSMX.TCH 275,000 AW2.TCH 0,598 AW3.TCH AAG1.TCH 20.000 AW11.TCH 20.000 AW21.TCH 20.000 AAG2.TCH AW12.TCH 20.000 AW22.TCH 20.000 AAG3.TCH 17.000 AW13.TCH AW23.TCH 17.000 AAG4.TCH 24.000 AW14.TCH 24,000 AW24.TCH AAG5.TCH 27.000 AW15.TCH 27.000 AW25.TCH 27.000 AAG6.TCH AW16.TCH 19.000 AW26.TCH 19.000 AAG7.TCH 13.000 AW17.TCH AW27.TCH 13.000 AAG8.TCH 15.000 AW18.TCH 15,000 AW28.TCH AAGg. TCH 18.000 AW19.TCH 18.000 AW29.TCH 18.000 AW31.TCH AW32.TCH 20,000 AW33.TCH 17.000 AW34.TCH 24,000 AW35.TCH AW36.TCH 19.000 AW37.TCH 13,000 AW38.TCH 15.000 AW39.TCH RGR.TCH 26.047 GR.TCH 32.750 STSG.TCH 176 WFI3.TCH WFI2.TCH 0 WFI1.TCH 0 WF7.TCH -1128 WF7D.TCH WF1N.TCH 0.000 WF2N.TCH 0.000 WF3N.TCH 0.000 WF4N.TCH WF5N.TCH 0.000 WF6N.TCH 0.000 WF7N.TCH 197.746 DTMD.TCH SA1.TCH 22.781 SA2.TCH 37.281 SA3.TCH 18.781 SA4.TCH SA5.TCH 10.320 SA6.TCH 74.438 SAIM.TCH 20,844 SA2M.TCH SA3M.TCH 17,328 SA4M.TCH 25.594 SA5M.TCH 9.383 SA6M.TCH TT1.TCH 268.000 TT2.TCH 213.000 TT3.TCH 267,000 TT4.TCH TT5.TCH 357.000 TT6.TCH 126.000 TT1M.TCH 268,250 TT2M.TCH TT3M.TCH 266.750 TT4M.TCH 210,500 TT5M.TCH 357,000 TT6M.TCH RUAT.TCH 4.277 RLAT.TCH 3.346 RUAM.TCH 4,258 RLAM.TCH 234.625 27.516 1648.000 1666.000 1860.000 1860.000 1763.000 1978.000 1585.000 1736.000 1736.000 1629.000 1880.000 0.050 1.000 1.159 20.O0O 17.000 24.000 19.000 13.000 15.000 20.000 27.000 18,000 0 15196.092 0.000 228.750 27.609 34.031 76.063 210.000 213.125 106.563 3.387 Verification Listing ~nlumberger Alaska Computing Center CCCL.TCH 0.000 BATT.TCH FLTT.TCH 0.000 DATN.TCH DT.TCH 56.000 DTUT.TCH DTLM.TCH 56.250 DCBL.TCH ** DEPTH = 14891.500 FEET TOD.TCH 488197349 TIME.TCH DIFF.TCH -0.500 TENS.TCH RB.TCH 198.625 WiT1.TCH AGT1.TCH 16.000 DTT1.TCH W3T2.TCH 2348.000 AGT2.TCH W2T3.TCH 1573.000 W3T3.TCH WIT4.TCH 1529.000 W2T4.TCH DTT4.TCH 60.281 W1T5.TCH AGT5.TCH 22.000 DTT5.TCH W3T6.TCH 1304.000 AGT6.TCH W2T7.TCH 900.000 W3T7.TCH W1T8.TCH 1805.000 W2T8.TCH DTT8.TCH 58.000 WiT9.TCH AGTg. TCH 18.000 DTTg. TCH CALU.TCH 4.793 FVEL.TCH CSMN.TCH 0.000 CSMX.TCH AAG1.TCH 16.000 AW11.TCH AW12.TCH 1915.000 AW22.TCH AW23.TCH 0.740 AAG4.TCH AAG5.TCH 20.000 AW15.TCH AW16.TCH 1654.000 AW26.TCH AW27.TCH 0.742 AAG8.TCH AAGg. TCH 18.000 AW19.TCH AW32.TCH 1.274 AW33.TCH AW36.TCH 0.648 AW37.TCH RGR.TCH 26.484 GR.TCH WFI2.TCH 0 WFI1.TCH WF1N.TCH 0.000 WF2N.TCH WF5N.TCH 0.000 WF6N.TCH SA1.TCH 21.688 SA2.TCH SA5.TCH 8.422 SA6.TCH SA3M.TCH 15.453 SA4M.TCH TT1.TCH 269.250 TT2.TCH TT5.TCH 357.500 TT6.TCH TT3M.TCH 267.500 TT4M.TCH RUAT.TCH 3.965 RLAT.TCH CCCL.TCH 0.000 BATT.TCH FLTT.TCH 0.000 DATN.TCH DT.TCH 56.500 DTUT.TCH DTLM.TCH 55.875 DCBL.TCH END OF DATA 17-jUL-1995 12:00 3.811 BATM.TCH 3.811 NATN.TCH 55.000 DTLT.TCH 25.156 RCCL.TCH 1071.000 ETIM.TCH 6235.000 MARK.TCH 1672.000 W2T1.TCH 55.781 WIT2.TCH 15.000 DTT2.TCH 2756.000 AGT3.TCH 972.500 W3T4.TCH 1988.000 W2T5.TCH 61.781 W1T6.TCH 17.000 DTT6.TCH 1918.000 AGT7.TCH 1220.000 W3T8.TCH 1928.000 W2Tg.TCH 54.094 WWM.TCH 190.375 W2Fg. TCH 1765.000 AW2.TCH 1739.000 AW21.TCH 1.013 AAG3.TCH 24.000 AW14.TCH 1835.000 AW25.TCH 0.490 AAG7.TCH 18.000 AW18.TCH 1927.000 AW29.TCH 1.331 AW34.TCH 1.165 AW38.TCH 30.641 STSG.TCH 0 WF7.TCH 0.000 WF3N.TCH 0.000 WF7N.TCH 31.516 SA3.TCH 82.938 SA1M.TCH 24.844 SA5M.TCH 213.000 TT3.TCH 126.000 TTiM.TCH 211.500 TT5M.TCH 4.496 RUAM.TCH 4.230 BATM.TCH 4.230 NATN.TCH 57.000 DTLT.TCH 21.563 RCCL.TCH 3.822 1.991 57.000 0.000 684.231 13.797 1453.000 1743.000 54.688 19.000 1808.000 670.500 1661.000 63.781 18.000 2062.000 364.750 0.967 1.000 0.757 0.753 19.000 1827.000 0.661 20.000 1833.000 0.187 1.365 1.150 176 -1176 0.000 197.746 16.688 19.953 7.703 268.000 269.500 357.500 4.043 4.246 2.594 56.000 0.027 FLSA.TCH SATN.TCH DTUM.TCH CCL.TCH CS.TCH DEVI.TCH W3T1.TCH W2T2.TCH WiT3.TCH DTT3.TCH AGT4.TCH W3T5.TCH W2T6.TCH WiT7.TCH DTT7.TCH AGT8.TCH W3T9.TCH ECCE.TCH W3Fg.TCH AW3.TCH AAG2.TCH AW13.TCH AW24.TCH AAG6.TCH AW17.TCH AW28.TCH AW31.TCH AW35.TCH AW39.TCH WFI3.TCH WF7D.TCH WF4N.TCH DTMD.TCH SA4.TCH SA2M.TCH SA6M.TCH TT4.TCH TT2M.TCH TT6M.TCH RLAM.TCH FLSA.TCH SATN.TCH DTUM.TCH CCL.TCH PAGE: 42 0.000 0.079 55.125 -0.001 1669.000 35.031 2092.000 2164.000 1879.000 56.875 22.000 2086.000 1030.000 1767.000 62.375 18.000 596.000 0.139 1.000 1.100 15.000 1954.000 0.799 17.000 1955.000 0.705 1.204 0.681 0.308 0 14861.908 0.000 232.000 26.750 29.063 76.313 211.000 213.250 108.188 4.453 0.000 -1.061 56.000 0.082 ,ape verification Listing Jchlumoerger Alaska Computing Center **** FILE TRAILER **** FILE NAME : TCH .004 SERVICE : LOG VERSION : 40.2 DATE : 95/06/21 MAX REC SIZE : 8192 FILE TYPE : PR LAST FILE : **** FILE HEADER **** FILE NAME : TCH .002 SERVICE : PLAY VERSION : 40.2 DATE : 95/06/21 MAX REC SIZE : 8192 FILE TYPE : PR LAST FILE : 17-JUL-1995 12:00 PAGE: 43 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ..... ..... i 66 0 2 66 0 3 79 4228 4 66 1 5 66 I 6 73 36 7 65 INCH 8 73 60 9 65 .lIN 11 66 1 12 68 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 6 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TOD TCH S 61 000 O0 0 2 1 I 4 73 8200000000 TIME TCH MS 61 636 21 0 2 1 1 4 68 8000000000 ETIM TCH S 61 636 21 0 2 1 1 4 68 8000000000 CS TCH F/HR 61 636 21 0 2 I 1 2 49 8200000000 ,ape Verification Listing ~chlumDerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 44 UU T .UU - OC SS- ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DIFF TCH F 61 636 21 0 2 1 1 4 68 --'8000020000- -------,,~ TENS TCH LBF 61 635 21 0 2 1 MARK TCH F 61 150 01 0 2 1 DEVI TCH DEG 61 620 11 0 2 1 RB TCH DEG 61 631 11 0 2 1 WiT1 TCH 61 000 O0 0 2 3 W2T1 TCH 61 000'00 0 2 3 W3T1 TCH 61 000 O0 0 2 3 AGT1 TCH DB 61 000 O0 0 2 3 DTT1 TCH US 61 000 O0 0 2 3 W1T2 TCH 61 000 O0 0 2 3 W2T2 TCH 61 000 O0 0 2 3 W3T2 TCH 61 000 O0 0 2 3 AGT2 TCH DB 61 000 O0 0 2 3 DTT2 TCH US 61 000 O0 0 2 3 W1T3 TCH 61 000 O0 0 2 3 W2T3 TCH 61 000 O0 0 2 3 W3T3 TCH 61 000 O0 0 2 3 AGT3 TCH DB 61 000 O0 0 2 3 DTT3 TCH US 61 000 O0 0 2 3 W1T4 TCH 61 000 O0 0 2 3 W2T4 TCH 61 000 O0 0 2 3 W3T4 TCH 61 000 O0 0 2 3 AGT4 TCH DB 61 000 O0 0 2 3 DTT4 TCH US 61 000 O0 0 2 3 WIT5 TCH 61 000 O0 0 2 3 W2T5 TCH 61 000 O0 0 2 3 W3T5 TCH 61 000 O0 0 2 3 AGT5 TCH DB 61 000 O0 0 2 3 DTT5 TCH US 61 000 O0 0 2 3 WiT6 TCH 61 000 O0 0 2 3 W2T6 TCIt 61 000 O0 0 2 3 W3T6 TCH 61 000 O0 0 2 3 AGT6 TCH DB 61 000 O0 0 2 3 DTT6 TCH US 61 000 O0 0 2 3 WIT7 TCH 61 000 O0 0 2 3 W2T7 TCH 61 000 O0 0 2 3 W3T7 TCH 61 000 O0 0 2 3 AGT7 TCH DB 61 000 O0 0 2 3 DTT7 TCH US 61 000 O0 0 2 3 W1T8 TCH 61 000 O0 0 2 3 W2T8 TCH 61 000 O0 0 2 3 W3T8 TCH 61 000 O0 0 2 3 AGT8 TCH DB 61 000 O0 0 2 3 DTT8 TCH US 61 000 O0 0 2 3 W1T9 TCH 61 000 O0 0 2 3 W2T9 TCH 61 000 O0 0 2 3 W3T9 TCH 61 000 O0 0 2 3 AGT9 TCH DB 61 000 O0 0 2 3 DTT9 TCH US 61 000 O0 0 2 3 WWM TCH 61 000 O0 0 2 3 68 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000O00 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8200000000 .~pe Verification Listing ~nlumDerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 45 c,^ss ECCE TCH IN 61 000 O0 0 2 3 i 6 49 --8200000000 CALU TCH IN 61 FVEL TCH US/F 61 W2F9 TCH 61 W3F9 TCH 61 CSMN TCH 61 CSM× TCH 61 AW2 TCH 61 AW3 TCH 61 AAG1TCH 61 AWl1TCH 61 AW21TCH 61 AAG2 TCH 61 AW12 TCH 61 AW22 TCH 61 AAG3 TCH 61 AW13 TCH 61 AW23 TCH 61 AAG4 TCH 61 AW14 TCH 61 AW24 TCH 61 AAG5 TCH 61 AW15 TCH 61 AW25 TCH 61 AAG6 TCH 61 AW16 TCH 61 AW26 TCH 61 AAG7 TCH 61 AW17 TCH 61 AW27 TCH 61 AAG8 TCH 61 AW18 TCH 61 AW28 TCH 61 AAG9 TCH 61 AW19 TCH 61 AW29 TCH 61 AW31TCH 61 AW32 TCH 61 AW33 TCH 61 AW34 TCH 61 AW35 TCH 61 AW36 TCH 61 AW37 TCH 61 AW38 TCH 61 AW39 TCH 61 RGR TCH GAPI 61 GR TCH GAPI 61 STSG TCH 61 WFI3 TCH 61 WFI2 TCH 61 WFI1TCH 61 280 50 0 2 3 000 O0 0 2 3 000 O0 0 2 3 000 O0 0 2 3 000 O0 0 2 1 000'00 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 310 01 0 2 1 310 01 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 1 000 O0 0 2 i 1 6 49 i 6 49 I 6 49 i 6 49 1 2 49 i 2 49 i 2 49 I 2 49 I 2 49 I 2 49 I 2 49 1 2 49 i 2 49 i 2 49 1 2 49 1 2 49 I 2 49 I 2 49 I 2 49 I 2 49 1 2 49 I 2 49 1 2 49 i 2 49 i 2 49 I 2 49 i 2 49 I 2 49 i 2 49 i 2 49 1 2 49 i 2 49 I 2 49 i 2 49 i 2 49 I 2 49 i 2 49 i 2 49 I 2 49 i 2 49 1 2 49 i 2 49 1 2 49 I 2 49 i 2 49 1 2 49 I 2 79 512 1024 79 512 1024 79 512 1024 79 8200000000 8200000000 8000000000 8000000000 8200000000 8200O00O00 8000000000 8000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000O0000O 90OO000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 9000000000 90O0000000 9000000000 9000000000 9000000000 800O020O00 8400000000 8000000000 8000000000 800000O0O0 80O0000000 .~pe Verification Listing .~nlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 46 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) WF7D TCH F 61 581 56 0 2 WFIN TCH 61 582 56 0 2 WF2N TCH 61 582 56 0 2 WF3N TCH 61 582 56 0 2 WF4N TCH 61 582 56 0 2 WF5N TCH 61 582' 56 0 2 WF6N TCH 61 582 56 0 2 WF7N TCH 61 582 56 0 2 DTMD TCH US/F 61 000 O0 0 2 SA1 TCH MV 61 000 O0 0 2 SA2 TCH MV 61 000 O0 0 2 SA3 TCH MV 61 000 O0 0 2 SA4 TCH MV 61 000 O0 0 2 SA5 TCH MV 61 000 O0 0 2 SA6 TCH MV 61 000 O0 0 2 SAIM TCH MV 61 000 O0 0 2 SA2M TCH MV 61 000 O0 0 2 SA3M TCH MV 61 000 O0 0 2 SA4M TCH MV 61 000 O0 0 2 SASM TCH MV 61 000 O0 0 2 SA6M TCH MV 61 000 O0 0 2 TT1 TCH US 61 000 O0 0 2 TT2 TCH US 61 000 O0 0 2 TT3 TCH US 61 000 O0 0 2 TT4 TCH US 61 000 O0 0 2 TT5 TCH US 61 000 O0 0 2 TT6 TCH US 61 000 O0 0 2 TT1M TCH US 61 000 O0 0 2 TT2M TCH US 61 000 O0 0 2 TT3M TCH US 61 000 O0 0 2 TT4M TCH US 61 000 O0 0 2 TTSM TCH US 61 000 O0 0 2 TT6M TCH US 61 000 O0 0 2 RUAT TCH DB/F 61 000 O0 0 2 RLAT TCH DB/F 61 000 O0 0 2 RUAM TCH DB/F 61 000 O0 0 2 RLAM TCH DB/F 61 000 O0 0 2 CCCL TCH 61 150 01 0 2 BATT TCH DB/F 61 000 O0 0 2 BATM TCH DB/F 61 000 O0 0 2 FLSA TCH 61 000 O0 0 2 FLTT TCH 61 000 O0 0 2 DATN TCH DB/F 61 000 O0 0 2 NATN TCH DB/F 61 000 O0 0 2 SATN TCH DB/F 61 000 O0 0 2 DT TCH US/F 61 000 O0 0 2 DTUT TCH US/F 61 000 O0 0 2 DTLT TCH US/F 61 000 O0 0 2 DTUM TCH US/F 61 000 O0 0 2 DTLM TCH US/F 61 000 O0 0 2 4 4 4 4 4 4 4 4 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 12 2 2 2 2 2 2 2 2 2 2 2 2 68 68 68 68 68 68 68 68 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 49 9000000000 9000000000 9000000000 9000000000 9O00O00000 9000000000 9000000000 9000000000 820OO0000O 8O00020000 8000020000 9000020000 9000020000 9000020000 80OO020000 8000020000 8000020000 9000020000 9000020000 9000020000 8000020000 800O02O00O 8000020000 9000020000 9000020000 9000020000 8000020000 8OO00200OO 8000O20000 9000020000 9000020000 9000020000 8000020000 8200020000 8200020000 8200020000 8200020000 8400000O0O 8200000000 8200000000 820000O000 8200000000 8240000000 8200000000 82000OO000 8200000000 8200000000 820000O000 8200O0O0OO 8200000000 .ope Verification Listing .~nlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE ~-- PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RCCL TCH 61 150 01 0 2 6 i 12 49 8000020000 CCL TCH 61 150 01 0 2 6 i 12 49 8400000000 47 ** DATA ** DEPTH : 15230.500 FEET ** TOD.TCH 488198125 TIME.TCH 1093.000 ETIM.TCH 20.544 CS.TCH DIFF.TCH -1.050 TENS.TCH 2200.000 MARK.TCH 13.797 DEVI.TCH RB.TCH 92.063 WiT1.TCH 0.000 W2T1.TCH 0.000 W3T1.TCH AGT1.TCH 0.000 DTT1.TCH 0.000 WIT2.TCH 0.000 W2T2.TCH W3T2.TCH 0.000 AGT2.TCH 0.000 DTT2.TCH 0.000 W1T3.TCH W2T3.TCH 0.000 W3T3.TCH 0.000 AGT3.TCH 0.000 DTT3.TCH WIT4.TCH 0.000 W2T4.TCH 0.000 W3T4.TCH 0.000 AGT4.TCH DTT4.TCH 0.000 WIT5.TCH 0.000 W2T5.TCH 0.000 W3T5.TCH AGT5.TCH 0.000 DTT5.TCH 0.000 WIT6.TCH 0.000 W2T6.TCH W3T6.TCH 0.000 AGT6.TCH 0.000 DTT6.TCH 0.000 WiT7.TCH W2T7.TCH 0.000 W3T7.TCH 0.000 AGT7.TCH 0.000 DTT7.TCH W1T8.TCH 0.000 W2T8.TCH 0.000 W3T8.TCH 0.000 AGT8.TCH DTT8.TCH 0.000 WiT9.TCH 0.000 W2T9.TCH 0.000 W3Tg. TCH AGTg.TCH 0.000 DTTg. TCH 0.000 WWM.TCH 0.000 ECCE.TCH CALU.TCH 1.063 FVEL.TCH 0.000 W2F9.TCH 1.000 W3Fg.TCH CSMN.TCH 0.000 CSM×.TCH 150.750 AW2.TCH 0.600 AW3.TCH AAG1.TCH 0.000 AW11.TCH 0.000 AW21.TCH 0.000 AAG2.TCH AW12.TCH 0.000 AW22.TCH 0.000 AAG3.TCH -0.713 AW13.TCH AW23.TCH -0.713 AAG4.TCH 0.000 AW14.TCH 0.000 AW24.TCH AAG5.TCH 0.000 AW15.TCH 0.000 AW25.TCH 0.000 AAG6.TCH AW16.TCH 0.000 AW26.TCH 0.000 AAG7.TCH 0.000 AW17.TCH AW27.TCH 0.000 AAG8.TCH 0.000 AW18.TCH 0.000 AW28.TCH AAGg.TCH 0.000 AW19.TCH 0.000 AW29.TCH 0.000 AW31.TCH AW32.TCH 0.000 AW33.TCH -0.713 AW34.TCH 0.000 AW35.TCH AW36.TCH 0.000 AW37.TCH 0.000 AW38.TCH 0.000 AW39.TCH RGR.TCH 25.203 GR.TCH 31.688 STSG.TCH 176 WFI3.TCH WFI2.TCH 0 WFI1.TCH 0 WF7.TCH -1192 WF7D.TCH WF1N.TCH 0.000 WF2N.TCH 0.000 WF3N.TCH 0.000 WF4N.TCH WF5N.TCH 0.000 WF6N.TCH 0.000 WF7N.TCH 197.746 DTMD.TCH SA1.TCH 21.453 SA2.TCH 36.000 SA3.TCH 17.922 SA4.TCH SA5.TCH 9.852 SA6.TCH 89.375 SAIM.TCH 19.734 SA2M.TCH SA3M.TCH 16.563 SA4M.TCH 23.641 SA5M.TCH 8.992 SA6M.TCH TT1.TCH 268.000 TT2.TCH 213.000 TT3.TCH 267.000 TT4.TCH TT5.TCH 357.000 TT6.TCH 126.000 TTIM.TCH 268.000 TT2M.TCH TT3M.TCH 266.750 TT4M.TCH 210.375 TTSM.TCH 356.750 TT6M.TCH RUAT.TCH 4.496 RLAT.TCH 3.020 RUAM.TCH 4.488 RLAM.TCH CCCL.TCH 0.000 BATT.TCH 3.758 BATM.TCH 3.789 FLSA.TCH FLTT.TCH 0.000 DATN.TCH 3.758 NATN.TCH 3.834 SATN.TCH DT.TCH 56.000 DTUT.TCH 55.000 DTLT.TCH 57.000 DTUM.TCH DTLM.TCH 56.375 DCBL.TCH 25.656 RCGL.TCH 0.001 CCL.TCN 1331.000 35 031 0 000 0 000 0 000 0 000 0 000 0 000 0 000 0.000 0.000 0.000 0.000 0.000 l.O00 1.080 0.000 -0.713 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0 15196.041 0.000 228.750 25.375 33.094 82.875 210.000 213.125 126.375 3.090 0.000 -1.849 54.875 0.003 ,ape Verification Listing ochlumberger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 48 ** DEPTH = 13852.500 FEET TOD.TCH 488201114 TIME.TCH 1067.000 ETIM.TCH DIFF.TCH 0.150 TENS.TCH 5520.000 MARK.TCH RB.TCH 153.000 WIT1.TCH 1668.000 W2T1.TCH AGT1.TCH 20.000 DTT1.TCH 93.375 WIT2.TCH W3T2.TCH 1677.000 AGT2.TCH 21.000 DTT2.TCH W2T3.TCH 1785.000 W3T3.TCH 1420.000 AGT3.TCH WIT4.TCH 1562.000 W2T4.TCH 1048.000 W3T4.TCH DTT4.TCH 91.250 W1T5.TCH 1930.000 W2TS.TCH AGTS.TCH 23.000 DTT5.TCH 91.000 WiT6.TCH W3T6.TCH 1620.000 AGT6.TCH 23.000 DTT6.TCH W2T7.TCH 1494.000 W3T7.TCH 1460.000 AGTT.TCH WIT8.TCH 1604.000 W2T8.TCH 1376.000 W3T8.TCH DTT8.TCH 91.563 WIT9.TCH 1806.000 W2T9.TCH AGTg. TCH 18.000 DTT9.TCH 54.188 WWM.TCH CALU.TCH 6.852 FVEL.TCH 190.750 W2F9.TCH CSMN.TCH 642.500 CSMX.TCH 1263.000 AW2.TCH AAG1.TCH 20.000 AW11.TCH 1651.000 AW21.TCH AW12.TCH 1677.000 AW22.TCH 1.288 AAG3.TCH AW23.TCH 1.186 AAG4.TCH 26.000 AW14.TCH AAG5.TCH 23.000 AW15.TCH 1965.000 AW25.TCH AW16.TCH 1797.000 AW26.TCH 0.583 AAG7.TCH AW27.TCH 0.720 AAG8.TCH 19.000 AW18.TCH AAGg. TCH 18.000 AWlg. TCH 1806.000 AW29.TCH AW32.TCH 0.982 AW33.TCH 0.779 AW34.TCH AW36.TCH 0.787 AW37.TCH 0.815 AW38.TCH RGR.TCH 25.328 GR.TCH 35.500 STSG.TCH WFI2.TCH -1024 WFI1.TCH -1024 WF7.TCH WFIN.TCH 0.000 WF2N.TCH 0.000 WF3N.TCH WFSN.TCH 0.000 WF6N.TCH 0.000 WF7N.TCH SA1.TCH 1.726 SA2.TCH 2.906 SA3.TCH SA5.TCH 0.709 SA6.TCH 13.555 SAiM.TCH SA3M.TCH 1.641 SA4M.TCH 2.678 SA5M.TCH TT1.TCH 275.000 TT2.TCH 219.500 TT3.TCH TT5.TCH 366.000 TT6.TCH 104.000 TTiM.TCH TT3M.TCH 273.500 TT4M.TCH 216.500 TTSM.TCH RUAT.TCH 5.227 RLAT.TCH 5.055 RUAM.TCH ¢CCL.TCH 0.000 BATT.TCH 5.141 BATM.TCH FLTT.TCH 0.000 DATN.TCH 5.141 NATN.TCH DT.TCH 49.250 DTUT.TCH 56.000 DTLT.TCH DTLM.TCH 58.250 DCBL.TCH 15.422 RCCL.TCH 3009.403 I3.797 1209.000 1684.000 92.188 20.000 1751.000 1024.000 1834.000 92.188 18.000 1227.000 338.250 1.653 1.000 0.908 0.616 20.000 1595.000 0.702 20.000 1602.000 0.191 1.277 0.708 176 -1192 0.000 197.746 1.744 1.639 0.733 274.500 269.250 364.750 5.711 5.617 12.852 42.500 0.006 CS.TCH DEVI.TCH W3T1.TCH W2T2.TCH W1T3.TCH DTT3.TCH AGT4.TCH W3T5.TCH W2T6.TCH WiT7.TCH DTTT.TCH AGT8.TCH W3T9.TCH ECCE.TCH W3Fg. TCH AW3.TCH AAG2.TCH AW13.TCH AW24.TCH AAG6.TCH AW17.TCH AW28.TCH AW31.TCH AW35.TCH AW39.TCH WFI3.TCH WF7D.TCH WF4N.TCH DTMD.TCH SA4.TCH SA2M.TCH SA6M.TCH TT4.TCH TT2M.TCH TT6M.TCH RLAM.TCH FLSA.TCH SATN.TCH DTUM.TCH CCL.TCH 1677.000 35.031 1537.000 1629.000 1692.000 91.563 26.000 1780.000 1727.000 1581.000 93.188 19.000 539.500 0.025 1.000 0.859 23.000 1666.000 1.164 23.000 1676.000 0.896 0.941 0.961 0.301 0 13817.908 0.000 256.500 2.898 2.824 14.945 217.000 208.625 134.000 5.527 0.000 18.031 64.875 0.019 END OF DATA ** ~ape Verification Listing ochlumDerger Alaska Computing Center **** FILE TRAILER **** FILE NAME : TCH .002 SERVICE : PLAY VERSION : 40.2 DATE : 95/06/21 MAX REC SIZE : 8192 FILE TYPE : PR LAST FILE : **** FILE HEADER FILE NAME : TCH .001 SERVICE : PLAY VERSION : 40.2 DATE : 95/06/21 MAX REC SIZE : 8192 FILE TYPE : PR LAST FILE : 17-JUL-1995 12:00 PAGE: 49 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 54 4 66 1 5 66 1 6 73 578 7 65 INCH 8 73 60 9 65 .lIN 11 66 151 12 68 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 6 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TOD TCH S 61 000 O0 0 I I 1 4 73 8200000000 TIME TCH MS 61 636 21 0 I i 1 4 68 8000000000 ETIM TCH S 61 636 21 0 1 I i 4 68 8000000000 CS TCH F/HR 61 636 21 0 I i i 2 49 8200000000 ,ape verification Listing ~chlumoerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 5O NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ~s ~c, L~ 6~ ~ ~ 0 ~ ~ ~ ~ ~ ~000000000 ~^~ ~c~ ~ ~l ~o ol o ~ ~ ~ ~ ~ ~ooooooooo ~ ~c~ ~^~ ~ ~o o~ o ~ ~ ~ ~ ~9 ~oooo~oooo GR TCH GAPI 61 31001 0 1 1 i 2 49 8400000000 STSGTCH 61 000O0 0 1 ! I 2 79 8000000000 ~cc~~c, al l~ool o 1 a 1 la ~9 aooooaoooo CCL TCH 61 150O1 0 1 6 i 12 49 8400000000 ** DATA ** ** DEPTH = 13809.000 FEET ** TOD.TCH 488206502 TIME.TCH 4998.000 ETIM.TCH 4.998 CS.TCH DIFF.TCH 0.150 TENS.TCH 4400.000 MARK.TCH 13.797 RGR.TCH GR.TCH 31.422 STSG.TCH 176 RCCL.TCH 0.001 CCL.TCH ** DEPTH = 7191.000 FEET ** TOD.TCH 488213035 TIME.TCH 480.000 ETIM.TCH 6538.265 CS.TCH DIFF.TCH 1.000 TENS.TCH 3195.000 MARK.TCH 97.688 RGR.TCH GR.TCH 41.625 STSG.TCH 176 RCCL.TCH 0.019 CCL.TCH 360.000 24.984 0.004 3746.000 26.828 0.056 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : TCH .001 SERVICE : PLAY VERSION : 40.2 DATE : 95/06/21 MAX REC SIZE : 8192 FILE TYPE : PR LAST FILE **** TAPE TRAILER **** SERVICE NAME : FMEST DATE : 95/05/30 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY ,ape Verification Listing ochlumoerger Alaska Computing Center 17-JUL-1995 12:00 PAGE: 51 **** REEL TRAILER **** SERVICE NAME : MEST DATE : 95/05/30 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY ....... SCHLUMBERGER ....... RECEIVED AU(; ~ 1 1~ COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO Alasl(a Oil & Gas Oons. Commission Ailchorage : STEWART PETROLEUM COMPANY : W. MCARTHUR RIVER #3 : WEST MCARTHUR RIVER : KENAI : ALASKA : 50-133-20461 : 95230 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1995 14:05 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/07/16 ORIGIN : FLIC REEL NAME : 95230 CONTINUATION # : PREVIOUS REEL : COMMENT : STEWART PETROLEUM CO., W. MCARTHUR RIVER #3, 50-133-20461 **** TAPE HEADER **** ~ SERVICE NAME : EDIT DATE : 95/07/16 ORIGIN : FLIC TAPE NAME : 95230 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : STEWART PETROLEUM CO., W. MCARTHUR RIVER #3, 50-133-20461 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A07 DATE : 95/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : SCHLUMBERGER WELL SERVICES ** COMPANY NAME: STEWART PETROLEUM COMPANY WELL: W. MCARTHUR RIVER #3 FIELD: WEST McARTHUR RIVER BOROUGH: KENAI STATE: ALASKA API NUMBER: 50-133-20461 LOCATION: 2899' FSL & 3957' FEL SECTION: 16 TOWNSHIP: 8N RANGE: 14W PERMANENT DATUM: SEA LEVEL ELEVATION: O' LOG MEASURED FROM KB 163' ABOVE PERMANENT DATUM LIS Tape Verification List!ng Schlumberger Alaska Computing Center 16-JUL-1995 14:05 PAGE: ELEVATIONS KB: 163' DF: 162' BIT SIZE 1: 9.875" @ 14161' BIT SIZE 2: 6.75" @ 15338' RUN NUMBER: 2 DATE LOGGED: 16-JUN-1995 TD DRILLER: 15338' TD LOGGER: 15335' TYPE FLUID IN HOLE: MILGEL NT-NEWDRILL DENSITY: 9.9 VISCOSITY: 44 PH: 9.08 FLUID LOSS: 4.8 MUD RESISTIVITY: 1.29 FILTRATE RESISTIVITY: 1.14 MUD CAKE RESISTIVITY: 1.49 @ 83 DEGF @ 67 DEGF @ 72 DEGF MAXIMUM TEMP RECORDED: 175 DEGF RUN NUMBER: 1 DATE LOGGED: 28-MAY-1995 TD DRILLER: 14161' TD LOGGER: 14130' TYPE FLUID IN HOLE: MILGEL NT-NEWDRILL DENSITY: 10.2 VISCOSITY: 46 PH: 9.2 FLUID LOSS: 4.2 MUD RESISTIVITY: 1.58 FILTRATE RESISTIVITY: 1.32 MUD CAKE RESISTIVITY: 2.12 @ 78 DEGF @ 55 DEGF @ 55 DEGF MAXIMUM TEMP RECORDED: 169 DEGF LOGGING DISTRICT: KENAI LOGGING ENGINEER: TIM SMITH WITNESS: MR. PAUL WHITE JOB REFERENCE NO: 95230 LDP/ANA: R. KRUWELL * FILE - EDIT.O01 * STEWART PETROLEUM COMPANY * WEST MCARTHUR RIVER * W. MCARTHUR RIVER #3 LIS Tape Verification Listing Schlumoerger Alaska Computing Center 16-JUL-1995 14:05 50-133-20461 "MAIN PASS MEASURED DEPTH DATA" DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME AIT .AIT LDT .LDT CNL .CNL GR .MER ARRAY INDUCTION TOOL LITHO DENSITY TOOL COMPENSATED NEUTRON TOOL GAMMA RAY MERGED FROM OPENHOLE LOGS AND CASED HOLE LOGS TO GIVE CONTINUOS GR CURVE PAGE: 3 TABLE TYPE : CONS TUNI VALU DEFI CN STEWART PETROLEUM COMPANY Company Name FN WEST MCARTHUR RIVER Field Name WN W. MCARTHUR RIVER #3 Well Name APIN 50-133-20461 API Serial Number FL 2899' FSL & 3957' FEL Field Location SECT 16 Section TOWN 8N Township RANG 14W Range COUN KENAI ~ounty STAT ALASKA State or Province NATI USA Nation WITN MR. PAUL WHITE Witness Name SON 584453 Service Order Number PDAT SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF KB Log Measured From APD FT 163. Above Permanent Datum EKB FT 163. Elevation of Kelly Bushing EDF FT 162. Elevation of Derrick Floor EGL FT -999.25 Elevation of Ground Level TDD FT 15338. Total Depth - Driller TDL FT 15335. Total Depth - Logger DFT MILGEL NT-NEWDRILL Drilling Fluid Type DFD G/C3 9.9 Drilling Fluid Density DFPH 9.08 Drilling Fluid Ph DFV S 44. Drilling Fluid Viscosity DFL F3 4.8 Drilling Fluid Loss RMS OHMM 1.29 Resistivity of Mud Sample MST DEGF 83. Mud Sample Temperature LIS Tape Verification Listing 16-JUL-1995 14:05 PAGE: Schlumberger Alaska Computing Center TUNI VALU DEFI RMFS OHMM 1.14 Resistivity of Mud Filtrate S MFST DEGF 67. Mud Filtrate Sample Temperatu RMCS OHMM 1.49 Resistivity of Mud Cake Sampl MCST DEGF 72. Mud Cake Sample Temperature BHT DEGF 175. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth GR Gamma Ray SP Spontaneous Potential HTEN Head Tension TENS Tension MRES MUD Resistivity MTEM Mud Temperature DPHI Density Porosity RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor QLS Quality control of long spacing for LDT QSS Quality control on short spacing ~or LD~ . LS Long Spacing Computed Count Rate {LL+LU/2) LU Long Upper 1-2 Window Count Rate (LUI+LU2) LITH Litholog Window Count Rate SS1 Short Spacing I Window Count Rate SS2 Short Spacing 2 Window Count Rate CALI Caliper NPHI Neutron Porosity RTNR Raw Thermal Neutron Ratio TNPH Thermal Neutron Porosity TNRA Thermal Neutron Ratio Calibrated NPOR Neutron Porosity from an Application Program RCNT RCNT RCFT RCFT CNTC CNTC CFTC CFTC ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1995 14:05 PAGE: TYPE REPR CODE -~,LG~-- .............................. 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM DEPT FT 584453 O0 000 O0 0 1 1 1 4 GR MER GAPI 584453 O0 000 O0 0 i I I 4 68 0000000000 SP AIT MV 584453 O0 000 O0 0 i I I 4 68 0000000000 HTEN AIT LB 584453 O0 000 O0 0 i 1 1 4 68 0000000000 TENS AIT LB 584453 O0 000 O0 0 1 1 1 4 68 0000000000 MRES AIT OHMM 584453 O0 000 O0 0 i i i 4 68 0000000000 MTEM AIT DEGF 584453 O0 000 O0 0 i i i 4 68 0000000000 DPHI LDT PU 584453 O0 000 O0 0 i 1 1 4 68 0000000000 RHOB LDT G/C3 584453 O0 000 O0 0 I i 1 4 68 0000000000 DRHO LDT G/C3 584453 O0 000 O0 0 1 i 1 4 68 0000000000 PEF LDT 584453 O0 000 O0 0 i I 1 4 68 0000000000 QLS LDT 584453 O0 000 O0 0 i 1 1 4 68 0000000000 QSS LDT 584453 O0 000 O0 0 I i i 4 68 0000000000 LS LDT CPS 584453 O0 000 O0 0 I I I 4 68 0000000000 LU LDT CPS 584453 O0 000 O0 0 1 I 1 4 68 0000000000 LITH LDT CPS 584453 O0 000 O0 0 1 I 1 4 68 0000000000 SS1 LDT CPS 584453 O0 000 O0 0 i I I 4 68 0000000000 SS2 LDT CPS 584453 O0 000 O0 0 1 1 I 4 68 0000000000 CALI LDT IN 584453 O0 000 O0 0 1 i I 4 68 0000000000 NPHI CNL PU 584453 O0 000 O0 0 I 1 i 4 68 0000000000 RTNR CNL 584453 O0 000 O0 0 I i I 4 68 0000000000 TNPH CNL PU 584453 O0 000 O0 0 1 1 1 4 68 0000000000 TNRA CNL 584453 O0 000 O0 0 1 1 1 4 68 0000000000 NPOR CNL PU 584453 O0 000 O0 0 i 1 1 4 68 0000000000 RCNT CNL CPS 584453 O0 000 O0 0 1 1 I 4 68 0000000000 RCFT CNL CPS 584453 O0 000 O0 0 i 1 1 4 68 0000000000 CNTC CNL CPS 584453 O0 000 O0 0 i i 1 4 68 0000000000 CFTC CNL CPS 584453 O0 000 O0 0 i i i 4 68 0000000000 REPR PROCESS CODE (HEX) 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ** DEPT. 15334.000 GR.MER TENS.AIT 6890.000 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 15200.000 GR.MER TENS.AIT 6920.000 MRES.AIT RHOB.LDT 2.486 DRHO.LDT QSS.LDT 0.073 LS.LDT SS1.LDT 293.517 SS2.LDT RTNR.CNL 1.502 TNPH.CNL RCNT.CNL 6100.562 RCFT.CNL DEPT. 15000.000 GR.MER TENS.AIT 6720.000 MRES.AIT RHOB.LDT 2.383 DRHO.LDT QSS.LDT 0.059 LS.LDT SS1.LDT 276.706 SS2.LDT RTNR.CNL 2.382 TNPH.CNL RCNT.CNL 4138.233 RCFT.CNL DEPT. 14800.000 GR.MER TENS.AIT 7120.000 MRES.AIT RHOB.LDT 2.387 DRHO.LDT QSS.LDT 0.039 LS.LDT SS1.LDT 259.847 SS2.LDT RTNR.CNL 2.387 TNPH.CNL RCNT.CNL 3810.946 RCFT.CNL DEPT. 14600.000 GR.MER TENS.AIT 6535.000 MRES.AIT RHOB.LDT 2.376 DRHO.LDT QSS.LDT 0.026 LS.LDT SS1.LDT 253.030 SS2.LDT RTNR.CNL 2.252 TNPH.CNL RCNT.CNL 4052.925 RCFT.CNL DEPT. 14400.000 GR.MER TENS.AIT 6175.000 MRES.AIT RHOB.LDT 2.350 DRHO.LDT QSS.LDT 0.047 LS.LDT SS1.LDT 291.351 SS2.LDT RTNR.CNL 1.711 TNPH.CNL RCNT.CNL 5223.573 RCFT.CNL DEPT. 14200.000 GR.MER TENS.AIT 6490.000 MRES.AIT RHOB.LDT 2.480 DRHO.LDT QSS.LDT 0.040 LS.LDT SS1.LDT 257.895 SS2.LDT 16-JUL-1995 -999.250 0.398 -999.250 -999.250 -999.250 -999.250 -999.250 53.059 0.401 0.132 377.068 377.715 12.777 3802.111 55.261 0.405 0.072 407.250 368.687 24.243 1698.906 74.967 0.418 0.030 378.850 354.440 23.170 1666.028 52.969 0.430 0.012 377.659 351.457 22.904 1828.769 42.196 0.441 0.101 459.442 397.384 17.150 2527.538 82.012 0.440 0.044 331.354 345.116 14:05 SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL SP.AIT MTEM.AIT PEF. LDT LU. LDT CALI. LDT TNRA.CNL CNTC.CNL SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL SP.AIT MTEM.AIT PEF. LDT LU. LDT CALI. LDT -999. 173. -999. -999. -999. -999. -999. 143. 174. 4. 356. 6. 1. 6047. 179. 173. 4. 383. 6. 2. 4225. 136. 171. 2. 360. 6. 2. 4097. 141. 169. 2. 357. 6. 2. 4202. 189. 168. 3. 437. 7. 1. 5146. 198. 167. 3. 316. 7. 250 88O 250 250 250 250 250 438 111 075 619 120 468 909 938 142 212 417 247 241 648 438 345 939 586 553 271 862 313 995 769 396 912 O95 733 688 421 424 690 805 678 784 063 445 161 627 479 HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT LITH. LDT NPHI.CNL NPOR. CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT L I TH. LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT L I TH. LDT NPHI .CNL NPOR.CNL CFTC. CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL PAGE: 1162.007 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1182.356 9.910 -0.012 87.886 13.315 12.226 4165.175 1180.829 16.210 -0.017 94.942 24.800 24.441 1900.554 1625.309 15.922 -0.025 101.564 24.972 25.069 1903.950 1308.955 16.594 -0.017 115.269 22.002 23.593 1961.196 1078.624 18.211 -0.045 127.244 14.942 16.351 2856.359 1353.279 10.299 -0.012 91.474 23.549 LIS Tape Verification Listing Schlumberger Alaska Computing Center RTNR.CNL 2.304 TNPH.CNL RCNT.CNL 3793.826 RCFT.CNL DEPT. 14000.000 GR.MER TENS.AIT 1790.000 MRES.AIT RHOB.LDT 2.407 DRHO.LDT QSS.LDT 0.027 LS.LDT SS1.LDT 254.379 SS2.LDT RTNR.CNL 2.158 TNPH.CNL RCNT.CNL 4129.393 RCFT.CNL DEPT. 13800.000 GR.MER TENS.AIT 1460.000 MRES.AIT RHOB.LDT 2.413 DRHO.LDT QSS.LDT 0.027 LS.LDT SS1.LDT 251.247 SS2.LDT RTNR.¢NL 2.348 TNPH.CNL RCNT.CNL 3894.277 RCFT.CNL DEPT. 13600.000 GR.MER TENS.AIT 1635.000 MRES.AIT RHOB.LDT 2.480 DRHO.LDT QSS.LDT 0.045 LS.LDT SS1.LDT 284.965 SS2.LDT RTNR.CNL 2.529 TNPH.CNL RCNT.CNL 3169.995 RCFT.CNL DEPT. 13400.000 GR.MER TENS.AIT 1555.000 MRES.AIT RHOB.LDT 2.363 DRHO. LDT QSS.LDT 0.012 LS.LDT SS1.LDT 244.961 SS2.LDT RTNR.CNL 2.410 TNPH.CNL RCNT.CNL 3881.254 RCFT.CNL DEPT. 13200.000 GR.MER TENS.AIT 1485.000 MRES.AIT RHOB.LDT 2.426 DRHO.LDT QSS.LDT 0.014 LS.LDT SS1.LDT 246.980 SS2.LDT RTNR.CNL 2.752 TNPH.CNL RCNT.CNL 3020.107 RCFT.CNL DEPT. 13000.000 GR.MER TENS.AIT 1675.000 MRES.AIT RHOB.LDT 2.499 DRHO.LDT QSS.LDT 0.021 LS.LDT SS1.LDT 250.872 SS2.LDT RTNR.CNL 2.468 TNPH.CNL RCNT.CNL 3634.215 RCFT.CNL DEPT. 12800.000 GR.MER TENS.AIT 805.000 MRES.AIT RHOB.LDT 2.383 DRHO.LDT QSS.LDT 0.022 LS.LDT 16-JUL-1995 14:05 23.465 TNRA.CNL 1667.714 CNTC.CNL 57.989 SP.AIT 0.499 MTEM.AIT 0.018 PEF. LDT 362.591 LU.LDT 350.760 CALI.LDT 20.199 TNRA.CNL 1778.059 CNTC.¢NL 51.794 SP.AIT 0.525 MTEM.AIT 0.013 PEF. LDT 358.868 LU.LDT 346.087 CALI.LDT 22.816 TNRA.¢NL 1566.693 CNTC.CNL 81.695 SP.AIT 0.533 MTEM.AIT 0.108 PEF.LDT 378.015 LU.LDT 380.152 CALI.LDT 23.547 TNRA.CNL 1220.391 CNTC.CNL 54.923 SP.AIT 0.539 MTEM.AIT 0.000 PEF.LDT 385.493 LU.LDT 347.165 CALI.LDT 22.885 TNRA.CNL 1615.608 CNTC.CNL 62.905 SP.AIT 0.548 MTEM.AIT 0.008 PEF. LDT 349.315 LU.LDT 345.087 CALI.LDT 26.750 TNRA.¢NL 1200.167 CNTC.CNL 81.148 SP.AIT 0.561 MTEM.AIT 0.027 PEF. LDT 319.003 LU.LDT 342.964 CALI.LDT 22.903 TNRA.CNL 1390.764 CNTC.CNL 41.839 SP.AIT 0.568 MTEM.AIT 0.008 PEF.LDT 379.190 LU.LDT 2.232 3912.721 -27.188 169.005 3.768 345.701 9.866 2.089 4091.285 -6.063 168.040 3.316 340.762 10.016 2.294 3934.474 -12.750 167.007 3.045 354.939 12.683 2.462 3187.477 -17.688 165.762 2.683 362.362 10.040 2.254 3898.170 8.813 164.792 2.857 332.355 13.984 2.656 3292.176 -46.063 163.121 2.701 310.824 12.687 2.392 3569.730 -25.000 161.138 2.480 358.852 NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT LITH. LDT NPHI .CNL NPOR.¢NL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT LITH. LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS. LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT PAGE: 23.985 1770.944 549.399 14.714 -0.022 89.312 19.128 19.488 1944.822 827.225 14.340 -0.015 101.343 22.053 22.668 1725.622 939.168 10.331 -0.002 107.927 22.844 23.243 1330.681 713.733 17.377 -0.010 124.792 21.197 22.549 1706.213 808.563 13.591 -0.015 101.215 25.241 29.329 1238.091 724.190 9.144 -0.036 94.364 21.422 21.869 1494.186 785.734 16.205 -0.017 126.255 LIS Tape Verification Listing Schlumberger Alaska Computing Center SS1.LDT 250.132 SS2.LDT RTNR.CNL 2.352 TNPH.CNL RCNT.CNL 4185.234 RCFT.CNL DEPT. 12600.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.¢NL -999.250 RCFT.CNL DEPT. 12400.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 12200.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL -RCNT.CNL -999.250 RCFT.CNL DEPT. 12000.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.¢NL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 11800.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 11600.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL 16-JUL-1995 14:05 348.926 CALI.LDT 21.494 TNRA.CNL 1746.180 CNTC.CNL 10.091 2.206 4185.009 70.938 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 59.656 SP.AIT -999.250 MTEM.AIT -999.250 PEF.LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNT¢.CNL 25.219 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 54.406 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 63.563 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 59.938 SP.AIT -999.250 MTEM.AIT -999.250 PEF.LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT LITH. LDT NPHI .CNL NPOR.¢NL CFTC. CNL HTEN.AIT DPHI. LDT QLS. LDT LITH. LDT NPHI .CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT Q LS. LDT LITH. LDT NPHI .CNL NPOR.CNL CFT¢.CNL HTEN.AIT DPH I. LDT QLS. LDT L I TH. LDT NPHI.CNL NPOR.¢NL CFTC.CNL HTEN.AIT DPHI. LDT QLS. LDT LITH. LDT NPHI .CNL NPOR.CNL CFTC. CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.¢NL CFTC.CNL PAGE: 19.974 21.036 1899.350 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 11400.000 GR.HER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 11200.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 11000.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.¢NL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL 16-JUL-1995 14:05 29.828 SP.AIT -999.250 MTEM.AIT -999.250 PEF.LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.¢NL -999.250 CNTC.CNL 47.875 SP.AIT -999.250 MTEM.AIT -999.250 PEF.LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 49.281 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL DEPT. 10800.000 GR.MER 55.969 SP.AIT TENS.AIT -999.250 MRES.AIT -999.250 MTEM.AIT RHOB.LDT -999.250 DRHO.LDT -999.250 PEF.LDT QSS.LDT -999.250 LS.LDT -999.250 LU.LDT SS1.LDT -999.250 SS2.LDT -999.250 CALI.LDT RTNR.CNL -999.250 TNPH.CNL -999.250 TNRA.CNL RCNT.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL DEPT. 10600.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 10400.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 10200.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.¢NL RCNT.CNL -999.250 RCFT.CNL 66.625 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 28.531 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNT¢.CNL 59.438 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFT¢.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT LITH. LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS. LDT LITH.LDT NPHI.CNL NPOR.CNL CFT¢.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFT¢.CNL PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 10000.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.¢NL -999.250 RCFT.CNL DEPT. 9800.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 9600.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 9400.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 9200.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 9000.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 8800.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL 16-JUL-1995 14:05 40.906 SP.AIT -999.250 MTEM.AIT -999.250 PEF.LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 52.219 SP.AIT -999.250 MTEM.AIT -999.250 PEF.LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 59.375 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 62.344 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 58.500 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 34.188 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL 53.656 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 HTEN.AIT DPHI.LDT QLS. LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPHI. LDT QLS. LDT L I TH. LDT NPHI.CNL NPOR.CNL CFTC. CNL HTEN.AIT DPH I. LDT QLS. LDT L I TH. LDT NPHI .CNL NPOR. CN L PAGE: -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 25O 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 10 LIS Tape Verification Listing Schlumberger Alaska Computing Center RCNT.CNL -999.250 RCFT.CNL DEPT. 8600.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 8400.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 8200.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 8000.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 7800.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO. LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 7600.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 7400.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT 16-JUL-1995 14:05 -999.250 CNTC.CNL -999.250 40.563 SP.AIT -999.250 -999.250 HTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 52.094 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 64.750 SP.AIT -999.250 MTEM.AIT -999.250 PEF. LDT -999.250 LU.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 49.656 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 53.406 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.¢NL -999.250 -999.250 CNTC.CNL -999.250 50.531 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 62.344 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 CFTC. CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT Q LS. LDT LITH. LDT NPHI .CNL NPOR.CNL CFTC. CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT L I TH. LDT NPHI.CNL NPOR.CNL CFTC. CNL HTEN.AIT DPH I. LDT QLS. LDT L I TH. LDT NPHI.CNL NPOR.CNL CFTC. CNL HTEN.AIT DPH I. LDT QLS. LDT LITH. LDT NPHI.CNL NPOR.CNL CFTC. CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL PAGE: -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 11 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 25O 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 _~o Tape Verification Listing Schlumberger Alaska Computing Center RTNR.CNL -999.250 TNPH.CNL RCNT.¢NL -999.250 RCFT.CNL DEPT. 7200.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL DEPT. 7191.000 GR.MER TENS.AIT -999.250 MRES.AIT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.250 LS.LDT SS1.LDT -999.250 SS2.LDT RTNR.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL 16-JUL-1995 14:05 -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 -999.250 39.875 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 41.625 SP.AIT -999.250 -999.250 MTEM.AIT -999.250 -999.250 PEF. LDT -999.250 -999.250 LU.LDT -999.250 -999.250 CALI.LDT -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 NPOR.CNL CFTC.CNL HTEN.AIT DPHI.LDT QLS.LDT LITH.LDT NPHI.CNL NPOR.CNL CFTC.CNL HTEN.AIT DPH I. LDT QLS. LDT LITH. LDT NPHI .CNL NPOR.CNL CFTC. CNL PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 12 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A07 DATE : 95/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A07 DATE : 95/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * FILE - EDIT.O02 * STEWART PETROLEUM COMPANY * WEST MCARTHUR RIVER * W. MCARTHUR RIVER #3 rape Verification Listing Schlumoerger Alaska Computing Center 16-JUL-1995 14:05 50-133-20461 "MAIN PASS HI RESOLUTION AIT MEASURED DEPTH DATA" DATA SAMPLED EVERY -.2500 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME AIT .AIT ARRAY INDUCTION TOOL PAGE: 13 TABLE TYPE : CONS TUNI VALU DEFI CN STEWART PETROLEUM COMPANY Company Name Field Name FN WEST MCARTHUR RIVER WN W. MCARTHUR RIVER #3 APIN 50-133-20461 FL 2899' FSL & 3957' FEL SECT 16 TOWN 8N RANG 14W COUN KENAI STAT ALASKA NATI USA WITN MR. PAUL WHITE SON 584453 PDAT SEA LEVEL EPD FT O. LMF KB APD FT 163. EKB FT 163. EDF FT 162. EGL FT -999.25 TDD FT 15338. TDL FT 15335. DFT MILGEL NT-NEWDRILL DFD G/C3 9.9 DFPH 9.08 DFV S 44. DFL F3 4.8 RMS OHMM 1.29 MST DEGF 83. RMFS OHMM 1.14 MFST DEGF 67. RMCS OHMM 1.49 MCST DEGF 72. Well Name API Serial Number Field Location Section Township Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Drilling Fluid Type Drilling Fluid Density Drilling Fluid Ph Drilling Fluid Viscosity Drilling Fluid Loss Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Resistivity of Mud Cake Sampl Mud Cake Sample Temperature _~o Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1995 14:05 PAGE: 14 TUNI VALU DEFI BHT DEGF 175. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth ATIO AT20 AT30 AT60 ATgO ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** coo 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 584453 O0 000 O0 0 2 1 1 4 68 0000000000 ATIO AIT OHMM 584453 O0 000 O0 0 2 1 1 4 68 0000000000 AT20 AIT OHMM 584453 O0 000 O0 0 2 I 1 4 68 0000000000 AT30 AIT OHMM 584453 O0 000 O0 0 2 I 1 4 68 0000000000 AT60 AIT OHMM 584453 O0 000 O0 0 2 i 1 4 68 0000000000 rape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1995 14:05 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) AT90 AIT 0HMM 584453 00 000 00 0 2 1 1 4 68 0000000000 15 ** DATA DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT DEPT. AT60.AIT 15314.000 AT10.AIT · 13.030 AT20.AIT 11.367 AT30.AIT 9.023 ATgO.AIT 9.299 15200.000 ATIO.AIT 16.895 AT20.AIT 19.698 AT30.AIT 15.917 AT90.AIT 15.422 15000.000 AT10.AIT 9.511 AT20.AIT 10.077 AT30.AIT 11.545 ATgO.AIT 12.853 14800.000 AT10.AIT 10.514 AT20.AIT 12.719 AT30.AIT 13.726 AT90.AIT 16.702 14600.000 ATIO.AIT 9.055 AT20.AIT 9.047 AT30.AIT 9.369 AT90.AIT 10.323 14400.000 ATiO.AIT 41.412 AT20.AIT 43.838 AT30.AIT 14.084 ATg0.AIT 13.993 14200.000 ATIO.AIT 10.567 AT20.AIT 9.770 AT30.AIT 8.220 AT90.AIT 8.785 14000.000 ATiO.AIT 12.600 AT20.AIT 12.747 AT30.AIT 10.930 AT90.AIT 11.646 13800.000 AT10.AIT 8.338 AT20.AIT 6.338 AT30.AIT 6.249 AT90.AIT 6.447 13600.000 AT10.AIT 7.648 AT20.AIT 8.731 AT30.AIT 19.556 AT90.AIT 22.160 13400.000 ATiO.AIT 9.126 AT20.AIT 6.076 AT30.AIT 4.997 ATgO.AIT 5.159 13200.000 AT10.AIT 4.238 AT20.AIT 3.958 AT30.AIT 4.951 ATg0.AIT 5.509 13000.000 AT10.AIT 15.743 AT20.AIT 9.347 AT30.AIT 8.906 AT90.AIT 10.046 12800.000 AT10.AIT 11.603 AT20.AIT 8.617 AT30.AIT 7.681 AT90.AIT 7.832 10.256 18.125 11.107 14.227 9.745 34.334 8.788 10.810 6.290 15.729 5.572 4.259 9.640 8.198 ~> Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 12676.000 ATIO.AIT AT60.AIT -999.250 AT90.AIT ** END OF DATA ** 16-JUL-1995 14:05 -999.250 AT20.AIT -999.250 -999.250 AT30.AIT PAGE: -999.250 16 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A07 DATE : 95/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001A07 DATE : 95/07/16 MAX RE¢ SIZE : 1024 FILE TYPE : LO LAST FILE : FILE - EDIT.O03 STEWART PETROLEUM COMPANY WEST MCARTHUR RIVER W. MCARTHUR RIVER #3 50-133-20461 "MAIN PASS TRUE VERITCAL DEPTH DATA" DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME AIT .AIT LDT .LDT CNL .CNL ARRAY INDUCTION TOOL LITHO DENSITY TOOL COMPENSATED NEUTRON TOOL Tape Verification Listing Schlumoerger Alaska Computing Center 16-JUL-1995 14:05 PAGE: 17 TABLE TYPE : CONS TUNI VALU DEFI CN STEWART PETROLEUM COMPANY Company Name FN WEST MCARTHUR RIVER Field Name WN W. MCARTHUR RIVER #3 Well Name APIN 50-133-20461 API Serial Number FL 2899' FSL & 3957' FEL Field Location SECT 16 Section TOWN 8N Township RANG 14W Range COUN KENAI County STAT ALASKA State or Province NATI USA Nation WITN MR. PAUL WHITE Witness Name SON 584453 Service Order Number PDAT SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF KB Log Measured From APD FT 163. Above Permanent Datum EKB FT 163. Elevation of Kelly Bushing EDF FT 162. Elevation of Derrick Floor EGL FT -999.25 Elevation of Ground Level TDD FT 15338. Total Depth - Driller TDL FT 15335. Total Depth - Logger DFT MILGEL NT-NEWDRILL Drilling Fluid Type DFD G/C3 9.9 Drilling Fluid Density DFPH 9.08 Drilling Fluid Ph DFV S 44. Dri'lling Fluid Viscosity DFL F3 4.8 Drilling Fluid Loss RMS OHMM 1.29 Resistivity of Mud Sample MST DEGF 83. Mud Sample Temperature RMFS OHMM 1.14 Resistivity of Mud Filtrate S MFST DEGF 67. Mud Filtrate Sample Temperatu RMCS OHMM 1.49 Resistivity of Mud Cake Sampl MCST DEGF 72. Mud Cake Sample Temperature BHT DEGF 175. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth ATIO AT20 AT30 AT60 AT90 · IS Tape Verification List!ng Schlumberger Alaska Computing Center 16-JUL-1995 14:05 DEFI GR Gamma Ray SP Spontaneous Potential HTEN Head Tension TENS Tension MRES MUD Resistivity MTEM Mud Temperature DPHI Density Porosity RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor QLS Quality control of long spacing for LDT QSS Quality control on short spacing ~or LD~ . LS Long Spacing Computed Count Rate (LL+LU/2} LU Long Upper 1-2 Window Count Rate (LUi+LU2) LITH Litholog Window Count Rate SS1 Short Spacing I Window Count Rate SS2 Short Spacing 2 Window Count Rate CALI Caliper NPHI Neutron Porosity RTNR Raw Thermal Neutron Ratio TNPH Thermal Neutron Porosity TNRA Thermal Neutron Ratio Calibrated NPOR Neutron Porosity from an Application Program RCNT RCNT RCFT RCFT CNTC CNTC CFTC CFTC PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 132 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 L~S Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1995 14:05 PAGE: 19 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB -~i~- REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 584453 O0 000 O0 0 3 1 1 4 68 0000000000 ATIO AIT OHMM 584453 O0 000 O0 0 3 i i 4 68 0000000000 AT20 AIT OHMM 584453 O0 000 O0 0 3 I 1 4 68 0000000000 AT30 AIT OHMM 584453 O0 000 O0 0 3 I 1 4 68 0000000000 AT60 AIT OHMM 584453 O0 000 O0 0 3 i 1 4 68 0000000000 AT90 AIT OHMM 584453 O0 000 O0 0 3 i 1 4 68 0000000000 GR TVD GAPI 584453 O0 000 O0 0 3 I 1 4 68 0000000000 SP AIT MV 584453 O0 000 O0 0 3 I I 4 68 0000000000 HTEN AIT LB 584453 O0 000 O0 0 3 i I 4 68 0000000000 TENS AIT LB 584453 O0 000 O0 0 3 I I 4 68 0000000000 MRES AIT OHMM 584453 O0 000 O0 0 3 I 1 4 68 0000000000 MTEM AIT DEGF 584453 O0 000 O0 0 3 I I 4 68 0000000000 DPHI LDT PU 584453 O0 000 O0 0 3 i I 4 68 0000000000 RHOB LDT G/C3 584453 O0 000 O0 0 3 i 1 4 68 0000000000 DRHO LDT G/C3 584453 O0 000 O0 0 3 i I 4 68 0000000000 PEF LDT 584453 O0 000 O0 0 3 1 1 4 68 0000000000 QLS LDT 584453 O0 000 O0 0 3 i 1 4 68 0000000000 QSS LDT 584453 O0 000 O0 0 3 1 1 4 68 0000000000 LS LDT CPS 584453 O0 000 O0 0 3 I I 4 68 0000000000 LU LDT CPS 584453 O0 000 O0 0 3 I I 4 68 0000000000 LITH LDT CPS 584453 O0 000 O0 0 3 1 I 4 68 0000000000 SS1 LDT CPS 584453 O0 000 O0 0 3 1 1 4 68 0000000000 SS2 LDT CPS 584453 O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN 584453 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNL PU 584453 O0 000 O0 0 3 i i 4 68 0000000000 RTNR CML 584453 O0 000 O0 0 3 I 1 4 68 0000000000 TNPH CML PU 584453 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CNL 584453 O0 000 O0 0 3 I 1 4 68 0000000000 NPOR CML PU 584453 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT CML CPS 584453 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT CML CPS 584453 O0 000 O0 0 3 I 1 4 68 0000000000 CNTC CML CPS 584453 O0 000 O0 0 3 I I 4 68 0000000000 CFTC CML CPS 584453 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9820.000 ATIO.AIT -999.250 AT20.AIT -999.250 AT30.AIT AT60.AIT -999.250 AT90.AIT -999.250 GR.TVD -999.250 SP.AIT HTEN.AIT 1085.316 TENS.AIT 6890.000 MRES.AIT 0.398 MTEM.AIT DPHI.LDT -999.250 RHOB.LDT -999.250 DRHO.LDT -999.250 PEF.LDT QLS.LDT -999.250 QSS.LDT -999.250 LS.LDT -999.250 LU.LDT LITH.LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 CALI.LDT -999.250 -999.250 173.880 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing tenter NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 9800.000 ATIO.AIT AT60.AIT 8.634 ATgO.AIT HTEN.AIT 1221.656 TENS.AIT DPHI.LDT 26.080 RHOB.LDT QLS.LDT -0.084 QSS.LDT LITH.LDT 127.379 SS1.LDT NPHI.¢NL 17.015 RTNR.¢NL NPOR.CNL 13.997 RCNT.CNL CFTC.¢NL 3761.423 DEPT. 9600.000 ATiO.AIT AT60.AIT 29.579 ATgO.AIT HTEN.AIT 1176.418 TENS.AIT DPHI.LDT 15.756 RHOB.LDT QLS.LDT -0.030 QSS.LDT LITH.LDT 95.197 SS1.LDT NPHI.¢NL 19.079 RTNR.CNL NPOR.CNL 19.130 RCNT. CNL CFTC.CNL 2757.087 DEPT. 9400.000 AT10.AIT AT60.AIT 10.354 ATgO.AIT HTEN.AIT 1722.906 TENS.AIT DPHI.LDT 10.380 RHOB.LDT QLS.LDT -0.004 QSS.LDT LITH.LDT 92.394 SS1.LDT NPHI.CNL 21.802 RTNR,CNL NPOR.CNL 22.086 RCNT.CNL CFTC.CNL 2075.638 DEPT. 9200.000 ATIO.AIT AT60.AIT 12.832 AT90.AIT HTEN.AIT 1274.979 TENS.AIT DPHI.LDT 14.069 RHOB.LDT QLS.LDT -0.001 QSS.LDT LITH.LDT 101.016 SS1.LDT NPHI.CNL 23.207 RTNR.CNL NPOR.CNL 22.656 RCNT.CNL CFTC.CNL 2029.421 DEPT. 9000.000 ATIO.AIT AT60.AIT 10.250 ATgO.AIT HTEN.AIT 1169.598 TENS.AIT DPHI.LDT 8.664 RHOB.LDT QLS.LDT -0.022 QSS.LDT LITH.LDT 77.618 SS1.LDT NPHI.CNL 28.654 RTNR.CNL NPOR.CNL 30.555 RCNT.CNL CFTC.CNL 1036.200 16-JUL-1995 14:05 -999.250 TNPH.CNL -999.250 RCFT.CNL 12.315 AT20.AIT 8.935 GR.TVD 6895.000 MRES.AIT 2.220 DRHO.LDT 0.068 LS.LDT 338.354 SS2.LDT 1.652 TNPH.CNL 5570.081 RCFT.CNL 18.701 AT20.AIT 31.814 GR.TVD 6795.000 MRES.AIT 2.390 DRHO.LDT 0.080 LS.LDT 313.992 SS2.LDT 2.025 TNPH.CNL 4975.536 RCFT.CNL 7.566 AT20.AIT 11.055 GR.TVD 7295.000 MRES.AIT 2.479 DRHO.LDT 0.028 LS.LDT 257.319 SS2.LDT 2.254 TNPH.CNL 4168.094 RCFT.CNL 11.285 AT20.AIT 13.405 GR.TVD 6630.000 MRES.AIT 2.418 DRHO.LDT 0.016 LS.LDT 245.164 SS2.LDT 2.313 TNPH.CNL 4383.098 RCFT.CNL 8.490 AT20.AIT 12.112 GR.TVD 6330.000 MRES.AIT 2.507 DRHO.LDT 0.014 LS.LDT 259.341 SS2.LDT 3.034 TNPH.CNL 2723.302 RCFT.CNL -999.250 -999.250 10.939 -999.250 0.398 0.187 666.098 462.092 13.749 3465.557 25.681 46.417 0.402 0.159 465.323 408.320 18.743 2530.117 10.251 56.040 0.421 0.042 331.315 349.982 21.382 1855.053 10.420 61.049 0.436 0.006 346.753 342.174 23.113 1896.601 11.877 112.934 0.443 0.053 319.171 357.517 29.618 947.850 TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNT¢.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL PAGE: 20 -999.250 -999.250 9.744 79.500 173.880 5.528 641.352 -999.250 1.535 5711.358 25.821 166.125 173.680 4.975 438.772 5.990 1.845 5118.922 12.878 197.250 171.237 3.255 314.784 7.762 2.133 4327.991 11.724 184.500 169.291 2.824 327.008 6.993 2.180 4385.615 13.376 226.875 167.231 3.680 308.193 9.995 2.772 2833.541 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1995 14:05 PAGE: 21 DEPT. 8800.000 ATIO.AIT AT60.AIT 6.996 ATgO.AIT HTEN.AIT 750,314 TENS.AIT DPHI.LDT 11.162 RHOB.LDT QLS.LDT 0.004 QSS.LDT LITH,LDT 91,276 SS1.LDT NPHI.CNL 15.789 RTNR.CNL NPOR.CNL 16,324 RCNT.CNL CFTC.CNL 2337.587 DEPT. 8600.000 ATIO.AIT AT60.AIT 6.590 AT90.AIT HTEN.AIT 794.805 TENS.AIT DPHI.LDT 9.088 RHOB.LDT QLS.LDT 0.002 QSS.LDT LITH.LDT 89.314 SS1.LDT NPHI.CNL 27.420 RTNR.CNL NPOR.CNL 25.178 RCNT.CNL CFTC.CNL 1123.548 DEPT. 8400.000 ATIO.AIT AT60,AIT 7,525 ATgO.AIT HTEN.AIT 808,712 TENS.AIT DPHI,LDT 7,180 RHOB.LDT QLS.LDT 0,004 QSS.LDT LITH,LDT 79,929 SS1.LDT NPHI.CNL 9.942 RTNR.CNL NPOR,CNL 11,919 RCNT.CNL CFTC.CNL 3285.703 DEPT. 8200.000 ATiO.AIT AT60.AIT 13.581 ATgO.AIT HTEN.AIT 773.931 TENS.AIT DPHI.LDT 15,300 RHOB.LDT QLS.LDT -0.015 QSS.LDT LITH.LDT 119.691 SS1.LDT NPHI.CNL 29.916 RTNR.CNL NPOR.CNL 33,132 RCNT. CNL CFTC.CNL 841.923 DEPT. 8000.000 ATiO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999,250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SSi. LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999,250 RCNT.CNL CFTC.CNL -999.250 DEPT. 7800.000 ATiO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999,250 TENS.AIT DPHI.LDT -999,250 RHOB.LDT 17.047 AT20.AIT 6,906 GR.TVD 1200.000 MRES.AIT 2.466 DRHO.LDT 0.008 LS.LDT 236.790 SS2.LDT 1.974 TNPH.CNL 4530,961 RCFT,CNL 6.424 AT20.AIT 7.196 GR.TVD 1465.000 MRES.AIT 2.500 DRHO. LDT 0.014 LS.LDT 251.453 SS2.LDT 2.902 TNPH.CNL 3056.058 RCFT.CNL 22.305 AT20.AIT 9.090 GR.TVD 1820.000 MRES.AIT 2,532 DRHO.LDT -0,013 LS. LDT 231,256 SS2.LDT 1,770 TNPH.CNL 5144.873 RCFT.CNL 7,448 AT20.AIT 14,963 GR.TVD 1255.000 MRES.AIT 2.398 DRHO.LDT 0.015 LS.LDT 260.307 SS2.LDT 3.021 TNPH.CNL 2413.204 RCFT.CNL 9.497 49.953 0,524 -0.002 320.846 330.490 17.240 2157.507 5.959 79.057 0.546 0.028 318.424 346.689 26.831 1036.116 9.036 49,688 0.559 -0.003 287.210 328,235 11,561 3182.784 8.825 83.134 0.571 0.031 383.019 366.068 32.351 757,262 -999.250 AT20.AIT -999.250 -999.250 GR.TVD 40.375 -999.250 MRES.AIT -999.250 -999.250 DRHO.LDT -999,250 -999.250 LS.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCFT. CNL -999.250 -999.250 AT20.AIT -999.250 GR.TVD -999,250 MRES.AIT -999.250 DRHO.LDT -999.250 55.938 -999.250-999.250 AT30.AIT SP.AIT MTEM. A ! T PEF. LDT LU. LDT CALI. LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU,LDT CALI,LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.¢NL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT 7.970 4.375 168,088 2.928 304.078 10.123 1.884 4445.126 6.371 -6,875 166.141 3.508 302.578 12.906 2.779 2956.752 9,590 -8,000 163,981 3,096 275,356 12,678 1,639 5304.801 11,556 -34.375 159.538 2.899 361.771 11.893 2.930 2497.750 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 7600.000 ATIO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT - LITH.LDT -999.250 SS1.LDT NPHI.¢NL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 7400.000 ATIO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 7200.000 ATIO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 7000.000 ATIO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 6800.000 ATiO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 16-JUL-1995 14:05 -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.¢NL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.¢NL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 -999.250 -999.250 -999.250 -999.250 60.156 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 59.844 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 61.344 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 38.750 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 47.563 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNT¢.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU. LDT CALI. LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU. LDT CALI. LDT TNRA.¢NL CNTC.CNL PAGE: 22 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumoerger Alaska Computing Center DEPT. 6600.000 ATIO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 6400.000 ATiO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.¢NL NPOR.CNL -999.250 RCNT.CNL CFT¢.CNL -999.250 DEPT. 6200.000 ATIO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 6000.000 ATIO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS,LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.¢NL -999.250 RCNT.CNL 'CFTC.CNL -999.250 DEPT. 5800.000 ATiO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB. LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 5600.000 ATiO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT 16-JUL-1995 14:05 -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.¢NL -999.250 RCFT.¢NL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 41.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 60.313 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 53.906 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 57.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 57.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 57.313 -999.250-999.250 AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF.LDT PAGE: 23 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.¢NL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 5400.000 ATiO.AIT AT60.AIT -999.250 AT90.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 5200.000 ATiO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 DEPT. 5146.500 ATiO.AIT AT60.AIT -999.250 ATgO.AIT HTEN.AIT -999.250 TENS.AIT DPHI.LDT -999.250 RHOB.LDT QLS.LDT -999.250 QSS.LDT LITH.LDT -999.250 SS1.LDT NPHI.CNL -999.250 RTNR.CNL NPOR.CNL -999.250 RCNT.CNL CFTC.CNL -999.250 16-JUL- 1995 14:05 -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.CNL -999.250 AT20.AIT -999.250 GR.TVD -999.250 MRES.AIT -999.250 DRHO.LDT -999.250 LS.LDT -999.250 SS2.LDT -999.250 TNPH.CNL -999.250 RCFT.¢NL -999.250 -999.250 -999.250 -999.250 -999.250 56.156 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 43.969 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 AT20.AIT -999.250 -999.250 GR.TVD 41.125 -999.250 MRES.AIT -999.250 -999.250 DRHO.LDT -999.250 -999.250 LS.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 TNPH.CNL -999.250 -999.250 RCFT.CNL -999.250 LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL AT30.AIT SP.AIT MTEM.AIT PEF. LDT LU.LDT CALI.LDT TNRA.CNL CNTC.CNL PAGE: 24 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001A07 DATE : 95/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumoerger Alaska Computing Center 16-JUL-1995 14:05 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/07/16 ORIGIN : FLIC TAPE NAME : 95230 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : STEWART PETROLEUM CO., W. MCARTHUR RIVER #3, 50-133-20461 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/07/16 ORIGIN : FLIC REEL NAME : 95230 CONTINUATION # : PREVIOUS REEL : COMMENT : STEWART PETROLEUM CO., W. MCARTHUR RIVER #3, 50-133-20461 PAGE: 25
